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Home My WebLink About206-132C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-04-14_21133_KRU-1J-182_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21133 KRU 1J-182 50-029-23321-00 Caliper Survey w/ Log Data 14-Apr-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 206-132 T37615 Kayla Junke Digitally signed by Kayla Junke Date: 2023.04.24 10:26:38 -08'00' C:\Users\aebell\Desktop\September 2021 Data Drop\CPA Data Drop 09152021\2021-09-13_14486_1J-182_Caliper Survey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 14486 KRU 1J-182 0-029-23321-00 Caliper Survey 13-Sep-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM Abby Bell _________________________________________ Signaturuururuururururrurururururuuruurururrururururrururuuuruuue 37' (6HW By Abby Bell at 11:41 am, Sep 15, 2021 RECEIVED STATE OF ALASKA 0 ALXSKA OIL AND GAS CONSERVATION COMMISSION V1AY 2 0 2016 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon IE Plug Perforations la Fracture Stimulate I1 Pull Tubing F Agotcautdown Performed: Suspend I- Perforate Ir Other Stimulate Alter Casing I- Change Approved Program 1 Plug for Redrill 1 Perforate New Pool Repair Well E Re-enter Susp Well E Other:lnstall LEM/Gas Lift Fi 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory I.- 206-132 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic L Service I 50-029-23321-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25661/ADL 25662/ADL 380058 KRU 1J-182 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 17844 feet Plugs(measured) None true vertical 3361 feet Junk(measured) None Effective Depth measured 17837 feet Packer(measured) 9224 true vertical 3360 feet (true vertical) 3365 Casing Length Size MD TVD Burst Collapse CONDUCTOR IN: 77 20 120 120 SURFACE 3631 13 3/8 3673 2151 INTERMEDIATE 9794 9 5/8 9831 3433 B-SAND LINER 8615 8.43 17839 3361 Perforation depth: Measured depth: 9282-10018, 10020-17585, 17708-17794 scANNED True Vertical Depth: 3373-3445,3445-3359,3559-3559 Tubing(size,grade,MD,and ND) 4.5, L-80,9036 MD,3340 TVD Packers&SSSV(type,MD,and ND) PACKER-HRD ZXP Liner Top Packer @ 9224 MD and 3365 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): NONE Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md 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 FY Exploratory Development P Service fl Stratigraphic 1- Copies of Logs and Surveys Run h.....: 16.Well Status after work: Oil FGas I"'." WDSPL E Printed and Electronic Fracture Stimulation Data EGSTOR r WINJ I- WAG r GINJ r SUSP fl SPLUG 1- 17. 