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201-203
STATE OF ALASKA , ALI OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing 0 Change Approved Program ❑ Plug for Redrill ❑ .erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Cony ESP to Jet Pump 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development 0 Exploratory❑ 201-203 3.Address: P. O. Box 100360,Anchorage, Stratigraphic❑ Service ❑ 6.API Number: Alaska 99510 50-029-23047-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1C-109 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 7,510 feet Plugs measured None feet true vertical 3,793 feet Junk measured None feet Effective Depth measured 7,510 feet Packer measured 4423,4597 feet true vertical 3,793 feet true vertical 3712, 3774 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 120 feet 16 158'MD 158 TVD RECEIVED PRODUCTION 4,898 feet 7 5/8" 4,938' MD 3808 TVD B-SAND LINER 2,886 feet 4 1/2" 7,483'MD 3793 TVD LINER 4,418 feet 5 1/2" 4,456'MD 3725 TVD NOV 0 9 2017 Perforation depth measured depth 4962-7450 feet AO GCC JJG CC True Vertical depth 3808-3793 feet Tubing(size,grade,measured and true vertical depth) 3.5" L-80 4, 320 MD 3,665 TVD Packers and SSSV(type,measured and true vertical depth) PACKER=HRD ZXP LINER TOP PACKER 4,423 MD 3,712 TVD PACKER=BAKER MODEL SCR-1 LINER TOP PACKER 4,597 MD 3,774 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A %%NNS) DEC 2 2 2017 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN – – – – Subsequent to operation: SHUT-IN – – – - 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic .❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-427 Contact Name:Andrew Beat Authorized Name: Andrew Beat Contact Email: Andrew.T.Beat@cop.com Authorized Title: Sr.Wells Engineer `\)Q /1 Contact Phone: (907)265-6341 Authorized Signature: Date: / Form 10-404 Revised 4/2017 V7—L )vi �I/ `d7 7 RLIDI ViS I, v ur J Lf{, F 1r - Submit Original Only III • Operations Summary (with Timelog Depths) 1C-109 c.onoaottimps '''' 4S.aska. 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 (ftKES) End Depth MKS) 10/9/2017 10/9/2017 1.50 MIRU MOVE RURD P PJSM-Skid rig floor to move position. 0.0 0.0 11:00 12:30 10/9/2017 10/9/2017 0.75 MIRU MOVE MOB P Pull rig off 1C-104 and stage on pad. 0.0 0.0 12:30 13:15 10/9/2017 10/9/2017 1.50 MIRU MOVE RURD P Lay rig mats around 1C-109 0.0 0.0 13:15 14:45 10/9/2017 10/9/2017 0.50 MIRU MOVE MOB P Stage rig in front of 1C-109. 0.0 0.0 14:45 15:15 10/9/2017 10/9/2017 1.75 MIRU MOVE WAIT T Well house on adjacent well 1C-10 too 0.0 0.0 15:15 17:00 tall for rig to get over.Remove well house from 1C-10. 10/9/2017 10/9/2017 1.00 MIRU MOVE MOB P Move and spot rig over 1C-109.Level 0.0 0.0 17:00 18:00 and shim rig. 10/9/2017 10/9/2017 1.00 MIRU MOVE RURD P Skid rig floor to drilling position 0.0 0.0 18:00 19:00 10/9/2017 10/9/2017 2.00 MIRU MOVE RURD P Rig up rig floor.Connect 0.0 0.0 19:00 21:00 communication line.Prep pits for water.Spot cuttings tank,lunch trailer, mud lab,and fuel tank. 10/9/2017 10/9/2017 1.50 MIRU WELCTL MPSP P Rig up lubricator.Test to 1000 psi. 0.0 0.0 21:00 22:30 Pull BPV.tbg=650 psi IA=700 psi.Rig down lubricator.Sim-ops/Take on fluids/begin taking on 8.4 ppg 3%KCL 140°filtered fresh water. Accept rig at 21:00 hrs on 10/9/17 10/9/2017 10/10/2017 1.50 MIRU WELCTL RURD P Rig up circ.lines in cellar. 0.0 0.0 22:30 00:00 10/10/2017 10/10/2017 1.00 MIRU WELCTL SEQP P PJSM-Blow circ lines out. Purge lines 0.0 0.0 00:00 01:00 with 8.4 ppg fresh water.Test lines to 2500 psi.Blow down lines. 10/10/2017 10/10/2017 0.75 MIRU WELCTL KLWL P Bleed IA and tubing down from 655 0.0 0.0 01:00 01:45 psi.to 45 psi. 10/10/2017 10/10/2017 0.50 MIRU WELCTL KLWL P Pump 100 bbls 8.4 ppg 3%KCL brine 0.0 0.0 01:45 02:15 down IA taking returns up tubing to flow back tank.7 bpm,870 psi pump pressure/75 wellhead pressure. Minimal returns to flow back tank. 10/10/2017 10/10/2017 0.25 MIRU WELCTL KLWL P Line up and bullhead 60 bbls 8.4 ppg 0.0 0.0 02:15 02:30 3%KCL brine down tubing at 7 bpm w/860 psi pump pressure,0 psi wellhead pressure.After 28 bbls pumped pump pressure increased to 960 psi and IA and tbg pressure at wellhead increased from 0 psi to 300 psi on IA and 350 psi on tbg.Continue to pump at 7 bpm.FCP/pump pressure=1240 psi,IA=400 psi tbg=450 psi. 10/10/2017 10/10/2017 0.50 MIRU WELCTL OWFF P With pumps off.IA=300 psi,tbg=150 0.0 0.0 02:30 03:00 psi. In 7 mins tbg bled to 0 psi and IA to 150 psi.Bleed off IA to flow back tank. .Tbg on vacuum and IA blowing slightly. 10/10/2017 10/10/2017 3.00 MIRU WELCTL OWFF P Monitor well. IA static and tbg blowing 0.0 0.0 03:00 06:00 slightly.Take fluid level shot. IA at 750'and tbg at 777'.After 45 mins take another fluid level shot. IA at 804' and tbg at 7802'.Sim-ops/Blow down lines. Page 1/6 Report Printed: 11/1/2017 g • • Operations Summary (with Timelog Depths) . 1 C-1 09 Plhifiips 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(ftKD) 10/10/2017 10/10/2017 2.00 MIRU WELCTL OWFF P Monitor well. Install 60 psi gauge on 0.0 0.0 06:00 08:00 tbg. In 1.5 hrs tbg built to 23 psi.IA static.Bleed tbg for 15 mins to 0 psi. Shut in and pressure built to 10 psi in 30 mins.Consult with Wells Superintendent RWO engineer. 10/10/2017 10/10/2017 0.25 MIRU WHDBOP MPSP P Set HP BPV. 0.0 0.0 08:00 08:15 10/10/2017 10/10/2017 0.75 MIRU WHDBOP NUND P Nipple down tree. 0.0 0.0 08:15 09:00 10/10/2017 10/10/2017 1.75 MIRU WHDBOP NUND P Nipple up BOPE. 0.0 0.0 09:00 10:45 10/10/2017 10/10/2017 1.75 MIRU WHDBOP OTHR P Change upper rams to 3 1/2"x 6" 0.0 0.0 10:45 12:30 VBR's. On hi-line power at 12:00 hrs. 10/10/2017 10/10/2017 1.50 MIRU WHDBOP RURD P Rig up to test BOPE. 0.0 0.0 12:30 14:00 10/10/2017 10/10/2017 7.00 MIRU WHDBOP BOPE P Test BOPE w/3 1/2"and 5 1/2"test 0.0 0.0 14:00 21:00 joints.All tests 250/2500 psi-5 min each.Test#1-Upper 3 1/2"x 6"VBR's w/5 1/2"test joint,Valves 1,12,13,14,20.Test#2-Kill and choke NCR's.Test#3-Manual kill and choke valves.Test#4-Lower 3 1/2"x 6" VBR's w/5 1/2"test joint.Test#5- Annular w/5 1/2"test joint,valves 9,11.Test#6-Blind rams,valves 5,8,10,upper IBOP,3 1/2"FOSV.Test #7-Valves 4,6,7,lower IBOP.Test#8- Valves 2,4,dart valve.Test#9-Valve 3,4"FOSV.Test#10-Manual and super chokes.Test#11-Lower VBR's w/3 1/2"test joint.Failed low pressure test.Functioned and retest good..Test #12-Upper VBR's w/3 1/2"test joint. Test#13-Annular w/3 1/2"test joint. Tested gas alarms and PVT/Flow show.Koomey draw down test- System pressure=3000 psi.Pressure after closure=1650 psi.200 psi attained=43 sec's. Full pressure attained=204 sec's.6 nitrogen bottles at 2241 psi avg. AOGCC right to witness waived by AOGCC inspector Lou Laubenstein 10/10/2017 10/10/2017 0.50 MIRU WHDBOP RURD P Rig down test equipment.Blow down 0,0 0.0 21:00 21:30 lines 10/10/2017 10/10/2017 1.00 MIRU WHDBOP MPSP P Rig up T-bar.Pull test dart.Engage 0.0 0.0 21:30 22:30 BPV and unseat poppet.Bleed pressure from under BPV. In 30 minutes pressure dissipated.Pull BPV.Sim-ops-Rig up to pull 3 1/2' ESP completion.Hang ESP sheave in derrick. 10/10/2017 10/11/2017 1.50 COMPZN RPCOMP RURD P Continue to rig up to pull ESP 0.0 0.0 22:30 00:00 completion.Hang elephant trunk and string rope.Sim-ops/Pump 20 bbls brine into tubing w/no returns.Set isolation sleeve. Page 2/6 Report Printed: 11/1/2017 • • =` . Operations Summary (with Timelog Depths) 1C-109 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 (5CKB) End Depth(ftKS) 10/11/2017 10/11/2017 0.50 COMPZN RPCOMP RURD P Rig up circ lines from IA to flow back 0.0 4,394.0 00:00 00:30 tank.Make up landing joint to hanger and top drive 10/11/2017 10/11/2017 0.50 COMPZN RPCOMP PULL P Close annular preventer on landing 4,394.0 4,390.0 00:30 01:00 joint.BOLDS.Work pipe between 200K and 50K.while applying steam to wellhead.Hanger free at 188K. Pull up and release packer at 160K 10/11/2017 10/11/2017 1.25 COMPZN RPCOMP CIRC P Circulate at 3 bpm=30 psi with gas 4,390.0 4,390.0 01:00 02:15 returns. After 88 bbls pumped IA pressure slowly increased to 120 psi, at 100 bbls pumped IA pressure increased to 250 psi with gas/crude returns,at 150 bbls pumped IA dropped to 0 psi,at 175 bbls pumped IA increased to 100 psi and at 250 bbls pumped IA pressure leveled out at 165 psi. Pumps off.Circulate total of 250 bbls w/90 bbls returns 10/11/2017 10/11/2017 0.25 COMPZN RPCOMP OWFF P Observe the well for flow. The 4,390.0 4,390.0 02:15 02:30 pressure dropping with minimal fluid/gas to 0 psi with no fluid or gas. Open the annular and no fluid at surface. 10/11/2017 10/11/2017 0.25 COMPZN RPCOMP PULL P Pull the tubing hanger to the rig floor 4,390.0 4,360.0 02:30 02:45 (PU=91K)with occasional 15K drag. 10/11/2017 10/11/2017 1.25 COMPZN RPCOMP PULL P Disconnet the ESP cable from the 4,360.0 4,330.0 02:45 04:00 tubing hanger,lay down the landing joint,lay down the tubing hanger with 4-1/2"joint and crossover 10/11/2017 10/11/2017 0.75 COMPZN RPCOMP RURD P Change elevators to 3-1/2"tubing. 4,330.0 4,330.0 04:00 04:45 Mobilize 3-1/2"tubing power tongs to the rig floor and RU. 10/11/2017 10/11/2017 1.75 COMPZN RPCOMP TRIP P TOOH standing back 3-1/2"tubing 4,330.0 3,380.0 04:45 06:30 spooling ESP cable removing cannon clamps from 4330'to 3380'MD. 10/11/2017 10/11/2017 1.25 COMPZN RPCOMP PULL P Continue to POOH laying down 3-1/2" 3,380.0 2,261.0 06:30 07:45 tubing spooling ESP cable removing cannon clamps from 3380'to 2261' MD. 10/11/2017 10/11/2017 1.00 COMPZN RPCOMP ALFT P Cut the ESP cable above/below the 2,261.0 2,261.0 07:45 08:45 Weatherford packer and splice together. Lay down the packer. 10/11/2017 10/11/2017 3.25 COMPZN RPCOMP PULL P Continue to POOH laying down 3-1/2" 2,261.0 53.0 08:45 12:00 tubing spooling ESP cable removing cannon clamps from 2261'to 53'MD. 10/11/2017 10/11/2017 1.75 COMPZN RPCOMP ALFT P Lay down Centrilift ESP components. 53.0 0.0 12:00 13:45 Recovered 78 cannon clamps,4 equipment clamps and 4 stainless steel bands. SimOps: DHD shot a fluid level of 870'MD at 13:30 hours. Page 3/6 Report Printed: 11/1/2017 • • Operations Summary (with Timelog Depths) koo 1C-109 +Conocc�#'hiiilps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time; End Time Dor(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/11/2017 10/11/2017 1.25 COMPZN RPCOMP RURD P PJSM. Secure rope to the end of the 0.0 0.0 13:45 15:00 ESP cable and spooling over the sheave to the unit. RD the ESP cable trunk and sheave. Clear the floor of cannon clamps and Centrilift job box. SimOps: DHD shot a fluid level of 894'MD at 14:30 hours. 10/11/2017 10/11/2017 1.50 COMPZN WELLPR TRIP P Make up G-Lock RBP on 3 1/2"EUE 0.0 920.0 15:00 16:30 8rd tubing and RIH to 920'MD. 10/11/2017 10/11/2017 0.75 COMPZN WELLPR MPSP P Set RBP as per Baker rep. 920.0 920.0 16:30 17:15 10/11/2017 10/11/2017 0.75 COMPZN WELLPR TRIP P POOH w/3 1/2"EUE 8rd tubing from 920.0 0.0 17:15 18:00 920'MD to surface.Lay down running tool.Fill hole w/8.4 ppg 3%KCL brine. 10/11/2017 10/11/2017 1.25 COMPZN WELLPR MPSP P Rig up test equipment.Purge lines of 0.0 0.0 18:00 19:15 air.Close blind rams and test RBP to 1000 psi/5 min's.Required.6 bbls to pressure up to 1000 psi.Rig down test equipment. 10/11/2017 10/11/2017 1.25 COMPZN WELLPR NUND P PJSM-Nipple down BOPE. Bleed 0.0 0.0 19:15 20:30 accumulator pressure.Pull riser. 10/11/2017 10/11/2017 3.00 COMPZN WELLPR NUND P PJSM-ND existing Vetco Gray Gen II 0.0 0.0 20:30 23:30 wellhead.Well head pulled w/14K up weight.NU new Gen II Mod Ill wellhead. 10/11/2017 10/12/2017 0.50 COMPZN WELLPR PRTS P Pressure casing neck seal to 0.0 0.0 23:30 00:00 250/5000 psi for 10 minute each. Witnessed by Co man. 10/12/2017 10/12/2017 5.50 COMPZN WELLPR NUND P NU BOPE. Install the riser. Obtain 0.0 0.0 00:00 05:30 and cut 1-7/8"bolts to size for BOP stack flange to the wellhead. SimOps: Load strap,tally and drift 3- 1/2"coated tubing. Mobilize test plug to the rig floor and prep to test the break. 10/12/2017 10/12/2017 1.00 COMPZN WELLPR BOPE P Install the test plug and RU testing 0.0 0.0 05:30 06:30 equipment. 10/12/2017 10/12/2017 0.75 COMPZN WELLPR BOPE P PJSM. PT the break,kill.line and 0.0 0.0 06:30 07:15 wellhead flanges to 250/2500 psi for 5 minutes each. 10/12/2017 10/12/2017 0.50 COMPZN WELLPR BOPE P RD testing equipment and pull the test 0.0 0.0 07:15 07:45 plug. 10/12/2017 10/12/2017 0.25 COMPZN WELLPR BHAH P PU and MU G-lock set RBP retrieving 0.0 0.0 07:45 08:00 head. 10/12/2017 10/12/2017 0.50 COMPZN WELLPR TRIP P TIH with RBP retrieving head to 920' 0.0 920.0 08:00 08:30 MD. 10/12/2017 10/12/2017 0.50 COMPZN WELLPR MPSP P Engage the retrieving head onto the 920.0 920.0 08:30 09:00 RBP,open the bypass valve,the fluid level dropped out of sight,add ten bbls and the well is still taking fluid. Release the G-lock set RBP,PU 20' and SO past the setting depth to ensure it is released. 10/12/2017 10/12/2017 1.00 COMPZN WELLPR PULD P POOH with RBP laying down 3-1/2" 920.0 15.0 09:00 10:00 tubing. 10/12/2017 10/12/2017 0.25 COMPZN WELLPR BHAH P Lay down the G-lock set RBP and 15.0 0.0 10:00 10:15 retrieving head. Page 4/6 Report Printed: 11/1/2017 • • Operations Summary (with Timelog Depths) rs� 1C-109 ConoccPhitiips 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 (ftKS) End Depth(ftKE) 10/12/2017 10/12/2017 0.50 COMPZN WELLPR BHAH P Clean and clear the floor. 0.0 0.0 10:15 10:45 10/12/2017 10/12/2017 1.25 COMPZN RPCOMP RURD P PJSM-Rig up to run 5 1/2"liner. 0.0 0.0 10:45 12:00 10/12/2017 10/12/2017 6.50 COMPZN RPCOMP PUTB P PJSM-Run 5 1/2"L-80 Hyd 563 0.0 4,438.0 12:00 18:30 TK15XT internally coated liner PU seal assy, 1 jt 3 1/2"tbg,GLM, 1 jt 3 1/2"tbg and SBE crossed over to 5 1/2"liner to 4438'MD. 10/12/2017 10/12/2017 0.50 COMPZN RPCOMP PUTB P RIH w/joint#109 and no-go 13.5'in at 4,438.0 4,448.0 18:30 19:00 4451'MD.Set down 5K.Pick up to 4448'MD.Pressure up IA to 1000 psi to confirm seal assy in SBE. 10/12/2017 10/12/2017 1.00 COMPZN RPCOMP HOSO P Lay down joints 109, 108, 107 and 4,448.0 4,416.0 19:00 20:00 106.Make up space out pups.(2.55', 4.39',6.37', 10.28',8.37').Pick up joint 106.and make up hanger. 10/12/2017 10/12/2017 1.50 COMPZN RPCOMP CRIH P PJSM-Rig up bail extensions.Rig up 4,416.0 4,416.0 20:00 21:30 to reverse circulate. 10/12/2017 10/12/2017 0.75 COMPZN RPCOMP CRIH P Test lines to 2500 psi.Reverse 4,416.0 4,416.0 21:30 22:15 circulate.60 bbls 8.4 ppg 3%KCL inhibited brine down IA.3 bpm,0 psi with no returns. 10/12/2017 10/12/2017 0.50 COMPZN RPCOMP FRZP P Reverse circulate 35 bbls diesel 4,416.0 4,416.0 22:15 22:45 freeze protect down IA.2 bpm,0 psi with no returns 10/12/2017 10/12/2017 0.50 COMPZN RPCOMP HOSO P Land hanger.Mule shoe at 4445.78' 4,416.0 4,445.8 22:45 23:15 MD.No-go spaced out 5'.RILDS. Test hanger seals to 250/5000 psi 10 min each.Witnessed by CoMan. PU=108K SO=83K 10/12/2017 10/12/2017 0.25 COMPZN RPCOMP RURD P Rig down and lay down landing joint. 4,445.8 0.0 23:15 23:30 10/12/2017 10/13/2017 0.50 COMPZN RPCOMP PRTS P Test IA to 2500 psi for 30 mins. 0.0 0.0 23:30 00:00 10/13/2017 10/13/2017 3.00 COMPZN RPCOMP RURD P RD testing equipment. Mobilize PTS 0.0 0.0 00:00 03:00 spooling unit to the rig floor. RU to run 3-1/2"completion. 10/13/2017 10/13/2017 0.50 COMPZN RPCOMP SFTY P PJSM for running completion with all 0.0 0.0 03:00 03:30 parties involved. 10/13/2017 10/13/2017 1.00 COMPZN RPCOMP PUTB P PU and MU seal assembly and 1 joint 0.0 56.0 03:30 04:30 of coated 3-1/2"tubing. Clean and repair die marks with coating. 10/13/2017 10/13/2017 2.50 COMPZN RPCOMP PUTB P PU and MU the gauge carrier,install 56.0 86.0 04:30 07:00 the PTS gauge and PT to 10000 psi for 30 minutes(good test). 10/13/2017 10/14/2017 17.00 COMPZN RPCOMP PUTB P Continue to RIH with completion on 86.0 2,299.0 07:00 00:00 coated 3-1/2"tubing from 86'to 2299' MD at midnight spooling TEC wire adding stainless steel bands above/below the coupling plus mid- joint.Clean and repair die marks with coating. Adding 5 bbls 8.4 ppg brine to hole every hour. Page 5/6 Report Printed: 11/1/2017 : • ! °-' Operations Summary (with Timelog Depths) 44, 1C-109 CcmocoPhillips 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) 10/14/2017 10/14/2017 11.00 COMPZN RPCOMP PUTB P Continue to RIH with completion on 2,299.0 4,225.0 00:00 11:00 coated 3-1/2"tubing from 2299'MD to 4225'MD.Spooling TEC wire adding stainless steel bands above/below the coupling plus mid-joint.Clean and repair die marks with coating. Adding 5 bbls 8.4 ppg brine to hole every hour. 10/14/2017 10/14/2017 0.75 COMPZN RPCOMP HOSO P Tag seals on SBE at 4300'MD.RIH 4,225.0 4,272.0 11:00 11:45 and no-go at 4316'MD w/10K down wt.Lay down joints 135, 134 and 133. Make up space out pups(10.20'and 2.25').Pick up joint 133. 10/14/2017 10/14/2017 1.25 COMPZN RPCOMP THGR P Make up hanger and landing joint. 4,272.0 4,272.0 11:45 13:00 Terminate TEC wire at hanger. 10/14/2017 10/14/2017 1.25 COMPZN RPCOMP CRIH P PJSM-Rig up LRS.Test mud lines to 4,272.0 4,272.0 13:00 14:15 1000 psi.Test LRS line to 4000 psi. Reverse circulate 52 bbls inhibited 8.4 ppg 3%KCL brine.3 bpm,30 psi. 10/14/2017 10/14/2017 0.75 COMPZN RPCOMP FRZP P Reverse circulate 27 bbls diesel 4,272.0 4,272.0 14:15 15:00 freeze protect with LRS. 1 bpm, 150 psi. 10/14/2017 10/14/2017 1.00 COMPZN RPCOMP THGR P Blow down choke and kill lines.Land 4,272.0 0.0 15:00 16:00 hanger.RILDS.Test hanger seals to 250/5000 psi for 10 min's each.Lay down landing joint. PU=74K SO=70K. Locator spaced out 4.26 off no-go.Mule shoe at 4319.78'MD ORKB. 10/14/2017 10/14/2017 0.75 COMPZN RPCOMP PRTS P Test IA to 3500 psi/30 mins. 0.0 0.0 16:00 16:45 10/14/2017 10/14/2017 0.25 COMPZN WHDBOP MPSP P Set HP BPV.PJSM on nippling down 0.0 0.0 16:45 17:00 BOPE. 10/14/2017 10/14/2017 1.50 COMPZN WHDBOP NUND P ND BOPE.Pull mouseholes,master 0.0 0.0 17:00 18:30 bushing and bell nipple.Blow down injection line.Sim-ops/Clear rig floor. 10/14/2017 10/14/2017 1.50 COMPZN WHDBOP NUND P Clean up wellhead.Make up adapter 0.0 0.0 18:30 20:00 flange,install test dart,NU tree.Sim- ops/Perform BWM. 10/14/2017 10/14/2017 3.00 COMPZN WHDBOP RURD Terminate TEC wire on wellhead. 0.0 0.0 20:00 23:00 Perform final integrity checks on TEC wire.Sim-ops/Rig up to test tree. Clean mud pits.Prep fuel trailer to move.Perform BWM. 10/14/2017 10/15/2017 1.00 COMPZN WHDBOP PRTS Test hanger void to 250/5000 psi for 0.0 0.0 23:00 00:00 10 mins each.Witnessed by Co ManTest tree w/diesel 250/5000 psi. for 5 min's each on chart. 10/15/2017 10/15/2017 0.50 COMPZN WHDBOP MPSP P Pull type HP BPV and set type H BPV. 0.0 0.0 00:00 00:30 OA=0 psi IA=67 psi Tbg=0 psi. 10/15/2017 10/15/2017 1.00 COMPZN WHDBOP FRZP P Rig up LRS.Test lines to 1000 psi. 0.0 0.0 00:30 01:30 Bullhead 20 bbls diesel down tubing. 1 bpm, 150 psi. 10/15/2017 10/15/2017 0.50 DEMOB MOVE RURD P Rig down lines,stow tools and secure 0.0 0.0 01:30 02:00 cellar. Release rig at 02:00 hrs. 10-15-17 Page 6/6 Report Printed: 11/1/2017 KUP 'VD 1C-109 CCll1C)CC3 t1 1 >5 .1 Well AttribuMax Angle TD AIc1S}cN.Ir1f,.., Wellbore API/UWI Field Name Wellbore Status Ind C) MD(ftKB) Act Btm(ftKB) LOMcos'tliuips 500292304700 WEST SAK PROD 1 92.83 5,496.29 7,510.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(8) Rig Release Date 1C-109,11/9/20179.13:45 AM SSSV:NONE 25 1/29/2017 Last WO: 10/15/2017 45.45 11/10/2001 Vertical sdlematc(wwa) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:RWO(Replace ESP for Jet Pump, pproven 11/8/2017 HANGER;34.8- lliy m -Install 5-1/2"Liner),Pull ISO,Set X-Lock w/Jet Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 158.0 158.0 82.00 WELD li Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND(...Wt/Len(...Grade Top Thread HANGER-3e.a il I. PRODUCTION 7 5/8 6.875 40.7 4,938.4 3,807.9 29.70 L-80 BTC Casing Description OD(n) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD(...Wt/Len(1.Grade Top Thread L' WINDOW Li 6 5.00.0 44940 4,525.0 3,7512 to 1C 109L1 r^ "" uu9'Casing Descnption OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread XO Threads.399 D-SAND LINER LEM 5.2 3.688 4,422.6 4,603.8 3,775.8 IBT Liner Details Liner,59.1 Nominal ID Top(ftKB) Top(NO)(ftKB) Top Incl C) Item Des Com (in) ^ 4,422.6 3,711.7 6526 PACKER "HRD"ZXP LINER TOP PACKER 4.940 Liner-Pup;98.5 4,441.4 3,719.5 66.05 SBE 190-47 SEAL BORE EXTENSION 4.940 CONDUCTOR,38.0-158.0 4,461.1 3,727.3 66.82 XO Reducing CROSSOVER(5.5"Hydril 563 x 4.5"IBT) 3.970 14,474.1 3,732.4 67.33 NIPPLE DB NIPPLE 3.750 Liner;130.4 4,483.5 3,736.0 67.70 HANGER LEM HH(above hook 10.61) 3.990 Tec Wire Guide Sub;4,152.7 .'iii 4,494.1 3,740.0 68.11 HANGER LEM HH(below hook 24.51") 3.688 Siding Sleeve;4,153.0 ;I• 4,563.3 3,764.0 71.75 NIPPLE 3.563"DB NIPPLE 3.563 X-Lack w/JET PUMP;4,154.0 n4,595.8 3,773.6 73.92 LOCATOR 4.5"LOCATOR+00 3.688 Tec Wire Guide Sub;4,157.7 ;.till 4,598.2 3,774.2 74.08 SEAL ASSY SEAL ASSEMBLY 5.60"w/2'SPACE OUT 3.000 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(8KB) Set Depth(ND(...WtlLen p...Grade Top Thread B-SAND LINER 4 1/2 3.958 4,597.1 7,483.0 3,793.4 12.60 NSCT ' 1 Liner Details j Nominal ID Tubing-Pup;4,243.7 -S _ Top(ftKB) Top(ND)(MB) Top Incl(°) Item Des Com (in) Gauge/Pump Sensor;4,247.7 4,597.1 3,773.9 74.00 PACKER BAKER MODEL'SCR-1'LINER TOP PACKER 4.970 4,601.9 3,775.2' 74.32 MILLOUT MILL OUT EXTENSION 4.400 XO Enlarging;4,258.5 j T. 4,604.0 3,775.8 74.47 00 Reducing XO 5 x 4.5 4.500 4,680.9 3,792.2 81.32 SLEEVE BAKER CMD SLIDING SLEEVE 3.413 ❑tier-Pup;4,292.7 4,685.4 3,792.9 81.76 00 Reducing XO 4.5X4" 4.000 LOCATOR;4,297.8 4,717.8 3,796.7 84.90 00 Enlarging XO 4 x 4.5" ' 4.000 XO Threads(Casing);4,302.5 7,446.9 3,793.5 90.18 XO Reducing XO 4.5 x 4" 4.000 SEAL ASSY;4,298.3 m Tubing Strings SBE;4,304.5 g S g Tubing Description String Ma...ID(in) Top(ftKB( Set Depth(ft..Set Depth(TVD((...Wt(lb/ft) Grade Top Connection XO Reducing;4,324.2 TUBING WO 2017 31/2 2.912 34.8 4,319.8 3,665.1 9.30 L-80 EUE 8rd Mad Completion Details Nominal ID Top(8KB) Top(ND)(ftKB) Top Incl r) Item Des Corn (in) GAS LIFT;4370.9 34.8 34.8 0.23 HANGER Tubing Hanger,Vetco Gray,10-3/4"x 4-1/2"IBT bottom x 3.900 4.909 MCA Top,4"H BPVG r. 37.5 37.5 0.25 XO Reducing Crossover Pup Joint,4-1/2"IBT Pin x 3-1/2"EUE 8rd Pin, 2.992 NOT Coated 4 4,152.7 3,576.1 54.61 Tec Wire Tec Wire Guide Sub,Baker,3-10,9.3#,L-80 EUE 8rd 3.000 00 Enlarging;4,428.2 IIS Guide Sub Mod Box x Pin LOCATOR;4,427.74,153.6 3,576.6 54.64 Sliding Sleeve Sliding Sleeve,Baker,CMU with 2.813"BX profile,NOT 2.807 illi.:.�..4 t Coated SEAL ASV;4,428.4 a: a ' :,e 4,157.7 3,579.0 54.80 Tec Wire Tec Wire Guide Sub,Baker,3-1/2",9.3#,L-80 EUE 8rd 3.000 Guide Sub Mod Box x Pin 4,231.9 3,620.2 57.68 00 Reducing 0-0,3-1/2"EUE 8rd Mod Box x 2-7/8"EUE 8rd Pin NOT 2.441 Coated c^ , 4,247.7 3,628.6 58.29 Gauge/Pump Gauge Carrier with PTS Gauge 2.44) Sensor 4,258.5 3,634.2 58.68 XO Enlarging Crossover,2-7/8"EUE 8rd Mod Box x 3-1/2"EUE 8rd Pin 2.441 at uv NOT Coated DSAND LINER,4,493.4-7,512.5 ..1:1 I-a _)) ((I 4,297.8 3,654.3 60.12 LOCATOR Locator,Baker,GBH-22(bottom of the locator spaced out 2.960 C 4• 4.26') WINDOW LI;4,4940-4,5259 4,298.3 3,654.5 60.13 JSEAL ASSY Seal Assembly,Baker,80-40 2.960 Tubing Description String Ma...ID(in) Top(ftKB( Set Depth(ft..1Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection 5-1/2"Liner RWO 51/2 4.870 38.4 4,456.0 3,725.3 15.50 L-80 Hydril 563 2017 _ Completion Details ' Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inc!(°( Item Des Corn (in) 38.4' 38.4 0.25 HANGER Mandrel Casing Hanger,Vetco Gray,Gent Mod 3,5-7/8 4.950 MCA Box x 5-1/2"BTC Box '7 x.c 59.1 59.1 0.39 Liner 5 1/2"15.58 L-80 Internally Coated Hyd 563 Box x Pin 4.870 µ Casing / D-SAND LINER LEM,4,422.6- `4 4,033.8 r 4F 130.4 130.4 0.80 Liner 5 1/2"15.58 L-80 Internally Coated Hyd 563 Box x Pin 4.870 Casing _ 4,304.5' 3,657.6 60.36 SBE SBE,Baker 80-40 4.000 3 1 1 4,324.2 3,6672 61.08 00 Reducing X-0 4 1/2"Hyd 521 Pin x 3 1/2"EUE 8rd Pin 2.930 4,426.2 3,713.2 65.42 XO Enlarging X-0 3 1/2"EUE 8rd Mod Box x 41/2"IBT Pin 2.990 4,427.7 3,713.8 65.48 LOCATOR 'Locator,Baker,GBH-22(bottom of the locator spaced out 3.870 5') I 4,428.4 3,714.1 65.51 SEAL ASSY Seal Assembly,Baker,192-47 3.860 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PRODUCTION;40.7-4.938.4-. - Top(TVD) Top Incl _. Top(ftKB) (ftKB( ('( Des Com Run Date ID(in( SLOTS;4,962.0-7,450.0w 4,154.0 3,576.9 54.66 X-Lock w/JET 2.81"X-LOCK W/3"RC JET PUMP(SER PH-1137/ 8/25/2017 PUMP 10B RATIO/63"OAL) _ L B-SAND LINER;4,597.1-7,483.0 4^ l KUP �D 1C-109 Conoc©Phillips Alaska.Inc, t CarrocoPhillips ••• 10-109,11/9/201791345AM. Vertical.chemahc(ravel) HANGER,34.8 . <.l;_ Perforations&slots Shot Dens 11 I Top(TVD) Btm(TVD) (shots) HANGER,38.4 $ i Top(11(B) Btm(ttKB) (RKB) (ttKB) Zone Date ft) Type Com 4,962.0 7,450.0 3,808.3 3,793.5 WS B,1C- 10/29/2001 32.0 SLOTS Slotted Liner I 109 ,,,.,stimulations&Treatments XO Threads;39.8 Proppant Designed(Ib) Proppant In Formation(Ib) Date Liner:59.1 ,, I Mandrel Inserts St Liner-Pup:985 ag Top(ND) Valve Latch Port Size TRO Run CONDUCTOR,38.0-158.0 • N Top(RKB) (ttt(B) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com I 1 4,370.9 3,689.2 Camco KBMG 1 DMY BK 0.000 0.0 10/12/2017 Liner,1304 Notes:General&Safety End Date Annotation Teo Wire Gums sub;4,1527 i*i' 11/10/2001 NOTE:MULTI-LATERAL WELL:1C-109(B-SAND),1C-109L1(D-SAND) Sliding Sleeve;4,1536, • 8/21/2008 NOTE:WORKOVER,SET D-SAND LEM X-Lock w/JET PUMP;4,154.0 Tec Wee Guide Sub,4,1577 <(p? 8/30/2008 NOTE:View Schematic w/Alaska Schematic9.0REV 3/4/2012 NOTE:WORKOVER 11/22/2014 NOTE:WORKOVER 10/15/2017 NOTE:WORKOVER-RWO(Replace ESP for Jet Pump,Install 5-1/2"Liner), Tubing-Pup,4,243.7 Gauge/Pump Sensor,4,247.7 XO Enlarging;4,258.5 Dyer-Pup,4,292.7` LOCATOR,4,297.8 00 Threads(Casing),4,302.5 SEAL ASSY,4,298 3, SBE;4,304.5 a&. XO Reducing,4,324 2 GAS LIFT,4,370.9 4. 00 Enlarging;4,428.2 3�L1, LOCATOR;4,427.7 4.11 . SEAL ASSY:4,428.4 ° 1f 11 D-SAND LINER,4,493 47,512 5 WINDOW LI;4,494.0-4,525.0 r' p D-SAND LINER LEM,4,422.6- 3:m 4,603.8 z.:A A1, -1 1 ( PRODUCTION,40.7-4,938.4—� SLOTS,4,9620-7450.0 r B-SAND LINER,4,597.1-7483.0 • • `, OF 7^ F 0) II/7 ,kVA THE STATE Alaska Oil and Gas --���— 7 o fLAsKA Conservation Commission ttsir# 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501 3572 `*"P Main: 907.279.1433 Fax 907.276.7542 www.aogoc.alaska.gov Andrew Beat Senior Wells Engineer SCANNED SEP 2 7 201Z ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, West Sok Oil Pool, KRU 1C-109 Permit to Drill Number: 201-203 Sundry Number: 317-427 Dear Mr. Beat: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1110 Hollis S. French Chair DATED this day of September,2017. RBDMSSEP 1 9 2017 • • RECEIVED STATE OF ALASKA SEP U 6 2011 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate❑ Pull Tubing Q Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other:Canv E5?to j c,L Er 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: P`. p ConocoPhillips Alaska,Inc. Exploratory ❑ Development D. 201-203 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-23047-00 . 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a' KRU 1C-109 . Will planned perforations require a spacing exception? Yes ❑ No Eli 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL025649 ' Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7510' ' 3793' 7510' • 3793' % 802 none none Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 158' 158' Surface Intermediate Production 4893' 7.625" 4937' 3804' Liner 2876' 4.5" 7480' 3793' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4962'-7450' 3808'-3794' 4.5"x 3.5" L-80 4396 (slotted liner) Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV: none PACKER-WFT HYDROW II FEED THRU MD=2174 TVD=1991 i 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q• Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 9/28/2017 Commencing Operations: OIL Q ' WINJ 0 WDSPL ❑ Suspended 16.Verbal Approval: Date: GAS 44 WAG ❑ GSTOR D SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Andrew Beat Contact Name: Andrew Beat Authorized Title: Sr.Wells ineer Contact Email: Andrew.T.Beat@conocophillips.com / Contact Phone: 265-6341 Authorized Signature: / Date: `AD/( COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 11-li27 Plug Integrity ❑ BOP Test Ilr7 Mechanical Integrity Test ❑ Location Clearance ❑ Other: 673/7 df' t�J/- .fO 2„5--f O $-5 ,41'3nv1cifr--- tt5f to Z 00 f7 moi RBDMS [t. SEP 1 9 2017 Post Initial Injection MIT Req'd'. Yes ❑ No LIV Spacing Exception Required? Yes 0 No G Subsequent Form Required: /0 — 4 04-- APPROVED BY I C2.