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Andrew Beat a 265-6341 Email Andrew.T.Beataconocophillips.com Printed Name Andrew Beat Title Sr. Wells Engineer Signature A Rhone:265-6341 s%/16. Form 10-404 Revised 5/2015 L 5y27/11, , Submit Original Only ..4#.1— ;(4 RBDMS V.1 MAY L 3 2016 • • Operations Summary (with Timelog Depths) :_4 W+ 1J-182 ConocoPhithhps Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(0KB) 4/17/2016 4/17/2016 0.50 MIRU MOVE MOB P Set matting boards for support 0.0 0.0 13:00 13:30 modules. 4/17/2016 4/17/2016 2.00 MIRU MOVE MOB P Spot and level support modules. 0.0 0.0 13:30 15:30 4/17/2016 4/17/2016 1.50 MIRU MOVE MOB P Spot rockwasher and pipe sheds. 0.0 0.0 15:30 17:00 4/17/2016 4/18/2016 7.00 MIRU MOVE RURD P Work on rig acceptance checklist. 0.0 0.0 17:00 00:00 Hook up electrical,water,steam and air lines.Level pipe shed. Install Hand -Y-Berm around boiler room and rockwasher.Calibrate and test gas alarms.Set pipe skate and geronimo line.Assemble mud pumps.Thaw out cellar tank.Set envirovac. Ready pits to take on fluid. Rig on shore power @ 18:30 hrs. 4/18/2016 4/18/2016 1.00 MIRU MOVE RURD P Work on rig acceptance checklist. 0.0 0.0 00:00 01:00 Replace water valves in pitroom, assemble pump#2.Stow tools and equipment from rig move. 4/18/2016 4/18/2016 5.50 MIRU WELCTL RURD P +Rig up hardline from tiger tank to 0.0 0.0 01:00 06:30 choke skid to cellar. Rig up lines in cellar to wellhead.Take on 3%KCL heated water.Rig Accepted @ 01:00 hrs. 4/18/2016 4/18/2016 1.50 MIRU WELCTL MPSP P Pick up lubricator. Rig up and pull 0.0 0.0 06:30 08:00 BPV. Tbg=100 psi IA=225 psi. 4/18/2016 4/18/2016 3.00 MIRU WELCTL SEQP T Thaw out hardline to tiger tank.Test 0.0 0.0 08:00 11:00 line to 2000 psi.Blow down hard line. 4/18/2016 4/18/2016 2.00 MIRU WELCTL KLWL P Bleed pressure from the IA to the tiger 0.0 0.0 11:00 13:00 tank.225 psi to 10 psi. 4/18/2016 4/18/2016 0.25 MIRU WELCTL SEQP P Test mud lines and pumps to 3500 0.0 0.0 13:00 13:15 psi. 4/18/2016 4/18/2016 1.25 MIRU WELCTL KLWL P Pump 135 bbls hot 3%KCL water 0.0 0.0 13:15 14:30 down tubing at 4 bpm/100 psi.No returns 4/18/2016 4/18/2016 0.50 MIRU WELCTL OWFF P Shut in tubing.Monitor well. Pressure 0.0 0.0 14:30 15:00 built 75 psi in 30 min's. 4/18/2016 4/18/2016 0.75 MIRU WELCTL KLWL P Pump 3%KCL water down IA at 8 0.0 0.0 15:00 15:45 bpm/575 psi.At 280 bbls pumped pressure built to 1500 psi.Shut down pump. 4/18/2016 4/18/2016 0.25 MIRU WELCTL OWFF P Monitor pressure. IA and tubing 0.0 0.0 15:45 16:00 pressure at 1500 psi. 4/18/2016 4/18/2016 0.25 MIRU WELCTL OTHR P Bleed off IA and tubing pressure. IA to 0.0 0.0 16:00 16:15 150 psi.Tubing to 400 psi.Shut in well. 4/18/2016 4/18/2016 0.75 MIRU WELCTL OWFF P Check OA pressure.OA at 1800 psi. 0.0 0.0 16:15 17:00 Rig up bleed tank and bleed down to 400 psi.Consult with Workover Engineer. 4/18/2016 4/18/2016 1.00 MIRU WELCTL PRTS P PJSM-Tighten lockdown screws.Test 0.0 0.0 17:00 18:00 pack off seals between OA and IA. 2000 psi/10 min.Good test. 4/18/2016 4/18/2016 1.00 MIRU WELCTL SFTY P Conduct safety stand down with rig 0.0 0.0 18:00 19:00 crew. Discussed recent incidents at Alpine. Page 1/12 Report Printed: 5/18/2016 • • ilkig Operations Summary (with Timelog Depths) &Wells 1J-182 ConocoPhil lips Rig: DOYON 141 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(EKE) 4/18/2016 4/18/2016 2.50 MIRU WELCTL KLWL P Pump 561 bbls 3%KCL water down 0.0 0.0 19:00 21:30 tubing taking returns up IA to tiger tank.5 bpm 600-700 psi FCP.Stage pump down to 3 bpm,300 psi due to out running vac truck.Full returns. 4/18/2016 4/18/2016 1.25 MIRU WELCTL OWFF P Monitor well.Tubing=30 psi IA=50 0.0 0.0 21:30 22:45 psi.Tubing gradually went on a vacuum.Bleed IA to tiger tank. IA pressure bled down to 0 psi but was still exhaling slightly. 4/18/2016 4/18/2016 0.50 MIRU WELCTL KLWL P Pump 40 bbls 3%KCL water down 0.0 0.0 22:45 23:15 tubing at 3.5 bpm,350 psi.Shut down and blow down line to tiger tank. 4/18/2016 4/18/2016 0.50 MIRU WELCTL OWFF P Monitor well.Static. 0.0 0.0 23:15 23:45 4/18/2016 4/19/2016 0.25 MIRU WHDBOP MPSP P Rig up and set BPV. 0.0 0.0 23:45 00:00 4/19/2016 4/19/2016 1.50 MIRU WHDBOP MPSP P Test BPV in direction of flow.500 0.0 0.0 00:00 01:30 psi/10 mins 4/19/2016 4/19/2016 0.50 MIRU WHDBOP SFTY P Conduct safety stand down with rig 0.0 0.0 01:30 02:00 crew. Discussed recent incidents at Alpine. 4/19/2016 4/19/2016 0.50 MIRU WHDBOP NUND P Nipple down tree.Stand back and 0.0 0.0 02:00 02:30 secure in cellar. 4/19/2016 4/19/2016 1.00 MIRU WHDBOP NUND P Install installation plate in wellhead as 0.0 0.0 02:30 03:30 per Vetco Grey rep. 4/19/2016 4/19/2016 1.00 MIRU WHDBOP NUND P Nipple up 13 5/8:x 13 5/8"drilling 0.0 0.0 03:30 04:30 spool. 4/19/2016 4/19/2016 2.50 MIRU WHDBOP NUND P Nipple up BOPE.Sim-ops/Modify riser 0.0 0.0 04:30 07:00 and load 4"drillpipe into pipe shed. 4/19/2016 4/19/2016 5.00 MIRU WHDBOP SVRG P PJSM-Perform BWM on BOPE. 0.0 0.0 07:00 12:00 4/19/2016 4/19/2016 2.00 MIRU WHDBOP NUND P Nipple up BOPE.Close ram doors, 0.0 0.0 12:00 14:00 install flow riser.Sim-ops/Inspect kelly hose w/Gates Hose Rep. 4/19/2016 4/19/2016 1.00 MIRU WHDBOP RURD P Rig up test equipment. Flood BOPE. 0.0 0.0 14:00 15:00 Set 4 1/2"donut test joint. 4/19/2016 4/19/2016 5.00 MIRU WHDBOP BOPE P PJSM-Test BOPE w/4 1/2"test joint to 0.0 0.0 15:00 20:00 250/2500 psi for 5 min each.#1:Top pipe rams,CV 1,12,13, 14&manual kill valve.#2:Upper IBOP, HCR kill, CV 9,&11.#3:Lower IBOP,CV 5,8& 10. #4:Dart„CV 4,6&7. #5: FOSV and CV 2. #6:HCR choke&4"kill line Demco valve, #7: Manual choke valve&HCR kill. #8:Annular preventer.#9:Lower pipe rams.