— L 1 Approved by: Q COMMISSIONER THE COMMISSION Date: Submit Form and rorm iu-4us neviseu 4/ZU A pi Lived dpllc tlun la vdlld fur 12 rnun ha rt UM the dale of approval. Attachments in Uuphcate *ft; i frit �,,O 131 NAL • • ConocoPhillips RECEIVED Alaska SEP 0 6 2017 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC 6 September 2017 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc. hereby submits an Application for Sundry Approval to work over Kuparuk(West Sak) Producer 1C-109(PTD#201-203). 1C-109 was drilled and completed in 2001 with an ESP.Throughout the well's production it has had several sanding issues which has led to ESP failures. The ESP failed and was subsequently replaced via a RWO in 2008,2012,and 2014.The ESP failed again in 2016 and a RWO is planned for later in 2017 to convert the artificial lift method from ESP to Jet Pump. This is a single casing well so a new tie-back liner will be installed to provide an additional steel barrier for the Jet Pump. The planned workover scope includes pulling the existing ESP completion,changing out the wellhead to accommodate the liner,installing a 5-1/2"liner from surface,and installing a new 3-1/2"Jet Pump completion. / If you have any questions or require any further information,please contact me at 265-6341. Sincerely, Andrew Beat Senior Wells Engineer CPAI Drilling and Wells • • 1C-109 Rig Workover P&R Tbg w/Liner Install (PTD#:201-203) Current Status: Shut-in Scope of Work: Pull the existing completion down to liner top packer. Change wellhead. Install 5-1/2"liner and 3- 1/2"jet pump completion. General Well info: Well Type: Producer MPSP: 802 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 1,171 psi/3,698' TVD(6.1 ppg EMW)measured on 09/11/2013 Wellhead type/pressure rating: Vetco Gen II, 514psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: CMIT PASSED—07/06/2017 IA DDT PASSED—07/12/2017 Earliest Estimated Start Date: September 28,2017 Production Engineer: Marina Krysinski Workover Engineer: Andrew Beat(263-6341/Andrew.T.Beat@ConocoPhillips.com) Pre-Rig Work 1. Inspect pad and work area for hazards. Complete the PJSM. Workover Procedure 1. MIRU. 2. Circulate KWF throughout well.Obtain SITP& SICP,if pressure is seen at surface,calculate new KWF, weight up,and repeat circulation as necessary.Verify well is dead. 3. Set BPV,ND tree,NU BOPE and test to 250/2,500 psi. ✓ a. If the lower pipe rams are unable to be tested because of the blanking plug position,the lower pipe rams will be tested upon pulling the completion. 4. Pull BPV, screw in landing joint,BOLDS's,unland tubing hanger. 5. POOH laying down 3-1/2"ESP completion. 6. RIH and set RBP at 100'.Pressure test from above to verify plug is set. 7. ND BOP stack.ND existing Vetco tubing head. 8. NU new Vetco wellhead to accommodate liner and tubing. Test flange seal to rated capacity. 9. NU BOP stack and test break to 250/2,500 psi. ✓ 10. Retrieve RBP. 11. RIH with 5-1/2"liner assembly to SBE located below liner top packer. Fully locate and space out at surface. 12. Pump corrosion inhibited fluid to fill the OA from the SBE to surface.Land liner hanger in wellhead. 13. RIH with 3-1/2"jet pump completion to SBE located at the liner bottom. Space out and MU tubing hanger. 14. Pump corrosion inhibited fluid in the IA from the SBE to surface.Land the tubing hanger,RILDS. 15. PT the tubing.Hold pressure on tubing and pressure test IA and chart. Bleed tubing pressure quickly to shear the SOV. 16. Pull the landing joint,install BPV. 17. ND BOPE. 18. NU tree.Pull BPV and install tree test plug.Test tree and pull test plug. 19. Freeze protect well with diesel. 20. RDMO. 1 • • 1C-109 Rig Workover P&R Tbg w/Liner Install (PTD#:201-203) Post-Rig Work 1. RU Slickline to pull SOV.Install jet pump. 2. Reset well house(s)and flowlines of adjacent wells. 3. Turn well over to operations. 2 • • 1C-109 ConocoPhillips West Sak Producer ESP to Jet Pump w/ Liner Install Well Details: PROPOSED API: 50-029-23047-01 PTD: 201-203 COMPLETION Wellhead: Vetco Gen III 5M Casing/Tubing Details: 16"82# H-40 Conductor to 158' KB 7-5/8"29.7# L-80 Production to 4,938' KB 5-1/2"26#L-80 Liner to 4,500' KB 3-1/2" 9.3#L-80 Tubing to 4,500' KB Misc Details: Max Inclination: 65° at ZXP Packer Max Dogleg: 9.9°/100' at 1,072' KB Last Tagged Fill: N/A Total Depth: 7,510' KB 3-1/2" KBG 2-9 GLM 3-1/2" CMU 2.813" DS (Jet Pump Location) JL � pvvvlp Ih51a11.rc W J1L. pdt 3-1/2" PTS Gauge Carrier Baker SBE a 3-1/2"CMU 2.813" BX Existing ZXP Liner Top Packer !■• D and B Sand Laterals Date: September 5,2013 Drawn By: Andrew Beat 44• KUP PROD �� 1C-109 Corm .cWhillips i$ 1 Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) .: tip, 500292304700. WEST SAK PROD 9283 5,496.29 7,510.0 4u ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-109,8/27/201712.23:34 PM SSSV:NONE 25 1/29/2017 Last WO. 11/22/2014 45.45 11/10/2001 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date casing t;or) Last Tag: Rev Reason:PULL WRP,CATCHER,GLV C/O pproven 8/27/2017 • (PULL DV) HANGER;36.1- ras ll Casing Strings �IL j Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread - CONDUCTOR 16 15.062 38.0 158.0 158.0 82.00 WELD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ,ii ,$, PRODUCTION 7 5/8 6.875 40.7 4,938.4 3,807.9 29.70 L-80 BTC XO Reducing(rudrg);s8.1 I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Sot Depth(TVD)...WtlLen(I...Grade Top Thread * WINDOW Lt 6 5.000 4,494.0 4,525.0 3,751.2 to 1C-109L1 ,,, Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread CONDUCTOR;36.0-158.0 .. D-SAND LINER LEM 5.2 3.688 4,422.6 4,603.8 3.775.8 IBT Liner Details I I Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Com (in) • 4,422.6 3,711.7 65.26 PACKER "HRD"ZXP LINER TOP PACKER 4.940 GAS LIFT;2,049.3 ' 4,441.4 3,719.5 66.05 SBE 190-47 SEAL BORE EXTENSION 4.940 4,461.1 3,727.3 66.82 XO Reducing CROSSOVER(5.5"Hydril 563 x 4.5"IBT) 3.970 4,474.1 3,732.4 67,33 NIPPLE DB NIPPLE 3.750 00 Threads;2,158.8 - 4,483.5 3,736.0 67.70 HANGER LEM HH(above hook 10.61) 3.990 PACKER;2,173.6 4,494.1 3,740.0 68.11 HANGER LEM HH(below hook 24.51") 3.688 4.563.3 3,764.0 71.75 NIPPLE 3.563"DB NIPPLE 3.563 4,595.8 3,773.6 73.92 LOCATOR 4.5"LOCATOR+XO 3.688 4,598.2 3,774.2 74.08 SEAL ASSY SEAL ASSEMBLY 5.60"w/2'SPACE OUT 3.000 GAS LIFT;2,286.7 Casing Description OD(in) ID(in) /Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread B-SAND LINER • 4 1/2 3.9584 4,597.1 7,483.0 3,793.4 12.60 NSCT Liner Details Nominal ID GAS LIFT;4,249.8 Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Com (in) O 4,597.1 3,773.9 74.00 PACKER BAKER MODEL'SCR-1'LINER TOP PACKER 4.970 4,601.9 3,775.2 74.32 MILLOUT MILL OUT EXTENSION 4.400 4.604.0 3,775.8 74.47 XO Reducing XO 5 x 4.5 4.500 GAUGE;4,303.8 4,680.9 3,792.2 81.32 SLEEVE BAKER CMD SLIDING SLEEVE 3.413 4,685.4 3,792.9 81.76 XO Reducing XO 4.5X4" 4.000 4,717.8 3,796.7� 84.90 XO Enlarging XO 4 x 4.5" 4.000 7,446.9 3,793.5 90.18 XO Reducing XO 4.5 x 4" 4.000 ESP INTAKE;4,363.8 _ Tubing Strings SEAL;4,388.3 = TubingDescription String Ma...ID(in) To ftKB Set Depth ft..,Set Depth TVD Wt lb/fl Grade Top Connection sP( p ( p (TVD) GEAR BOX;4,382.1 i= 3.5"ESP 31/2 2.992 36.1 4,396.1 3,700.4 9.30 L-80 EUE8rd ESP MOTOR;4,383.9 j COMPLETION GAUGE;4,392.2 �.,. Completion Details Centrzizer;4,394.1Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 36.1 36.1 0.24 HANGER VETCO-GRAY TUBING HANGER 5.325 2,173.6 1,991.4 42.20 PACKER WEATHERFORD HYDROW 11 DUAL STRING,ESP Feed 2.908 I -Thru PACKER(2166') I 4,303.8 3,657.3 60.34 GAUGE WELL DISCHARGE GAUGE UNIT 2.992 4,363.8 3,685.9 62.69 ESP INTAKE TTC RECEIVER/CROSSOVER COUPLING w/ 2.992 PERFORATED INTAKE 4,368.3 3,688.0 62.89 SEAL TANDEM SEAL SECTION 4,382.1 3,694.2 63.49 GEAR BOX GEAR REDUCTION UNIT • 4,383.9 3,695.0 63.57 ESP MOTOR ESP MOTOR D-SAND LINER;4,493.4- a 4,392.2 3.698.7 63.93 GAUGE WELL LIFT MOTOR GAUGE UNIT 7,512.5 (I 4,394.1 3.699.5 64.02 Centralizer MOTOR CENTRILIZER 11 I ll Perforations&Slots WINDOW L1;4,494.04,525.0 Shot Dens Top(TVD) Btm(TVD) (shots/f Top(ftKB) Blm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 4,962.0 7,450.0 3,808.3 3,793.5 WS B,1C-109 10/29/2001 32.0 SLOTS Slotted Liner - WS B,1C-109 ' -I Stimulations&Treatments Proppant Designed(Ib) Proppant In Formation(Ib) Date 7'13-C_ Mandrel Inserts D-SAND LINER LEM;4,422.6- 4■ 1 -St 4,603.8 IE' ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 3 ( 2,049.3 1,899.3 CAMCO KBMG 1 GAS LIFT OPEN 8/25/2017 1 I 2 2,286.7 2,075.6"CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/27/2014 yl 4,249.8 3629.7 ICAMCO KBMG 1 GAS LIFT SOV BK 0.000 0.0 2/7/2017 -1Notes: - Notes:General&Safety End Date Annotation j 11/10/2001 NOTE:MULTI-LATERAL WELL.1C-109(B-SAND),1C-109L1(D-SAND) 8/21/2008 NOTE:WORKOVER,SET D-SAND LEM PRODUCTION;4R7-4R38.4 6/30/2008 NOTE:View Schematic w/Alaska Schemat)c9.OREV 3/4/2012 NOTE:WORKOVER 11/22/2014 NOTE:WORKOVER SLOTS;4,962.0-7,450 0 B-SAND LINER;4,597.1-7,483.0 • • Bettis, Patricia K (DOA) From: Beat,Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Wednesday, September 6, 2017 10:24 AM To: Bettis, Patricia K (DOA) Subject: RE: [EXTERNAL]KRU 1C-109 (PTD 201-203): Sundry Application Attachments: 1C-109_Current Schematic.pdf Patricia, Good catch.Will an email submission suffice or would you like me to drop off paper copies? Thanks, Andrew (303)378-8881 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Wednesday,September 06, 2017 10:00 AM To: Beat,Andrew T<Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]KRU 1C-109 (PTD 201-203): Sundry Application Good morning Andrew, Please submit a wellbore schematic showing the current status of the wellbore. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • S Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Wednesday, September 6, 2017 9:59 AM To: 'And rew.T.Beat@conocophillips.com' Subject: KRU 1C-109 (PTD 201-203): Sundry Application Good morning Andrew, Please submit a wellbore schematic showing the current status of the wellbore. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 . STATE OF ALASKA A OIL AND GAS CONSERVATION COIV�SION RC^C�` ,�® r REP OF SUNDRY WELL OPERATIONS ECE \/ 1. Operations Performed: Abandon r Repair well 17 Plug Perforations r Perforate r AP Rol ieP "2 012 Alter Casing r" Pull Tubing 17 Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re- e7ft�1� eram • Commission Operator Name: 4. Well Class Before Work: ��`� t p 5. Pefdi�t'Yxs 2. O d14Aumber: ConocoPhillips Alaska, Inc. Development p' Exploratory r - 201 -203 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service - 50- 029 - 23047 -00 `Ci0 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25649 ■ . 1C-109 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): -. none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 7510 feet Plugs (measured) None true vertical 3793 feet Junk (measured) None Effective Depth measured 7510 feet Packer (measured) 2176, 4423, 4597 true vertical 3793 feet (true vertucal) 1993, 3712, 3774 Casing Length Size MD TVD Burst Collapse CONDUCTOR 120 16 158 158 SURFACE 4898 7.625 4938 3808 B -SAND LINER 2886 4.5 7483 3793 ._ Perforation depth: Measured depth: 4962' - 7450' ZO1Z True Vertical Depth: 3808' - 3794' �P r Tubing (size, grade, MD, and TVD) 3.5, L - 80, 4396 MD, 3700 TVD Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD HYDROW II DUAL - STRING PACKER @ 2176 MD and 1993 TVD PACKER - HRD ZXP LINER TOP PACKER @ 4423 MD and 3712' TVD PACKER - BAKER SCR -1 LINER TOP PACKER @ 4597 MD and 3774 TVD NO SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing. Pressure Prior to well operation shut - Subsequent to operation shut -in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory I Development i- - Service f" Stratigraphic r 16. Well Status after work: - Oil 17 Gas r WDSPL r Daily Report of Well Operations XXX GSTOR E WINJ r WAG r GINJ E SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Brett Packer na 265 -6845 Printed Name Brett Packer Title Wells Engineer Signature /i Phone: 265 -6845 Date 11(3 /t Z Form 10-404 Revised 1112011Rf3Dms APR 0 4 X011 __e ri_4(- (2._ Ibmit priginal Only s KUP • 1C -109 ConocoPhillips � I Well Attributes Max Angle & MD TD Alaska, Inc. Wellbore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) GanoctiPhillps 500292304700 WEST SAK PROD 92.83 5,496.29 7,510.0 " "' Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date ••• WetiConilo' - iC - 109 3/25/201245351 PM ,SSSV: NONE 0 7/10/2009 Last WO: 8/21/2008 45.45 11/10/2001 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: WORKOVER ninam 3/25/2012 Casing Strings HANGER, 35 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd hilitL - CONDUCTOR 16 15.062 38.0 158.0 158.0 82.00 WELD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 5/8 6.875 40.7 4,938.4 3,807.6 29.70 , L - 80 BTC 1F 'Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd WINDOW L1 6 5.000 4,494.0 4,525.0 3,751.2 to 1C - 109L1 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd D -SAND LINER LEM 5.2 3.688 4,422.6 4,603.8 Liner Details 3,775.5 4.5 IBT CONDUCTOR, Top Depth 38 -158 (TVD) Top Inc! Nonni... 1 i 1 Top (ftKB) (ftKB) P) item Description Comment ID (!n) 4,422.6 3,711.7 65.26 PACKER "HRD" ZXP LINER TOP PACKER 4.940 4,441.4 3,713.7 63.64 SBE 190-47 SEAL BORE EXTENSION 4.940 GAS LIFT, { -� 4,461.1 3,723.8 64.95 X0 Reducing CROSSOVER (5.5" Hydril 563 x 4.5" IBT) 3.970 2.052 4,474.1 3,730.1 65.82 NIPPLE DB NIPPLE 3.750 4,483.5 3,734.4 66.44 HANGER LEM HH (above hook 10.61) 3.990 4,494.1 3,739.0 67.15 HANGER LEM HH (below hook 24.51 ") 3.688 PACKER, 2,176 4,563.3 3,763.3 71.75 NIPPLE 3.563" DB NIPPLE 3.563 4,595.8 3,773.1 73.92 LOCATOR 4.5" LOCATOR + X0 3.688 4,598.2 3,773.9 74.08 SEAL ASSY SEAL ASSEMBLY 5.60" w /2 SPACE OUT 3.000 Casing Description String 0... ing ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd GAS ..1;,; , B - SAND LINER I 4 1/2 I Str 3.958 I 4,597.1 7,483.0 I 3,793.4 I 1260 NSCT _ 2,289 Liner Details all Top Depth (TVD) Top Incl Nonni... um Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 4,597.1 3,773.5 74.00 PACKER BAKER MODEL 'SCR -1' LINER TOP PACKER 4.970 GAUGE, 4,306 4,601.9 3,775.0 74.32 MILLOUT MILL OUT EXTENSION 4.400 . 4,604.0 3,775.6 74.47 XO Reducing XO 5 x 4.5 4.500 4,680.9 3,791.3 81.73 SLEEVE BAKER CMD SLIDING SLEEVE 3.413 . 111 4,685.5 3,792.2 82.12 X0 Reducing 'XO 4.5X4" 4.000 INTAKE, 4,364 4,717.8 3,796.7 84.91 XO Enlarging X0 4 x 4.5" 4.500 SEAL, 4,368 Reduction, - 7,447.0 3,793.5 90.18 XO Reducing ' XO 4.5 x 4" 4.000 4,382 MOTOR,4,384 Set - r-1 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB (f ) 501 Depth ... Depth (TVD) ... String Wt... String ... String Top Thrd GAUGE, 4,392 UGC* TUBING 31/2 I 2.992 36.0 4,396.0 I 3,699.8 9.30 I L - 80 I EUE8RDMOD Centralizer, 4.394 1 I Completion Details Top Depth (TVD) Top Inc' N WINDOW L7, 4,494.4,525 - 4`^ Top (ftKB) (ftKB) ( °) Item Description Comment I (in) D - SAND LINER 36.0 36.0 0.41 HANGER VETOC GRAY TUBING HANGER 4.5 00 LEM, - 4,423 74.6 74.6 0.57 XO Reducing CROSSOVER, 4.5 x 3.5 2.992 PRODUCTION, 41 N, - 2,176.2 1,993.6 42.23 PACKER ESP FEED-THRU PACKER, WEATHERFORD HYDROW II 3.250 • SLOTS, DUAL-STRING PACKER 4,982 -7,450 e-sAND LINER. 4,306.3 3,658.1 60.19 GAUGE WELLLIFT DISCHARGE GAUGE UNIT (S/N: 11937003) 2.992 .,,,. 4,513 4,363.8 3,685.7 62.70 INTAKE TTC RECEIVING X0 COUPLING w/ PERFORATED INTAKE 2.992 TD (1 0 07 7,510 (S/N:11990183) D - SAND LINER, 4,368.3 3,687.7 62.89 SEAL TANDEM SEAL SECTION. (S/N's: 11623189- B/116115891 - T) 4,493 - 7,513 . < 4,382.1 3,693.6 63.49 Reduction GEAR REDUCTION UNIT (S/N: 11965655) 4,383.9 3,694.3 63.57 MOTOR ESP MOTOR, 562MSP1 60/1240/29 (S/N: 12057562) 4,392.2 3,698.1 63.93 GAUGE WELLLIFT MOTOR GAUGE UNIT (S/N: 192 - 00766) 4,394.1 3698.9 64.01 Centralizer MOTOR CENTRALIZER. (P/N: C63569) Perforations & Slots Shot it Top (TVD) Btm (WD) Dens - Top (MB) Btm )ftKB) (9KB) (ftKB) Zone Date (sh.- Type Comment - 4,962 7,450 3,808.3 3,793.5 WS B, 1C -109 10/29/2001 99.0 SLOTS Slotted Liner Notes: General & Safety End Date Annotation .._ mol 11/10/2001 NOTE: MULTI - LATERAL WELL: 1C -109 (B- SAND), 1C -109L1 (D -SAND) _G 8/30/2008 NOTE: View Schematic w/ Alaska Schematic9.0 OPIO 1 Mandrel Details Top Depth Top Port )WD) Inc! OD Valve Latch Size TRO Run ii Stn Top (ftKB) (ftKB) ( °) Make Model (in) Sery Type Type lie) (psi) Run Date Com... J� 1 2,051.8 1,901.2 42.34 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 3/9/2012 2 2,289.1 2,077.3 41.34 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 3/9/2012 1 ! 1C-109 Pre -Rig Well Work DATE SUMMARY 12/28/11 ,PRE RWO T -POT BONNETRSSED ), T -PPPOT BONNET ( PASSED ), -POT UPPER BODY ( PASSED ), T -PPPOT UPPER BODY ( PASSED ), T -POT LOWER BODY ( PASSED ), T -PPPOT LOWER BODY ( PASSED ), GLS TEST ( PASSED ), GLS -PP TEST ( PASSED ), FT -LDS, LDS © 6:00 FROZEN REST ALL NORMAL. 2/9/12 PULLED 4 1/2 SLIPSTOP © 4199' SLM, SET 4 1/2 CATCHER @ 4197' SLM, REPLACED SOV @ 4168' RKB w /DV, RDMO TO SPOOL NEW ,125 WIRE, IN PROGRESS. 2/10/12 PULLED 4 1/2 CATCHER © 4194' SLM, PULLED 4 1/2 D &D PACK OFF ASSY', KOBE SHEARED @ 4199' SLM, PULLED 4 1/2 TTCESP P- 18,G42, VORTEX GAS SEPARATOR, ( 37'9 "OAL) COMPLETE. LITTLE RED PUMPED 225 HOT DIESEL DOWN IA AND 67 HOT DIESEL DOWN TUBING. CALLED IN FOR BPV. • • ConocoPhillips Time Log & Summary WelNiew Web Reporting Report Well Name: 1C -109 Rig Name: NORDIC3 Job Type: RECOMPLETION Rig Accept: 3/4/2012 10:00:00 AM Rig Release: 3/11/2012 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/04/2012 24 hr Summary Move Rig over 1C -109. Rig accepted at 10:00 hrs. Berm, level, and shim up Rig. MIRU support equipment. Fill Pits with Sea Water. RU and PT Lines. Circulate well. Shot Fluid level. Install BPV 08:00 15:00 7.00 MIRU MOVE RURD P Shuffle rig mats from 1C -102 to 1C -109. Move in and set rig down over 1C -109. Berm up and spot auxiliary equipment. Accepted Nordic Rig 3 at 10:00 hrs on 3-4 -12 15:00 16:00 1.00 MIRU MOVE OTHR P Load Pits with kill wt fluid 16:00 17:00 1.00 COMPZ WHDBOMPSP P PU and RU lubricator. Pull 4 "'H' BPV and lay down lubricator. 17:00 17:30 0.50 COMPZ WHDBO PRTS P MU kill line to rig and PT at 250 / 3,000 psi. 17:30 19:30 2.00 COMPZ WELCTI KLWL P Open up well 0 psi TBG and 600 psi IA. Notify DSO and Security prior to venting gas and vent gas as planned from IA. Bleed IA down to 80 psi. 19:30 21:30 2.00 COMPZ WELCTL KLWL P PJSM- Circulate down IA 160° seawater w/ 3% KCI, 6 bpm, 150 psi ICP, 60 bbls away down IA and getting diesel returns to surface, 220 bbls down IA, 56 bbls return < 80 %, pump 95 bbls down TBG 6 bpm, 150 ICP, 220 FCP, no returns, Pump 25 BBLS down IA 6 bpm, 220 ICP, 300 FCP, 18 bbls clean returns, shut in and monitor for flow, TBG / IA both on vac. 21:30 22:30 1.00 COMPZ WELCTI KLWL P Monitor for flow, TBG / IA both static 22:30 22:45 0.25 COMPZ WELCTI KLWL P PJSM with Well Integrity Rep. shooting fluid level. 22:45 23:30 0.75 COMPZ WELCTI KLWL P TBG / IA 0 psi. Shoot first fluid level at 720 -ft MD, monitor well for 30 minutes, shoot second fluid level at 780 -ft MD, well taking fluid at 5.5 bph. confer with town engineer. 23:30 00:00 0.50 COMPZ WHDBO THGR P PJSM- Lubricate and set 4" Type "H" / BPV. �/ 03/05/2012 ND Tree. Install blanking plug. NU BOPE. Preform initial BOPE test 250/3000. Pull Blanking plug and BPV. Install isolation sleeve. Shoot fluid levels. Prep for de- complete. MU landing joint. 00:00 00:15 0.25 COMPZ WHDBO SFTY P PJSM- Discuss hazards to nipple down tree and NU BOPE 00:15 01:15 1.00 COMPZ WHDBO NUND P ND Tree. Inspect threds, install blanking plug Page 1 of 6 lime Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 04:00 2.75 COMPZ WHDBO NUND P NU 13 -5/8" BOPE. 2 -3/8" Solids UPR, 2 -7/8 "- 5 -1/2" variable LPR's. 04:00 12:30 8.50 COMPZ WHDBO BOPE P Conduct Initial BOP test at 250 / 3,500 psi with 2 -3/8 ", 3 -1/2" and 4 -1/2" Test joint. Test 3 -1/2" 8rd and 4 -1/2" NSCT FOSV and associated BOP equipment. Test upper and lower kelly valve 250/3500, good test. all alarms checked, koomey draw down tested good, rig down test equipment. Went off Cold Weather Restriction at 09:00 hrs - Continue loading equipment on rig 12:30 18:00 5.50 COMPZ RPCOM OTHR P Loading Pipe shed with 31/2 Recompletion string and 2 3/8 clean out string, Rack and Tally. Baker tools and Centrilift ESP equipment. Shoot fluid level on IA at 1,124 -ft, RU circulating hoses. 18:00 19:30 1.50 COMPZ RPCOM THGR P Pull blanking plug and BPV, set isolation sleeve, MU landing joint to TBG hanger. RU circulating hoses. 19:30 20:00 0.50 COMPZ RPCOM CIRC P Circulate 78 bbls filtered KWF down IA, no returns, TBG and IA both on vac 20:00 22:00 2.00 COMPZ RPCOM OWFF P Monitor well for flow, TBG 0 psi and static, IA on vac, shoot fluid level on IA at 53 -ft and TBG at 863 -ft, let IA go static (1 hr 20 min) shoot IA fluid level at 786 -ft, TBG fluid level at 909 -ft. Confer with town engineer, 20 bph hole fill, triple displacement every 5 stands pulled. Cold weather restriction in effect as of 23:00 hrs. -37 amb. 22:00 00:00 2.00 COMPZ RPCOM OTHR P RD circulating equipment. RU floors for de- completion. Spot Heat Trace spool. RU ESP spool safety devices. 03/06/2012 BOLDS. Pull TBG hanger to Floor. RU Cable to spooler. Pull 4 -1/2" ESP completion standing 4 -1/2" tubing back. Clean and clear floors. Load out ESP de- completion. MU and TIH with 7 -5/8" casing scraper / clean out assembly BHA #1. 00:00 00:15 0.25 COMPZ RPCOM SFTY P PJSM- Discuss procedures and hazards for pulling ESP completion. 20 bph hole fill and triple displacement every 5 stands pulled. 00:15 01:30 1.25 COMPZ RPCOM THGR P BOLDS. un -land tubing hanger with 190k, pull tubing hanger to floor, up wt 110k, lay down tubing hanger. Page 2of6 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 12:30 11.00 4,315 0 COMPZ RPCOM TRIP P POOH w/ 4 -1/2" tubing. Run ESP cable and heat trace cable over sheaves to spools. Stand back tubing in derrick for work string. Continue to POOH w/ 4 -1/2" ESP completion standing back 4 -1/2" tubing in derrick, keeping accurate account of clamps / bands recovered, spooling ESP / Heat Trace and I -TEC wire. Found water and oil in Tandem seals and motor sections. Scale build up on ESP components. Clamp count recovered: 460 -5 -ft Mid Joint Dual Channel 3 -4 -ft Mid Joint Dual Channel 13 -3 -ft Mid Joint Dual Channel 1 End Shoe Clamp 100 Dual Channel 26 Single Channel 8 SS Bands 2 Flat Guards 3 Protectolizers 12:30 18:30 6.00 0 0 COMPZ RPCOM OTHR P Clean and clean Floor. Off load ESP components, Clamps, Heat trace and I -Tec wire. Change over to 2 3/8 TBG handling equipment. Re -load ESP Completion components. Set wear ring. 18:30 20:00 1.50 0 0 COMPZ WELLPF SFTY P PJSM with Crane Operator. Discussed the planned ESP Spool swap -out. Perform ESP Spool exchange with out any problems. 20:00 20:30 0.50 0 0 COMPZ WELLPF RURD P Rig up floor to handle 2 3/8" Tubing. 20:30 00:00 3.50 0 2,571 COMPZ WELLPF PUTB P PJSM. Make -up Mule Shoe. Single in with 2 3/8" Tubing from the Pipe Shed to 2,571 -ft. Up Weight = 50K. down Weight = 50K. 03/07/2012 Continue to pick -up Clean -out BHA. Clean out the B -Sand Lateral down to 7,480 -ft. TOOH. PU and beginTlH with Test Packer and Retrievable Bridge Plug. 00:00 00:30 0.50 2,571 3,080 COMPZ WELLPF PUTB P Finished picking up the 2 3/8" Tubing from the Plpe shed (96 jts). 00:30 02:00 1.50 3,080 3,109 COMPZ WELLPF PULD P Change floor equipment to make -up the the 7 5/8" Casing Scraper, 4 3/4" Bumper Sub, 4 3/5" Oil Jar section of BHA #1. 02:00 03:00 1.00 3,109 3,570 COMPZ WELLPF PUTB P Continue to single in with 4 1/2" NSCT Tubing from Plpe shed (15 Jts). Page3 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 06:30 3.50 3,570 4,667 COMPZ WELLPF TRIP P Continue tripping in with 4 1/2" NSTC Tbg stands from the Derrick. Passed through the ZXP Packer at 4,423 -ft with no problems. continue easing through the LEM Liner compountants. Tagged up at 4,588 -ft. Bring Pump on line 3.0 bpm /450 psi. Got returns, being washing through fill from 4,588 -ft. to 4,667 -ft 06:30 11:00 4.50 4,667 7,475 COMPZ WELLPF TRIP P RIH f/ 4,667 -ft to 4,760 -ft, Reverse Circulate @ 5 bpm at 240 psi for 3 TBG Volumes. Continue to RIH to 7,475 -ft and Tag up. PU 10 -ft off tag. 11:00 13:00 2.00 7,465 7,465 COMPZ WELLPF CIRC P Clear TBG at 3 bpm at 500 psi. Reverse circulate 235 bbls at 5 bpm at 180 ICP 400 FCP Returning 1 bbl for 5 bbls pumped. 13:00 15:00 2.00 7,465 7,465 COMPZ WELLPF OWFF P Blow down top drive. Monitor well for 1 hr. Shhot fluid level twice - FL © 282 -ft. 15:00 17:00 2.00 7,465 3,108 COMPZ WELLPFTRIP P POOH w/ 4 1/2" 12.6# NSCT TBG from 7,465 -ft to 3,108 -ft. 17:00 22:30 5.50 3,108 0 COMPZ WELLPF PULD P lay down 7 5/8 CSG Scraper assy and 96 jts of 2 3/8 PH -6 Clean -out String. Off-load Plpe Shed as needed. Clear and clean Floor. 22:30 00:00 1.50 0 305 COMPZ WELLPF TRIP P PJSM. Make -up BHA #2, Baker Retrievable Bridge Plug and Retrievamatic Packer. Begin to trip in with 4 1/2" Tubing from the Derrick to 305 -ft. Up and Down Weight = 43K. D3/08/2012 Continue of TIH withTest Packer and Retrievable Brid Plu Test Casing. TOOH and single down the 4 1/2" Tubing in the Pipe Shed. Pick -up and service the ESP Assembly. Start picking up the 3 1/2" Completion as designed. 00:00 04:30 4.50 305 4,410 COMPZ WELLPF TRIP P Finish trip in with the test Packer and Retrievable Bridge Plug from 305 -ft... Set RBP at 4,410 -ft. Fill hole (27 bbls, fluid lever was 1,750 -ft). 04:30 07:30 3.00 4,410 4,358 COMPZ WELLPF PRTS P Perform a quick visual test against the RBP to 500 psi. Good. Set Packer at 4,358 -ft. Pressure test down the Tubing against the RBP at 1,500 psi x 15 minutes. - good test. Pressure test IA at 3,000 psi for 30 minutes. Good test. Release test packer and RIH, engage RBP and release same. 07:30 12:30 5.00 4,358 0 COMPZ WELLPF PULD P POOH laying down 41/2 12.6 #, L -80 NSCT Tubing, Test packer and RBP. 12:30 13:30 1.00 0 0 COMPZ WELLPF OTHR P Change over to 31/2 TBG equipment and RU to PU ESP equipment Page 4 of 6 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 00:00 10.50 0 2,117 COMPZ RPCOM RCST P PJSM. MAke -up ESP Motor, Seal Section. Service same. Make -up TECH Wire and attach ESP Cable. Test same. Good. Begin to single in the Completion with 3 1/2 ", 9.3 lb /ft, L -80, EUE 8rd Tubing from the Pipe Sled to 2,117 -ft. Up Weight = 61K. Down Weight = 59K. Install Clamps per procedure. Check ESP Cable every 1,000 -ft. 03/09/2012 Continue to single in the 3 1/2" ESP Completion. MU and Land Tbg Hanger. RU S -Line. Set WRP. Load IA w /Gel Diesel. Set and test Pkr. Pull DV. Freeze Tbg. Set DV. PT Tbg. RD S -Line. 00:00 00:30 0.50 2,117 2,180 COMPZ RPCOM RCST P Continue to pick -up the 3 1/2" Completion. Pick -up the Lower GLM w /Dummy Valve. Pick -up the Weatherford Hydrow II Dual- String Packer. 00:30 04:00 3.50 2,180 2,180 COMPZ RPCOM OTHR P Make the bottom and top ESP Splice through the Feed -Thru Packer. Test ESP Cable. Good. 04:00 08:30 4.50 2,180 4,318 COMPZ RPCOM RCST P Install the Upper GLM w /Dummy Valve. Continue to single in with the 3 1/2" Completion as designed from 2,180 -ft to 4,318 -ft 92K up wt, 72k do wt. 08:30 13:00 4.50 4,318 4,400 COMPZ RPCOM THGR P MU hanger and make Final splicew/ ESP Cable - Good test. Land hanger with Centralizer at 4,400 -ft. and Run in lock down screws. Pressure test pack offs at 250/5,000 psi good test. Drifted TBG,GLMS & hanger to 2.867 ". Use Jet Lube to each joint end. Torque TBG to 2250 ft -lbs. Installed (4) Seal Clamps across Tandem Seal Section Assembly. Installed (3) SS Flat Bands on DGU. Installed (81) 3500A Single Channel & (1) 4500 Cross Coupling Cannon Clamp on every other joint from MLE splice to surface. 13:00 19:00 6.00 0 0 COMPZ RPCOM SLKL P PJSM with Slick line crew. Load lubricator and surface control equipment in pipe shed. RU Slick line and mu blind box on kick over tool. PT lubricator at 500 psi. Rih and locate lower GLM at 2,282 -ft SLM. POOH and MU DGU and WFT WRP. RIH to 2,324 -ft, load TBG w/ 30 t bbls Neat diesel. Wait for DGU timer to fire and set WRP. POOH MU and Rih w/ 30" catcher sub and set on top of WRP, 2,302 -ft SLM. POOH and RD slick line. Page 5 of 6 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 20:30 1.50 0 0 COMPZ RPCOM PACK P Pump 78 bbls of Gelled Diesel down the 7 5/8" x 3 1/2" Annulus. Pump stright diesel down the Tubing (1 bb) and begin the Packer setting sequence. Set the Feed -Thru Weatherford Hydrow II Packer in 500 psi steps up to 3,000 psi. Hold the 3,000 psi x 15 minutes. Good. Bleed pressure to ")" psi. Pressure up on the 7 5/8" x 3 1/2" Annulus to 1,550 psi x 30 minutes. (lost —100 psi in 30 minutes). Good. Record tests on Chart. 20:30 00:00 3.50 0 0 COMPZ RPCOM OTHR P Begin the bleeding down the 7 5/8" x 3 1/2" Annulus following the decompression schedule as per program. 03/10/2012 Nipple down BOP Stack. Nipple up Tubing Adaptor and Tree.Test Tree. Perform final ESP Cable check. Pull TWCV and Install BPV. Secure Cellar. Prep to release Rig. 00:00 01:00 1.00 0 0 COMPZ WHDBO MPSP P PJSM. Set Back Pressure valve. 01:00 10:00 9.00 0 0 COMPZ WHDBO NUND P Remove Ram Blocks from the 13 3/8" BOP. Inspect and prep for storage. Nipple down BOP Stack. and prep for setting on Skid. 10:00 11:00 1.00 0 0 COMPZ WHDBO OTHR P Meg ESP cable pre nipple up of bonnet 11:00 11:30 0.50 0 0 COMPZ WHDBO NUND P NU Vetco Gray 41/16" 5M x 13 5/8" 5M TBG Bonnet. Test Bonnet at 250/5,000 psi. 11:30 12:30 1.00 0 0 COMPZ WHDBO MPSP P Pull BPV / Run TWC with dry rod 12:30 13:15 0.75 0 0 COMPZ WHDBO PRTS P Test tree at 250 / 5,000 psi, 13:15 14:15 1.00 0 0 COMPZ WHDBO MPSP P Pull TWC / Run BPV with dry rod 14:15 15:00 0.75 0 0 COMPZ WHDBO OTHR P Meg ESP cable Post nipple up of bonnet 15:00 21:30 6.50 0 0 COMPZ MOVE RURD P Prep for moving rig off well. 21:30 22:00 0.50 0 0 COMPZ MOVE RURD P Move off of Well. (Note: Pad Operator was present). 22:00 00:00 2.00 0 0 COMPZ MOVE RURD P Load out 13 5/8" 5K BOP Stack on skid. Secure and clean Cellar. 03/11/2012 Install the 13 5/8" BOP Stack on transport skid. Install the 11" BOP Stack on Sub - Structure Stump. Wait on Power Company to de- energize an electrical line. Wait on Snow Removal to open access road leaving C -Pad. Release Rig. 00:00 06:00 6.00 0 0 COMPZ MOVE RURD P Complete loading out the 13 5/8" 5K BOP Stack onto the transport skid. Load the 11" 5 K BOP Stack on the Sub - Structure Stump. Nordic 3 released 06:00 hrs on 3- 11 -12. Page 6 of 6 Page 1 of 1 • • Maunder, Thomas E (DQA) From: Maunder, Thomas E (DOA) Sent: Monday, September 29, 2008 10:44 AM To: 'Gauer, Cody' Subject: RE: 1C-109 (201-203) Workover Thanks Cody. This fills in the missing days. Tom Maunder, PE AOGCC From: Gauer, Cody [mailto:Cody.Gauer@conocophillips.com] Sent: Monday, September 29, 2008 10:39 AM To: Maunder, Thomas E (DOA) Subject: RE: 1C-109 (201-203) Workover ~.~kt~d~j.: ~`~i=~ rya ~ ~0~8 Tom, The reason for the workover was to replace a failed ESP. There was a concentric coil cleanout performed while the rig was off the well. I have attached the Daily reports to reflect that. Do you need another form of documentation? Cody Gauer Performance Engineer ConocoPhillips Alaska,Inc. 907-263-4802 -office 907-S7S-5407 -mobile Cody.Gauer(~ConocoPhil lips.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, September 29, 2008 10:12 AM To: Gauer, Cody Subject: iC-109 (201-203) Workover Cody, I was reviewing the 404 for the work recently performed on this well and had a couple of questions. 1. What was the reason for the workover? 2. It appears that there was a rig work interruption befinreen noon 8/13 and noon August 18. There is a comment about concentric coil on the initial entry on 8118. If there was work conducted during the break, then the appropriate reports documenting the operations should be provided. Email is fine. Thanks in advance, Tom Maunder, PE AOGCC 9/29/2008 ft~~~l ~/ CL,J • STATE OF ALASKA ~ O~$ CEP 0 4 2 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERgTIO,R~ca Oi- & Gas Cons. Commission 1. Operations Performed: Abandon ^ Repair Well ^~ Plug Perforations ^ Stimulate ^ Other ` Alter Casing ^ Pull Tubing ~ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhlllips Alaska, InC. Development ~ Exploratory ^ 201-203 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23047-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 40' 1 C-109 ' 8. Property Designation: 10. Field/Pool(s): ADL 25649 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 7510' feet true vertical 3793' ' feet Plugs (measured) Effective Depth measured 7510' feet Junk (measured) true vertical 3793' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 118' 16" 158' 158' SURFACE 4836' 7-5/8" 4938' 3808' PRODUCTION 2886' 4-1/2" 7483' 3793' Perforation depth: Measured depth: slotted liner pert from 4965'-7450' true vertical depth: 3808'-3794' Tubing (size, grade, and measured depth) 4-1/2", L-80, 4315' MD . Packers 8 SSSV (type & measured depth) no packer 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 182 7 9 -- 211 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: OiIO 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 Cody Gauer @ 263-4802 Printed Name Cody auer Title Ph 263 4802 Wells Engineer ~~3/b ~ > ~C D t ! ~- Signature one: - ~~ a e , Pre red b h r n All u -Drake 263-4612 Form 10-404 Revis~ed~00~16^ ~ ~ ~, i H L ?' `r/ o$ Submit Origin~nl~ j~ - f KUP ~~~~~~~~~~~~~5 ~ `, Well Attributes null uWl 5002923047 Comment H: ... ' u 'SSSV: NONE J , .,.~ ~... -.. ~i 4nnotation Depth IR Last Tag: Casino Strings 1 C-109 Frem Name W 11 Status Maxi mum Inclination I/ Tmal Depth (tthBj WEST SAK __1PROD 92.83 7,525.0 tm) Date :A of lion End Date KB-Grountl Distance lR) Rig Release Date 0 ~ 7/1/2008 -Last WO: ~ 8/21/2008 45.45 11/10/2001 End Date Annotation Entl Date Rev Reason WORKOVER, GLV C/O 8/22/2008 Gaang Desunpnun uDl,nj ID I,nj ~, Tuy IRN6j Set Depth lh.. SetDrylh jl V'D/Ih.. Wliltrtx... liratle Tap GOnneelron CONDUCTOR 16 15.062 ~ 0.0 158.0 158.0 82.00 WELD Casing Description OD (in) ID (in) Top IRKB) Set Depth IR.. Set Depth (ND) IR.. Vyt (Iba/... Grade Top Connecton WINDOW L1 6 5.000 4,494.0 4,525.0 3,751.2 to 1C-109Li Casing Description OD lin) ID lin) Top IRKB) Set Depth IR.. Set Depth (ND) (R.. Vyt (Iba/... Grade Top Connecton LINER D TOP 4 1/2 3.958 i 0.0 4,550.0 3,759.5 12.60 L-80 ~ BTC Casing Description OD (in) ID (in) Top IRKB) Set Depth IR.. Set Depth (ND) (R.. Vyt pBa/... Grade Top Connection LEM L7 5.2 3.688 4,422.6 4,603.8 3,775.5 4.5IBT Casing Description OD (in) ID (in) Top IRKB) Set Depth IR.. Set Depth (ND) (R.. Vyt (Ibs/... Grade Top Connection PRODUCTION 75/8 6.875 0.0 4,938.0 3,807.6 27.00 L-80 ~ BTC Casing DesMptlon OD lin) ID (in) Top IRKB) Set Depth (R.. Set Depth (ND) IR.. Vyt (Ibs/... Grade Top Connection LINER B i 4 1/2 3.958 4.962.0 7.450.0 3.793.5 12.60 NSCT 7ubin_g Strings T bmq Desniptgn iUDl~n) i1D lrnl IoP Ih aetlxpth lnK... iSel Depth ITVDI ItdIBi Wlllbs/ill rode Tiiy wnneclron TI IF I'li.~ 1 1 ~ ~ _„ J:, .. ,. L--'(1 11 ~:1:7 Completion Details I op p[nn) Imn: uescnpnon Gommen[ lu pn) 36.6 HANGER Hanger 4.600 4,222.7~DISCHARGE Phoenix Discharge Pressure Sub 3.948 4,270.61X0 INTAKE TTC Crossover Coupling wfPerforated Intake 4,280.2SEAL Tandem Seal Section, P/N # CSE6878SA 4,294.OMOTOR ESP Motor 190 Hp KMH 2415V/48A, PIN #0215036906 4,310.9GAUGE tPhoenix MS-2 Gauge 4,313.O~CENTRALIZER Motor Centralizer Perfora6lJna Top Btm I ihol ~ Top Btm (ND) (ND) ! Dens (RKB) (RKB) (RKB) (RKB( i Type Zone Ish°°~ Date ( Comment 4,962.01 7,450.0 3,808.3 3,793.SISIOtted WS 8, 1C-109 99.010129/2001 PERFS thru slotted liner Notes: General 8 Safety ...... Eno Date auwoltou I 1117012001 NOTE: MULTI-LATERAL WELL: 1C-109 (B-SAND), 1C-109L1 (D-SAND) Mandrel Details i ~ SeC Deplh I I Furl ~ ~ Top ITVDI Valve Latch Size i IRKB) IRKB) Make ~ Model ODlin) TYPe LTYPe lin) '. Stn TRO Run k (Psi) Run Date Comment _ _ 2,760.4 3,662.6 CAMCO IKBG-2-1R 1 DMV '~.BK-5 0 0.0~&2112008 2 4,168.8 3,662.6 CAMCO ~KBG-2-1R 1 DMY BK-5 0; 0.0 8/21/2008 • a Cor~o~oPhilips Time Log & Summary W2fJview Web Rep°ritng Report - _ ____ - . Well Name: 1C-109 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 8/18/2008 12:00:00 PM Rig Release: 8/21/2008 12:00:00 PM Time Logs _ __ _ __ Date From To Dur S. Depth E Depth Phase Code Subcode T Comment 8/06/2008 z4hrsummarv Release Nordic Rig 3 from 1C-135 @ 23:59 hrs on 8-5-08. Move Nordic rig 3 to 1C-109. MIRU and berm up. Accept rig and Pull BPV. Open up well and Circ w/ seawater and kill well, no losses. Install BPV and ND Tree and NU BOPE. Test BOPE 00:00 01:30 1.50 MIRU MOVE MOB P Set Mats and Move Nordic Rig 3 in to 1 C-109. MIRU MOVE Accept Nordic Rig 3 @ 01:30 hrs on - -08 01:30 02:30 1.00 MIRU MOVE RURD P Spot rig over well and Set down on mats. Berm u . 02:30 04:30 2.00 COMPZ RPCOM OTHR P Lubricate out BPV, Tie in circulating lines to Tree. Open up well SITP 450 si; SIIAP 500 si. 04:30 05:00 0.50 COMPZ RPCOM SFEQ P PT surface lines. 05:00 08:00 3.00 COMPZ WELCTL CIRC P Circulate well w/ 285 bbl of 6% KCL SW, 2 b m 280 si. No losses 08:00 09:00 1.00 COMPZ RPCOM OWFF P Monitor well for 30 min. Slowdown lines. 09:00 11:00 2.00 COMPZ RPCOM PULD P PJSM, load ESP equipment with crane 11:00 12:00 1.00 COMPZ RPCOM OTHR P RD cellar lines, set BPV 12:00 18:00 6.00 COMPZ RPCOM NUND P ND tree, install test plug into hanger. PJSM, NU BOPE. CO upper pipe rams to 2-7/8" x 5-1 /2" variables. 18:00 00:00 6.00 COMPZ WELCTL BOPE P PJSM, ressure test BOPE 250/3000 psi, annular 250/25~Q,p~j. 24 hr Notification was given @ 1900 hrs and return call was @ 1910 hrs on 8-5-08. Jeff Jones asked for 2 hr notice prior to conducting BOPE Test. Update was given @ 1600 hrs on 8-6-08. Test was not witnessed b AOGCC Re . 8/07/2008 Continue to pressure test BOPE 250/3000 psi, annular 250/2500 psi. 24 hr Notification was given @ 1900 hrs and return call was @ 1910 hrs on 8-5-08. Jeff Jones asked for 2 hr notice prior to conducting BOPE Test. Update was given @ 1600 hrs on 8-6-08. Test was not witnessed by AOGCC Rep. Pull blanking plug and BPV. Install ISO sleeve and Landing jt. Unland hanger -Pull allowable Max on 4.5 tbg. Circ. 50 bbls of hot diesel followed by 160? seawater, no losses. Work stuck pipe free. RU ESP equip. and POOH w/ ESP decom letion. Page 1 0# 9 • Time Logs _ __ __ Date From To Dur S- Depth E. De th Phase Code Subcode T Comment 00:00 01:00 1.00 COMPZ WELCTI BOPE P PJSM, pressure test BOPE 250/3000 psi, annular 250/2500 psi. 24 hr Notification was given @ 1900 hrs and return call was @ 1910 hrs on 8-5-08. Jeff Jones asked for 2 hr notice prior to conducting BOPE Test. Update was given @ 1600 hrs on 8-6-08. Test was not witnessed b AOGCC Re . 01:00 02:30 1.50 COMPZ RPCOM OTHR P Pull Blanking plug, Pull BPV, Install Isolation sleeve. MU Landin Jt. 02:30 03:00 0.50 COMPZ RPCOM SFTY P Held PJSM w/ rig crew, LRS, Vetco Gra and Centrilift. 03:00 03:30 0.50 COMPZ RPCOM SFEQ P PT line to Tiger Tank to 1,000 psi. PT CMT line and LRS to 2,500 si. 03:30 04:00 0.50 COMPZ RPCOM OTHR P Unland hanger @ 180k and uII~Q, 200k w/ 44" of stretch. Continue to _maintain_ 200k while circulatino. no losses. 04:00 07:00 3.00 COMPZ RPCOM CIRC P Circulate w/ 50 bbls 130? Diesel @ 2 bpm @ 620 psi followed by 160? seawater @ 2 bpm - w/ 18 bbls seawater away pressure declining. Continue to circulate diesel from well bore to tiger tank, no losses. RD hoses, blow down kill tank lines. 07:00 08:30 1.50 COMPZ RPCOM OTHR P PJSM. Pull up 200K, establish circulation down the tbg and up the IA 6 bpm @340 psi. Stop pumping, close annular, pump down the tbg and pressure up tubing and IA to 2000 psi. Dump pressure from the IA side. Qpen annular and pull up 15', u wt 110K. 08:30 00:00 15.50 4,297 0 COMPZ RPCOM PULD P Monitor well. RU ESP cable and heat trace sheaves. Pull hanger to the floor and lay down. POOH with 4-1/2" completion. Stand back 4-1/2" completion. Clamp count pulled: 18 x Single Channel xcplg clamps, 96 x Dual Channel xcplg clamps, 46 x 2' Mid jt Dual Channel xcplg clamps, 27 x 3' Mid jt Dual Channel xcplg clamps, 25 x 4' Mid jt Dual Channel xcplg clamps, 445 x 5' Mid jt Dual Channel xcplg clamps, 3 x ESP Protectrolizers, 2 x Flat Guards. ESP Feild report -Top pump spun, Bottom 2 did not. Tandem seal section was pressurized, ESP Cable Checked good. Motor was grounded w/good oil in bottom and no oil @ to . ~_„~__.~ Page ~ caf ~ C~ Time Logs ___ Date From To Dur S. Depth E. Depth P h ase Code Subcode T Comment _ 8/08/2008 _ _ 24 hr Summary Clear and clean rig floor and pipe shed. PU and Rih w/ 3 1/2 mule shoe on 3 1/2 IBT and xo to 3 1/2 IF DC's followed by 3 1/2 DP to 4,252' and begin washing down @ 6 bpm @ 570 psi and reverse circulating @ 5 bpm @ 480 psi. Wash down to 4,628' and reverse circulate and sweep hole w/ hi visc sweep to clean well bore of fine silt sands. Total losses to well bore toda was 847 bbls. Total losses to date 847 bbls. 00:00 03:30 3.50 0 0 COMPZ RPCOM OTHR P Box and send out all cannon clamps, wrap spools w/absorb and shrink wrap -prep for shipping. Clean and clear rig floor. Prep for mule shoe clean out run. 03:30 05:00 1.50 0 477 COMPZ RPCOM RURD P PJSM w/ rig crew on picking up and Rih w/Mules oe c can ou s nno. set wear bushin . CO floor to DP 05:00 10:30 5.50 477 3,481 COMPZ RPCOM TRIP P PU drill collars and RIH to 477'. RIH with 3.5" DP from 477' to 3481'. Up wt = 75K, do wt = 65K. 10:30 12:30 2.00 3,481 3,481 COMPZ RPCOM RURD P Crane arrived PJSM, remove ESP cables ooler/e ui ment. 12:30 13:30 1.00 3,481 4,252 COMPZ RPCOM TRIP P Continue RIH w/ 3.5" DP from 3481' to 4252'. Up wt = 100K, do wt = 75K. 13:30 16:30 3.00 4,252 4,478 COMPZ RPCOM FCO P Wash down from 4252' to 4478'. Up wt = 100K, do wt = 75K. Circ at 6 bpm @ 570 psi, rev circ at 5 bpm @ 480 si. 16:30 18:00 1.50 4,478 4,513 COMPZ RPCOM FCO P Tagged at 4478', washed thru from 4478' to 4481', start losing fluids. Rev circ at 5 bpm @ 170 psi, no returns. RIH, wash down to 4513' at 6 bpm. Returns back to surface at 1:2 ratio. Circulate bottoms up to circ out gas. Return ratio gradually increased from 50% to about 90%, 18:00 00:00 6.00 4,513 4,628 COMPZ RPCOM FCO P Continue to wash down f/ 4,513' to 4 455' and set down in CMU in "D" Lat. Pull up above Hook @ 4,493'. W_ ash down and entered Mother bow and wash to 4 628'. 31' inside "B" Lat. liner. Circulating @ 6 bpm @ 580 psi and reverse circulating @ 6 bpm @ 550 psi. Reverse circulate, Pump and chase hi visc sweep to assist in cleaning fine sands from well bore. Total losses to well bore today was 847 bbls. Total losses to date 847 bbls. 8/09/2008 Blow down TD and Pooh w/ C/O assy. RIH w/ Lateral nozzle assy and wash to 4,635' and POOH. RIH w/ LEM Dummy assy to 4,280'. Total losses to well bore toda was 716 bbls. Total losses to date 1,563 bbls. 00:00 02:30 2.50 4,628 478 COMPZ RPCOM TRIP P Pooh f/ 4,628' to 478'. 02:30 03:30 1.00 478 0 COMPZ RPCOM PULD P Stand back DC's and lay down 3 1/2 IBTM mule shoe ass . ParJe 3 ssf ~ l r ~ Time Low _ Date From To Dur___ _S_ Depth E. De th Phase Code Subcode T Comment 03:30 04:00 0.50 COMPZ RPCOM OTHR P Load and bring BHA equipment to rig floor 04:00 04:30 0.50 COMPZ RPCOM SFTY P Held PJSM w/ Baker and Rig crews 04:30 08:00 3.50 0 470 COMPZ RPCOM PULD P PU and MU Lat nozzle assy. Swap floor equipment. RIH with Nozzle, SB locator, lateral wash nozzle, Jars, DC and um out sub. 08:00 10:00 2.00 470 4,490 COMPZ RPCOM TRIP P RIH w/ 3-1/2" DP to 4490'. Up wt = 105K, do wt = 75K. Pump DP volume. 10:00 12:00 2.00 4,490 4,590 COMPZ RPCOM FCO P Wash down to 4603' pumping 5 bpm @ 420 psi. Pressure increase t~ 500 psi (nozzle inside Pumping 2 bpm @ 140 psi, wash down to 4635' pressure increased to 500 psi (seal assembly into SCR). Sit down 10K at 4640' (seal locator on top of SCR). Circulating 5 bpm, PUH 12' got hung up. Needed to rotate DP to free pipe. POOH tp 4590'. 12:00 13:30 1.50 4,590 4,590 COMPZ RPCOM CIRC P Circulate 2 annular vol. Bull head 40 bbl down the IA. 13:30 16:30 3.00 4,590 4,538 COMPZ RPCOM OTHR P POOH and hang up at 4538'. Try to rotate and work DP, could not work f_re_e,. Pumped 70 bbl of Safelube down the IA and spot accross the BHA. Able to rotate the DP free. 16:30 18:30 2.00 4,538 470 COMPZ RPCOM TRIP P POOH with 3-1/2" DP workstring to 470'. 18:30 19:00 0.50 470 0 COMPZ RPCOM PULD P POOH laying down Nozzle BHA 19:00 19:30 0.50 COMPZ RPCOM SFTY P Held PJSM w! Sperry, Baker and Rig crew on PU and MU of LEM dummy ass w/ MWD Tools. 19:30 20:30 1.00 0 115 COMPZ RPCOM PULD P Load LEM tools to for LEM Dummy run and PU and MU the same. 20:30 21:00 0.50 115 115 COMPZ RPCOM DHEO P Shallow test MWD @ 50 spm @ 120 - 480 si. 21:00 00:00 3.00 115 4,280 COMPZ RPCOM TRIP P RIH w/ LEM dummy assy to 4,280'. Total losses to well bore today was 716 bbls. Total losses to date 1,563 bbls. 8/10/2008 Continue to Rih w/ LEM dummy assy -not able to latch up as of fill. Pooh and change tail length. Parted below orient lug. Rih and fish out Parted TBG. RIH w/ string mill assy. Total losses to well bore toda was 594 bbls. Total losses to date 2,157 bbls. 00:00 02:00 2.00 4,280 4,582 COMPZ RPCOM TRIP P Continue to RIH w/singles f/ 4,280' to 4,582', Unable to get down w/ . LEM Bullhead 22 bbls @ 5 bpm @ 360 psi and attempt to work through. Unable to et down to latch u . 02:00 04:30 2.50 4,582 115 COMPZ RPCOM TRIP P Pooh f/ 4,582' to 115' rage4ot9 i Time Logs _ _ _ ________ _ _ _ Date From To Dur S Depth E. De th Phase Code S bcod_e _T_ Comment 04:30 05:30 1.00 115 0 COMPZ RPCOM PULD P Pooh w/ LEM BHA found to have arted last 7.79' of LEM below lug, 1 ~t. 4.5" IBT 12.6# TBG, 1- 4.5" IBT 12.6# Bent jt w/ mule shoe. Leaving 71' f .Estimated TOF @ 4,511'. Top of Hook Hanger 4,493', Bottom 4,511'. 05:30 09:00 3.50 0 0 COMPZ FISH WOEQ T Call out fishing tools to spear 4.5" 12.6 #IBT TBG. Clean floor, W.O.O., service T.D. W.O.T. 09:00 11:00 2.00 0 0 COMPZ FISH PULD P load fishing tools. MU fishing BHA/S ear. 11:00 13:00 2.00 0 4,438 COMPZ FISH TRIP P RIH to to 4438'. Up wt = 93K, do wt = 75K. 13:00 16:00 3.00 4,438 4,470 COMPZ FISH FISH P RIH to 4540, sat down 10K to latch fish. PUH, up wt = 98K. PUH to 4512', hang up, worked free. PUH to 4501' and hang up. Unable to work free. Pumped 70 bbl of Safelube and spot it across the fish. Work® ed free and PUH to 4470' and han u . Attempted to work free, but could not. Placed the string into 15K tension and rotated to the right and came free. POOH with u wt of 98K. 16:00 18:00 2.00 4,470 76 COMPZ FISH TRIP P POOH with 3-1/2" workstring. 18:00 18:30 0.50 76 0 COMPZ FISH PULL P POOH laying down fish. All recovered. 18:30 19:30 1.00 0 66 COMPZ FISH PULD P Prepare to RIH w/ 5.5" Smooth OD string mill. PU and RIH w/ milling BHA. 19:30 20:30 1.00 66 837 COMPZ FISH TRIP P RIH to 837' 20:30 22:30 2.00 837 837 COMPZ RIGMNT SVRG P PJSM, Cut and Slip Drill line, and service ri . 22:30 00:00 1.50 837 4,525 COMPZ FISH TRIP P Continue to RIH w/milling assy. 8/11 /2008 Dress Hook hanger, POOH. RIH w/ LEM Dummy #2, latch in & out to verify Top of Hook. POOH. RIH w/ LEM Completion assy. Total losses to well bore toda was 537 bbls. Total losses to date 2,694 bbls. 00:00 02:00 2.00 4,494 4,556 COMPZ FISH MILL P Tag and Rotate through f/ 4,499' U 4,503' and f/ 4,503' t/ 4,524' and ream back thru @ 50 rpm @ 2,220 to 5,100 ft/Ibs. @ 2 bpm @ 60 to 80 psi. Rot wt 83k @ 2,220 ft/Ibs free torque. up wt 95k do wt 73k Slide thru w/ 2k dra . 02:00 04:00 2.00 4,556 66 COMPZ FISH TRIP P Pooh w/dressing BHA. 04:00 05:00 1.00 66 0 COMPZ FISH PULD P POOH laying down dressing BHA. 05:00 06:00 1.00 0 0 COMPZ FISH OTHR P Unload all Baker fishing tools from i e shed and ri floor. 06:00 08:00 2.00 0 0 COMPZ RPCOM RURD P C/O muleshoe off bent joint, MU straight joint, MU LEM and MWD tool. Swa handlin a ui ment. ~- F'~g~ ~ cif 9 ~~ Time Logs Date From To Dur__ S Doh E. De th Phase Code Subcode T Comment____ _ ____ __ 08:00 10:00 2.00 0 4,593 COMPZ RPCOM TRIP P RIH to w/ 3-1/2" DP, shallow pulse test MWD at 850'. Copt RIH to 4494', tagged top of hanger, PUH and rotate and work through. Up wt = 93K, do wt = 73K. Continue in hole. 10:00 12:00 2.00 4,593 4,443 COMPZ RPCOM TRIP P BHA depth at 4539", orientation 125R (pumping 3 bpm @ 400 psi). LEM tagged hooked with bottom of BHA at 4552', sat down 20K, orientation changed to 101 R. PUH (no over pull) to 4520' and rotate to 145L. RIH to 4552', sit down 24K, orientation changed to 25R. PUH 25K over pull) to 4519" and rotate to 112L. RIH to 4552', sit down 25K, orientation changed to 27R. PUH 15K over ull to 4443'. 12:00 14:30 2.50 4,443 470 COMPZ RPCOM TRIP P POOH with 3-1 /2" DP, standing back. 14:30 15:30 1.00 470 0 COMPZ RPCOM RURD P RD MWD tool, LEM and straight 'oint. 15:30 17:30 2.00 0 0 COMPZ RPCOM OTHR P Load i e shed with LEM completion 17:30 18:00 0.50 0 0 COMPZ RPCOM OTHR P Remove 4.5 bent joint from com letion strip 18:00 20:30 2.50 0 190 COMPZ RPCOM PULD P PU and MU 4.5 completion string below LEM. PU and MU LEM w/ inner MWD strip . 20:30 21:00 0.50 190 190 COMPZ RPCOM OTHR P Change over to DP Equipment. 21:00 00:00 3.00 190 4,375 COMPZ RPCOM TRIP P RIH w/ LEM Com letion to 4 375' 90k u wt 75k do wt. 8/12/2008 Orient and latch in to hook and verify latch up. Set ZXP PKR and PT to 500 psi. Release off LEM completion and POOH LD DP. 00:00 01:30 1.50 4,375 4,604 COMPZ RPCOM PACK P Latch L M, w/ 75k do wt and un latch f/ hook w/ 120k up wt. 20k osw. S, et ZXP w/ 3 500 on Packer set Ca? 4,422'. PT to 500 psi on IA. Seals stabbed into SCR-1 PKR 4,600'. 01:30 08:00 6.50 4,422 0 COMPZ RPCOM TRIP P POOH laying down DP 08:00 10:00 2.00 0 0 COMPZ RPCOM RURD P C/O floor equipment, LD MWD and running tool, pull wear bushing, unload i eshed 10:00 11:00 1.00 0 0 COMPZ RPCOM PULD P !?U MU seals and completion 11:00 13:00 2.00 0 4,425 COMPZ RPCOM RCST P RIH to 4425' with seals and 4-1/2" tubing completion. Up wt = 82K, do wt = 72K. _ ~- ' _ F~~ b of 9 r Time Logs _ _ _ ____ _ ___ ___ Da e_ From To Dur S- De th E. De th Phase Code Subcode T Comment 13:00 16:30 3.50 4,425 COMPZ RPCOM HOSO P Tag at 4427' (inside the ZXP packer). Needed to rotate string several times and bump down to get past the tag. No go at 4444'. PUH to 4415', RIH and tag again at 4427 and worked through. No go at 4444', sit down 20K. Pressure up IA to 500 psi, strip up through the annular 11' before IA pressure dropped off. PUH and run_ s ace out u PU MU han er. 16:30 22:30 6.00 COMPZ RPCOM FRZP P Circ 115 bbl of diesel down the IA for freeze protect prior to landing the hanger for freeze protect. Bullhead 65 bbl of diesel down the tubing to balance the well and for freeze protect. Needed to allow the IA and tubin to u-tube and bled ressure. 22:30 00:00 1.50 COMPZ RPCOM HOSO P Set seal assembly in SBE, rigged up . and tested IA x tbg at 500 psi for 10. minutes. Test aood. Drained stack and landed 4-1/2" completion, RILDS. U wt 82K, dwn wt 72K. 8/13/2008 ND BOP's, NU tree and tested, installed BPV, released Nordic 3 rig at 12:00 hrs 8-13-08, RDMO 1C-109. 00:00 00:30 0.50. COMPZ RPCOM SFEQ P Tested upper and lower hanger seals at 250 and 5,000 si. Test ood. 00:30 09:00 8.50 COMPZ RPCOM NUND P install TWC. ND 13 5/8" BOPE. NU tree 09:00 10:00 1.00 COMPZ RPCOM SFEQ P Test void to 5000 psi, test tree to 5000 si 10:00 12:00 2.00 COMPZ RPCOM RURD P Lubricate out TWC. Install BPV. Release rig at 12:00 hrs. Tbg press = 0, IA ress = 0. 8/18/2008 Q~ ~ ~ ~c~ Accepted Nordic Rig 3 onto 1 C-109 on 8/18/2008 @ 12:00 noon, pulled SOV from GLM#1 @ 4376', set BPV, removed scaffolding, laved liner, double stacked rig mats on 1C-109, positioned rig over well, bermed up cellar, RU lubricator and pulled BPV, RU hardline to kill tank, tested same at 120 psi air and 500 psi water, loaded its with 8.8 6% KCL sea water. 12:00 20:00 8.00 0 0 COMPZ RPCOM WOEO X Accepted Nordic 3 riq _ 12:00 hrs 8-18-2 8. Waiting on concentric coil to mob off well location, slickline to pull SOV from GLM#1 @ 4376', set BPV, remove scaffolding, lay liner, double stack ri mats on 1C-109. 08:00 10:00 2.00 0 0 COMPZ RPCOM OTHR P Ramp up and position rig over well, berm u cellar. 10:00 11:00 1.00 0 0 COMPZ RPCOM OTHR P RU lubricator and pull BPV. 11:00 12:00 1.00 0 0 COMPZ RPCOM RURD P RU hardline to kill tank, test same at 120 psi with air and 500 psi with water, load pits with 8.8 ppg 6% KCL sea water. 8/19/2008 ND tree, NU and tested BOP, start decompletion 4 1/2" service string. 00:00 01:00 1.00 COMPZ RPCOM CIRC P RU circ lines and pumped 220 bbls down IA taking returns through tbg, 8.8 ppg 6% KCL seawater at 5 bpm. ICP 210 si, FCP 130 si. p~r~e 7 of 9 Time Logs ___ _ _ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 01:00 01:30 0.50 COMPZ RPCOM OWFF P Shut in and monitor well. No pressure, flushed hardline with 10 bbls fresh water and blew down hardline to kill tank, RD circ lines.. 01:30 02:00 0.50 COMPZ RPCOM OTHR P Installed BPV. 02:00 03:00 1.00 COMPZ RPCOM NUND P ND tree and hang. off in cellar. 03:00 11:00 8.00 COMPZ RPCOM NUND T Dressed inner hanger neck, installed 4.909" test dart, NU 13 5/8" BOP and function test. Leaking around wellhead flan e. 11:00 14:30 3.50 COMPZ WELCTL BOPE T ND stack at wellhead flange. Inspect ring gasket and found two bad spots. Inspected wellhead groove and spool groove. Cleaned and replaced BX 160 rin asket. NU BOPE a ain. 14:30 19:00 4.50 COMPZ WELCTL BOPE P Test ROPE 250/3000 pS1. Testing witnessed by John Crisp (AOGCC), remove test dart and BPV. 19:00 20:00 1.00 COMPZ RPCOM RURD P Install isolation sleeve in hanger, MU landin ~nt and head in, BOLD's. 20:00 21:00 1.00 COMPZ RPCOM CIRC P Pull hanger to floor, 82K up wt, and break circ staging up to 3 bpm 60 psi, never got returns, after hole fill and attem ted circ -lost 133 bbls shut down um s. 21:00 22:00 1.00 COMPZ RPCOM RURD P RD circ lines and head pin, LD landin 'nt and han er. 22:00 00:00 2.00 4,372 1,491 COMPZ RPCOM TRIP P POOH with 4 1/2" NSCT service strin from 4 372' to 1,491' standi~ back tubin .Drifted and strapped while standing back. Total fluid loss = 249 bbls for last 24 hrs. 8/20/2008 RU and RIH with 4 1/2" ESP completion to 4,272', cut cables and spliced to connectors. 00:00 02:00 2.00 1,491 0 COMPZ RPCOM TRIP P Cont POOH with 4 1/2" service string standing back and drifting NSCT, LD IBT, mandrel and seal assembl . 02:00 03:30 1.50 0 0 COMPZ RPCOM RURD P R run ESP on 4 1/ "NSCT, load um com onents. 03:30 09:30 6.00 0 3,032 COMPZ RPCOM RCST P PU motor centralizer, Guardian sensor, and motor. Serviced motor. PU Tandem Seal Section and service. RU cable over sheave and secure motor lead. MU TTC Xover/intake. RIH with 4 1/2" completion, installling Phoenix MS-2 ag ucae and splice into TEC wire, as per procedure & tally, performing electrical inspections/tests on cable eve 1000'. 09:30 21:00 11.50 3,032 4,240 COMPZ RPCOM RCST P Start Heat Trace @ approximately 3032'. Continue RIH w/ESP Completion, performing electrical inspections/tests on cable every 1000'. Page ~ csf ~ ~~ • Time Logs Date From To Dur S De,~th E Depth Phase Code Subcode T Comment____ 21:00 22:00 1.00 4,240 4,273 COMPZ RPCOM OTHR P PU and MU hanger and landing joint, orient hanger and RIH, install enetrators. 22:00 00:00 2.00 4,273 4,273 COMPZ RPCOM OTHR P Cut cables and splice to pigtails, finish installin clam s. 8/21 /2008 RDMO 1C-109 and move rig onto well 1C-184. 00:00 01:30 1.50 4,273 4,315 COMPZ RPCOM RCST P Install cable ends onto penetrators, land hanger up wt 105K -down wt 75K, RILD's, test upper and lower body seals at 5,000 psi for 10 minutes. 