#10: Blind rams and CV 3.Accumulator test:system pressure=2950 psi,After closing= 1300 psi,200 psi attained after 44 sec,full pressure attained after 174 sec,Five bottle nitrogen avg=2020 psi. Performed drawdown test on manual and hydraulic chokes. PVT and gas alarms tested. BOPE test witnessed by AOGCC Rep. Brian Bixby. Page 2/12 Report Printed: 5/18/2016 • 0 0 Operations Summary (with Timelog Depths) a 1J-182 C onocc ehithps Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ttKE) End Depth(ftKB) 4/19/2016 4/19/2016 0.50 MIRU WHDBOP RURD P Rig down test equipment. 0.0 0.0 20:00 20:30 4/19/2016 4/19/2016 1.00 COMPZN RPCOMP MPSP P PJSM-Rig up and pull blanking plug 0.0 0.0 20:30 21:30 and BPV. 4/19/2016 4/19/2016 1.50 COMPZN RPCOMP RURD P PJSM-Mobilbize casing and ESP 0.0 0.0 21:30 23:00 equipment to rig floor 4/19/2016 4/20/2016 1.00 COMPZN RPCOMP RURD P PJSM-Rig up Centrilift equipment. 0.0 0.0 23:00 00:00 Hang sheave and attach elephant trunk. 4/20/2016 4/20/2016 1.00 COMPZN RPCOMP RURD P PJSM-Pull Baker rope through sheave 0.0 0.0 00:00 01:00 to rig floor for ESP cable.Make up 4 1/2"IBTM x XT-39 XO to 4 1/2" landing joint. 4/20/2016 4/20/2016 0.75 COMPZN RPCOMP PULL P Make up landing joint to hanger and 8,092.0 8,088.0 01:00 01:45 top drive to landing joint.BOLDS. Unseat hanger w/185K. Pick up 4'. 4/20/2016 4/20/2016 1.25 COMPZN RPCOMP CIRC P CBU.8 bpm,400 psi,46%FO. 8,088.0 8,088.0 01:45 03:00 4/20/2016 4/20/2016 0.25 COMPZN RPCOMP OWFF P OWFF.Static.Blow down top drive 8,088.0 8,088.0 03:00 03:15 4/20/2016 4/20/2016 1.25 COMPZN RPCOMP PULL P Pull hanger to rig floor.Unplug and 8,088.0 8,060.0 03:15 04:30 test penetrator and ESP cable. Lay down hanger and landing joint. 4/20/2016 4/20/2016 0.50 COMPZN RPCOMP PULL P POOH laying down 4 1/2"IBTM tubing 8,060.0 7,760.0 04:30 05:00 f/8060'MD t/7760'MD. 4/20/2016 4/20/2016 1.25 COMPZN RPCOMP RURD P Run ESP cable through sheave and 7,760.0 7,760.0 05:00 06:15 down to spooler unit.Attach cable to spooler as per Centralift reps. 4/20/2016 4/20/2016 5.75 COMPZN RPCOMP PULL P PJSM-POOH laying down 4 1/2"IBTM 7,760.0 3,863.0 06:15 12:00 tubing f/7760'MD t/3863'MD. Calc disp=17.8 bbls Act disp=22.5 bbls 4/20/2016 4/20/2016 1.75 COMPZN RPCOMP PULL P Con't to POOH laying down 4 1/2" 3,863.0 3,162.0 12:00 13:45 IBTM tubing f/3863'MD t/3162'MD. 4/20/2016 4/20/2016 0.75 COMPZN RPCOMP RURD T Lower ram pin sheared on tubing 3,162.0 3,162.0 13:45 14:30 tongs.Lay down tongs and rig up back up tongs. 4/20/2016 4/20/2016 5.50 COMPZN RPCOMP PULL P Cont to POOH laying down 4 1/2" 3,162.0 54.0 14:30 20:00 IBTM tubing f/3162'MD t/54'MD. Calc disp for trip=43.72 bbls Act disp for trip=49.13 bbls. 4/20/2016 4/20/2016 0.50 COMPZN RPCOMP OWFF P Cut cable at motor lead. Pull ESP to 54.0 0.0 20:00 20:30 rig floor.Monitor well.Static. 4/20/2016 4/20/2016 1.00 COMPZN RPCOMP PULL P PJSM-Inspect,break and lay down 0.0 0.0 20:30 21:30 ESP seals and motor. Recover 230 ea 4.5", 1 ea 5.13"x 4.5", 4 ea 5.13"Cannon Clamps and 2 ea SS bands. Lost 4 SS bands downhole 4/20/2016 4/21/2016 2.50 COMPZN WELLPR RURD P PJSM-Rig down and lay down casing 0.0 0.0 21:30 00:00 equipment, ESP cable,elephant trunk, sheave and tools.Monitor well via trip tank.Static.Clear rig floor. 