01:30 02:00 0.50 4,315 4,315 COMPZ RPCOM PULD P LD landing jnt, remove isolation sleeve, set TW . 02:00 04:30 2.50 4,315 4,315 COMPZ RPCOM NUND P PJSM, ND 13 5/8" BOP and check cable integrity, phase to phase and phase to ground resistivity, and me er heat trace to 2500 Vdc. 04:30 07:00 2.50 COMPZ RPCOM NUND P PJSM, NU tree and test 250 / 5000 si 07:00 08:30 1.50 COMPZ RPCOM NUND P PU Lubricator and pull TWC. 08:30 10:00 1.50 COMPZ RPCOM FRZP P RU LRS & freeze protect w/ 96 bbls diesed down IA & 53 bbls diesel down tubin . 10:00 12:00 2.00 COMPZ WELCTL OTHR P RU Lubricator and set H-BPV. Clean location. RDMO. Released Nordic 3 1200 hrs on 8-21-08. F~~~ 9 ~sf 9 • Well Service Report ~__ 1 C-109 Drilling Support - Exp WO Freeborn, Mike ~ 8/15/2008 BJ CCT FCO ~ 195 10228966 ~- ,~ _ BJSvcs RICHARDSON Initial ~ _ INITIAL T/I/0= 0\0\0 ~__' IFina1 ~ Field: WEST SAK ;Pressures:FINAL T/I/0= 0\0\0 ~ ~ Move to 1C. MIRU. BOPE test. Install BHA ~ ~~ 12:00 PM ~ ~ ~ Travel from 1 J-pad to 1 C-pad with BJ/MI equipment. 01:00 PM Lay out containment. Spot BJ surface equipment. Rig up BJ/MI equipment. 06:00 PM Crew change & TGSM 06:30 PM MIRU / BOPE Test. Install BHA. • • Well Service Report j 1 C-109 Drilling Support - Exp WO ~ 8/16/2008 10228966 BJSvcs CPAI Rep ~-- ~ Initial ~ T\I\O 0\0\200111\O Final ~ Field: WEST SAK Pressures: i0\0\200 ed solids to 6,130' CTMD at which point coil became detained. to change out BHA. Solids to surface have been minimal with fluid •~ ~ ~ ~ 12:00 AM Continue to rig up on well. PT all surface equip to 2,500 PSI. RIH. SIWHP = 0 PSI. DWN WT = -2,000#. Bring pumps on line to .6 BPM to 01:45 AM ensure sandvac is operational. Once confirmed lowered rate to 3.3 BPM for RIH. Divert all returns to opentop tank due to diesel in well bore. 02:45 AM Current depth = 4,000'..48 BPM @ 4,748 PSI CTP. RIH @ 9 FPM until we enter liner. Up WT = 14K. DWN WT = 7,200#. Continue to RIH for FCO. CK @ 4,700' CTMD Up WT = 18,000# .5 BPM @ 4,639 PSI CTP. 0 WHP. 03:45 AM DWN WT = 8,500#. PUH 100'. RBIH taking 100' BITES. Heavy gas in returns ith no sand 11.9 sec bucket. 04:45 AM Currently @ 4,900'CTMB, pump rate .48 WHP 0 psi CTP 4860 psi. Bucket test 12 seconds with no sand or gas in returns. 06:00 AM Crew change & TGSM Currently @ 5,300'CTMD. Conitnue to take 100' bites. Up weight 23,000# Dn 06:30 AM eight 8,500#. Over last five hours bucket test between 12-14 seconds. Increased pump rate to .53 BPM WHP 0 psi CTP 5,300 psi. Very little sand in returns. Bucket test rate starting to creep up to 15-17 seconds. Currently @ 5,750"CTMD. Pump rate .53 BPM WHP 0 psi CTP 5350 psi. 11:30 AM Bucket test remain 15-17 seconds. Return rate .42 BPM, very little sand in returns, screens maybe plugging off. 02:30 PM ttempt to troubleshoot low return rate. 03:30 PM Continue in hole. Currently @ 5845'CTMD tagged up. PUH heavy (31,000#) • • Well Service Report 1 C-109 Drilling Support - Exp WO Freeborn, Mike ~._'' ^ .- 8/17/2008 i 195 ® .. ® .. .- 10228966 ~ _r ~BJSvcs ~RICHARDSON Initial ~ I i-~ Final ~ Field: WEST SAK Pressures: ( , ;Pulled OOH to change BHA. No damage to tools witnessed. Struggled with ' 'return rate earlier in the day. Currently at 6,800' CTMD making progress. Solids content mild. ~ .. ~. . 12:00 AM Continue to POOH for tool swap. OOH with leak on HP side of reel. Repair. Pull off well inspect BHA. BHA 01:00 AM packed full of fine sand paste. Intake still clear, but rest of screan packed off. Swap BHA after purging coil at high rate. Currently struggling to latch hydro con. Installation of new bottom hole 04:00 AM assembly is complete along with function test. PT all surface equipment of 2,500 PSI. Prepare to RIH. 06:00 AM Crew change & TGSM 06:30 AM Start in hole at 30' FPM. Weight check @ 3,100'CTMD 15,000#. Currently @ 4,720'ctm, pump rate .50 BPM WHP 0 psi CTP 5430 psi. Bucket 08:30 AM est started out at 12-13 seconds, but last few have been 18-20 second bucket est. Spent last three hours trouble shooting plugged intake screens, cut pump rate 10:00 AM o min. rate, till loss of returns occurred, fluid would fall out of annulus and clear intake screens, but only temporarily. Tried this several times at different depth with only temporary success. Shut down pump and shift tool to jet mode. Start in hole to 5,100' CTMD then 01:00 PM PUH to 4,800'CTMD. Shift BHA back to sand vac mode, same results, emporarily able get 12-13 second bucket test, then back to 20 second tests. Increase pump rate to .58 BPM, start back in hole. Currently @ 6170'CTMD. Over cast three hours, increased pump rate to .58 02:30 PM BPM WHP 0 psi. CTP 5950 psi. Bucket test 16-17 seconds with trace to 2tbls sand per test. Up weight 24,000# Dn 5,850#. Continue in hole @ 1-2 FPM • 10,000# over last weight check. Pump rate .52 BPM WHP 0 psi CTP 5430 psi. Bucket test bouncing around from 13-18 seconds. Very little to no sand in returns. 05:30 PM Crew change & TGSM 06:00 PM 5,960' CTMD DWN WT = 5,000#..5 BPM @ 5,890 PS1. Up WT = 24,000#. Was able to make to 6,153' before becoming detained. Up WT went as high as 40K. PUH to 4000' to purge coiled tubing. At 2355 hrs. informed BJ to 08:00 PM POOH for tool change. Do not feel good with fluid loss at this time. Well appears to be drinking water assisting in difFerential sticking. Will see with new ool. • • Well Service Report j ~1 C-109 Drilling Support - Exp WO Freeborn, Mike __ ~ 8/18/2008 195 10228966 ~ ~~ ~~~' ~~~ "~ ~~ ~ .. BJSvcs ~ RICHARDSON flnitial ~ ( ! i ~ ~ INITIAL T/I/0= 0/0/200 Field: iWEST SAK iFinal +FINAL T/I/0= 0/0/200 1 (Pressures: I I ICUMPLETED BJ CCT FLU IN 1 Nt "13" LA I tKAL I U P13 i U C~ 1 ~7480'CTMD. TOTAL VOLUME OF SAND RECOVERED WAS 1 BARREL. I, {ON SURFACE WITH COIL. FREEZE PROTECT TUBING WITH 70 BBLS DIESEL. SECURED WELLHEAD, RDMO BJ/ MI SURFACE EQUIPMENT TO 1 C-135. ,. agged TD at 7,480.1' CTMD in 100' increments @ 04:12AM..57 BPM @ 12:00 AM 5,853 PSI 15 SEC bucket checks. lil to no sand. 0 PSI WHP. Prepare to PUH at 10 FPM UP WT = 20,233# Plan is to puh @ 10 fpm TO 7,100' ctmd then pick up speed to 100 FPM to. 04:00 AM Currently at 4,600' CTMD comming OOH at 10 FPM to 4,200' Then let er rip! 06:00 AM Crew Change & TGSM 06:30 AM On surface with coil. Pump 70 bbls diesel down tubing for freeze protectioon. Close swab. Rack back injector/lubricator, lay down BHA, purge coil, remove BOPE from 08:15 AM ellhead and rack back. Note: During BHA disassembly metal shavings were removed from screen,sand intake, and throat. 10:00 AM Secure wellhead. Rig down BJ/MI surface equipment #or move to 1 C-135. Notified DSO of well status and departure. End ticket. • • aking 50' bites. 05:30 PM Crew change & TGSM Currently at 6,800' CTMD. DWN WT = 4K. Pump Ra#e = .59 BPM @ 5,995 06:00 PM PSI CTP. Bucket checks = 14-15 sec. 0 WHP. Up WT normal so far. Light sand in returns. Just not enough toget excited about. Up WT = 23K. Page 1 of 3 • • Maunder, Thomas E (DOA) From: Gauer, Cody [Cody.Gauer@conocophillips.com] Sent: Wednesday, August 13, 2008 2:12 PM To: Maunder, Thomas E (DOA) Subject: RE: 1C-109 (201-203) Thanks Tom, I appreciate you taking a look at that. Cody Gauer WeIis Engineer ConocoPhillipsAlaska,inc' ~~N~~~ AUG ~ ~ 2D08 907-263-4802 -office 907-575-5407 -mobile Cody.Gauer@ConocoPhillips.cotn From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, August 13, 2008 1:40 PM To: Gauer, Cody Subject: RE: 1C-109 (201-203) Cody, Based on what I read in the operations report, I do not see any reporting issue here. It appears that the bag was closed and pressure applied in order to determine were the seal stack disengaged from the seal bore to determine the space out. There also appears to have been some pressure on the well after u-tubing to equalize the freeze protection diesel. Since the tubing was bullheaded, it would seem that having some residual pressure would not be unusual. I will place a copy of this message in the file. Call or message with any questions. Tom Maunder, PE AOGCC From: Gauer, Cody [mailto:Cody.Gauer@conocophillips.com] Sent: Wednesday, August 13, 2008 9:30 AM To: Maunder, Thomas E (DOA) Subject: 1C-109 Hi Tom, I am still waiting for a callback from the rig, but here are the details I have. -Freeze protection was being pumped with tubing above the SBA. Diesel was being used. -The tubing hanger was above the bag, and the bag was closed as they were pumping the diesel -The well came up to 500 psi as a result of being underbalanced -The pressure was bled off and the tubing was landed. I am not sure if we are required to report anything, but I wanted to check with you to keep you informed and make sure. Below is the daily summary. Please contact me if you have questions. Thanks. 8/13/2008 Page 2 of 3 • . Cody Gauer Wells Engineer ConocoPhillips Alaska,Inc. 907-263-4802 -office 907-575-5407 -mobile Cody.Gauer~a ConocoPhillips._com Tune LO SUIT1tT1 [Show all time logs. ] From To Duration Start End ,phase Code Sub Time Activity (hrs) !Depth..,: Depth Code __ _ _ _ !Latch LEM w/ 75k do wt and un latch f/ hook w/ 120k up wt. 20k osw. Set ZXP packer w/ 00:00 01:30 1.50 4375 4604 COMPZN RPCOMP: PACK ; P 3,500 psi. Top PBR on Packer set @ 4,422'. PT to 500 psi on IA. Seals stabbed into SCR-1 PKR ,, , @ 4,600'. 01:30 08:00 6 50 4422 0 'COMPZN RPCOMPi TRIP ; p POOH laying . down DP C/O floor ;equipment, LD 08:00 10:00 2 0 0 COMPZN RPCOMP: KURD p MWD and running tool, pull: ', `wear bushing, !unload pipeshed PU MU seals and 10:00 , 11:00 1 0 0 COMPZN ' RPCOMP! PULD P completion ',equipment. RIH to 4425' with seals and 11:00 13:00 ! 2 0 ' 4425 i COMPZN ,; RPCOMP' RCST p 4-1/2" tubing completion. Up wt=82K,dn wt = 72K. 8/13/2008 Page 3 of 3 tag again at !4427 and worked through. ', "No go at 4444', '!sit down 20K. 'Pressure up IA ', 'to 500 psi, strip 13:00 ' 16:30 3.50 ', 4425 ' COMPZN RPCOMP HOSO ; P ; up through the i 'annular 11' before IA ,ipressure dropped off. PUH ; !and run space out pup. PU MU ,' __ _ _ _ hanger. Circ 115 bbl of 'diesel down the IA for freeze ;protect prior to 'landing the hanger for freeze protect. Bullhead 65 bbl i 16:30 22:30 6 COMPZN RPCOMP! FRZP P ! of diesel down ', 'the tubing to 'balance the well 'and for freeze j protect. Needed 'i i to allow the IA and tubing to u- tube and bled (pressure. ' Set seal !assembly in SBE, rigged up and tested IA x tbg at 500 psi !for 10 minutes. 22:30 00:00 1.50 ' ; COMPZN i RPCOMP' HOSO P ,Test good. ;Drained stack !and landed 4- 1/2" completion, ,, RILDS. Up wt 82K, dwn wt 72K. 8/13/2008 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc II }~ DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 Permit to Drill 2012030 Well Name/No. KUPARUK RIV U WSAK 1C-109 Operator CONOCOPHILLIPS ALASKA INC SV"~ 17 6X' Aòò> API No. 50-029-23047-00-00 MD 7510--" TVD 3793 ,,- Completion Date 11/10/2001"-- Completion Status 1-01L Current Status 1-01L UIC N "---- ~---- -- - -- REQUIRED INFORMATION Mud Log No Samples No Directional Survey ~~~-_. -. - --.- -- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Logl Electr Data Digital Dataset Type MedlFrmt Number ED D (data taken from Logs Portion of Master Well Data Maint) -~-- Name Log Log Run Scale Media No 1 1 Interval Start Stop 120 7455 - - ED 120 OH/ CH Received Open 3/4/2002 Open 1216/2002 Comments C 7510 i I Digital Well Logging Data I [ Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity --- -- Well CoreslSamples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received?,--J( í N Daily History Received? (J)N &N ~-- Formation Tops Analysis Received? ~ ------ --- ------ ~--.---- Comments: Compliance Reviewed By: ~ Date: -tf ~itTr~cI- ~-5 -- - ( i \~ ó(O¡"dQ3 1/<-11/ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 22, 2001 RE: MWD Formation Evaluation Logs: 1C-109, AK-MM-11171 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 99518 lC-lO9: Digital Log Images 1 CD Rom RECEIVED DEe 06 2002 Alaska O~ & Gas Cons Com . . Anchorag~ mISSIOn ¡.! ., ~ ~" '. WELL LOG TRANSMITI AL To: State of Alaska Alaska Oil and Gas ConseIVation Co. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 i\nchorage, Alaska 99501 February 26, 2002 RE: MWD F onnation Evaluation Logs 1 C-1 09, AK-MM-11171 1 LDWG fonnatted Disc with verification listing. API#: 50-029-23041-00 ðOJ-aOß 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 s¡gn4 - l. 0 00 p^-_J Date: RECEIVED r{~ p Ur"¡ /: ?OO2 '. \. , 1.... '" Alaska Oil & Gas Cons, Commission Anchorage " ( ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. Mallary Phone(907)265~4 Fax: (907) 265-6224 January 9,2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Reports for 1C-109 and 1C-109L1 (201-203 and 201-204) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Reports for the drilling operations on the multilateral wells 1 C-1 09 and 1 C-1 09L 1. If you have any questions regarding this matter, please contact Steve McKeever at 265-6826. Sincerely, 2~~o Drilling Engineering Supervisor P AI Drilling R~C~ \\lEt) (\ ~ l\j(Jl J ~ ~ I{\\SS\O{\ c(' ).s. Com O.~ &. GiS ~_a ~ þ...t\c~~-¡q. CMlskad OR \ Gt NAL ,e' " ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil 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 ....~ 1i ..A:A ...., " ~~l ED i?J~:~~, ¡" ~~. ¡':l H, ,-'. 7. Permit Number 201-203 8. API Number 50-029-23047-00 .'" .., -..-.Ih 1487' FNL, 699' FWL, Sec. 12, T11N, R10E, UM : I/:'~,::_c','! (ASP: 561706, 5968747) At Top Producing Interval . i,,'" ; i , 1 ': ~.Jl~LQ.:..Q.L} 1378 FNL,220 FEL, Sec. 11, T11 N, R10E, UM I. Ie-': 1::1:;" (ASP: 560786, 5968848) .' ,-, " ..'~ At Total Depth ~ ._.~_.)3j).._,_w ~ 890' FSL, 176' FEL, Sec. 11, T11N, R10E, UM ,:"",..n_'-~""'."'(ASP: 560857, 5965837) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 40' ADL 25649 ALK 467 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. October 17, 2001 October 26, 2001 November 10, 2001 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 7510' MD 13793' TVD 7510' MD /3793' TVD YES 0 No 0 22. Type Electric or Other Logs Run GR/Res, CCL 23. ."' ,. ."'.-"'"!'[--,"",~.._,.;.".,,':-- 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1 C-1 09 11. Field and Pool West Sak Oil Pool Kuparuk River Field 15. Water Depth, if offshore N/A œetMSL 20. Depth where SSSV set N/A feet MD 16. No. of Completions 1 21. Thickness of Permafrost 1905' CASING SIZE 16" WT. PER FT. 62.5# 29.7# 12.6# GRADE H-40 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 158' Surface 4938' 4597' 7483' HOLE SIZE 2411 CEMENTING RECORD AMOUNT PULLED 282sxAS1 519 sx AS III Lite, 262 sx Class G wI GasBlok Slotted screen 7.625" 4.5" 9.875" 6.75" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE 4.5" TUBING RECORD DEPTH SET (MD) 4306' PACKER SET (MD) N/A Open Hole 4.5" Slotted Liner Completion from 4965' - 7450' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. Date First Production December 4, 2001 Date of Test Hours Tested 12/10/2001 5 hours Flow Tubing Casing Pressure press. 326 psi not available 28. Test Period> Calculated 24-Hour Rate> PRODUCTION TEST Method of Operation (Flowing, gas lift. etc.) Flowing - sharing production volumes from 1C-109L 1 Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE 147 1 10 100 OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) 676 24 47 not available CORE DATA GAS-OIL RATIO 35 Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A RECEIVED JAN 0 9 2007 Alaska Oil & Gas Cons. Commission Anchorage -- Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ORIGINALRBDMSBFL ~\jAN IO;ro¿ 29. (' GEOLOGIC MARKERS 30. (' FORMATION TESTS NAME MEAS. DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. West Sak D West Sak A3 West Sak Base 4486' 7510' 7510' 3737' 3793' 3793' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Steve McKeever 265-6826 Signed /17 f) ~ . Ìkc¿t~~a-~.~ r( V ./ Title Drillina Enaineerina Supervisor Date q ~ 1) '2... C. Mallary 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. ~~~~::O~~~~~p~:i~~eration: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water~~Ë1VË1) Item 28: If no cores taken, indicate Ilnonell. JAN 0 9 2002 Form 10-407 Alaska Oil & Gas Cons. Commission 0 RIG I N A L Anchorage ( Page 1 pi 10 PHILLIPS ALASKA INC. . . . . . .. Operations Summary Report . Legal Well Name: 1 C-109 Common Well Name: 1C-109 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 245 Sub Code 10/16/2001 22:00 - 00:00 2.00 MOVE MOVE MOVE . 10/17/2001 00:00 - 03:30 3.50 MOVE OTHR MOVE 03:30 - 12:00 8.50 WELCTL NUND SURFAC 12:00 - 13:00 1.00 WELCT SFTY SURFAC 13:00 - 14:00 1.00 WELCTL NUND SURFAC 14:00 - 15:00 1.00 WELCTL BOPE SURFAC 15:00 - 16:30 1.50 WELCTL OTHR SURFAC 16:30 -17:00 0.50 DRILL PULD SURFAC 17:00 -19:30 2.50 DRILL PULD SURFAC 19:30 - 20:00 0.50 WELCTL SFTY SURFAC 20:00 - 21 :00 1.00 DRILL CIRC SURFAC 21 :00 -'00:00 3.00 DRILL DRLG SURFAC 10/18/2001 00:00 - 01 :00 1.00 DRILL DRLG SURFAC 01:00 - 01:30 0.50 DRILL SURV SURFAC 01 :30 - 04:00 2.50 DRILL DRLG SURFAC 04:00 - 05:00 1.00 RIGMNT OTHR SURFAC Spud Date: 10/17/2001 End: Group: Start: 10/17/2001 Rig Release: Rig Number: 245 Description of Operations 05:00 - 06:00 1.00 DRILL TRIP SURFAC 06:00 - 08:00 2.00 RIGMNT OTHR SURFAC 08:00 - 10:30 2.50 RIGMNT OTHR SURFAC 10:30 -11:00 0.50 DRILL TRIP SURFAC 11 :00 - 15:00 4.00 DRILL DRLG SURFAC 15:00 - 00:00 9.00 DRILL SURFAC 10/19/2001 00:00 - 13:30 13.50 DRILL DRLG SURFAC 13:30 - 15:00 1.50 DRILL CIRC SURFAC 15:00 - 18:30 3.50 DRILL TRIP SURFAC 18:30 - 19:00 0.50 DRILL OTHR SURFAC 19:00 -19:30 0.50 RIGMNT RSRV SURFAC 19:30 - 00:00 4.50 DRILL TRIP SURFAC Prepare and move rig from 1 C-125 to 1 C-1 09 ML. 240' away from CPM. Level rig. Align utility module with drill mod ule. Remove # 4 Lampson fl service. NU 13 5/8" diverter for multilateral well. Pre spud safety meeting with both crews and Company rep and toolpusher. Finish nipple up in cellar. Hook up cellar pu mp. Install valves on 4" on conductor. PU 7 5/8" landing joint, MU hanger and mark landing joint depth. Function test diverter system. PU wear ring and run in hole. Check setting depth. Function test accumulator. PU drilling tools to rig floor. PJSM. PU and MU BHA. Diverter Drill. Fill conductor. Check for leaks. Drill 9 7/86 surface hole fl 158'-280'. (122') Drill 9 7/8" surface hole fl 280' to 296' (16') ART=.25 hrs Run Gyro survey wi rig wireline machine. Drill 9 7/8" surface hole from 296' to 530' ( 234') ART 1.25 hrs. Work on discflo tank and pump. Trying to ge t pump to pump rocks and mud. Suction of p ump possibly plugged wi gravel. Work to unp lug suction and get pump to pickup. Work dr ill string while trying to free up. Trip out to inside of conductor pipe to conti nue working on discflo tanklpump . Working on discflo tank/pump. Rocks pluggi ng up suction. Trip in hole, then trip out of hole to change sheave on Discflo pump, to run faster. Trip in hole to continue drilling 9 7/8" surfa ce hole. Directional drill 9 7/8" surface hole fl 530' t 0 1000'. (470') (TVD= 996') ART = .25 hrs AST= 2.85 hrs Directiona.1 drill 9 7/8" surface hole fl 1000' to 1851'. (851') (TVD=1746') ART=1.45 hr s. AST = 3.75 hrs. Directional drill 9 7/8" hole fl 1851' to 3458 , (1607') (TVD = 3080') ART = 3.27 hrs. AST = 6.57 hrs. . CBU, Monitor well, pump dry job. POOH. Check MWD. LID UBHA sub. Blow down top drive. Service rig and top drive. Trip back in hole w/ bit # 1RR & BHA # 2. W ork through hole 11 (8xx-14 stands dp)1916' Printed: 12/12/2001 9:31:38 AM ( PHilliPS. ALASKA INC. Operations Summary Report Legal Well Name: 1 C-1 09 Common Well Name: 1C-109 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 245 Sub Code 10/19/2001 19:30 - 00:00 4.50 DRILL TRIP SURFAC 10/20/2001 00:00 - 12:00 12.00 DRILL DRLG SURFAC 12:00 - 20:30 8.50 DRILL DRLG SURFAC Page 2 of 10 Start: 10/17/2001 Rig Release: Rig Number: 245 Spud Date: 10/17/2001 End: Group: 20:30 - 22:00 1.50 DRILL CIRC SURFAC 22:00 - 00:00 2.00 DRILL TRIP SURFAC 10/21/2001 00:00 - 03:00 3.00 DRILL TRIP SURFAC 03:00 - 04:00 1.00 DRILL OTHR SURFAC 04:00 - 05:00 1.00 DRILL TRIP SURFAC 05:00 - 06:00 1.00 DRILL TRIP SURFAC 06:00 - 09:30 3.50 DRILL SURFAC 09:30 - 13:00 3.50 DRILL CIRC SURFAC 13:00 - 16:00 3.00 DRILL TRIP SURFAC 16:00 -18:00 2.00 DRILL OTHR SURFAC 18:00 - 18:30 0.50 WELCTL OTHR SURFAC 18:30 - 20:00 1.50 CASE RURD SURFAC 20:00 - 00:00 4.00 CASE RUNC SURFAC 10/22/2001 00:00 - 04:00 4.00 CASE RUNC SURFAC 04:00 - 09:30 5.50 CASE CIRC SURFAC 09:30 - 11 :30 2.00 CEMEN PUMP SURFAC 11 :30 - 12:30 1.00 CEMEN DISP SURFAC 12:30 - 14:30 2.00 CEMEN RURD SURFAC 14:30 -16:30 2.00 WELCTL OTH.R SURFAC 16:30 - 19:00 19:00 - 21:30 21 :30 - 23:00 2.50 WELCTL NUND SURFAC 2.50 WELCTL OTHR SURFAC 1.50 WELCTL OTHR SURFAC to 2421'. Rotate and circ through 2862+-'. Directional drill 9 7/8" hole fl 3458' to 4402 , (944') (TVD= 3704') ART = 3.52 hrs. AS T = 5.25 hrs. Directional drill 9 7/8" hole fl 4402' to 4950 , (548') (TVD= 3808') ART = 3.23 hrs. AS T = 2.87 hrs. Circulate and condition mud and hole @ TD( 4950' MD=3808' TVD) fl 7 5/8" casing. PJSM. Monitor well, Pump dry job. POOH fl 9 7/8" hole opener. Tight @ 4,000' 3818' 3683' 3583'. Continue POOH wI BHA # 3 & Bit # 1RR @ T D of 4950' MD (TVD=3808') SLM no correctio n. Download Sperry MWD. LID motor, bit, and MWD tools. MU 9 7/8" hole opener assmebly. BHA #3. RIH wI BHA # 3 (9 7/8" hole opener) for clea nout run prior to running 7 5/6" casing. Tigh thole @ 3844' to 3875'. Wash 115' to botto m. Circulate and condition mud and hole f/ 7 51 8" casing. POOH wI hole opener. LID hole opener assembly. Pull wear bushing. PJSM. RU GBR to run 7 5/8" surface casing. PJSM. Run 7 5/8", 29.7 #/ft, L-80, BTC Mod casing. %'"' joints in hole @ midnight = 2495' Run 55 joints 7 5/8" casing (58-113) to 493 8'. LID frank's fillup tooll, PU/MU hangr and landing joint. Circ and condition mud and hole for cement job. Recip pipe approx 8'. PJSM. Pressure test lines to 3500 psi. Came nt per program. Displace cement @ 6 BPM and 600 psi. Slow pumps to 3 bpm for last 20 bbls. Pump 232 5 strokes. Did not bump plug. Floats held. C I P @ 1225 hrs 10-22-2001 Rig down cement equip &, landing joint, Was h out stack. Rig up drilling bales and elevators. PU stan d of 4" HWDP. Attempt to set packoff. Bolts holding upper and lower parts together she are d. N/D BOPE. Remove packoff through bottom of wellhead. Clean extended neck of 7 5/8" hanger, Exam ine packoff, clean inside of wellhead, Notic Printed: 12/12/2001 9:31:38AM ,r' PHilliPS ,ALASKA INC. .. . . .. .. . " OperationsSuïnmaryReport Page ~ of1 0 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date: 1 C-1 09 1C-109 ROT - DRILLING Nabors Nabors 245 1 0/22/2001 10/23/2001 Spud Date: 10/17/2001 End: Group: Start: 10/17/2001 Rig Release: Rig Number: 245 . Description of Operations' 21 :30 - 23:00 , Sub Code 1.50 WELCTL OTHR SURFAC 23:00 - 00:00 1.00 WELCTL NUND SURFAC 00:00 - 03:30 3.50 WELCTL NUND PROD 03:30 - 06:30 3.00 WELCTL OTHR PROD 06:30 - 07:30 1.00 WELCTL OTHR PROD 07:30 - 13:30 6.00 WELCTL NUND PROD 13:30 - 15:00 1.50 WELCTL BOPE PROD 15:00 - 19:30 4.50 WELCTL BOPE PROD 19:30 - 20:30 1.00 WELCTL OTHR PROD 20:30 - 21 :00 0.50 WELCTL OTHR PROD 21:00 - 21:30 0.50 RIGMNT RSRV PROD 21 :30 - 00:00 2.50 DRILL PULD PROD 10/24/2001 00:00 - 04:00 4.00 DRILL PULD PROD 04:00 - 06:00 2.00 DRILL TRIP PROD 06:00 - 07:30 1.50 DRILL TRIP PROD 07:30 - 13:00 5.50 DRILL DRLG PROD 10/25/2001 10/26/2001 13:00 - 13:30 0.50 DRILL CIRC PROD 13:30 - 14:00 0.50 DRILL OTHR PROD 14:00 - 15:30 1.50 DRILL OTHR PROD 15:30 - 19:00 3.50 DRILL DRLG PROD 19:00 - 20:30 1.50 DRILL CIRC PROD 20:30 - 22:00 1.50 DRILL FIT PROD 22:00 - 00:00 2.00 DRILL OTHR PROD 00:00 - 13:00 13.00 DRILL DRLH PROD 13:00 - 15:00 2.00 DRILL CIRC PROD 15:00 - 17:00 2.00 DRILL WIPR PROD 17:00 - 17:30 0.50 RIGMNT RSRV PROD 17:30 - 18:30 1.00 DRILL WIPR PROD 18:30 - 21 :00 2.50 DRILL CIRC PROD 21:00 - 21:30 0.50 DRILL CIRC PROD 21 :30 - 00:00 2.50 DRILL DRLH PROD 00:00 - 07:00 7.00 DRILL DRLG PROD ed gouges from flutted hanger being recip. 0 n off drill side of wellhead. Nipple down wellhead. Arrange for another w ellhead from warehouse. Nipple down wellhead. Remove from cellar. Check new packoff over extended neck of ha nger. Fit fine. Check fit of pack off in new w ellhead. Fit fine. Assemble new wellhead onto starting head. Torque lockdown screws. Test to 1000 psi. OK. Attempt to install packoff. Would only g 0 down 2.00. below top of wellhead with run ning tool. Calculated need to go to 2.90. to be on top of flutted hanger. loosen all lockdown bolts. Install pack off i n wellhead. NU BOP. RU BOP test equipment. Test BOP and choke manifold to 250 psi and 3000 psi. Install wear bushing. RD test equipment. Service top drive. PU BHA. MU bit. Orient. Upload MWD. PU BHA. Sh allow test MWD. RIH Run real-time GR log. Tag cement at 4336'. Drill hard cement to 4 835'. Continue running real time logs to 45 50' . Circ bottoms up. RU test equipment PJSM. MIT casing to 3000 psi for 30 min. Drill out through float equipment and shoe. Drill 30' new hole to 4980'. Circ hole clean. Change mud to Baradril-N system. Perform FIT. Max pressure 650 psi. Bled b ack to 400 psi. FIT MW=11.0 ppg Clean mud pits. DRLG F/ 4980' TO 6468' ART = 6.95, AST = 1 .5 Circ, Pump sweep around, Cond for wiper tri p. POOH to Shoe, No problems with trip. Service'Rig & Top Drive RIH to bottom, No trouble. Circ Bottoms up, Change over to new mud. Perform PWD baseline test with new mud in hole. DRLG f/ 6468' to 6752' ART = 2.55 hrs. Drill ahead from 6752' to TD at 7510' MD (3 Printed: 12/12/2001 9:31 :38 AM ,i (' . PHilliPS ALASKA INC.. . . - .. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-109 1 C-109 ROT - DRILLING Nabors Nabors 245 Page 40110 Spud Date: 10/17/2001 End: Group: Start: 10/17/2001 Rig Release: Rig Number: 245 Desen plio n.. olOpe rations 10/26/2001 00:00 - 07:00 7.00 DRILL DRLG PROD 07:00 - 09:30 2.50 DRILL CIRC PROD 09:30 - 10:00 0.50 DRILL SFTY PROD 10:00 - 13:30 3.50 DRILL WIPR PROD 13:30 - 14:00 0.50 RIGMNT RSRV PROD 14:00 - 15:00 1.00 RIGMNT RURD PROD. 15:00 - 16:30 1.50 DRILL WIPR PROD 16:30 - 19:30 3.00 DRILL CIRC PROD 19:30 - 00:00 4.50 DRILL TRIP PROD 00:00 - 00:30 0.50 DRILL TRIP PROD 00:30 - 02:00 1.50 DRILL TRIP PROD 10/27/2001 02:00 - 03:30 1.50 DRILL PULD PROD 03:30 - 05:00 1.50 DRILL PULD PROD 05:00 - 06:00 1.00 CASE PULR PROD 06:00 - 06:30 0.50 CASE SFTY PROD 06:30 - 10:30 4.00 CASE PULR PROD 10:30 - 11 :00 0.50 CASE PULR PROD 11 :00 - 11 :30 0.50 CASE SFTY PROD 11 :30 - 12:00 0.50 CASE PULR PROD 12:00 - 12:30 0.50 CASE SFTY PROD 12:30 - 17:30 5.00 CASE PULR PROD 17:30 - 18:00 0.50 CASE RURD PROD 18:00 - 22:30 4.50 CASE RUNL PROD 22:30 - 23:30 1.00 CASE CIRC PROD 23:30 - 00:00 0.50 CASE RUNL PROD 10/28/2001 00:00 - 03:00 3.00 CASE RUNL PROD 03:00 - 04:30 1.50 CASE PTCH PROD 04:30 - 08:00 3.50 LOG RURD PROD 793' TVD). Pump 30 bbl Hi Vis sweep at 74 20' MD ART=2.25 AST=2.25 Pump 30 bbl Hi Vis sweep. Circulate and co ndition mud. PJSM - pulling pipe. Monitor well. Pump dr y job. Short trip to 4900' Service top drive. Slip and cut 80' drilling line. RIH to TD. CBU. Pump 30 bbl Hi Vis sweep. Change h ole over to new mud. Pump dry job. Trip out of hole and strap pipe. Drop rabbit Continue POOH to BHA. Strap pipe. Recov er rabbit. LID jars. Stand back DC's. Drain motor. B reak out bit. Bit grading is on 10/26/01 rep 0 r t. Download MWD. Stand back in derrick. LD motor. PJSM - Discuss pick up procedures. 24 jts 4-3/4" DC and 12 jts 4" HWDP. RU to run liner. PJSM - discuss liner running procedures. PU and run 4-1/2" slotted liner as per proce d u re. PU sliding sleeve and 2 jts blank liner. Ver ify sliding sleeve is open. PJSM - discuss inner string running procedu res. PU and run 2-78. inner string and wash cups Tour change. Conduct PJSM wI new crew an d discuss inner string running procedures. Run 2-7/8" inner string and wash cups. Spa ce out cups inside 4. blank joints. MU Pack er assembly on inner string and liner. RD liner and tubing handling equipment. RU to run drill pipe. RIH wI liner on drill pipe, DC's, and HWDP at 3 minI stand. Fill pipe every stand. Bre ak circulation every 5 stands. Circulate bottoms up (72' above casing shoe ). Good clean returns. Continue RIH wI liner. RIH wI liner, 3 miti's per std. std. Shoe @ 7 483' PT lines to 4000 psi. Set packer & release f / same. LID single & BID Top Drive. Hold PJSM. Rig up SWS to run GR/CCL. Part ed wI while picking up tools fI V-door. Rehe ad wireline. Rig up lubricator. Printed: 12/12/2001 9:31:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: t ( .' PHILLIPS ALASKA INC. . . . . . . - . Operations Summary Report 1C-109 1C-109 ROT - DRILLING Nabors Nabors 245 2.50 LOG 'Sub. Code ELOG PROD 10/28/2001 08:00 - 10:30 10:30 -14:30 14:30 - 23:00 4.00 CMPL T CIRC PROD 8.50 CMPLT TRIP PROD 23:00 - 23:30 0.50 RIGMNT RSRV PROD 23:30 - 00:00 0.50 WINDO PULD PROD 10/29/2001 00:00 - 03:30 3.50 WINDO PULD PROD 03:30 - 07:30 4.00 WINDO PROD 07:30 - 08:30 1.00 WINDO SETW PROD 08:30 - 09:00 09:00 - 10:30 11:30 -12:30 12:30 - 15:00 15:00 - 16:30 16:30 - 17:00 17:00 - 20:00 10/30/2001 20:00 - 20:30 20:30 - 00:00 00:00 - 00:30 00:30 - 02:00 02:00 - 03:00 03:00 - 03:30 03:30 - 07:30 07:30 - 09:00 09:00 - 09:30 09:30 - 12:00 12:00 - 15:30 0.50 WINDO CIRC PROD 1.50 WINDO STWP PROD 1.00 WINDO CIRC PROD 2.50 WINDO 1.50 WINDO PROD PROD 0.50 RIGMNT RGRP PROD 3.00 WINDO RIP PROD 0.50 WINDO STWP PROD 3.50 WINDO STWP PROD 0.50 WINDO STWP PROD 1.50 WINDO CIRC PROD 1.00 WELCTL OTHR PROD 0.50 WINDO CIRC PROD 4.00 WINDO RIP PROD 1.50 WINDO OTHR PROD 0.50 WELCTL OTHR PROD 2.50 WELCTL BOPE PROD 3.50 WELCTL BOPE PROD Page 5.of10 Spud Date: 10/17/2001 End: Group: Start: 10/17/2001 Rig Release: Rig Number: 245 . Description of Operations Run GR/CCL with SWS (RA sub @ 4517' WLM ). POOH wI W.L. & rig down SWS. Displace well wI 3% KCL, pump between Ann ulus & liner 300 bbls. @ 10 BPM. PIU & dis place between wash string & liner @ 10 BPM . Packing off around upper cups, lost approx .100 bbls. Pull up to clear liner top w. top cups. circ 200 bbls @ 6 -8 bpm wI full retur ns until returns clean. Monitor well, POOH. Close sliding sleeve @ 4683', Continue POOH, LID liner running too Is. Rig up GBR & LID inner wash string 2-71 8" Fox tubing. Service Rig & Top Drive. P/U Whip stock assy. PJSM. PIU whipstock assy, M/U MWD & chan ge out internal components, orient tools, Up load data to MWD. RIH wI whipstock assy. Test MWD @ HWDP. Break circ, Orient whipstock (19 deg to left of HS). Sting into Liner top, Set anchor & s hear off bolt. Top of window @ 4494'. Finish displacing hole wI Baradril-N mud. Mill window fl 4494' to 4498' wI starting mill Pump sweep around. Monitor well, PJSM on t ripping, Pump dry job. POOH wI starting mill assy. Change out mills, PJSM, RIH w, 2nd mill ass y. Repair air hose on Top Drive Continue RIH, Take MWD surveys @ 4330',4 355' ,4380' ,4405'. Ream fl 4494' to 4498' Milling window fl 4498' to 4519' Mill window fl 4519' to 4525' Ream window, pump sweep, circ out metal c uttings. Perform FIT, Mud wt. 9.0 ppg., 4525' MD, 37 51' TVD. 600 psi, bled to 505 psi. (11.6 ppg emw) Monitor well, Pump dry job. POOH to HWDP, monitor well, Continue POO H. LID Mill assy. D.L. LWD info. P/U stack washing tool & wash stack cavitie s. Pull wear bushing. PJSM. Rig up test equipment. Break dart va Ive & inspect same. Reassemble dart valve. Test Bop's complete to 250/3000 psi. Prform accumulator test. AOGCC rep. Chuck Schev Printed: 12/12/2001 9:31:38 AM ( PHILLIPS ALASKA INC. , .. , ' , " Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-1 09 1 C-1 09 ROT - DRILLING Nabors Nabors 245 10/30/2001 12:00 - 15:30 3.50 WELCTL BOPE PROD 15:30 - 16:30 1.00 WELCTL BOPE PROD 16:30 - 19:30 3.00 DRILL TRIP PROD 19:30 - 23:30 4.00 DRILL TRIP PROD 23:30 - 00:00 0.50 RIGMNT RSRV PROD 10/31/2001 00:00 - 01 :00 1.00 DRILL TRIP PROD 01 :00 - 18:00 17.00 DRILL DRLG PROD 18:00 - 19:00 1.00 DRILL CIRC PROD 19:00 - 20:30 1.50 DRILL WIPR PROD 20:30 - 21 :00 0.50 RIGMNT RSRV PROD 21 :00 - 22:30 1.50 DRILL WIPR PROD 22:30 - 00:00 1.50 DRILL CIRC PROD 11/1/2001 00:00 - 01 :30 1.50 DRILL CIRC PROD 01 :30 - 02:00 0.50 DRILL DRLG PROD 02:00 - 03:00 1.00 WELCTL OBSV PROD 03:00 - 03:30 0.50 WELCTL CIRC PROD 03:30 - 16:30 13.00 DRILL DRLG PROD 16:30 - 20:00 3.50 DRILL CI RC PROD 20:00 - 20:30 0.50 DRILL SFTY PROD 20:30 - 00:00 3.50 DRILL TRIP PROD 11/212001 00:00 - 02:00 2.00 DRILL TRIP PROD 02:00 - 02:30 0.50 DRILL SURV PROD 02:30 - 03:30 1.00 DRILL PULD PROD 03:30 - 03:45 0.25 DRILL SFTY PROD 03:45 - 04:30 0.75 DRILL PULD PROD 04:30 - 07:00 2.50 DRILL TRIP PROD 07:00 - 08:00 1.00 DRILL URM PROD 08:00 - 08:30 0.50 DRILL URM PROD 08:30 - 16:00 7.50 DRILL URM PROD 16:00 - 17:30 1.50 DRILL CIRC PROD Spud Date: 10/17/2001 End: Group: Start: 10/17/2001 Rig Release: Rig Number: 245 Descri ptio n'of Operations e witnessed test. Rig down test equip. & Install wear bushing. PSJM, PIU BHA. Reset adjustable bent housi ng, (1.8). Orient tools. Program LWD tools. RIH wI Drilling assy, Shallow test MWD @ 3 76' . Service Rig & Top Drive. Pump survey @ 4455'. Orient motor. Conti nue RIH to 4525'. Drill ahead from 4525' to 6060' MD (TVD 374 1'). ART=5.3 AST=4.5 Circulate and condition mud. Short trip to window. Lubricate rig and service top drive. Trip in hole. Condition mud. Circulate bottoms up. Chan ge hole over to new mud. Continue changing hole over to new mud. P ump survey. Drill ahead 6060' to 6165' (TVD 3742'). AR T=0.25 AST=0.25 Flow check. Saw pit gain and increased flo w. Shut in well. Monitor pressure. 0 psi c asing and DP. Open well. Monitor pressure. Circ bottoms up. Mud is slightly aerated. Blow down top drive. Drill ahead from 6165' to TD at 7525' MD (T VD 3733' ART=5.5 AST=1.0 Total for the u pper lateral: ART=11.05 AST=5.75 Condition mud. Circ bottoms up. Pump swe ep. Pump 2.5 hole volumes. Displace well with new mud. Monitor well. PJSM - discuss procedure for pulling out of hole. Pump dry job. POOH. Monitor well at window. SLM out of hole. Continue POOH. SLM out of hole. No corre ct ion. Download MWD. LD BHA. PJSM - Discuss procedures for picking up n ew bit and BHA. PU hole opener and BHA. RIH wI hole opener to top of window at 4494 'MD. Fill pipe and slide through window to 4550' MD Ream from 4572' to 4972' MD. Tight spot at 4972' . Ream through tight spot at 4972'. Ream from 4972' to TD at 7525'. Circulate and condition mud. Pump hi vis s Printed: 12/12/2001 9:31:38 AM " "" "" " " "pH ILLIPSALASKAJNC." " " " " "" " " Operations Sumrna,yReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-109 1C-109 ROT - DRILLING Nabors Nabors 245 ( Start: 10/17/2001 Rig Release: Rig Number: 245 Spud Date: 10/17/2001 End: Group: 11/212001 16:00 - 17:30 1.50 DRILL CIRC PROD 17:30 - 19:30 2.00 DRILL WIPR PROD 19:30 - 20:00 0.50 RIGMNT RSRV PROD 20:00 - 21 :30 1.50 DRILL WIPR PROD 21 :30 - 00:00 2.50 DRILL CIRC PROD 11/3/2001 00:00 - 04:30 4.50 DRILL TRIP PROD 04:30 - 05:30 1.00 DRILL PULD PROD 05:30 - 08:30 3.00 FISH PULD PROD 08:30 - 09:00 0.50 FISH PULD PROD 09:00 - 10:00 1.00 FISH OTHR PROD 10:00 - 12:00 2.00 FISH OTHR PROD 12:00 - 13:00 1.00 FISH CIRC PROD 13:00 - 15:00 2.00 FISH OTHR PROD 15:00 -17:00 2.00 FISH PULD PROD 17:00 - 18:00 1.00 RIGMNT RSRV PROD 18:00 - 20:00 2.00 CASE RURD PROD 20:00 - 23:30 3.50 CASE PULA PROD 23:30 - 00:00 0.50 CASE RURD PROD 11/4/2001 00:00 - 00:15 0.25 CASE SFTY PROD 00:15 - 01:00 0.75 CASE PUTB PROD 01 :00 - 04:00 3.00 CASE PUTB PROD 04:00 - 04:30 0.50 CASE PUTB PROD 04:30 - 06:00 1.50 CASE DEOT PROD 06:00 - 07:30 1.50 CASE DEaT PROD 07:30 - 10:00 10:00 - 11 :30 2.50 CASE 1.50 CASE RUNL PROD RUNL PROD weep. Circ bottoms up. Monitor well. Pump dry job. Blow down top drive. POOH above window. Lubricate rig. Service top drive. RIH to TD. No tight spots encountered. Circulate and condition mud. Pump hi vis s weep. Circulate until returns are clean. Ch ange hole over to new mud. POOH w/ hole opener to top of window at 44 94' MD. Monitor well. POOH to BHA. Monitor well. PJSM. LD BHA. PU MWD in derrick and lay down. PU whipstock retrieving tool and BHA. RIH w/ HWDP. LD both sets of drilling jars. Test MWD. Blow down top drive. RIH to stand 39. MU top drive. Pump surve y. Orient retrieving tool. Attempt to latch whipstock. Latched up at 1 200. Up weight @ 4400'=138K Dn weight @ 4400'=120K Circ bottoms up. Monitor well. Pump pill. Blow down top drive. POOH to fishing tools. PJSM. LD Fishing tools and whipstock. Service rig and top drive. C/O strip-o-matic RU GBR. PJSM. Load tools onto floor. RIH w/ 4.5. slotted liner. RU to run 2-7/8N inner wash string. PJSM - discuss inner string running procedu reo PU CMD shifting tool and lower cup assembl y. RIH w/ 2-7/8. inner wash string and cups. T ag shoe and space out cups. PU flanged hook hanger/running tools. MU t 0 inner wash string. MU flanged hook hange r to 4-1/2" liner. PU MWD orienting sub. Orient sub 180 deg from hook hanger. PU 4-3/4" drill collar an d MWD flow sub. Load MWD tools and land i n orienting sub. RIH w/ 2 stands DP. Surfa ce test MWD. MWD not pulsing. POOH 2 stands DP. Pull MWD tools. Repla ce 2 components. Load MWD tools and land in orienting sub. RIH wI 1 stand of DP. Su rfaèe test MWD. Good. RIH to top of window at 4494' MD. Attempt to slide through window. Tag packe r for lower lateral. PU above window and ro tate 90 deg. Work torque down. RIH and ta g packer. PU above window and rotate 120 deg. PU 30' and RIH. Tag packer. PU to t Printed: 12/12/2001 9:31:38 AM ( ( , PHILLIPS, ALASKA: INC.. . . . . OperationsSumrnafyReport .. Legal Well Name: 1 C-1 09 Common Well Name: 1C-109 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 245 Sub Code 11/4/2001 10:00 - 11:30 1.50 CASE RUNL PROD 11:30 -12:00 0.50 CASE RUNL PROD Spud Date: 10/17/2001 End: Group: Start: 10/17/2001 Rig Release: Rig Number: 245 Description of. Operations 12:00 - 16:00 4.00 CASE RUNL PROD 16:00 - 18:00 2.00 CASE RUNL PROD 18:00 - 21:30 3.50 CASE OTHR PROD 21 :30 - 23:30 2.00 CASE OTHR PROD 23:30 - 00:00 0.50 CASE OTHR PROD 11/5/2001 00:00 - 00:15 0.25 CASE SFTY PROD 00:15 - 01 :30 1.25 CASE CIRC PROD 01 :30 - 03:00 1.50 CASE CIRC PROD 03:00 - 03:30 0.50 CASE SFTY PROD 03:30 - 04:30 04:30 - 12:00 1.00 RIGMNT RURD PROD 7.50 CASE RUNL PROD 12:00 - 13:00 13:00 - 13:30 1.00 CASE 0.50 CASE RUNL PROD RUNL PROD 13:30 -16:30 3.00 CASE RUNL PROD 16:30 - 16:45 0.25 DRILL SFTY PROD 16:45 - 17:00 0.25 DRILL PULD PROD 17:00 - 23:30 6.50 DRILL PULD PROD 23:30 - 00:00 0.50 WELCTL BOPE PROD 11/6/2001 00:00 - 03:00 3.00 WELCTL BOPE CMPL TN 03:00 - 07:30 4.50 WELCTL BOPE CMPLTN 07:30 - 08:30 1.00 WELCTL BOPE CMPL TN op of window. Rotate 180 deg. PU 30' and RIH. Liner slid into upper lateral. RIH wI slotted liner on DP to 4896' and pum p survey. MWD working well. Up wt 160K Dn wt 135K RIH wI slotted liner on DP. Stop wI hanger 50' above window. Up wt 195K, Dn wt 115K. Orient hanger. RIH and set down in window w/20K. Attempt to set down more weight. Run in hole 6' more to get total of 40K set 0 n hook hanger. Pump survey. hanger is 20 deg right of expected orientation. Hook han ger is 6' deeper that expected. RU HES slickline unit. RIH and retrieve MW D tools. RD slickline unit. Drop ball. Ball did not seat. Circ and surg e trying to get ball on seat with no success. Release HR liner running tool wI left hand r otation. PJSM - discuss liner wash procedures Pump 30 bbl hi vis sweep. Displace wI 250 bbls 9.0 ppg brine at 9 bpm and 3500 psi. Good returns during circulation. Pump out of hole laying down to 7235'. Con tinue pumping brine at 9 bpm at 3100 psi. T op cups are in 7-5/8" casing. Goods returns during circulation. Pumped 450 bbls. Ret urns are clean. 150 NTU turbidity. Monitor well. PJSM - discuss cutting drillin g Ii n e Slip and cut 112' drilling line. POOH laying down drill string. LD MWD equ ipment. Check orienting sub. Orienting lug is tight and has not moved since RIH. Lay down liner running tools. Drill string has been pulling wet. RU and p ump down 2-7/8" tubing. Shear out ball sea t with 4000 psi. POOH laying down 2-7/8" inner wash string. PJSM - discuss running and laying down dril I pipe out of derrick. RU floor to LD drill pipe out of derrick. RIH wI drill pipe out of derrick and POOH la ying down. Clean up floor and load floor with tools for BOP test joint. RU , pull wear bushing, set test plug, AU to weekly test BOPE. Test BOPE to 300 psi low and 3000 psi high. Test witness waived by AOGCC rep. John C ri s p. RID test equipment, clear floor. Blow down t Printed: 12/12/2001 9:31:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: , , , , , , , ,. ,P~ILLIPSALASKAINC'~" Operations Summary Report. 1 C-109 1C-109 ROT - DRILLING Nabors Nabors 245 07:30 - 08:30 08:30 - 09:30 09:30 - 15:00 15:00 - 19:00 19:00 - 22:00 22:00 - 00:00 1117/2001 00:00 - 00:30 00:30 - 02:00 02:00 - 03:00 03:00 - 04:00 04:00 - 05:30 05:30 - 06:30 06:30 - 11 :00 11 :00 - 12:00 12:00 - 15:30 15:30 - 19:00 Spud Date: 10/17/2001 End: Group: Start: 10/17/2001 Rig Release: Rig Number: 245 . DescriptionotOperations Sub.., Code' 1.00 WELCTL BOPE CMPL TN 1.00 CMPL T RURD CMPL TN 5.50 CMPL T RUNT CMPL TN OTHR CMPLTN CMPL TN CMPL TN CMPL TN CMPL TN 1.00 CMPL T SUN CMPL TN 1.00 CMPL T PULD CMPL TN 1.50 CMPL T RUNT CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN 19:00 - 00:00 5.00 CMPL TN RURD CMPL TN 11/8/2001 00:00 - 01 :00 1.00 CMPLT RURD CMPL TN 01 :00 - 06:00 5.00 CMPL T RUNT CMPL TN 06:00 - 09:00 09:00 - 11 :00 11:00 -17:00 3.00 CMPL T SUN . 2.00 CMPL T SUN CMPL TN CMPL TN 6.00 CMPL TN RUNT CMPL TN op drive and kill and choke lines. RU to run 4 1/2. completion string. Run 4 1/2. completion string with bullplug 0 n bottom to attempt to get to lower lateral. Attempt to get into lower lateral. Rotate pip e past 4508' to 4515'. Slack off to 4560'. Ta gged up at 4560' (CMD sliding sleeve depth of upper lateral) Space out to have x-o @ 4300', MU two pie ce hanger, Land, Run in lockdown screws. RU halliburton wireline to run centralift dum my pump (3.80" OD). Finish Ru Halliburton WL to run 3.80. drift d ummy pump. Run dummy pump drift 3.80" to 4300'. No pr obi ems. RD halliburton WL. POOH wI tubing hanger and pups. RIH wI 4 1/2" tubing. Got past "V" in hook h anger, went to 4602' bullplug depth( = 4493' fl 6" OD: top of hook wall hanger) LID single, RU to circ 400 bbls filtered brin e. Pump 10 bpm @ 950 psi. Final NTU's 18. POOH wI 4 1/2" tubing. Rack back in derrick for ESP completion run. LID 2 7/8" tools, clear rig floor. RU Halliburton video to run in well and obse rve hook wall hanger. RIH wI halliburton 2 1/8" camera to observe hook hanger. Cuttings bed @ 4396'. Did not reach hook wall hanger. POOH, RD WL. RU to run production tubing/ESP. Splicing pi g tail for pump. RU to run 4 1/2" ESP completion. Splice mot or lead connection. PUIMU Centralift motor centralizer, Phoenix guage, centralift 190HP motor, tandem seal section, TTC crossoverlscreen. Fill mtr wit h oil, check rotation, check continuity, meg ger mtr, PU 2 joints(jt # 1 & # 2) 4 1/2" NSTC 12.6#1 ft tubing and Phoenix pressure sub. PJSM to set ESP with Halliburton slic.kline. Run pu mp assembly, run packoff, set pressure test tool. Test packoff to 1000 psi for 15 min. OK. RID Halliburton slickline. Prepare to run ES P assembly wI pump in tubing. PJSM with te am members. RIH wI 4 1'2" ESP completion string. Run 3 joints(jt # 3-#5) 4 1/2" tubing, Camco GLM 0 n pups, then jts #6-#40, continue and start heat trace on jt # 41 (10' down from box), c Printed: 12/12/2001 9:31:38AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-109 1C-109 ROT - DRILLING Nabors Nabors 245 17:00 - 20:00 20:00 - 00:00 11/9/2001 00:00 - 00:30 CMPL TN 00:30 - 12:00 12:00 - 15:00 OTHR CMPL TN 15:00 - 18:00 OTHR CMPL TN 18:00 - 19:00 CMPL TN 19:00 - 19:30 CMPL TN 19:30 - 21 :00 CMPL TN 21 :00 - 00:00 3.00 WELCTL NUND CMPL TN 11/10/2001 00:00 - 04:00 4.00 WELCTL NUND CMPL TN 04:00 - 06:00 2.00 WELCTL NUND CMPL TN 06:00 - 12:00 6.00 WELCTL OTHR CMPL TN 12:00 - 14:30 2.50 CMPLTN FRZP CMPLTN 14:30 - 16:30 2.00 CMPL T FRZP CMPL TN 16:30 - 18:30 CMPL TN 18:30 - 20:30 2.00 CMPL T OTHR CMPL TN Start: 10/17/2001 Rig Release: Rig Number: 245 Spud Date: 10/17/2001 End: Group: ontinue to jt # 45. Heat trace line pinched @ rotary table. Install clamps as recommend ed. Splice Centralift heat trace cable @ jt # 45 , 3'-5' below box of joint # 45. Check cable, OK. RIH wI 4 1/2M ESP completion assembly. Run joints #46- #75. Depth @ midnight 2350' In stall clamps as recommended. PJSM with team members on running 4 112M ESP completion. Continue to run 4 112M completion assembly. Install clamps as reccomended. Megger as recommended. Run from 2350' to 4270'. Splice pig tail on heat trace line to tubing h anger. Splice pig tail on ESP cable to tubing hange r. Orient, land tubing. Run in lockdown screws Test hanger to 5000 psi on upper and lower MO" rings. LID landing joint. Finish laying down central ift equipment from rig floor. PJSM. Change pipe rams, both top and botto m pipe rams to 4 1/2" x 7M VBR. Nipple down BOPE. Nipple up christmas tree. Test tree to 250 & 5000 psi.Test hanger pac koff to 5000 psi. Had to redress two way ch eck. Check electrical connections by Centra lift and Phoenix. RU to freeze protect. Reverse circ 170 bbls 9 ppg KCL taking returns to CPM. Follow wit h 110 bbls diesel- final pressure 900 psi. "u" tube diesel from annulus to tubing. Final pressure 251 psi. Set BPV with lubricator. Rig down cellar equ ipment. Clean up cellar area after rig is moved off h ole. Rig released @ 2030 hrs 11/10101 for m ove to 1 R-35. Pad to pad move 8 miles from well to well. Printed: 12/12/2001 9:31:38 AM Date 11/04101 11/07/01 11/08/01 12/02/01 ( 1 C-1 09 Event H ¡story ( Comment PULLED MWD TOOL F/4458' RKB, COMPLETE. [OTHER STIM] RUN ESP DRIFT SET ESP 4. X 41' ESP PUMP, SET 4. X 6' PACK-OFF, TESTED PACK-OFF TO 1000#, SET 4. SLIP STOP. [ESP WORK] PULLED 4.5. BPV F/ TBG HANGER, PULLED DV F/4090' RKB, SET SOY (SHEAR OUT AT 2000 PSI) PERFORMED SBHP SURVEY, @ 4190' WLM, COMPLETE. [PRESSURE DATA] Page 1 of 1 12/12/2001 (' It AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Surveys Re: Distribution of Survey Data for Well 1 C-1 09 GYRO dD/- ~ D3 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 0.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 20-Nov-01 RECE'\/ED NOV 2 9 2001 Alaska Oil &: Gas Cons. Commission Am~Þ:orage (Ý) <) ra \ ....... Q fâ DEFINITIVE ~- Kuparuk River Unit North Slope, Alaska Kuparuk 1C, Slot 1C-109 1 C-1 09 Gyro Job No. AKMM11171, Surveyed: 26 October, 2001 SURVEY REPORT 21 November, 2001 Your Ref: API-500292304700 Surface Coordinates: 5968746.59 H, 561706.13 E (700 19' 30.5440" N, 149029' 58.6776" W) Surface Coordinates relative to Project H Reference: 968746.59 N, 61706.13 E (Grid) Surface Coordinates relative to Stucture Referance: 229.60 N, 664.05 W (True) Kelly Bushing: 102.O4ft above Mean Sea Level -~~ ~ I spe'-'I'\I-sul! DRILLING SERVices A Halliburton Company Survey Ref: svy9663 < ~ Kuparuk River Unit Measured Depth Incl. Azlm. (ft) 0.00 0.000 0.000 106.00 0.700 275.000 201.00 1.100 292.000 Sperry-Sun Drilling Services Survey Report for fC-f09 Gyro Your Ref: API-500292304700 Job No. AKMM11171, Surveyed: 26 October, 2001 . DEFINIT\VE North Slope, Alaska Kuparuk 1C Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Depth Northlngs EIstlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) . -102.04 0.00 O.OON O.OOE 5968746.59 N 561706.13 E 0.00 Tolerable Gyro 3.96 106.00 0.06N 0.65W 5968746.64 N 561705.48 E 0.660 -0.31 98.95 200.99 0.45 N 2.07W 5968747.02 N 561704.06 E 0.502 -1.23 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. ',-- Vertical depths are relative to AKB = 102.04' MSL. Northings and Eastings are relative to 1487' FNL & 699' FWL. Magnetic Declination at Surface is 26.099° (15-0ct-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1487" FNL & 699' FWL and calculated along an Azimuth of 156.780° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 201.000., The Bottom Hole Displacement is 2.12f1., in the Direction of 282.236° (True). Survey tool program for 1C-109 Gyro From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 ~ To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 201.00 200.99 Tolerable Gyro ~ I --- u- ~ 21 November, 2001 - 10:56 -__.---h --------- Page 2 of 2 Drl/lQuest 2.00.09.003 ( ( 20-Nov-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Surveys Re: Distribution of Survey Data for Well 1 C-1 09 dOJ/ dD3 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Su rvey: Window / Kickoff Survey Projected Survey: 201.00' MD 'MD 7,510.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED NOV 2 9 2001 Alaska Oil 8: Gas Cons, Commission Ancf;orage II DEFINITIVE Kuparuk River Unit North Slope, Alaska Kuparuk 1C, Slot 1C-109 1C-109 Job No. AKMM11171, Surveyed: 26 October, 2001 -~, "0": SURVEY REPORT 21 November, 2001 Your Ref: API- 500292304700 Surface Coordinates: 5968746.59 N, 561706.13 E (70" 19' 30.5440" N, 149" 29' 58.6776" W) Surface Coordinates relative to Project H Reference: 968746.59 N, 61706.13 E (Grid) Surface Coordinates relative to Stucture Referance: 229.60 N, 664.05 W (True) . Kelly Bushing: 102.04ft above Mean Sea Level . ..-.., ~ I =par""'V-5ull DAILLING SERVices A Halliburton Company Survey Ref; svy9707 Sperry-Sun- Drilling Services . Survey Report for fC-109 Your Ref: API- 500292304700 DEFINITIVE Job No. AKMM11171, Surveyed: 26 October, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (D/100ft) . 201.00 1.100 292.000 98.95 200.99 0.45 N 2.07W 5968747.02 N 561704.06 E -0.47 MWD Magnetic 320.99 1.530 297.960 218.90 320.94 1.63 N 4.55W 5968748.18 N 561701.57 E 0.376 -1.67 411.09 2.200 309.420 308.96 411.00 3.29N 6.95W 5968749.83 N 561699.15 E 0.847 -3.35 -~- 477.62 2.380 318.210 375.43 477.47 5.13 N 8.86W 5968751.65 N 561697.23 E 0.592 -5.21 508.65 2.490 335.530 406.44 508.48 6.23N 9.57W 5968752.74 N 561696.51 E 2.388 -6.31 556.30 2.790 321.430 454.04 556.08 - 8.08N 10.72 W 5968754.58 N 561695.35 E 1.496 -8.17 601 .15 2.810 337.250 498.83 - 600.87 9.94N 11.82 W 5968756.44 N 561694.23 E 1.718 -10.04 649.84 4.720 11.610 547.42 649.46 13.01 N 11.88 W 5968759.50 N 561694.14 E 5.907 -13.11 693.30 6;140 14.170 - 590.68 692.72 17.01 N 10.95 W 5968763.51 N 561695.04 E 3.314 -17.10 737.43 6.400 8.060 634.55 736.59 21.74 N 10.03 W 5968768.24 N 561695.92 E 1.622 -21.82 776.08 7.410 353.200 672.92 774.96 26.34 N 10.02 W 5968772.85 N 561695.89 E 5.288 -26.43 834.28 7.600 348.550 730.63 832.67 33.84 N 11.23 W 5968780.34 N 561694.62 E 1.093 -33.94 877.91 7.330 346.590 773.89 875.93 39.38 N 12.45 W 5968785.86 N 561693.36 E 0.851 -39.48 939.58 8.170 341 .550 834.99 937.03 47.36 N 14.75W 5968793.83 N 561690.99 E 1.751 -47.48 982.96 9.450 331.710 877.86 979.90 53.42 N 17.41 W 5968799.87 N 561688.28 E 4.548 -53.57 1031.53 12.930 328.990 925.50 1027.54 61.59 N 22.10 W 5968808.00 N 561683.52 E 7.245 -61. 78 1072.28 16.940 329.420 964.87 1066.91 70.62 N 27.47 W 5968816.98 N 561678.08 E 9.844 -70.84 1126.25 18.640 331.270 1016.26 1118.30 84.95 N 35.62 W 5968831.24 N 561669.81 E 3.319 -85.24 1168.78 20.120 332.900 1 056.37 1158.41 97.42 N 42.22 W 5968843.66 N 561663.11 E 3.705 -97.77 1218.58 20.820 335.070 1103.03 1205.07 113.07 N 49.85 W 5968859.25 N 561655.35 E 2.073 -113.49 .----- 1262.79 21 .300 334.840 1144.29 1246.33 127.47 N 56.58 W 5968873.59 N 561648.50 E 1.102 -127.94 1315.64 21.250 335.840 - 1193.54 1295.58 144.89 N 64.58 W 5968890.95 N 561640.36 E 0.693 -145.43 1359.74 23.460 335.580 1234.32 1336.36 160.18 N 71.48 W 5968906.18 N 561633.3~ E 5.016 -160.77 1409.94 25.970 336.150 1279.92 1381.96 179.33 N 80.06 W 5968925.26 N 561624.60 E 5.022 -180.00 1467.36 26.530 336.300 1331.41 1433.45 202.57 N 90.30 W 5968948.41 N 561614.17 E 0.982 -203.32 1504.33 28.480 334.440 1364.21 1466.25 218.09 N 97.42 W 5968963.87 N 561606.92 E 5.763 -218.90 1569.42 29.910 334.330 1421.02 1523.06 246.72 N 111.14W 5968992.38 N 561592.96 E 2.199 -247.64 1598.98 32.290 334.140 1446.33 1548.37 260.47 N 117.78 W 5969006.08 N 561586.21 E 8.058 -261.44 1660.13 34.190 333.550 1497.48 1599.52 290.55 N 132.56 W 5969036.04 N 561571.19 E 3.152 -291.65 1694.70 35.160 332.550 1525.91 1627.95 308.08 N 141.48 W 5969053.50 N 561562.13 E 3.253 -309.25 ---------- m____- --------- 21 November, 2001 - 10:56 Page 2 of 6 DrIllQuesI2.00.09.003 Sperry-Sun Drilling Services . Survey Report for 1C-109 Your Ref: API- 500292304700 Job No. AKMM11171, Surveyed: 26 October, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct Azim. Depth Depth Northlngs Eastlngs Northlngs . Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) . 1721.68 37.050 330.620 1547.70 1649.74 322.06 N 149.04 W 5969067.41 N 561554.44 E 8.175 -323.29 1788.77 38.960 330.310 1600.57 1702.61 358.00 N 169.41 W 5969103.18 N 561533.78 E 2.861 -359.40 1833.36 41.700 330.580 1634.56 1736.60 383.10 N 183.64 W 5969128.16 N 561519.34 E 6.157 -384.62 - 1883.41 41.350 330.880 1672.03 1774.07 412.04 N 199.86 W 5969156.97 N 561502.88 E 0.804 -413.70 1976.80 40.370 330.680 1742.66 1844.70 465.36N 229.69 W 5969210.05 N 561472.62 E 1.059 -467.27 .. _.. 2072.12 42.320 330.610 1814.21 1916.25 520.24 N 260.56 W 5969264.67 N 561441.31 E 2.046 -522.41 2166.60 42.240 330.790 1884.12 1986.16 575.67 N 291.66 W 5969319.85 N 561409.74 E 0.154 -578.10 2262.02 41.710 329.720 1955.06 2057.10 631.08 N 323.32 W 5969374.99 N 561377.63 E 0.933 -633.77 2356.87 41.140 329.080 2026.18 2128.22 685.10 N 355.26 W 5969428.75 N 561345.24 E 0.749 -688.05 2449.64 40.860 328.500 2096.19 2198.23 737.15 N 386.80 W 5969480.54 N 561313.28 E 0.509 - 740.37 2545.63 38.250 325.070 2170.20 2272.24 788.30 N 420.23 W 5969531.41 N 561279.43 E 3.545 - 791.79 2640.36 32.050 318.640 2247.65 2349.69 831.26 N 453.67 W 5969574.10 N 561245.64 E 7.615 -835.04 2735.20 27.010 310.610 2330.18 2432.22 864.20 N 486.68 W 5969606.76 N 561212.36 E 6.747 -868.25 2828.20 26.280 300.370 2413.34 2515.38 888.37 N 520.50 W 5969630.65 N 561178.35 E 4.994 -892.70 2924.61 25.890 289.820 2499.98 2602.02 906.31 N 558.73 W 5969648.27 N 561139.96 E 4.823 -910.96 3019.42 24.160 278.040 2585.94 2687.98 916.05 N 597.44 W 5969657.69 N 561101.17 E 5.554 -921.02 3114.07 23.720 261.610 2672.54 2774.58 915.98 N . 635.50 W 5969657.31 N 561063.12 E 7.039 -921.27 3208.97 26.790 249.440 2758.42 2860.46 905.67 N 674.44 W 5969646.69 N 561024.26 E 6.341 -911.29 3303.31 28.570 239.570 2842.01 . 2944.05 886.77 N 713.83 W 5969627.46 N 560985.04 E 5.207 -892.72 3396.08 30.160 232.130 2922.88 3024.92 861 .22 N 751.36 W 5969601.60 N 560947.71 E 4.287 -867.48 ~, 3487.99 33.4 70 224.070 3001.01 3103.05 828.81 N 787.24 W 5969568.90 N 560912.10 E 5.854 -835.38 3582.33 36.520 218.000 3078.30 3180.34 787.98 N 822.64 W 5969527.78 N 560877.04 E 4.903 - 794.84 3676.90 39.500 209.530 3152.86 3254.90 739.59 N 854.82 W 5969479.13 N 560845.2Q E 6.346 -746.73 3771.58 41.480 198.800 3224.95 3326.99 683.63 N 879.80 W 5969422.96 N 560820.74 E 7.642 -690.98 3866.41 45.960 191.890 3293.51 3395.55 620.48 N 896.96 W 5969359.67 N 560804.10 E 6.900 -627.97 3961.14 49.310 188.630 3357.34 3459.38 551.62 N 909.37 W 5969290.72 N 560792.26 E 4.355 -559.22 4055.66 52.920 185.760 3416.68 3518.72 478.65 N 918.53 W 5969217.67 N 560783.69 E 4.491 -486.33 4150.87 54.540 180.410 3473.03 3575.07 402.05 N 922.63 W 5969141.04 N 560780.23 E 4.838 -409.76 4245.49 58.210 178.260 3525.42 3627.46 323.28 N 921.68 W 5969062.28 N 560781.82 E 4.315 -330.99 4339.87 61.650 180.020 3572.70 3674.74 241.63 N 920.48 W. 5968980.65 N 560783.70 E 3.986 -249.34 -- -- ~--- ---_.--- 21 November, 2001- 10:56 Page 3 of 6 DrlllQuest 2.00.09.003 Sperry-Sun. Drilling Services . Survey Report for 1C-109 Your Ref: API- 500292304700 . Job No. AKMM11171, Surveyed: 26 October, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1C Measured Sub-Sea Vertical Local Coordinates . Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs . Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) . (ft) (ft) (ft) (ft) (O/100ft) . 4434.57 65.780 179.520 3614.63 3716.67 156.74 N 920.13 W 5968895.76 N 560784.74 E 4.387 -164.45 4529.27 69.490 177.720 3650.66 3752.70 69.21 N 918.00 W 5968808.25 N 560787.59 E 4.294 -76.90 4624.38 75.820 177.800 3679.00 3781.04 21.46 S 914.46 W 5968717.61 N 560791.88 E 6.656 13.79 -. 4718.23 84.950 179.280 3694.66 3796.70 113.86 S 912.12 W 5968625.24 N 560794.98 E 9.851 106.21 4749.65 87.660 178.300 3696.69 3798.73 145.20 S 911.46 W 5968593.90 N 560795.90 E 9.169 137.56 4811.92 86.490 178.310 3699.86 3801.90 207.36 S 909.62 W 5968531.75 N 560798.25 E 1.879 199.74 4884.56 87.230 177.460 . 3703.84 3805.88 279.84 S 906.94 W 5968459.30 N 560801.52 E 1.550 272.24 4967.35 89.320 180.140 3706.34 3808.38 362.57 S 905.21 W 5968376.59 N 560803.93 E 4.104 354.97 5023.61 91.110 180.410 3706.12 3808.16. 418.82 S 905.48 W 5968320.34 N 560804.13 E 3.218 411.22 5076.40 91.540 181.000 3704.90 3806.94 471-.59 S 906.13 W 5968267.56 N 560803.91 E 1.383 463.99 5120.05 91.910 180.170 3703.59 3805.63 515.22 S 906.57 W 5968223.93 N 560803.83 E 2.081 507.61 5170.41. 90.250 179.540 3702.64 3804.68 565.57 S 906.44 W . 5968173.59 N 560804.37 E 3.526 557.96 5213.85 89.200 179.040 3702.85 3804.89 609.01 S 905.91 W 5968130.16 N 560805.26 E 2.677 601.39 5265.85 88.400 177.730 3703.94 3805.98 660.97 S 904.44 W 5968078.20 N 560807.15 E 2.951 653.37 5307.60 89.820 177.920 3704.59 3806.63 702.69 S 902.86 W 5968036.50 N 560809.08 E 3.431 695.10 5360.33 90.550 177.630 3704.42 3806.46 755.38 S 900.81 W 5967983.83 N 560811.56 E 1.490 747.80 5403.51 91.050 175.720 3703.81 3805.85 798.48 S 898.31 W 5967940.75 N 560814.42 E 4.572 790.92 5454.48 92.030 174.880 3702.44 3804.48 849.26 S 894.13 W 5967890.01 N 560819.01 E 2.532 841 .73 5496.28 92.830 175.320 3700.67 3802.71 890.86 S 890.56 W 5967848.43 N 560822.92 E 2.184 883.37 5550.10 90.740 177.790 3698.99 3801.03 944.55 S 887.33 W 5967794.77 N 560826.59 E 6.010 937.09 ,-. 5594.15 90.120 178.130 3698.66 3800.70 988.57 S 885.76 W 5967750.76 N 560828.52 E 1.605 981.12 5645.42 90.370 177.600 . 3698.45 3800.49 1039.81 8 883.85 W 5967699.55 N 560830.86 E 1.143 1032.37 5695.05 90.550 177.030 3698.05 3800.09 1089.38 8 881.53 W 5967650.00 N 560833.59 E 1.204 1081.96 5740.17 91.910 178.830 3697.08 3799.12 1134.46 8 879.90 W 5967604.93 N 560835.59 E 4.999 1127.05 5821.13 89.010 180.070 3696.43 3798.47 1215.40 8 879.12 W 5967524.00 N 560837.03 E 3.896 1208.00 5929.89 88.950 178.340 3698.36 3800.40 1324.138 877.61 W 5967415.29 N 560839.43 E 1.591 1316.73 6024.48 89.690 182.010 3699.49 3801.53 1418.708 877.90 W 5967320.72 N 560839.92 E 3.958 1411.29 6116.89 90.550 186.080 3699.29 3801.33 1510.868 884.42 W 5967228.51 N 560834.16 E 4.501 1503.39 6213.79 90.060 184.210 3698.78 3800.82 1607.36 8 893.11 W 5967131.94 N 560826.27 E 1.995 1599.82 6308.62 90.120 183.240 3698.63 3800.67 1701.998 899.27 W 5967037.26 N 560820.89 E 1.025 1694.40 - ..... q.-.. -_._- .. 21 November, 2001 - 10:56 Page 4 of 6 DrlllQuest 2.00.09.003 . Sperry-Sun Drilling Services Survey Report for 1C-109 Your Ref: API- 500292304700 Job No. AKMM11171, Surveyed: 26 October, 2001 . . . North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) " (ft) (0/100ft) , 6400.21 90.550 182.780 3698.09 3800.13 1793.45 5 904.08 W 5966945.77 N 560816.83 E 0.687 1785.81 6496.65 90.120 181.270 3697.53 3799.57 1889.83 5 907.49 W 5966849.37 N 560814.21 E 1.628 1882.16 6591.78 90.680 180.180 3696.87 3798.91 1984.945 908.69 W 5966754.24 N 560813.79 E 1.288 1977.26 -- 6686.87 91.050 178.340 3695.43 3797.47 2080.01 5 907.46 W 5966659.19 N 560815.80 E 1.974 2072.34 6781.02 89.690 178.180 3694.82 3796.86 2174.11 5 904.60 W 5966565.11 N 560819.43 E 1 .454 2166.46 ' -~- 6875.75 90.000 177.390 3695.08 3797.12 2268.77 S 900.94 W 5966470.49 N 560823.87 E 0.896 2261 .14 6970.73 90.370 175.500 3694.77 3796.81 2363.56 5 895.05 W 5966375.75 N 560830.54 E 2.028 2355.98 7064.84 90.740 175.010 3693.86 3795.90 2457.35 S 887.27 W 5966282.03 N 560839.10 E 0.652 2449.83 7159.63 90.000 178.220 3693.25 3795.29 2551.965 881.67 W 5966187.47 N 560845.47 E 3.475 2544.48 7253.80 90.490 180.300 3692.84 3794.88 2646.11 5 880.46 W 5966093.33 N 560847.46 E 2.269 2638.64 7348.77 90.490 179.010 3692.03 3794.07 2741.075- 879.89 W 5965998.37 N 560848.81 E 1.358 2733.61 7443.48 90.180 177.210 3691.48 3793.52 2835.735 876.76 W 5965903.75 N 560852.72 E 1.928 2828.28 7510.00 90.180 177.210 3691.27 3793.31 2902.175 873.52 W 5965837.34 N 560856.50 E 0.000 2894.75 Projected Survey All data is in Feet (US) unless òtherwise stated. Directions and coordinates are relative to True North, Vertical depths are relative to RKB = 102.04' MSL. Northings and Eastings are relative to 1487' FNL & 699' FWL. Magnetic Declination at Surface is 26.099° (15-0ct-01) The Dogleg Severity is in Degrees per 1 00 feet (U5). - - Vertical 5ection is from 1487' FNL & 699' FWL and calculated along an Azimuth of 179.520° (True). -" Based upon Minimum Curvature type calculations, at a Measured Depth of 7510.000., The Bottom Hole Displacement is 3030.78ft., in the Direction of 196.751° (True). ~ I ---- - _.- ~----------- ----- "---- 21 November, 2001 - 10:56 Page 5 of 6 DrlllQuest 2.00.09.003 .- . Kuparuk River Unit Comments Measured Depth (ft) 7510.00 '---- Sperry-Sun Drilling Services Survey Report for lC-l09 Your Ref: API.. 500292304700 Job No. AKMMl117l, Surveyed: 26 October, 2001 Station Coordinates" TVD Northlngs Eastlngs (It) (ft) (ft) 3793.31 Survey tool program for 1C-109 From Measured Vertical Depth Depth (ft) (ft) 0.00 201.00 , '--.- 21 November, 2001 - 10:56 0.00 200.99 2902.17 S To Measured Vertical Depth Depth (ft) (ft) 201.00 7510.00 200.99 3793.31 Comment 873.52 W Projected Survey . ~ - Survey Tool DeScription Tolerable Gyro (1C-109 Gyro) MWD Magnetic (1 C-1 09) North Slope, Alaska Kuparuk 1C ~ ---- ~ I --- - --- DrlllQuest 2.00.09.003 Page 6 of 6 ,;1' { ~u~uŒ [ffi~ ~~~~~~ / / ( TONY KNOWLES, GOVERNOR ALAS IiA 0 IL AND GAS COl\TSERVATI ON COMMISSION 333 W. "JTH 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 1 C-I 09 Phillips Alaska, Inc. Pennit No: 201-203 Sur Loc: 1487' FNL, 699' FWL, Sec. 12, TIIN, RlOE, UM Btmhole Loc. 969' FSL, 241' FEL, Sec. 11, TIIN, RlOE, UM Dear Mr. Mallary: Enclosed is the approved application for pennit to drill the above referenced well. The pennit 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 pennitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted 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 fonn 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 surfacelproductioncasing annulus of a well approved for annular disposal on I C Pad must comply with the requirements and limitations of 20 AAC 25.080. Approval of this pennit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~~~ Cammy Oeclìsli Taylor Chair BY ORDER RIïffHE COMMISSION DATED this~ay of October, 2001 jj c/Enclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. PHILL\,JS Alaska, Inc. . A Subsidiary of PHILLIPS PETROLEUM COMPANY ( Post Office Box 100360 Anchorage, Alaska 99510-0360 Chuck Mallary Phone (907) 265-6434 Fax: (907) 265-1535 Email: anallar@ppco.com October 11, 2001 Commissioner Cammy Oechsli Taylor Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, West Sak Multilateral Producer, lC-l09 & lC-l09Ll Dear Commissioner Taylor: Phillips Alaska, Inc. hereby applies for two Permits to Drill for an onshore production well, a multilateral well for West Sak production. The two lateral legs of the well will be designated lC-l09 (main bore) and lC-l09Ll (sidetrack bore) Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of lC-l09 is Sunday, October 14, with operations on lC-l09Ll expected to commence approximately 10 days later. If you have any questions or require any further information, please contact Steve McKeever at 265- 6826. Chuck Mallary GKA Drilling Engineering Supe isor RECEIVED OCT 11 2001 Alaska Oil & Gas Cons. Commission Anchorage OR I GI NAL ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL klCf( \ 1 a. Type of work: Drill ~ Redrill U Re-entry 0 Deepen 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 14871 FNL, 699' FWL, Sec. 12, T11 N, R1OE, UM At top of productive interval 17041 FSL, 2381 FEL, Sec. 11, T11 N, R10E, UM At total depth 969' FSL, 2411 FEL, Sec. 11, T11 N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well 969 @ TO feet 1C-10 28' @ 700' 16. To be completed for deviated wells Kickoff depth: 600' MD 18. Casing program size 20 MC 25.005 1b. Type of well. Exploratory 0 Stratigraphic Test U Service 0 Development Gas 0 Single Zone ø ..~þ 5. Datum elevation (OF or KB) RKB = 102 feet AMSL feet 6. Property Designation ADL 25649 ALK 467 7. Unit or property Name 11. Type Bond (see 20 MC 25.0251) Kuparuk River Unit Statewide 8. Well number Number 1 C-1 09 #59-52-180 9. Approximate spud date Amount October 14, 2001 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVO) 2560 7513' MD 13800' TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 1330 psig At total depth (TVD) 1748 psig Settina DeDth Development Oil I:!I Multiple Zone 0 10. Field and Pool Kuparuk River Field West Sak Oil Pool Maximum hole angle 90° Hole 24" Casino 16" Weioht 62.5# 29.7# 12.6# Specifications Grade Couplino H-40 Weld L-80 BTCM L-80 NSCT LenQth 120' 49761 28201 MD 41.21 412 46931 TOD TVD 41.2' 41.21 3736' MD 161' 50171 7513' Bottom TVD 1611 38041 38001 Quantity of Cement (include staoe data) 282 sx AS 1 530 sx AS Lite & ~sx Class G slotted screen Z.yO 9.875" 6.75" 7.625" 4.5" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Plugs (measured) Effective Depth: measured true vertical feet feet Junk (measured) Casing Conductor Surface 0 Length Size Cemented Measured depth True Vertical depth RECEIVED OCT 11 2001 Perforation depth: measured true vertical Alaska Oil & Gas Cons. CommissÎon Anchorage 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 DRefraction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21. I hereby certify n the f~ng >ïu~ and corr" tr:. best of my knowledge Questions? Call Steve McKeever 265-682l SIgned C ~ ~~~ Title; DriNmgEng;_ringSup",,",'" Date II Pd of c. Mallarv II ~ . - AII""...-nr~/a: 1/ Commission Use Onl\ Permit Number, 7', -::< API number V [I "7. 0 0 Approval date ¡ /\ I / \ See cover letter '2-D - 2<X-..) 50- 0 '2.-'}' - 230,'" I(} If n Jf) I for otherrequirements Conditions of approval Samples required 0 Yes 1:&1 No Mud log required "" I 0 Yes ~ No Hydrogen sulfide measures 0 Yes ~Jo Directional survey required IRI Yes 0 No Required working pressure for BOPE 0 2M; ~M; 0 5M; 0 10M; 0 0 Other: Approved by Original Signed BV - - I I' I Commissioner by order of the commission Date I Ò) I/J¡r){ G rJ r' I ;~ ~ ,II j¡j¡¡licate Form 10-401 Rev. 12/1/85. OR ,," ( {" -::ation for Permit to Drill, Well 1 C-109 . Revision No.O Saved: 11-0ct-01 Permit It - West Sak Well #1 C-1 09 Application for Permit to Drill Document MoximizE We-II VQIU~ Table of Contents 1. Well Name........................ ............................................ ... ..........................................2 Requirements of 20 AAC 25.005 (f)........................................................................................................2 2. Location Sum mary ...................................................... .............................................2 Requirements of 20 AAC 25. 005( c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b)........................................................................................................3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25. 005( c)(3) ................................................................................................... 3 4. Dri II i ng Hazards Information ...................................... .............................................3 Requirements of 20 AAC 25.005 (c)(4) """""""""""""""""""""""""""""........................................3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casi ng and Cementing 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 u id Program............................................................................................. 5 Requirements of 20 AAC 25. 005(c)(B) ................................................................................. ..................5 Surface Hole Mud Program ....................................................................................................................5 Lateral Mud Program ..............................................................................................................................5 9. Abnormally Pressured Formation Information ...................................................... 6 Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................6 1 (). Seismic Analysis......................................................................................................6 Requirements of 20 AAC 25.005 (c)(1 0) ........................................................... ..................................... 6 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 12. Evidence of Bondi ng................................................................................................ 6 ð RlGr¡¡~ L ( (' ;cation for Permit to Drill, We1l1C-109 Revision No.O Saved: 11-0ct-O1 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................6 13. Proposed Dri II i ng Program ... ...... ............ .............. ......... ..................................... .....6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................8 15. Attachments............................................................................................................. 8 Attachment 1 Directional Plan......................................................."""""""""""""""""""""""""""'" 8 Attachment 2 Diagrams of the BOP / Diverter System .". ....... ...... .......... ........ ........................ ...............8 Attachment 3 Drilling Hazards Summary............................................................................................... 8 Attachment 4 Cement Loads and CemCADE Summary ....................................................................... 8 Attachment 5 Well Schematic................................................................................................................8 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be Identified by a unique name designated by the operatvr and a unique API number assigned by the commis:<;io() under 20 AAC 25".040(/)). F()r a well with multiple well branc/7es/ ead7 branch must :,ì"rni/arly be identified by a unique name and API number by adding a suffix tv the name deggnated fvr the well by tbe operatvr and tv the number as'!:Jìgned tv the well by tbe c:ommis-siofl. The well for which this Application is submitted will be designated as lC-l09, 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Pe/7mt to Onll must be accompanied by each of the following Items~ except for an item already on file with the commission and identlfïed in the application: (2) a plat identifYing the property and the property~<; owners and showing (A)the coo/dinates of' the proposed location of'the well at the slJrf"ace/ at the top of each objectiVt': fo/Tnation and at total depth referenced tv governmental section lines. (8) the coordinates of the propo.sed location of the well at the surf-aCf!/ referenced to the .state plane coordinate system for this state as maintained by the National Geodetic Survey in tbe National Oceanic and AtmospheJic Administration; (C) the proposed depth of the well at the top or each objeäive formation and at tvtal depth; Location at Surface I 1487' FNL, 699' FWL, Section 12, Tl1N, Rl0E, UM NGS Coordinates RKB Elevation 101.9' AMSL Northings: 5,968,746 Eastings: 561,706 Pad Elevation 60.7' AMSL Location at Top of Productive Interval West Sak "8" Sand NGS Coordinates Northings: 5,968,523 1704' FSL, 238' FEL, Section 11, TllN, Rl0E, UM Eastings: 560,771 4905 3796 3694 Location at Total De th NGS Coordinates Northings: 5,965,916 Eastings: 560,791 UM 7513 3800 3698 and (0) other information requÜ"ed by 20 AAC 25.050{b); ð Rlë11lj L ( f °c:ation for Permit to Drill, We1l1C-109 Revision No.O Saved: 11-0ct-O 1 Requirements of 20 AAC 25.050(b) If a well is to be 1i7tentiona/ly deviated, the application for a Permit to Drill (Form 10-401) must (1) include a pla~ drawn to a suitable scale, showing the path of the proposed wellbore, including 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 well~ to the extent that those names are known or discoverable in public records, and show tJ7at each named operator has been fumisJìed a copy of the application by certified mai~' or (B) 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 Of/I! must be accompanied by each of the following items, except for an item already 017 file with the commi~"'5ion and Identified in the application: (3) a diagram and descliption of the blowout prevention equipment (BOPE) as required by 20 AAC 25:035, 20 AAC 2S.03~ or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack will be utilized to drill and complete welllC-l09. Please see "Diagram and Description of the Blowout Prevention Equipment for Nabors Rig 245e", placed on file with the Commission. One of the spacer spools used in the stack arrangement is a combination diverter spool and spacer spool. Please see Attachment 2. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An applk:ation for a Permit to Drill must be accompanied by each of the following items, except fof' an item already on file wIth the commis.c,ion and identified in tile application: (4) infO/mation on dlilliny hazard~~ ineiuding (A) the maximum cfownhole pressure that may be em.:vunterect clitetia used to determine it, and maximum potential surface pressure based 0/7 a methane gradient; The expected reservoir pressures in the West Sak sands in the lC pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight). These are pressures obtained from actual well test data from the nearby WS1-0l well. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 1330 psi, calculated thusly: MPSP =(3800 ft)(0.46 - 0.11 psi/ft) =1330 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data conceming potentìal causes of" hole problems such as abnormally geo-pres..c;ured strata, lost circulation zones~ and zones that have a propensity for differential sticking; Please see Attachment 3: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by eaäl of'the f'ollowing items~ except for an item already 0/7 file with the commi::,:;ion and Identified i/7 the application: (.5) a descriptio/7 ofthe procedure for conducting folmation integrìty teste;, as required under 20 AAC 2.5,030(1); 10-109 PERMIT IT. doc 0 RfG1imt f' (' 'cation for Permit to Drill, We1l1C-109 Revision No,Q Saved: 11-0ct-O1 lC-l09 will be completed with 7-5/8" surface casing landed in the West Sak B-Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that Phillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner; pre- perforated liner; or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Top atm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (lb/tt) Grade Connection (tt) (tt) (tt) Cement PrO.Qram 16 24 62.5 H-40 Welded 120 41/41 161 / 161 Cemented to surface with 225 cf Arcticset 1 7-5/8 9-7/8 29.7 L-80 BTCM 4976 41/41 5017/3804 Cemented to Surface with 530 sx AsLite Lead, 240 sx Class G Tail 4-1/2 6-3/4" 12.6 L-80 NsCT 2820 4693/ 3736 7513/3800 siotted- no slotted Lower cement Lateral 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Pel7mt to Dnïl must be acevmpzmied by each of'the following Items~ except for an item already on fìle with the commission and Identified in the application: (7) a diagram and desCliption of the dive/fer ;,ystem as required by 20 AAC 25. 035, unless this reqwi'emfmt is waived by the comm£<;sion under 20 AAC 25.035(/1)(2); A combination 13-5 BOP stack / diverter system will be used in the drilling of lC-l09. Please see diagrams in Attachment 2. 1C-1~,". 9 P.,EFJMJT," ',:r,.c/"",.IO~", .. a'i':' , Page~ qlC¡i\ L ' ¡(P(jn"tet1¡p.'41.;-Qc,t, ~Q:t~ ." liiVC~j~ !I f (I 'cation for Permit to Drill, We1l1C-109 Revision No,O Saved: 11-0ct-O1 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 items, except for an item a/ready on file with the commission and Identified in the application: (8) a dnlling fluid program, tf7c1uding a diagram and descriptio/7 of the cfrilling flUId system, as required by 20 AAC 25".033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program Spud to Base of Permafrost Base of Permafrost to 9-718" Hole TD Initial Value Final Value Initial Value Final Value Density (ppg) 8.5 ~9.4 <9.4* 9.4* Funnel Viscosity (seconds) 150-200 150-200 150 75 Yield Point(cP} 30-60 30-60 20-40 18-30 Plastic Viscostiy (lb1100 sf) 8-15 11-22 15-30 15-30 10 second Gel Strength (lb1100 10-30 10-25 10-25 10-25 sf) 10 minute Gel Strength (lb1100 25-55 25-55 20-40 20-40 sf) pH 8-9 8-9 8-9 8-9 API Filtrate( cc} 8-15 6 5-6 5-6 Solids (%) 5-8 5-8 5-8 6-11 *9.8 ppg if hydrates are encountered Lateral Mud Program B sand lateral Initial Value Final Value Densil:y (ppg) 8.9-9.0 8.9-9.0 Funnel Viscosity (seconds) 45-60 45-60 Yield Point 18-25 18-25 {cP} Plastic Viscostiy (lbj100 sf) 8-14 8-14 Tau 0 4-7 4-7 BID sand laterals Initial Value Final Value Chlorides 13-15K 13-15K pH 8-8.5 8-8.5 API filtrate <6 <6 **HTHP filtrate <10 <10 MBT <2.5 <2.5 ***Solids ppb <12 <12 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 585 Mud Cleaner, (2) Alpha-Laval Model 418-VT- 5 Centrifuges, Degassers, PVT System with visual and audio alarms, Trip Tank, Flow Sensor, and Fluid Agitators. Please see "Diagram of Mud System, Nabors Rig 245e", placed on file with the Commission. 0 RttSl£ f { ~ation for Permit to Drill, Well 1 C-1 09 Revision No.O Saved: 11-0ct-01 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Pem7it 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: (9) for an exploratory or stratigraphic test wel¿ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.03J(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 file with the commis"Sion and Identified in the application: (10) for an exploratory or stratigraphic test we/~ a seismic refraction or reflection analysis as required by 20 AAC 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 Penmt to Dlill must be accompanied by each of'the following Items, except lor an Item already on file with the commission and identIfied in the application: (1.1) for a well dn!led from an off.<;I70re platform, mobile bottom-lounded structure, jack.up ržq, or floating drilling vesse¿ an analy..':>ì:'i of seabed conditions as requif'ed by 20 AAC Z5:06.1(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 Dn!1 must be accompanied by ead7 of the following ¡[ems~ except tÓr an item already on file with the commission and identified in the application: (.l2) evidence sÝlOwli7g that the requirements of'20 AAC 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 application for a Permit to Drill must be accompanied by each of the following item:."", except for an item already 017 file with the commission and identified in the appliec-1tion: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 158' RKB. Weld landing ring on conductor. Install Vetco Gray Gen II wellhead. 2. Move in / rig up Nabors 245e. Install Diverter / BOPE and function test. 3. Spud and directionally drill 9-7/8" hole to casing point at +/- 5017' MD / 3804' lVD as per directional plan. Run MWD, LWD 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. Remove 16" Diverter line, install blind flange, activate 1500 psi) 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 +/- 7,513' MD / 3,800' lVD as per directional plan. '3.CJOÒ and test BOP's to ~ psi (annular preventer to 0 n r~lf¡æ~~ (' {' ~ation for Permit to Drill, We1l1C-109 Revision No.O Saved: 11-0ct-O1 9. POOH and lay down MWD, LWD and PWD tools. 10. Pick up and rack back weight pipe as needed for liner running. 11. RIH with 6-3/4" hole opener and ream entire open hole. 12. Circulate and condition hole to run liner. 13. PU and run 4-1/2" Slotted Liner (run liner with 2-7/8" inner wash string). 14. Land liner, set liner packer @ +/- 4,693' MD / 37361 1\ID and displace drilling mud with 30/0 KCL brine weighted to 8.9 ppg, mixed with seawater and previously weighted brine. POOH. Note: Remaining operations are covered under the lC-l09 Ll Application for Permit to Drill, and are provided here for information only. 1. Run and set Baker 2-trip whipstock system, 30 degrees to left of high side at window point of 4,601' MD / 3,734' 1\ID 2. Displace wellbore to used Baradril'N fluid from the lower lateral. 3. Mill starting window in D-sand. POOH. 4. Polish and complete window with finishing mill and 2 watermelon mills. 5. Pick up 6" drilling assembly, RIH, and drill 20-50 feet of new hole. i!;' 6. Change over to clean BaraDril'N drilling mud. ~ 7. Perform Formation Integrity Test to 12.0 ppg EMW. ~ 8. Continue to directionally drill to TD of D sand lateral at 7,508' MD / 3,746' 1\ID. POOH. 9. POOH and lay down MWD, LWD and PWD tools. 10. RIH with 6" hole opener and ream entire open hole. 11. Circulate and condition hole to run liner. POOH and lay down hole opener assembly. 12. RIH with whipstock retrieval tool to whipstock. Retrieve whipstock and POOH, 13. PU 4" Liner with flanged hook hanger, CMD, and 4-1/2" slotted liner and 2-7/8" inner wash string, 14. RIH, until hook hanger is just above window. Orient hook hanger to window with MWD tool and land hanger. 15. Release hanger running tool and POOH. 16. Make up diverter on GS running tool and RIH. Set diverter in Hook Hanger and POOH, 17. Make up 2-7/8" cup tool assembly and inner wash string and RIH to TD. 18. Displace drilling mud from outside the liner with 3% KCL brine weighted to 8.9 ppg. Pick up and disengage from pack off bushing and displace mud from inside the liner with 3% KCL brine weighted to 8.9 ppg. POOH. 19. RIH with GS running tool on 4-1/2" completion tubing. Circulate the main bore with clean brine at 8.9 ppg, at a high rate. Run dummy ESP through tubing string on wireline. Latch into diverter and unsnap diverter from Hook Hanger. POOH, standing back tubing. 20. Make up ESP and components as required and RIH. Run heat trace on tubing through permafrost zone. 21. Land tubing with ESP above window. Install BPV, nipple down stack, nipple up and test tree. Pull BPV. Freeze protect well with diesel by pumping into annulus, taking returns from tubing and allowing to equalize. 22. Set BPV and move off. ()111S111~ L f f :cation for Permit to Drill, We1l1C-109 Revision No.O Saved: 11-0ct-O1 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 following item::,~ except for an item already 017 file with the commission and Identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.," Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 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. 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 Diagrams of the BOP / Diverter System Attachment 3 Drilling Hazards Summary Attachment 4 Cement Loads and CemCADE Summary Attachment 5 Well Schematic 0111m1J~ L 1000 -500 -1 000 -1500 -2000 -2500 -3000 DrillQuesl 2.00.09.003 Scale: 1 inch = 500ft -2000 -1500 End Dir, Slart Sail @ 63.15": 4157.151t MD, 3562.82ft TVD 500 Begin Dir @ 7.0°/10011 : 4357.1711 MD, 3653. 161t TVD End Dir, Start Sail @ 77.94° : 4597.4211 MD, 3733.0811 TVD 0 ,'.' f Eastings -1 000 f"I1 '~J' 1000 -500 500 Begin Dir @ 6.0"/10011 : 2538.9011 MD, 2252.3811 TVD Increase in Dir Rale @ 4.0°/10011 : 900.001t MD, 898.771t TVD Begin Dir @ 3.0"/100It (9-7/8" Hole): 600.001t MD, 600.0011 TVD -----.--------- ------------ Sf-H..: X '.c 5G170G.13' E &. Y~. 596<)74(\.59' N 148TFNL&.699' l3ec:12-T11I\!-R1 I ,.:;/~:' . --- - - - - - - - -..- Begin Dir @ 7.62°/10011: 4856.5611 MD, 3787.2211 TVD .Jl /' 7.5/8" Casing ../' 5016.811 MD "................................................................................................"...........................,,~......... 3803.911 TVD ß.Hoel (7..5/8" Csg PI), Start Sail (çþ 90,09" (in 6,.3/4" Hole): 50'16.84ft MD, 380~š.90ft TVD ............,...................................................................................................".......................... en C') c: ..c: t 0 Z 5" Liner 7512.911 MD 3799.911 TVD Phillips Alaska, Inc. North Slope, Alaska Kuparuk River Unit 1 C Pad 1 m 1 09 ( pO1) ....... ,... 0 a. ~ ID 0") 0 ,... ó ,... Reference is True North Well: Current Well Properties Plan: 1C-109 -- Horizontal Coordinates: Ref. Global Coordinates: Ref. Stucture Referance : Ref. Geographical Coordinates: 5968746.59 N, 561706.13 E 229.60 N, 664.05 W 70" 19' 30.5440" N, 149" 29' 58.6776" W (1487' FNL & 699' FWL, Sec 12-T11N-R10E) 101.90ft above Mean Sea Level True North Feet (US) RKB Elevation: North Reference: Units: ----- l spe ~ r'1':J - 5 U 11 ¡oj a! DEìptr1 (ß-Too): 7512.91H MD, 3799.90fl TVD (969' FNU~ 216' FEl. See 1 1-.T11 N-R1 OE) . , ., .. r..1RILLENIC; !:;E::r~VIC'ES A, H¡; WJbU1:r1mfl. t<m1tP'lHlI)? -2000 -1500 1000 500 0 -500 -1 000 -1 500 -2000 -2500 -3000 -1 000 0 500 OR/~INAL -500 1200 ..-... a:I ~ ~ 1 800 ..s:: - c.. Q) 0 CtI u t Q) > 2400 3000 ....... ...... 0 0 CD ~600 - --- q;. ~ ~ r--- DriliQuest 2.00.09.003 0 """"00---"" ""_"00""00 . 00 oo. 00...... 0000.... 00 oo. 00....... 00 00000000.. 00 - ....00..... 00.00.. _0000..00...00. _00 00... -. ........... ..-....... - .....--... - .... -.... -.. ....--. .----.----... ..---.---...- 'moo.._.oo' "m_. -... -.... ...... ......-.....-- ..... -.... ..00 ...m- 'm...m"', "oo_'m"', -.... .... ....-... ......... ......, ........"'"", 600 -1200 ¡ SHL: X=: 561106.13' E & Y =: 596874659' N (1487' F!\lL & 699' FWL, See 12-111 N-R10E) ..m..m..m... ..- ,"..oo_.m"'oooo' ""'00""_'" -............----. .... .-............... ... ..moo. m...oo. ...._.m.......",' ..... -................... -.. ................. "'00 ""oo"...m .oo.oooo..m.'" ¡,fiJ.o Begin Dir @ 3.0°/1 0 Oft (9-7/8" Hole): 600.00ft MD, 600.00ft TVD Increase in Dir Rate @ 4.00/100ft : 900.00ft MD, 898.77ft TVD End Dir, Start Sail @ 40.5° : 1687.60ft MD, 1605.05ft TVD , ¡ ! ¡ Begin Dir @ 6.00/1ÓOft: 2538.90ft MD, 2252.38ft TVD ! I ¡ End Dir, St~rt Sail @ 63.15° : 4157.15ft MD, 3562.82ft TVD I , ¡ ! Begin Dir @ 7.00/100ft : 4357.17ft MO, 3653.16ft TVD \' "" rFJ°'o ~.... Iii Phillips Alaska, Inc. North Slope, Alaska Kuparuk River Unit 1 C Pad 1C-109 (wpO1) N '.\l,,' "7F' Reference is True North Well: Current Well Properties Plan: 1C-109 I Horizontal Coordinates: . Ref. Global Coordinates: Ref. Stucture Referance : Ref. Geographical Coordinates: 5968746.59 N, 561706.13 E 229.60 N, 664.05 W 70" 19' 30.5440' N, 149" 29' 58.6776" W (1487'FNL&699'FWL, Sec12-T11N-R10E) 101.9011 above Mean Sea Level True North Feet (US) RKB Elevation: North Reference: Units: sp I'Y-SUI1 G SeRViCeS ~'="""""",",,~,,",""""-'-' A H~I ¡¡btirt()!'I ç{1ro~ny End Dir, Start Sail @ 77.94° : 4597.42ft MD, 3733.08ft TVD Begin Dir @ 7.62°/100ft : 4856.56ft MD, 3787.22ft TVD /B-Hee! {7-5!8" Csg Pt), Start San @ 90.09'0 (in 6-3/4" Ho!e): S016.B4ft MD, ~ißO3.90ft TVD /l,ð,Oo.o V ¿ ---.---.~'----., 5' lire, ¡ /---,/ 7512.911 MD "-2....." ~oo.o "-'----00 00 00 00 00 00 3799.911TVD <--" .------- <;;7-0 . <ftJ . ~ . f}.0 . fi>0 . 1~ . ! .---'---. . . . . . --' ""'" 7-518' Casirg 1C-109B (wp01) /""'" SO16.8ft MD 3803.9ft TVD -600 0 Tota! Depth (B-Toe): 7512,9itt tAD, 3799.90ft TVD (969' FNL fx 216' FEL. See 11-T 11 N-F11 DE) 600 1200 2400 1800 3000 3600 n. 'f ~ ,~¡- 600 1200 1800 2400 - 3000 3600 C) :J:J ~:g ~Ÿ~.'l ~ .¿' -~.j -=-.'.;.:> ~'" ~i;? r-- Kuparuk River Unit North Slope, Ar#: Kuparuk 1 C, $Iot Plan: 1C-109~¡¡¡~1G-10 -~ . ....... ... .. .. , Rgy;seêiF1(JCJt:tóber, 2001 'OSAL REPORT 10 October, 2001 Your Ref: per Prelim Plan version #3 Surface Coordinates: 5968746.59 N, 561706.13 E (70019' 30.5440" N, 149029' 58.6776" W) Surface Coordinates relative to Project H Reference: 968746.59 N, 61706.13 E (Grid) Surface Coordinates relative to Stucture Referance: 229.60 N, 664.05 W (True) Kelly Bushing: 101.90ft above Mean Sea Level -" Proposal Ref: pro9646 it. îth tíWtV'.d1 e-i,1n~r Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 0.00 0.000 0.000 -101.90 0.00 100.00 0.000 0.000 -1.90 100.00 200.00 0.000 0.000 98.10 200.00 300.00 0.000 0.000 198.10 300.00 400.00 0.000 0.000 298.10 400.00 500.00 0.000 0.000 398.10 500.00 600.00 0.000 0.000 498.10 600.00 700.00 3.000 335.000 800.00 6.000 335.000 900.00 9.000 335.000 1000.00 12.999 334.422 -'- .996.91 1100.00 16.998 _i3?4.1J 1093.48 1200.00 20.997.;-...- ....- 333.91~ 1188.02 1300.00 24.997--..--i333.7?f£ 1280.05 1400.00 28.997 333.685 1369.14 1500.00 32.996 333.608 1352.94 1454.84 1600.00 36.996 333.546 1434.84 1536.74 1687.60 40.500 333.500 1503.15 1605.05 1700.00 40.500 333.500 1512.58 1614.48 1800.00 40.500 333.500 1588.62 1690.52 1900.00 40.500 333.500 1664.66 1766.56 C) 1905.71 40.500 333.500 1669.00 1770.90 ::t:J 2000.00 40.500 333.500 1740.70 1842.60 2100.00 40.500 333.500 1816.74 1918.64 ~-= 2200.00 40.500 333.500 1892.78 1994.68 ~h. ': ,-~; ~'~-"3 ~. ~: :r: r~- -.:2 10 October, 2001 - 6:40 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-109 -1C-109B (wp01) Your Ref: per Prelim Plan version #3 Revised: 10 October, 2001 North Slope, Alaska Kuparuk 1 C Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings E;fj~!~l1g§ - Rate Section Comment (ft) (ft) (ft) (ft) - (o/100ft) 0.00 N 0.00 E 5968746.59N 561706.13 E 0.00 SHL: X = 561706.13' E & Y = 5968746.59' N (1487' FNL & 699' FV See 12- T11 N-R 1 OE) 0.00 N 0.0013 59ØS746.59N 561706.13 E 0.000 0.00 - 0.00 N ..ÆtOO E -- 59681Z.4E3:59 N 561706.13 E 0.000 0.00 0.00 N __a~mO 5968746i59 N 561706.13 E 0.000 0.00 0.00 N;;;O.OOE 5968746.59 N 561706.13 E 0.000 0.00 5968746.59 N 561706.13 E 0.000 0.00 5968746.59 N 561706.13 E 0.000 0.00 Begin Dir @ 3.00/1O0ft (9-7/8" Hole): 600.00ft MD, 600.00ft TVD 1.11 W 5968748.95 N 561705.00 E 3.000 -2.37 4.42 W 5968756.04 N 561701.63 E 3.000 -9.48 9.94W 5968767.82 N 561696.02 E 3.000 -21.31 Increase in Dir Rate @ 4.00/100ft : 900.00ft MD, 898.77ft TVD 38.55 N 18.10 W 5968784.99 N 561687.71 E 4.000 -38.55 61.85 N 29.34 W 5968808.20 N 561676.28 E 4.000 -61.85 91.11 N 43.61 W 5968837.34 N 561661.77 E 4.000 -91 .11 126.17N 60.83 W 5968872.25 N 561644.27 E 4.000 -126.17 166.87 N 80.91 W 5968912.79 N 561623.85 E 4.000 -166.87 213.00 N 103.77 W 5968958.73 N 561600.61 E 4.000 -213.00 264.35 N 129.29 W 5969009.87 N 561574.67 E 4.000 -264.35 --. 313.42 N 153.73 W 5969058.73 N 561549.83 E 4.000 -313.42 End Dir, Start Sail @ 40.5° :"1 .60 MD, 1605.05ft TVD 320.63 N 157.32 W 5969065.91 N 561546.18 E 0.000 -320.63 378.75 N 186.30 W 5969123.80 N 561516.72 E 0.000 -378.75 436.87 N 215.28 W 5969181.68 N 561487.27 E 0.000 -436.87 440.19 N 216.93 W 5969184.98 N 561485.58 E 0.000 -440.19 Base Permafrost 494.99 N 244.26 W 5969239.56 N 561457.81 E 0.000 -494.99 553.11 N 273.24 W 5969297.44 N 561428.35 E 0.000 -553.11 611.24 N 302.21 W 5969355.32 N 561398.90 E 0.000 -611.24 Page 2 of 7 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-109 - 1C-109B (wp01) Your Ref: per Prelim Plan version #3 Revised: 10 October,2001 North Slope, Alaska Kuparuk 1 C Kuparuk River Unit Vertical Section Dogleg Rate (0/100ft) Global Coordinates Northings . Eástings (ft) ... .(ft) Local Coordinates Northings Eastings (ft) (ft) Vertical Depth (ft) Sub-Sea Depth (ft) Measured Depth (ft) Comment Incl. Azim. 561369.44 E 561339.99 E 561310.53 E 561299.08 E -669.36 -727.48 -785.60 -808.21 0.000 0.000 0.000 0.000 331.19 W 360.17 W 389.15 W 400.42 669.36 N 727.48 N 785.60 N 808.21 N 2300.00 2400.00 2500.00 2538.90 40.500 40.500 40.500 40.500 333.500 333.500 333.500 333.500 1968.82 2044.86 2120.91 2150.48 2070.72 2146.76 2222.81 2252.38 Begin Dir @ 6.0°/1 OOft : 253['-1 M 2252.38ft TVD -842.11 561280.73 E 6.000 842.11 N 41 37.439 330.290 2197.99 2299.89 2600.00 Top K-15 4 ftJ~87 449045 481.85 W 515.35 W 549.56 W -842.78 -890.37 -929.22 -958.23 -977.09 561280.35 E 561249.37 E 561216.65 E 561182.92 E 561148.55 E 6.000 6.000 6.000 6.000 6.000 5969585.90 N 5969633.23 N 5969671.81 N 5969700.55 N 5969719.12 N 842.?êN 89p.37N ... 929..6.2 Ni ~.Q8.29..f\J~~i 977.09N 2601.27 2700.00 2800.00 2900.00 3000.00 37.376 32.656 28.283 24.541 21.760 330.219 323.966 315.841 305.260 291.687 2199.00 2279.86 2366.07 2455.66 2547.67 2300.90 2381 .76 2467.97 2557.56 649.57 -985.58 -983.62 -971.22 -948.52 -915.78 561113.93 E 561079.42 E 561045.41 E 561012.27 E 560980.37 E 6.000 6.000 6.000 6.000 6.000 584.12 W 618.64 W 652.75 W 686.08 W 718.25 W 5969727.33 N 5969725.09 N 5969712.41 N 5969689.44 N 5969656.43 N 985.58 N 983.62 N 971 .22 N 948.52 N 915.78 N 3100.00 3200.00 3300.00 3400.00 3500.00 20.339 275.400 20.564 258.184 22.383 242.510 25.458 229.756 29.396.219:89 . ......... . . i214.4Qg, ~12,3Q~ 20EL368 201.591 197.637 Top Ugnu C -887.21 -873.35 -821.68 -761.36 -693.04 560959.06 E 560950.05 E 560921.64 E 560895.46 E 560871.79 E 6.000 6.000 6.000 6.000 6.000 739.80 W 748.93 W 777.76 W 804.44 W 828.67 W 5969627.69 N 5969613.75 N 5969561.85 N 5969501.31 N 5969432.80 N 887.21 N 873.35 N 821.68 N 761.36 N 693.04 N 3569.67 3600.00 3700.00 3800.00 3900.00 32.485 33.896 38.761 43.868 49.141 068.00 3093.38 3173.94 3249.05 3317.87 3169.90 3195.28 3275.84 3350.95 3419.77 ~ Top Ugnu B -653.27 -617.47 -601.70 -535.48 -486.08 5969392.92 N 5969357.05 N 5969341 .25 N 5969274.91 N 5969225.43 N 560860.20 E 560850.90 E 560847.10 E 560833.00 E 560824.20 E 6.000 6.000 6.000 6.000 6.000 653.27 N 617.47 N 601.70 N 535.48 N 486.08 N 840.59 W 850.18 W 854.11 W 868.75 W 877.96 W 3453.90 3481 .55 3492.90 3535.61 3562.82 3953.76 4000.00 4019.83 4100.00 4157.15 52.025 54.528 55.607 59.997 63.150 195.767 194.274 193.662 191.337 189.803 3352.00 3379.65 3391.00 3433.71 3460.92 Top Ugnu A End Dir, Start Sail @ 63.15°: 4157.1 MD, 3562.82ft TVD a ::0 - -- c;-) - - <:: 4400.00 65.754 ~ ......... 10 October, 2001- 6:40 560818.00 E 560803.53 E 560798.87 E 560795.26 E -448.41 -360.49 -332.14 -310.23 5969187.71 N 5969099.67 N 5969071.28 N 5969049.34 N 0.000 0.000 0.000 0.000 448.41 N 360.49 N 332.14 N 310.23 N 884.47 W 899.66 W 904.56 W 908.35 W 4200.00 4300.00 4332.24 4357.17 63.150 63.150 63.150 63.150 189.803 189.803 189.803 189.803 3582.17 3627.34 3641 .90 3653.16 3480.27 3525.44 3540.00 3551 .26 K-13 Shale Begin Dir @ 7.00/1O0ft : 4357.17ft M 3653.16ft TVD 560789.55 E -272.06 914.37 W 5969011.13 N 7.000 272.06 N 188.157 3569.73 3671.63 DrillQuest 2.00.09.003 Page 3 of 7 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-109 -1C-109B (wp01) Your Ref: per Prelim Plan version #3 Revised: 10 October,2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates'.' . Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings .§fj§!~JÌg§ .' .'. Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft). CO/100ft) 4500.00 71 .897 184.554 3605.84 3707.74 179.45 N 924.63 W 59689J 8.4ß~N 560780.06 E 7.000 -179.45 4597.42 77.941 181.282 3631.19 3733.09 85.56 N 929.37 W &mpg8?~;~Q~N . . 5607'76.08 E 7.000 -85.56 End Dir, Start Sail @ 77.94° : 4597.4 MD, 3733.08tt TVD 4600.00 77.941 181.282 3631.72 3733.62 83.04 N 59ô8821.9BN 560776.05 E 0.000 -83.04 ~. 4601 .32 77.941 181.282 3632.00 3733.90 81.74 N 5968a20~69 N 560776.03 E 0.000 -81 .74 Top West Sak D 4700.00 77.941 181.282 3652.61 3754.51 14.73 S 5968724;20 N 560774.67 E 0.000 14.73 4797.58 77.941 181.282 3673.00 3774.90 9~~t75 5968628.78 N 560773.32 E 0.000 110.13 Top West Sak C 4800.00 77.941 181.282 3673.51 3775.41 933.80 5968626.41 N 560773.28 E 0.000 112.50 4856.56 77.941 181.282 3685.32 3787.22 935.04 W 5968571.10 N 560772.50 E 0.000 167.80 Begin Dir @ 7.62°/1 oott : 4856.56ft MD, 3787.22tt TVD 4900.00 81 .234 180.937 3693.17 935.87 W 5968528.39 N 560772.03 E 7.620 210.51 4905.56 81.656 180.894 3694.0 . 935.96 W 5968522.89 N 560771.98 E 7.620 216.01 Top West Sak B 5000.00 88.815 180.164 936.82 W 5968428.84 N 560771.89 E 7.620 310.05 5016.84 90.092 180.035 936.85 W 5968412.00 N 560772.00 E 7.620 326.90 B-Heel (7-5/8" Csg Pt), Start Sail @ 90.09° (in 6-3/4" Hole): 5016.84tt MC 3803.90tt TVD 7-5/8" Casing Target - 1 C-1 09 (B-Heel), Current Target 5100.00 90.092 . . 18Ø1O35 3701.87 3803.77 410.05 S 936.90 W 5968328.85 N 560772.63 E 0.000 410.05 5200.00 90.092 1'80.035 3701.71 3803.61 510.05 S 936.96 W 5968228.85 N 560773.39 E 0.000 510.05 5300.00 90.092 180.035 3701.55 3803.45 610.05 S 937.02 W 5968128.85 N 560774.16 E 0.000 610.05 -, 5400.00 90.092 180.035 3701.39 3803.29 710.05 S 937.08 W 5968028.86 N 560774.92 E 0.000 710.05 5500.00 90.092 180.035 3701.23 3803.13 810.05 S 937.15 W 5967928.86 N 560775.68 E 0.000 810.05 5600.00 90.092 180.035 3701.07 3802.97 910.05 S 937.21 W 5967828.86 N 560776.44 E 0.000 910.05 5700.00 90.092 180.035 3700.91 3802.81 1010.05 S 937.27 W 5967728.86 N 560777.20 E 0.000 1010.05 5800.00 90.092 180.035 3700.74 3802.64 1110.05 S 937.33 W 5967628.87 N 560777.96 E 0.000 1110.05 a 5900.00 90.092 180.035 3700.58 3802.48 1210.05 S 937.39 W 5967528.87 N 560778.72 E 0.000 1210.05 6000.00 90.092 180.035 3700.42 3802.32 1310.05 S 937.45 W 5967428.87 N 560779.48 E 0.000 1310.05 =t:J 6100.00 90.092 180.035 3700.26 3802.16 1410.05 S 937.51 W 5967328.88 N 560780.24 E 0.000 1410.05 ~"'^'" 6200.00 90.092 180.035 3700.10 3802.00 1510.05 S 937.57 W 5967228.88 N 560781.01 E 0.000 1510.05 c;-:> 6300.00 90.092 180.035 3699.94 3801.84 1610.05 S 937.63 W 5967128.88 N 560781.77 E 0.000 1610.05 -~ ~ ~ r---'° October, 2001 - 6:40 Page 4 of 7 DrillQuest 2.00.09.003 Kuparuk River Unit Measured Depth (ft) 6400.00 6500.00 6600.00 6700.00 6800.00 6900.00 7000.00 7100.00 7200.00 7300.00 7400.00 7500.00 7512.91 Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Depth Northings Eastings Northings J;~~~¡(Ìg::t Rate (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DDft) 3699.78 3801.68 1710.05 S 937.70 W 9967Q4~.8~IN 56()782.53 E 0.000 3699.62 3801.52 1810.05 S 937.76 W q~~69 ... 9\!\J.... ... 56078.3.29 E 0.000 3699.46 3801.36 1910.05 S 937.82 W 5~f)682,. ... 560784.05 E 0.000 3699.30 3801.20 2010.05 S 937.88 \f\{.... 59~Q!28.89N 560784.81 E 0.000 3699.14 3801.04 2110.05 S 937+94 W. 5966628.90 N 560785.57 E 0.000 3698.98 Oow.......... 5966528.90 N 560786.33 E 0.000 3698.82 06Wi 5966428.90 N 560787.10 E 0.000 3698.66 .12W 5966328.91 N 560787.86 E 0.000 3698.50 8.18W 5966228.91 N 560788.62 E 0.000 3698.34 38.25 W 5966128.91 N 560789.38 E 0.000 ... 938.31 W 5966028.92 N 560790.14 E 0.000 938.37 W 5965928.92 N 560790.90 E 0.000 938.38 W 5965916.01 N 560791.00 E 0.000 Incl. Azim. Sperry-Sun Drilling Services Proposal Report for Plan: 1C-109 - 1C-109B (wp01) Your Ref: per Prelim Plan version #3 Revised: 10 October,2001 .. ........ .... ..... . . . ... . . ..... . . . . .. All data is in Feet (US) ulÌl~.~$ othetlisè~Jated. Directions and coordinates are relative to True North. Vertical depths are relativetþf3KJ3ffiji1 01.9' MSL. Northings and Eastings are relative to 1487' FNL & 699' FWL. Magnetic Declination at Surface is 26.1040 (08-0ct-01) 90.092 180.035 90.092 180.035 90.092 180.035 90.092 180.035 90.092 180.035 90.092 180.035 90.092 180.035 90.092 180.035 90.092 180.035 90.092 180.035 90.092 180.035 90.092 180.035 90.092 180.035 The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1487' FNL & 699' FWL and calculated along an Azimuth of 180.0000 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7512.91ft., The Bottom Hole Displacement is 2974.84ft., in the Direction of 198.387° (True). C) :J:1 ---- C":) Vertical Section 1710.05 1810.05 1910.05 2010.05 2110.05 2210.05 2310.05 2410.05 2510.05 2610.05 2710.05 2810.05 2822.96 North Slope, Alaska Kuparuk 1 C Comment ~--L Total Depth (B-Toe): 7512.91ft MD, 3799.90ft TVD 5" Liner Target-1C-109 (B-Toe), Current Tar .-.., """""";;.tI ~ ~'....., .J':;:=-~ r--- 10 October, 2001 - 6:40 Page 5 of 7 DrillQuest 2.00.09.003 Kuparuk River Unit Comments Sperry-Sun Drilling Services Proposal Report for Plan: 1C-109 - 1C-109B (wp01) Your Ref: per Prelim Plan version #3 Revised: 10 October, 2001 Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 0.00 N 0.00 E 600.00 O.OON 0.00 E 898.77 21.31 N 9.94W 1605.05 313.42 N 153.73W 2252.38 808.21 N 400.42 W 3562.82 486.08 N 877 3653.16 310.23 N 90 3733.08 85.56 N 92 3787.22 167.80. 935. 3803.90 326.89 936.85 3799.90 0.00 600.00 900.00 1687.60 2538.90 4157.15 4357.17 4597.42 4856.56 5016.84 7512.91 Comment SHL: X = 561706.13' Begin Dir @ 3.0~jl,OO Increase in. pirl3?- End Dir,;$tartSai!>,@ '. Beain,Ofñ@ 6.œ/jOOft y = 5g9:~l46.59IN (1487' FNL & 699' FWL, Sec 12-T11 N-R1 OE) -7/8" HÒlêj;§oo.OOft MD, 600.00ft TVD °11 OOft : 90O?OOft MD, 898.77ft TVD : 1687.60ft MD, 1605.05ft TVD 38.90ft MD, 2252.38ft TVD Formation Tops Formati on PiaI'} (Below Well Origin)..'...>... Sub-Sea Dip Dip Dir. (ft) Deg. Deg. 1669.00 0.000 2199.00 0.000 3068.00 0.000 3352.00 0.000 3391.00 0.000 C) 3540.00 0.000 ~ 3632.00 0.000 3673.00 0.000 """'-""~~c.. ~ 3694.00 0.000 ~~~'Ò) ...-- 0.471 0.471 0.471 0.471 0.471 0.471 0.471 0.471 0.471 ~,~.."" ;~~~ ~~ ~-10 October, 2001 - 6:40 tatt§'ail @ 63.15° : 4157.15ft MD, 3562.82ftTVD r @ 7;0°/1 OOft : 4357.17ft MD, 3653.16ft TVD EndDir, Start Sail @ 77.94° : 4597.42ft MD, 3733.08ft TVD Begin Dir @ 7.62°/1 OOft: 4856.56ft MD, 3787.22ft TVD B-Heel (7-518" Csg Pt), Start Sail @ 90.09° (in 6-3/4" Hole): 5016.84ft MD, 3803.90ft TVD Total Depth (B-Toe): 7512.91ft MD, 3799.90ft TVD Profile Measured Vertical Depth Depth (ft) (ft) Penetration Point Sub-Sea Depth Northings Eastings (ft) (ft) (ft) Formation Name 1905.71 1770.90 1669.00 2601.27 2300.90 2199.00 3569.67 3169.90 3068.00 3953.76 3453.90 3352.00 4019.83 3492.90 3391.00 4332.24 3641.90 3540.00 4601.32 3733.90 3632.00 4797.58 3774.90 3673.00 4905.56 3795.90 3694.00 440.19N 216.93 W Base Permafrost 842.78 N 418.87 W TopK-15 887.21 N 739.80 W Top Ugnu C 653.27 N 840.59 W Top Ugnu B 601.70 N 854.11 W Top Ugnu A 332.14 N 904.56 W K-13 Shale 81.74 N 929.46 W Top West Sak D 110.13S 933.75 W Top West Sak C 216.01 S 935.96 W Top West Sak B North Slope, Alaska Kuparuk 1 C '-" ~ Page 6 of 7 DrillQuest 2.00.09.003 Kuparuk River Unit Casing details From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) <Surface> 4800.00 <Surface> 3775.41 5016.84 7512.91 3803.90 3799.90 Targets associated with this we/lpath Target Name 1 C-1 09 (B-Heel) 1 C-1 09 (B-Toe 1 C-1 09 (D-Heel) 1C-109 (D-Toe) CJ =t:J ~c c;~ _. -...-. CL:".. -"",,",,--, - ...s;,-"",-~- r-=1ð October, 2001 - 6:40 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-109 - 1C-1098 (wp01) Your Ref: per Prelim Plan version #3 Revised: 10 October, 2001 Casing Detail 7-5/8" Casing 5" Liner Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 3803.90 326.90 S 936.85 W Mean Sea LeveVGlobal Coordinates: 3702.00 5968412.00 N 560772.00 E Geographical Coordinates: 700 19' 27.3281" N 149030' 26.0245" W 3799.90 2822.97 S 938.38 W Mean Sea LeveVGlobal Coordinates: 3698.00 5965916.00 N 560791.00 E Geographical Coordinates: 70° 19' 02.7771" N 149° 30' 26.0599" W 3743.90 327.10 S 911.85 W Mean Sea LeveVGlobal Coordinates: 3642.00 5968412.00 N 560797.00 E Geographical Coordinates: 70° 19' 27.3261" N 1490 30' 25.2947" W 3745.90 2823.17 S 913.38 W Mean Sea LeveVGlobal Coordinates: 3644.00 5965916.00 N 560816.00 E Geographical Coordinates: 70° 19' 02.7751" N 149030' 25.3304" W Page 7 of 7 Target Shape Point Point Point Point North Slope, Alaska Kuparuk 1 C -, Target Type Current Target Current Target Current Target --, Current Target DrillQuest 2.00.09.003 ( Sperry -Sun Anticollision Report ( Company: Field: Reference Site: Reference Well: Reference Wellpath: Phillips Alaska Inc. Kuparuk River Unit Kuparuk 1C Pad Plan: 1C-109 1C-109B (WP01) Date: 10/10/2001 Time: 10:06:54 Page: 1 GLOBAL SCAN APPLIED: All wellpaths \\ithin 200'+ 100/1000 of reference Interpolation Method: MD Interval: 100.00 ft Depth Range: 41.20 to 7513.00 ft Maximum Radius: 947.18 ft Reference: Error Model: Scan Method: Error Surface: Well: Plan: 1C-109, True North 1 C1 091 N245-1 01.9' RKB 101.9 Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Co-ordinate(NE) Reference: Vertical (TVD) Reference: Survey Program for Definitive Wellpath Date: 10/9/2001 Validated: No Version: Planned From To Survey Toolcode Tool Name ft ft 41.20 900.00 Planned: 1 C-1 09B V1 CB-GYRO-MS Camera based gyro multishot 900.00 7513.00 Planned: 1C-109B V1 MWD MW D - Standard Casing Points MD TVD Diameter Hole Size Name ft ft in in 5016.90 3803.92 7.625 9.875 7-5/8" 7513.00 3800.00 5.000 6.750 5" ------------ Summary <--,----,-----,-------- Offset.Wcllpath -----------,,-------,~> 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-03 1 C-03 V1 856.99 900.00 473.92 21.22 452.73 Pass: Major Risk Kuparuk 1 C Pad 1 C-04 1C-04 V1 4889.81 4100.00 176.80 126.98 59.39 Pass: Major Risk Kuparuk 1 C Pad 1 C-05 1 C-05 V1 696.30 700.00 265.65 16.01 249.65 Pass: Major Risk Kuparuk 1 C Pad 1 C-06 1 C-06 V1 500.00 500.00 194.40 12.65 181.76 Pass: Major Risk Kuparuk 1 C Pad 1 C-07 1 C-07 V1 2385.79 2300.00 120.73 73.54 55.54 Pass: Major Risk Kuparuk 1 C Pad 1 C-08 1 C-08 V1 1539.42 1500.00 75.04 30.96 44.96 Pass: Major Risk Kuparuk 1 C Pad 1 C-09 1 C-09 V1 1329.01 1300.00 96.10 44.62 51.49 Pass: Major Risk Kuparuk 1 C Pad 1 C-1 0 1C-10V1 699.26 700.00 26.78 19.29 7.49 Pass: Major Risk Kuparuk 1 C Pad 1 C-1 02 1 C-1 02 lB' Lateral VO 399.82 400.00 123.62 9.16 114.49 Pass: Major Risk Kuparuk 1 C Pad 1 C-1 02 1 C-1 02 'D' Lateral V2 399.82 400.00 123.62 8.90 114.75 Pass: Major Risk Kuparuk 1 C Pad 1 C-111 1C-111VO 498.74 500.00 29.56 12.11 17.51 Pass: Major Risk Kuparuk 1 C Pad 1 C-11 1C-11 VO 399.95 400.00 272.02 9.72 262.30 Pass: Major Risk Kuparuk 1 C Pad 1C-117 1C-117V1 788.26 800.00 117.44 18.74 98.80 Pass: Major Risk Kuparuk 1 C Pad 1 C-119 1C-119VO 688.96 700.00 143.66 17.11 126.59 Pass: Major Risk Kuparuk 1 C Pad 1C-121 1C-121 V1 690.33 700.00 177.93 17.01 160.93 Pass: Major Risk Kuparuk 1 C Pad 1 C-12 1C-12VO 1255.42 1200.00 275.82 28.45 248.54 Pass: Major Risk Kuparuk 1 C Pad 1C-123 1C-123 V5 778.40 800.00 207.68 19.60 188.11 Pass: Major Risk Kuparuk 1 C Pad 1 C-127 1C-127 V5 685.93 700.00 262.45 17.13 245.35 Pass: Major Risk Kuparuk 1 C Pad 1 C-13 1C-13VO 899.05 900.00 211.03 20.15 190.88 Pass: Major Risk Kuparuk 1 C Pad 1 C-16 1C-16 VO 299.99 300.00 225.57 7.45 218.11 Pass: Major Risk Kuparuk 1 C Pad 1 C-17 1C-17 VO 299.89 300.00 166.61 7.38 159.24 Pass: Major Risk Kuparuk 1 C Pad 1 C-18 1C-18 VO 693.97 700.00 310.03 15.82 294.22 Pass: Major Risk Kuparuk 1 C Pad Plan: 1C-129 1C-129 VO Plan: C-Sand 688.24 700.00 285.49 17.96 267.60 Pass: Major Risk Kuparuk 1 C Pad Plan: 1C-125 1C-125 V2 Plan: 1C-125 686.05 699.90 227.21 17.08 210.17 Pass: Major Risk , ,".. ."" r. WELL mil' AILS A.l'<lI-COLLISION SETTINGS SURVEY PROGRAJI" C()~IPA.W 1~,rAß-' w¡.¡ J'^lIll~'r,\ll_' +N!-5 +FJ-W Northing Ea'ling Ld¡IUJe Long<ude Slo. Depth Fro Depth To Survey/Plan Tool 1~,A""""ln... \l".\fm'I"Wl) am-.. Interpolation Method:MD Interval: 50.00 I~'u.., K"I"..u.. K,- Ian: IC-I('I) 229.68 .fM. ¡o 59ó874.~.59 56Jï06.13 70'19'3O.544N 14<r29'58.678W foliA Depth Range From: 41.20 To: 7513.00 41.20 900.00 Planned: IC-IæB <"pOI) VI CB-GYRO.MS Hd 1X,'~" 1<"1'>'!SJ.I.'I"I"",," I"""" Maximum Range: 947.18 Reference: Plan: IC-1O9B (wpOI) 900.00 7513.00 PIa,."",J: lC-l09B (,,"pOI) VI ~ WD l",'~w,... ~¡"d.",: ~h....."("....,,,.c l",~ Sy"..m IW"WS,\ V.S,"'", 0"" 0"" Su.1'" "..,,~¡"d..: : T.....I"jn',S,"'" ".... .S;'S . E':\\" 1<"","\\,1) \'n..S..",,"c: IJI .d+('.,.~ "", W.urio~~¡"d"": HubI\.",1 i'>3.'" n.m ow 1 C-O8 í) ,133 ~.. r ~_.¡ -+-:. --~~- I C-O7 II) 41 100 100 - 200 200 300 300 - 400 400 500 500 ------- 700 700 ----~ 900 900 - 1100 1100 ,,-.~_.-. 1300 1300 - 1 500 1500 2000 2000 - 2500 2500 - 3000 3000 - 4000 4000 - 5000 5000 - 6000 6000 - 7000 7000 8000 -125 100 ~ ~ .~ .-... c: "Ó ~. ~ .-' --"-75 -----, -50 LEGEND IC-03 (IC-03). Major Risk I C-O4 (I C-O4), Major Risk I CoO) (I C-O.'i). Major Risk I C-O6 (I C-O6). Major Risk I C-O7 (I C-O7). Major Risk I C-O8 (1 CoOS). M;uor Risk I C-O9 (I C-O9), Major Risk IC-IO (IC-IO). M;uor Risk lC-IO2 (IC-1O2 'H' Lateral), Maj. lC-IO2 (IC-IO2 'D' Lateral). Maj I Colli (I C-III), Major Risk IC-II (lC-II), Major Risk I C- J 17 (I C-117), Major Risk IC-119 (IC-119), Major Risk IC-121 (lC-121), Major Risk IC-12 (lC-12), Major Risk IC-Il} (lC-123). Major Risk IC-127 (IC-127), Major ~k lC-I3(IC-I3).MajorR' -", I C-16 (I C-16), Ivlajor R, IC-17 (IC-17). Major Risk I C-18 (I C-18), Major Risk Plan: IC-129 (IC-J29), Major R Plan: IC-12) (IC-125). Major Ri -25 90 0 --25 -50 75 ,/... . , IC-IO9B (wpOI) C.~""; ---..1:00 IC-1O9 (wpOI) ,~, =-:- ~~ c~ ."',¿. ~: .e' :-6-3--.- , 50/0. '/./7 Or> ,-cl/' :>; SECTION IJET.\IIS S.... MD I",; ,'\/; TV ) +N/-s +E/.W I>lx¡: Tb"c VSn' r.'!,d I ~I.~ fJ.OO 0.00 4\.20 O.W (I.f)\) O.l~' f).W 0.00 2 WJ.OO 0.00 0.00 (/XI. 00 fJ.m 0.(>0 fJ.OO OOfJ fJ.m 3 900.00 9.1XJ .1.15.00 8Y8.77 ~l.J1 .9.'JI .I.m ,.15.00 .IH1) 4 I (,87.5fJ ~O.S( ",-SO I(,O~.% ,1:>..1$ .15171 4.1)\) ,'~.I.I .2.t~.'11 5 253S.90 4/J.50 :>:>.1. Sf) 22S~.,7 1«110.1 ..ll~IA.\ O.I~1 fJ.I~' MO.70 6 4157.20 li1.15 159.W 'S',2.IIS 411".07 .Si7.9-1 'dO :12.1" 1><-1.'" .1157.20 Hl.5 IX9.I!O Y"l19 .\10.2.1 .'¡OX.1J \) r~) O.IX) .7,'Y, 8 ~S97AO ï7.'J.-I In~" .17JJ.IO ,'-',2 ."IY.\.J :.I~' ,ê"'" 211.Xl 9 4851>.1\1) 77.9-1 I X \.29 .1787.25 .11>7.110 'IIS.OS O.IXJ O.W ¡H12 lC-UlJ lL-W(lC :!.lJ'D Plan; ~¡Î (,>pOI) (Plan: IC-I('I)/IC-I09B <,,'POI») :=100 B~ahl Date: 1011012001 Date; 'Þ.ccked: Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [50ft/in] I}.lc: :o,';,w.:J: ~~------ Dalo; ,pprovcd: 13-5 Diverter 'Iì'P System Elevations( "Jabors Rig 245e . West Sak Multilateral Wells ,------------------¡ I . .----~::~ \:=-----. . I I I . I I I . I I I I I I . I I I . I . I . I I ~ ~ "'" -,-- When measurements were made, Drill Module was on one set of matts. Top of kill line window. I 23.34 ft. I .... ~ I 22.16 ft. I ~ ~ r---- , n I I, ~ " I I It._--- ~ Centerline of Kill line. .... 21.01ft Bottom of kill line window. Top of Vetco Gray 13-5K Diverter Spool, 8.51 ft. (102.12") ~ IÞ 0 IÞ Top of Vetco Gray 13-5K Well Head, 4.67 ft. (56.12") All Measurements are from Pad level - i.e. Bottom of Matts = 0.00 ft. 7 -5/8" Casing KEY: 1. Landing Ring, 16" x 13-5/8", Vetco Gray, with 7-518" Casing Landed, Vetco Gray. 2. Well Head, 10-3/4\1 Vetco Gray Quick Connect Bottom x API 13-5/8" 5000 psi Flange Up, Vetco Gray. 3. Diverter Spool, 13-5/8" x 13-5/8" 5000 psi top and bottom with API 16-3/4", 5,000 psi side outlet, Vetco Gray. 4. Spacer Spool(s), 13-5/8" 5000 psi x 13-5/8" 5000 psi,9.5 ft long, Nabors. 5. Single Ram BOP, 13-5/8" x 5000 psi, with pipe rams, Nabors .... ~ Top of annular preventer WHEN I I RAISED TO MAXIMUM HEIGHT 31.85 ft. POSSIBLE WITH BOP CRANE .... ~ Elevation of top of annular preventer, nippled up 8 I 31.26 ft. I 7 Bottom of Choke line window. I 22.99 ft. I Top of choke line window. Top of drilling spool I 23.34 ft. I ~ ~ 122.16 ft. I .... (ð Centerline of choke line. ----1 Q I . I' I , , I ---_JI 6 ~ ~ 21.01ft. 5 118.01 ft I Top of Spacer Spool 4 Top of diverter line window in cellar wall, ~ 7.34 ft. ----1 ( ) I . I' I , , I ---_JI ~ 3 ..... '" 2 Center Line of 16" Diverter Line ~ ~ 6.58 ft. Bottom of Diverter line window in cellar wall. 4.15 ft. . . . . . 1 ¡ . . . . . ... (ð Pad level 0.00 ft. ~ ~. L:ti~~ :'top t matts under cellar box 6. Drilling Spool, 13-5/8" x 5000 psi, w/2 Side Outlets, Nabors 7. Double Ram BOP,13-5/8" x 5000 psi, with Pipe Rams on Top and Blind Rams on Bottom, Nabors 8. Annular BOP, 13-5/8" x 5000 psi, Hydril GK, Nabors 9. Choke Valve, Manual Operation, 4-1116" x 5,000 psi, Nabors 10. Choke Valve, Hydraulically Operated, 4-1/16" x 5,000 psi, Nabors 11. Kill Line Valve, Manual Operation, 3-1/8" x 5,000 psi, Nabors 12. Kill Line Valve, Hydraulically Operated, 3-1/8" x 5,000 psi, Nabors .. :)') '~~.l ¡ :):' ,;: i #2 prepared by Steve McKeever 7/05/01 (" --~-- ( EFSO 16-3/4" 5,000# BX 152 Øl0.50 I $& I $.~ lI) f"-. f"-. ..- 0 LO 0 N ROTATING FLANGE 13-5/8" 5,000# BX 160 (2 PLACES) 0 ~ r 0 0 ~ N EFSO 3-1/8" 5,000# R35 (2 PLACES) r Ø26.50 l 0 0 f"-. ..- QUOTE: 1976 ORIGINAL DA TE: 01/05/01 DWG. UPDATE AS PER CUST. RQST.: 06/01/01 ACADEMY PETROLEUM [NDU~TRIE~ EDMONTON. ALBERTA, CANADA TEL: (780) 466 6360 FAX: (780) 466 6380 DWG. NAME: DRilLING SPOOL 13.63-5.000# ROT. MAIN LAYOUT FILE: DRSP RT 13 CW EFSOS DATE: 06/01/01 ABB Vetco Gray VjÎj~I"d1 11.4... ( f lC-l09 Drilling Hazards Summary (SEE WELL PLAN AND ATIACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Broach of Conductor Gas Hydrates Running Sands and Gravels Abnormal Reservoir Pressure Lost circulation Hole swa bbi ng on tri ps Risk Level Low Low Moderate Low Low Moderate Miti ation Strate Monitor cellar continuously during interval. Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Maintain planned mud parameters, Increase mud weight, use weighted swee s run ravel isolation strin . Diverter drills, increased mud weight. Hazard Abnormal Reservoir Pressure Stuck Pi pe Lost Circulation Hole Swabbing on Trips Risk Level Low Low Low Moderate Miti ation Strate Stripping drills, Shut-in drills, Increased mud wei ht. Good hole cleaning, PWD Tools, Hole 0 ener Decreased mud wei ht Reduced um rates, Mud rheolo , LCM Trip speeds, Proper hole filling (use of trip sheets, Pum in out 6" Open Ho~ 2" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pi pe Lost Circulation Hole Swabbing on Trips Risk Level Low Low Low Moderate Miti ation Strate Stripping drills, Shut-in drills, Increased mud wei ht. Good hole cleaning, PWD Tools, Hole 0 ener, Decreased mud wei ht Reduced um rates Mud rheolo LCM Trip speeds, Proper hole filling (use of trip sheets, Pum in out 10-109 Drilling Hazards Summary prepared by Stey,e McKeever U frttfÙ h ri L ( I' f Schlu lDbar gap West Sak 1C-109 Dual Purpose Well, Cement Loads and CemCADE Summary. 36% Excess Below permafrost, 260% Above permafrost with 60 bbls to suñace. 9-7/8" Openhole. TD @ 6017' MD. 7-618", 29.7# Casing. Base of permafrost @ 1906' MD. Port collar for no cement to surface contingency. Port Collar @ 1000' MD Tail Slurry TOC @ 4101' MD (600' above D Sand). Proposal Date - October 11, 2001 - Chris Avant Volume Cales: Pump 40 bbls CW preflush, 50 bbls MudPUSH XL @ 10.2 ppg. Cement from TD to 4101' MD with Class G + adds @ 15.8 ppg, and from 4101' to surface with ASLite @ 10.7 ppg. Lead Slurry ReQuirements: ASLite @ 10.7 ppg - 4.44 ft3/sk (4101' -1906') x 0.2148 ft3/ft x 1.35 (35% excess) 1906' x 0.2148 x 3.5 (250% excess) 50 bbls cement to surface Total 2350.1 ft3/4.44 ft3/sk = 636.5 ft3 = 1432.9 ft3 = 280.7 ft3 = 2350.1 ft3 = 529.3 sks Round upto 630 sks BHCT: 81oF (Temp gradient: 2.4oF/100 ft below permafrost) Tail Slurry ReQuirements: Low Temperature GasBlok Cement @ 15.8 ppg, Class G + 3.0% D053 + 0.45% D65, 0.3% M117, 2.0 gps D600G, 0.2% D47, -1.2 ft3/sk (5017' - 4101') x 0.2148 ft3/ft x 1.35 (35% excess) 80' (shoe joints) x 0.2578 ft3/ft Total 286.2 ft3/1.2 ft3/sk = 265.6 ft3 = 20.6 ft3 = 286.2 ft3 = 238.5 sks Round upto 240 sks CemCADE* Summary: Fluid sequence: Establish circulation using FW. 40 bbl CW100 preflush, Drop Bottom Plug, 50 bbls 10.2 ppg MudPUSH XL spacer, 530 sks (419 bbls) ASLite Lead, 240 sks, (52 bbls) Class G + adds; Drop Top Plug. Displacement is approximately 227 bbls. Circulation: Circulation and cementing at or less than 6 bpm is within safe ECD to avoid breaking down the formation. Recommend dropping the rate below 3 bpm for the last 20 bbls of displacement for bumping the plug as well as maintaining returns. Estimated maximum' surface pressure during the job is 500 psi. Run dye marker in the spacer to provide insight into the decision to open port collar or performing a top job. Recommended Conditioned Mud Properties: 9.4 ppg, PV < 12, Ty < 12, as thin and light as possible for effective mud removal. ORIGINAL Well # 1 C-1 09, (' FE #AK0209 West Sak Multilateral Well Planned Completion Schematic Sheet 1 of 4: Casing String Details 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 1611 Conductor ~ @ +/- 158' MD *:~::f.::. ~~¡~1 .,,<,w, ":'~~~'& ,.:.' ~ ,;.::~::~*:::;:::~~ '.:::*~-::¡~1:1¡:* . ~,.:~~$. ':¡¡$:~.:.i~¡t. '~:f.:.. ~ ,:,*~~", , '?:?:~'~*'~" '.':.,> ,::::::::::::::1b ':~ftt::~...~ '~t\ ~~~,." ~~ø, -"-:':i-.~ ~:~~:':" "'-:::':':'~ :::::*->:~~:;.' ,~:::::::.:::;:.,~,. ':~:~ ~.:~.w' ~.~~.- d~ "":? ::::.& - . ~:$:;'¡':~ ~ (»~'" . ~~:::~~ ~~":¡:::~:;::..::;:. ':w' ,..:~#:-:.~7" (:::~~~~¿:¡: ,:::~:t "¡l::%.:-::"$i~-:' ~~$~ ~*?: ,,-"'. ~:¡~¡:Wt:J' ~~'tJ{'~~¡~¡~~~:~~¡:~ :~*;$ " "~:"*:':':~ :;¡J.~ ~.::;.: .(:.:~.~ ' ,:?'7" ~. ....,~':;.. .,~:'i W ::~~:!:~:~~ -::~1W '~~~~~:.?':" ..!.~~~:~~~~ ::::~ ~,- '.:::t ,*1\ '~¡:;\ .~~::::~, ':i$¡:\ ,..$;:.;., . ~*~~ ,,:$f~¡:§}~~ J.:;:~ 'M~. J§¡$ ....:0$ .. -ø( 'WI ~~ '::::::~~" ~¡~$':. ¡::::::..,:~::::~:~;.. , ~&?%""~""" & :~::'¡;: ',',' ,- " ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Nabors Rig 245 AKB @ 0' Eastings: 561,706.13 Northings: 5,968,746.59 Elevation: 101.9' 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, 7-5/811, 29.7#, L-80, BTC Pin Set @ +/- 1000' MD / 988' TVD (x) Pup Joints Casing: ~ 7-5/8",29.7#, L-80, BTCM, as ----- required to space out window joint. (498-6805)4 foot pup (498-6800)6 foot pup (498-6795) 1 0 foot pup ~ (477-8475)20 foot pup ----- (x) Joints Casing: (463-4825)7-5/8",29.7#, L-80, BTCM 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 ~ ~ Float Collar: Weatherford Model 402, 7-5/811, 29.7#,BTCM (463-4827)Joint with Float Shoe (2) Joints Casing: 7-5/8",29.7#, L-80, BTCM (463-4828)Joint with Thread Locked Box ~ ~ Float Shoe: ~ Weatherford Model 303, 7-5/8", 29.7#, BTCM TD 9-7/811 Hole: (463-4826) Joint with Float Shoe 5,017 MD / 3,804' TVD See Sheet 1 for Casing Details Well # 1 C-1 09, AFE #AK0209 West Sak Multilateral Well Planned Completion Schematic Sheet 2 of 4: Lower Lateral Liner Details PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY (1) Set Shoe Assembly, consisting of: (1) Set Shoe, Baker Model 'GPV', 5.560" Max CD, 5", 18# SLHT Box (492~1550) (1) Crossover, 4" SLHT Box x 5" SLHT Pin (PAl supplied, 492-1915) (1) Joint Tubing, 4", 9.5#, L-80, SLHT (PAl supplied, 492-1220) (1) Crossover, 4-1/2",12.6#, NSCT Box x 4",9.5#, SLHT Pin (PAl supplied, 500-3030) - (x) Joints 4-1/2" Slotted Pipe, 4-1/2", 12.6#, L-80, NSCT (PAl supplied,_- ) (1) Crossover Sub, 4", 9.5#, SLHT box x 4-1/2",12.6#, NSCT Pin (PAl supplied, 500-3040) (1) Joint Tubing, 4",9.5#, L-80, SLHT (PAl supplied, 492-1220) (1) Crossover, 4-1/2", 11.6#, SLHT Box x 4",9.5#, SLHT Pin (PAl supplied, 492-1915) (1) Sliding Sleeve, Baker Model 4-1/2" 'CMD', w/3.43"ID, 4-1/2",11.6# SLHT Box x Pin (492A1510) (2) Joints 4-1/2" Blank Pipe, 4-1/2", 11.6#, L-80, SLHT (PAl supplied, ---- ) (1) Crossover Sub, 5-1/2",17#, SLHT Box x 4-1/2'" 11.6# SLHT Pin (PAl supplied,_- ) (1) Packer Assembly (496~9670), Baker, consisting of: (1) Mill Out Extension, Baker, 3' Long, 5-1/2", 23# 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. Liner Top Packer Set @ +/- 4,693' MD / +/-3,736' TVD -">, 6" Open Hole TD: 7,513' MD /3,800' TVD ---------------- ----------------------------------------- ----------------------------------------, ----------------------------------------- ---------------------------------------- Centralizers: 4-1/2" x 5-3/4" Rigid Straight Blade on every other joint in open hole Surface / Production Casing 7-5/8" 29.7# L-80 BTC Mod Set @ 5,017' MD /3,804' TVD 1C-t09 Planned Completion Schematic Sheet 2 of 4: Lower Lateral Liner Details prepared by Steve McKeever October 10, 2oot See Sheet 1 for Casing Details Top of Window at +/- 4,619' MD, 3,735' TVD Well # 1 C-1 09, AFE #AK0209 West Sak Multilateral Well Planned Completion Schematic Sheet 3 of 4: Upper lateral Liner Details Liner Top Packer Set @ +/. 4,799' MD / 3,736' TVD PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY (1) Set Shoe, 3-1/2", Baker Model 'GPV', (4.50" Max aD), 3-1/2", 9.2#, SLHT Box. (496-9fÆ5) (1) Joint 3-1/2" Bent Pipe, Baker, 3-1/2", 9.2#, L-80, SLHT, Length 18.5'. (496-9695) (1) Crossover Sub, 4", 9.5#, SLHT Box x 3", 9.2#, SLHT Pin (Phillips supplied, 500-3050) (1) Joint Tubing, 4", 9.5#, L-80, SLHT (PAl supplied, 4$2-1220) (1) Crossover, 4-1/2", 12.6#, NSCT Box x 4",9.5#, SLHT Pin (PAl supplied, soo-amo ) -, (x) Joints 4-1/2" Slotted Pipe, 4-112", 12.6#, L-80, NSCT (PAl supplied, --~ (1) Crossover Sub, 4", 9.5#, SLHT box x 4-1/2", 12.6#, NSCT Pin (PAl supplied, 500-3040} (1) Joint Tubing, 4",9.5#, L-80, SLHT (PAl supplied, 492-1220) (1) Crossover, 4-1/2",11.6#, SLHT Box x 4",9.5#, SLHT Pin (PAl supplied, 492-1915) (1) Sliding Sleeve, Baker Model 4-1/2" 'CMD', wI 3.43" ID, 4-1/2",11.6# SLHT Box x Pin (492-1510) (2) Joints Tubing, 4-1/2", 11.6#, L-80, SLHT (PAl supplied, -- (1) Crossover, 4-1/2",11.6#, Cæing Butress Box x 4-1/2", 11.6#, SLHT Pin (PAl supplied, 500-3060) (1) Swivel Sub, Baker, 4-1/2", 11.6#, Cæing Buttress Box x Pin (BOT supplied) (1) Liner Hanger, Baker Flanged Hook Hanger, Size 7-5/8" x 4-1/2", 4-1/2",11.6#, BTC Pin Down (49f~-8360) _0. Centralizers: 4-1/2" x 5-112" Rigid Straight Blade on every other joint in open hole ------------------------- ------------------------- ------------------------- Surface / Production Casing 7-5/8" 29.7# L-80 BTC Mod Set @ 5,013' MD /3,804' TVD 6" Open Hole TD: 7,503' MD 13,742' TVD ----------- ----------- ------------ ----------- See Sheet 2 for Lower lateral Liner Details 1C-109 Planned Completion Schematic Sheet 3 of 4: Upper Lateral Liner Details prepared by Steve McKeever August 18, 2001 f Well # 1 C-1 09, AFE #AKO209 West Sak Multilateral Well (' Planned Completion Schematic Sheet 4 of 4: Tubing String Details PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Tree Assembly, (49ì-OO80) Vet co Gray Gen II, API 13-518 - 5000 psi Flange Down x 4-1/16" 5000 Studded Top, with Penetrators Tubing Hanger, (493--3005) 4-1/2", Vetco Gray wI 4.909" MeA Top Connection, 4-1/2" L- 80 NSCT full Joint Down ESP Power Cable Penetrator (49"1-6860) Heat Trace Penetrator (497-9275} Nabors Rig 245 RKB @ 0' Eastings: 561 ,706 .13 Northings: 5,968,746.59 Elevation: 101.9' AMSL Tubing Head Assembly, Vetco Gray (1) Joint Tubing (x) Pup Joints Tubing, as required to spaceout heat trace. 16" Conductor: +/- 158' MD .",:~$ ....x.;.. ~:Z.[ ..._,......,=, *:>: '~:~:;.::'«~~:::.~ .~;:::: ¡:.~t: ,.".',' ,:" ~i.:f¡' ,;: ::::::~" *" ~:~: .._,¡~ %. f.: ,.:'." ':':'. ., ~:::.: m' ~ ~::::: Ø'» ,.; ':~. '::.:::~:&.:. ..:.',.~ ";" ,. .~~:::~ .-...., Connector, Field Attachable, Power Cable (497-6850) Connector, Field Attachable, Heat Trace (497 9270) Power Cable, Centrilift, #4 AWG Double Armor (497-6605) :<:~:::.§¡l~ .~~ ....". l~"Ø: '-:: ~tr:..~:~:.~¡~~t"Æ' , -:::::&::::$~$j~ ~~~:::::::-:-.. ",""""""~:~~ '~:::::"~ Heat Trace, RayChem, Surface to +1- 3,000' MD. (497~6615) (x) Joints Tubing Port Collar: +/- 1000' MD I 988' TVD (1) Gas Lift Mandrel, CAMCO 4-1/2" x 1" Model KBG-2 (481-9620), with dummy valve installed. 4-11 2" IBT Pin x Pin, with 6 foot 4-1/2" XO Pups, top and bottom. Tubing String: 4-11211, 12.6#, L-80, N SCT (463~4970) (3) Joint Tubing (1) Joint Tubing (1) Sub, Phoenix Discharge Temperature and Pressure (1) Pup Joint Tubing, 10 ft length (1) Pup Joint Tubing, 10 ft length (1) Through Tubing Conveyed Electric Submersible Pump (TTCESP) Assembly, Centrilift, consisting ot Top of lower lateral Liner: +1- 4,693' MD /3,736' TVD (1) Slotted Nipple, CentrUift, 4-1/2" (1) Crossover, Centrilift, 4-1/2", TTC (1) Tandem Seal Section, CentrUift Model GST3 DB HL PFS (497-6510) (1) ESP Assembly, CentrUift Model 21FCNPSH I 140FC2700 (conveyed through tubing) (497-6515) (1) Motor, Centrilift, 190 HP KMH 2415/48 (497-6~jm)) (1) Gauge, Phoenix, Model, MS-1 Gauge (497-6500) (1) Centralizer, Motor, Centrilift, 6.25" 00 to be spaced out +1- 4560' MD above Hook Hanger (497-6550) Top of Window: +/~ 4,601' MD / 3,734' TVD -- -- -- ---- -- ---=-- -- -- -- -- -- -- -- -- -- -- -- -- -- -- - = ======================== D-Sand lateral 6" Open Hole TD: 7,508' MD I 3,746' TVD 7-5/8" Shoe: +/- 5,017' MD / 3,804' TVD ------------------------ B-Sand Lateral 6" Open Hole TD: 7,513' MD I 3,800' TVD 1 C-1 09 Planned Completion Schematic Sheet 4 of 4: Casing String Details prepared by Steve McKeever e 1 2 1 . """" ( (' American Expresse Cash Advance Draft 168 ~' - :. 2{)() DATE O¿. () þc >' I ~ I R?-40/IOJI A aGe c $1 /ce).. ()()~ á--c- . ~ !r c> t:)...-- DOLLARS Issued by Integrated Payment System, Inc. Englewood, Colorado Payable at Norwest Bank of Grand junction - Downtown, NA Grand junction, Colorado PERIOD ENDING .. 09 IC - ( I: ¡. 0 2 ¡. 0 0 ~ 0 0 I: :1 5 III 0 ¡. ? 5000 5 :1 bill 0 ¡. b 8 ~ CHECK 1 ST ANDARD LETTER DEVELOPMENT " V DEVELOPMENT RED RILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL ( (' TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERIP ARAGRAPHS TO BEINCLUDEDINTRANSNDTTALLETTER WELLNAME ,KR-U ¡Œ. -/09 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LA TERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR })ISPOSAL WNO ANNULAR DISPOSAL <.--> YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS ~ YES + SP ACING EXCEPTION Templates are located m drive\jody\templates "CLUE" The permit is for a new wellbore segment of existing well . Permit No, API No. . . Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25,005(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. . . P. .Iease note tbat an d. iSPO., sal of fluids gen.~r. ate. d~. . ftl. ~ ~.. ~i 51 ,4øPI,t!..c;/-'t-w' " (~/A~:æ<.~ dy;/fI, ~~~ru.y!~I-. 7:,/~ ¡l1J~ ;e; -yo ~ ~ '. ~L~ ~ð. ~~ .~ ~-,f"-iJ, ~á. .-t t.ti'¡~¡,(luS "'71 I c?.,.- (-~/ ,,?y'. ¡<V¡fU¡ A(VLI.lcc> J:7etY Enclosed is the approved application foÌ"-{>ermit, to, drill the above referenced well. The permit is approved ,subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. /7' ..-;-; eM s~ ,--/I- ù.~~ . 'L ¿(. WELL PERMIT CHECKLIST COMPANY WELL NAME ¡fl. ~ / er:, PROGRAM: exp --, dev - redrll FIELD & POOL tf -~ n IS?) INIT CLASS t::. ¡/ I ¿J/ L GEOL AREA ("J [, ADMINISTRA TION 1. Pennit fee attached. . . . . . . . . . . . . . . . . . . . . . .'- Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . . N 3. Unique well name and number. .. . . . . . . . . . . . . . . . ' 'N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . . N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . ' N 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . Y N. 8. If deviated, is wellbóre plat induded.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . ' N 10. Operator has appropriate bond in force. . . . . . . . . . . . .' N 11. Pennit can be issued without conservation order. . . . . . . . ' N 12. Pennit can. be issued without administrative approval.. . . . . N 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y ,N 14. Conductor string provided. . . . . . . . " . . . . . . . . . (YJ N 15. Surface casing protects all known USDWs. . . . . . . . (y) N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . (Y) N 17. CMT vol adequate to.tie-in long string to surf csg. . . . . . . . .#>-Y t"L~'C:> \Ð~~'\",- \ \ ' 18. CM~ will co~er all known productive horizons. . . . . '. . . .. . ~<E> c:....~~Ç\~CJ <...'C ""'~\~~\ö"" 19. Casing designs adequate for C~ T, B & permafrost. . . . . . . . N ~ "-- I ... ~ 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . . N \c...'Å~ \{"o...~ ~'c::.... ~~ ,~~C2:.~ c:t... \Ç>\ \. . 21. If a re-drill, has a 10-403 for abandonment been approved. . . V ~.... "-J þ.. .:> ~- - ~. \ J". ~~: _\.. \ \ -- \ \ " ~ 22. Adequate well bore separation proposed.. . . . . . . . . . .. . N '"" \D~ ~ ~ ~ ~~~'> "cR.- ~"~\~J \ r .J',~ ~ 'l\'U\ c:" '\ ~\~~:cr 23. If diverter required, does it meet regulations. . . . . . . . . . N , 24. Drilling .fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N \ . 26. BOPE press rating appropriate; test to scr:î) psig. N 1:i.~\' <ts~ \""S"3ZJ t'~'. ~rocÐ ÞS'\ \~ c:.~~\~~ ~~ 27. Choke manifold compliesw/API RP-53 (May 84). . . . . . . . N \ '\ ~ . 28. Work will occur without operation shutdown. . . . . . . . . . . N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y @ 30. Pennit can be issued w/o hydrogen sulfide measures. . . . ,. êÞ ~. 31. Data presented on potential overpressure zones. . .2' . . ~ 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y N AP~ DATE, 33. Seabed condition survey (if off-shore). . . . . . . . . ... Y N ~ 10' Ii ,¿,71 34. Contact name/phone for weekly progress reports [exp} atory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; . (C) will not impair mechanical integrity pf the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING:' UIC/Annular COMMISSION: ~ÞB /~ - ~t W~ ~ 9g~ " týJ F ¡Z> / serv wellbore seg _ann. disposal para req - ) ON/OFF SHORE 0#7 UNIT# AP R DATE , .1Q:J..L Ö ENGINEERING c 0 Z 0 -I ~ ::0 ( - -I m - DATE 1°/1' Z -I .J: GEOLOGY - APPR DATE Y N Y N Þ. "-"ú~~~~\ ~-\-~ ~ c ~ ~'? ~ t\. ~ ' . ? bs-.. : ";0 .\e. ~ ~ C>. ~ Q ~ ~ ~ ~,,('....'-.) \ ú"'¡, Ö\I'o, \ c:... I(£) C> ~ ~ 11::' ~~\, , en » ::0 m » ( Com mentsllnstructions: c:\msoffiœ\wordian\diana\checklist (rev. 11/01/100) (" ( 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, infonnation 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. ~ è;:,crry-Sun Dl"il1in<:J Secv'ices :...:3 Scan Utility è'~,evision: 3 :3 LisLic, $Revisi.:n: .) :~' Tue Feb 19 C1Î: 1.; : l - :":.- Reel Heaoer Service Iìame.............LISTPE :'3":e.....................ù2/021l9 ,:;ri,;¡in...................STS Keel Name................UNKNO1tJN Continuation Number......Ol Previous Reel Name....... UNKNOìri/N Comments.................STS LIS Tape Header Service name.............LISTPE ~ìat.e.....................02/02/19 Oriçrin...................STS Tape Name................UNKNOWN Continuation Number..... .01 Previous Tape Name.......UNKNOWN Comments.................STS LIS Physical EOr Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS II WELL NNŒ: API NUMBEE: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: jJ JOB DA'I'A - West. Sak JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 I\K-M.M-IJ171 A. WE.AVER D. WESTER II SURFACE LOCATION SECTION: TOíÑNSHI P: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL,: MSL 0) II WELL CASING RECORD t Writing Library. Scientific Technical SerVlces Writing Library. Scientific Technical Services lC-109 500292304700 PHILLIPS Alaska, Inc. Sperry Sun 19-FEB-02 MWD RUN 2 J.\K-MM-l11 71 J",. WEAVER D. WESTER 12 UN 10E 1478 699 .00 102.04 60.70 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPE,N HO.LE CASING IJRU,LERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 158.0 9.880 7.625 4938.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 - 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER ¡V¡UELLER TUBE DETECTORS AND ELEC'I'ROMAGNETIC WAVE QOJ-dO5 { ( ~ES:S?IVITY PHASE -1 : Ev'JR4 ) . ." . >!l':C DP\T.r.. IS PDC PER THE GK.r.. GEOSIENCE GROUP (E-i'VUL :"~()¡~í ~" SCHjr¡¡.A.~T-; Or Fi-1.ILLIFS .:".,~':\SK~" IN<:~. D.:è..TE:=:' Clli,:I.jIJ':::. .:c.,LL i'H'JD LOG HE)\DER CoAT}:'.. RET,",INS THE ORIGHL::.I. DRILLER'S DEFTH REFERENCES. 4. MWD RUNS 1 - 2 REPRESENT WELL lC-109 WITH API # 50-029-23047-00. THIS WELL REACHED A TOTAL DEPTH OF 7510' MD, 3793' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = S¡V¡OOTHED GAJv1MA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SJ'v¡OOTHED PHASE SHIFT' DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SED!? = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name.............STSLIB.OO1 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.. .....02/02/19 Maximum Physical Record..65535 file Type................LO Previous File Name.. .....STSLIB.OOO Comment Record FILE HEADER fILE NUMBER: EDITED ¡V¡ERGED MWD Depth shifted and DEPTH INCREMENT: it FILE SU¡V¡HARY PBU 'l'OOL CODE GR RPD RPM RPS RPX ROP FET 1 clipped curves; all bit runs merged. .5000 STl\RT DEPTH 120.5 148.0 148.0 148.0 148.0 158.5 158.5 STOP DEPTH 7455.0 7462.0 7462.0 7462.0 7462.0 7509.5 7462.0 $ H BASELINE CURVE fOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT lJNSHIFTED DEPTH --------- BASELINE DEPTH $ it MERGED PBU MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 2 MERGE ':rOP 120.5 4950.0 MERGE BASE 4949.5 7509.5 # REMARKS: MERGED MAIN PASS. " y # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.............. ...Down Optical log depth units. ..... .....Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN I( ~l- :-:3:-: :r-a:~ìeS ;=;e1' re,:-:c,~-,::i.............Undefjned .1\bsent value......................-999 ¡)e¡.::,th Units....................... I::'3t!..1!è'i Spe<.:::i f i,:ati,:,n Blc,ck sub-t",':::,E'... C, !"\OP GR KP:-: RFS RP vj RPD FET Ì'!1iJD HWD !'ívJD H,'JD ¡vrwD H¡'\JD Jl.1~\JD Units Size Nsam Rep Code Offset Channel FT .:1 1 68 0 1 fT/H 4 1 68 .:1 ~ API 4 1 68 8 3 OHMlV¡ 4 1 68 1::: :\ OHHH .1 1 68 1 \::- :) OHMlv1 .:1 ] 6 e :::: Ci \) OHMIv¡ ,1 1 G:::~ ::: .:1 --; ¡ IF;, .:1 1 68 ¿ 8 8 : iêìlYI'Õ' Servi,::e Order ;)EPT First Last Name Service Unj.t Min Max Mean Nsam Reading Readinq DEPT FT 120.5 7509.5 3815 14779 120.5 7509.5 ROP MWD FT/H 1.13 465.4 178.819 14703 158.5 7509.~) GR !'IWD APT 12.59 1 H . tl[) 65.9173 1,1670 120.5 7455 RPX MWD OHMM 0.24 2000 45.7469 14629 148 7462 RPS MWD OHMM 0.25 2000 67.9221 14629 148 7462 RPM MWD OHMM 0.06 2000 80.8687 14629 148 7462 RPD MWD OHMM 0.16 2000 123.473 14629 148 7462 FET MWD J-IR 0.15 99.83 1.274~)4 14608 158.5 7462 First Reading For Entire Fi1e..........120.5 Last Reading For Ent:i..re File...........7~)O9.5 File Trailer Service name.............STSLIB.OO1 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/02/19 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.OO2 Physical EOF File Header Service name. ... .... .....STSLIB.OO: Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/02/19 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 GR RPX RPD RPS RPM FET ROP 2 header data for each bit run in separate files. 1 .5000 S'l'l\RT DE PTH 120.5 148.0 148.0 148.0 148.0 15EI.5 158.5 STOP DEPTH 4911.5 4904.0 4904.0 4904.0 4904.0 4904.0 4949.5 $ # LOG HEADER DATA ( L'.~ TE: LOG,:;::: D: SOFT\'J.I\.R::: SURFACE: SOFTWARE VERSION: ::-O\'JN!iOLE SOFTí\1.:':I.RE \i~~RSlm~: DATA TYPE (MEMORY OR REAL-TIME): T=:, DRILLER ([1'): TOP LOG INTERVAL (FT): POTTOM LOG UJTERV."-cL (FT): CIT ROTATING SPEED (RFM): HOLE INCLINATION (DEG 1.lHJII'-'lüÌ.j ,"-cNGLE: HA.XIHUH ANGLE: " TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROHAG. RESTS. <'1 ,., .:;:' # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: HUD DENSITY (LB/G): HUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OI-IMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERA'rURE (MT): MUD AT HAX CIRCULATING TERMPERATUT.Œ: MUD FILTRATE AT MT: MUD CAKE AT HT: II NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): II TOOL STANDOFF (IN): EIi\TR FREQUENCY (HZ): # REMARKS: $ II Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units.... ..... ..Feet Data Reference Point..............Undefined Frame Spacing......... ... ...... ...60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Unj.ts....................... Datum Specification Block sub-type...O ( ::::-0:::7-:::" Insit'ô:' --\.I~~;.'-: 6ó.:!.( )vlem<) ry .:1950. I~ . I} 0::."'7 " TOOL NUMBER PB02231FHRG6 PB02231fHRG6 9.880 4938.0 Water Based 9.00 150.0 9.2 400 5.8 4.500 3.415 5.000 4.000 65.0 87.8 65.0 65.0 Name Service Order Un:Lts Size Nsam Eep Code Offset Channel DEPT Frr 4 1 6l~ 0 1 ROP MWDOI0 FT/I-! 4 1. 68 4 2 GR ¡vn;'ifDOlO API 4 1 68 8 3 RPX ¡vn;'ifDO 1 0 OHMM 4 1 6[:3 12 4 RPS MWDOlO OHMM 4 1 68 16 5 RPM MWDOIO OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1. 68 24 7 FET MWD010 I-IR 4 :1 68 28 8 First Last Name Service Uni.t Mi.n Max Mean Nsarn Reading Reading DEPT FT 120.5 4949.5 2535 9659 120.5 4949.5 ROP MWD010 FT/H 1.13 431.53 173.895 9583 158.5 4949.5 G;\ 1'11';[1010 .;;?1 ;.!\r\TOO 1;) OHI'!>í ¡.¡NOeil (1 OHHH ::< E':': R?S R?]'¡ ~\PD >:ì,,~'c<l. 1:1 OHHH Ì"!~'JDI) 11:1 OHHJvI ¡.n'ÌOOl;) HR. è:::T ( L~. 59 0.24 (1. :25 ::;.3t: 0.24 0.15 ( lU. t-:::, 66. 9.:J ê ,.:; 54. ~J:::25 120.5 148 c) :;': 1 . ~ 95t:.:ô .~ :? C: ~ 9513 95L~ :::00(1 :::000 ::: C)OO :2000 11.08 Ht; .:J 91:1 ~ :=-:1.766::' .:j ~¡ .; 9.:j.8~j67 9::1.::; ::.~! 8 148 158.5 491:14 4904 165.50.') 0.671436 9513 949::: First Reading For Entire File..........120.5 Last Reading For Entire File..... ......4949.5 File Trailer Service name.............STSLI8.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation. .... ..02/02/19 Maximum Physical Record..65535 File Type................LO Next File Name.. .... .....8T8LI8.003 Physical EOF file Header Service name.... ....... ..STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.......O2/02/19 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.002 Comment Record fILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPO RPM RP8 RPX FET GR ROP $ H LOG HEADER DJ\TA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VER.8ION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (tJIEMORY OR REAL-T'IME): TO DRILLER (FT): TOP LOG INTERVAL (fT): BOTTOM. LOG INTERVr\.L (F"j'): BIT ROTATING SPEED (RPM): HOLE INCLINA'rION (DEG ¡VIINIMUM }\NGLE: MAXIMUM ANGLE: # 3 ..., ¿ .5000 START DEPTH 4904.5 4904.5 4904..5 4904.5 4904.5 4912.0 4950.0 STOP DEPTH 7462.0 7.162 . 0 7462.0 7462.0 7462.0 7455.0 7509.5 26-0CT-01 Ins.ite 4.05.5 66.16 Memory 7510.0 89.0 92.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAM¡V¡A RAY EWR4 ELECTROMAG. RESTS. 4 $ ti BOREHOLE l\ND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER PB02229I-IAGR4 PBO2229HAGR4 6.750 { ( DRILLER'S CASING DEPTH (FT;: " BOREHOLE CONDITIONS HUD TY?::: MUD DENSITY (LB/G): MUD VISCOSITY (S): ','; a ':. e: :' :: a 8 -:':2 ~;. ~Il! '17.0 fLì..i I D LOS S ( C 3) : 9.0 13000 3.1 !-'lUD FH: MUD CHLORIDES (PPM): RE:SISTIVITY (OHìV!H) _~T TEHPER..~TURE (DEGF) MUD AT MEASURED TEMPERATURE (NT): MUD AT J,t~:.': CIRCUL.J\TIN(; TER1'¡PER)'\TURE: HUD FILTR..il.TE tl.'I' 1'-11': MUD CAKE AT MT: . :'0 () .395 rj t., . " ,:', , . ':. .400 .950 68 . '~I 68.0 # NEUTRON TOOL MATRD:: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............ .....Down Optical log depth units....... ....Feet Data Reference Point...... .... ....Undefined Frame Spacing.....................60 .1IN Max frames per record.......... ...Undefined Absent value......................-999 Depth Units....................... Datum Sped. fication Block sub-type... 0 Name Service Order Units Size Nsam. Rep Code Offset Channel DEFT FT 4 1 68 0 1 ROP MWD020 FT II-I 4 1 68 4 2 GR MWD020 API 4 1 6f3 8 3 RPX MWD020 O!-IMM 4 1 68 12 4 RPS MWDO20 OI-lMM 4 1 68 16 5 RPM MWDO20 OHMM 4 1 68 20 6 RPD M~'¡¡DO20 O!-IMM 4 J. 68 24 7 FET M~'¡¡DO20 IIn 4 1 6fJ 28 8 Fir.'st Last Name Serv.ice UnH Min Max Mean Nsam Reading Reading DEPT FT 4904.5 7509.5 6207 5211 4904.5 7509.5 ROP MWD020 FT/H 4 . ~~ 6 465.4 188.035 5120 4950 7509.5 GR MWD020 API 31. 79 f:HL 9 9 6.3.9765 5087 4912 7455 RPX MWD020 OHMM 0.98 1760.08 29.429 5116 4904.5 7462 RPS MWD020 OHMM 1.21 2000 42.1796 5116 4904.5 7462 RPM JVlWD020 O!-IJVlM 0.06 2000 54.7841 5116 4904.5 7462 RPD MWD020 OI-lMM 0.16 2000 45.3152 5116 4904.5 7462 FET MWD020 HR 0.17 99.83 2.39352 5116 4904.5 7462 First Reading For Entire File..........4904.5 Last Reading For Entire File...........7509.5 File Trailer Service name.............STSLIB.O03 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/02/19 Maximum Physical Record..65535 File Type................LO Next File Name......... ..STSLI8.004 ~ ?ìy;/sic::al EOF '" aç'e T!:" ail e r Se~vice name.... ....... ..LiSTPE =)aLe.....................'~,,:::/,~<::J:~(; OrigirJ...................STS Tape ¡Jame................Uì'JKNOí'JN Continuation Number..... .0: ~~e>:t Tape ¡Jaíí¡e........... U;Jj'~:iO~'nJ Comments.................STS LIS Writing Library. Reel Trailer Service name........... ..LISTPE Date.....................O:2/0:2/19 Origin...................STS Eeel Name................UN1{NOWN Continuation Number......OJ Nex't Reel Name........... UNk."NOWN Comments.................STS LIS Physical EOF Physical EOF End Of LIS file Wci tiny Library. ~ Scientific Technical Services Scientific Technical Services