4/21/2016 4/21/2016 1.25 COMPZN WELLPR BOPE P Set test plug and rig up to test BOPE. 0.0 0.0 00:00 01:15 4/21/2016 4/21/2016 1.25 COMPZN WELLPR BOPE P Test annular preventer,upper and 0.0 0.0 01:15 02:30 lower VBR's w/4"test joint to 250 psi low/2500 psi high for 5 min ea. Page 3/12 Report Printed: 5/18/2016 i r l Operations Summary (with Timelog Depths) Drilling 1J-182 ConocoPhillips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB). 4/21/2016 4/21/2016 0.50 COMPZN WELLPR BOPE P Rig down test equipment. Pull test 0.0 0.0 02:30 03:00 plug.Set 9"ID wear bushing. 4/21/2016 4/21/2016 1.75 COMPZN WELLPR SLPC P Slip and cut 156'drilling line 0.0 0.0 03:00 04:45 4/21/2016 4/21/2016 2.00 COMPZN WELLPR BHAH P Mobilize Baker Fishing tools to rig 0.0 0.0 04:45 06:45 floor for clean out BHA. 4/21/2016 4/21/2016 2.25 COMPZN WELLPR BHAH P PU clean out BHA. MU jetted 0.0 227.0 06:45 09:00 bullnose,polish reamer,extensions,5 jts 4"DP,csg scraper,string magnet, bumper sub and jar as per Baker Fishing Hand. 4/21/2016 4/21/2016 0.50 COMPZN WELLPR BHAH P Clear floor.PJSM for picking up 227.0 227.0 09:00 09:30 drillpipe. 4/21/2016 4/21/2016 2.50 COMPZN WELLPR PULD P Pick up and RIH w/4"XT-39 drillpipe 227.0 3,268.0 09:30 12:00 from pipe shed f/227'MD t13268'MD. Drift w/2.34"drift. 4/21/2016 4/21/2016 4.25 COMPZN WELLPR PULD P Pick up and RIH w/4"XT-39 drillpipe 3,268.0 8,050.0 12:00 16:15 from pipe shed f/3268'MD t/8050' MD. Drift w/2.34"drift.PU 140K SO 42K Calc disp=30.43 Act disp=29.7 4/21/2016 4/21/2016 1.25 COMPZN WELLPR CIRC P Break circ.Stage pump up to 550 8,050.0 8,050.0 16:15 17:30 gpm,2600 psi. Pump 34.5 bbl hi-vis sweep. PU 140K SO 40K 4/21/2016 4/21/2016 1.00 COMPZN WELLPR TRIP P POOH.Stand back 10 stands DP in 8,050.0 7,131.0 17:30 18:30 derrick.PU 140K SO 42K. Calc disp=5.4 bbls Act disp=5.78 bbls. 4/21/2016 4/21/2016 1.25 COMPZN WELLPR WASH P PU and RIH w/4"DP f/7131'MD 7,131.0 7,165.0 18:30 19:45 t/7153'MD. Lost slack off wt.Brk circ and wash down to 7165'MD.500 gpm,2300 psi. 4/21/2016 4/21/2016 1.25 COMPZN WELLPR PULD P Pick up and RIH w/4"XT-39 drillpipe 7,165.0 8,185.0 19:45 21:00 from pipe shed f/7165'MD t/8185' MD. Drift w/2.34"drift.PU 140K SO 40K 4/21/2016 4/21/2016 1.25 COMPZN WELLPR REAM P Break circ.Wash down to 8233'MD. 8,185.0 8,300.0 21:00 22:15 Wash and ream f/8233'MD t/8300' MD.550 gpm,2800 psi, 10 rpm,6K tq, PU 115K SO 50K. 4/21/2016 4/21/2016 0.50 COMPZN WELLPR TRIP P RIH on elevators (/8300'MD t/8626' 8,300.0 8,626.0 22:15 22:45 MD. Lost SO wt. 4/21/2016 4/21/2016 0.50 COMPZN WELLPR WASH P Break circ.Wash f/8626'MD t/8650' 8,626.0 8,650.0 22:45 23:15 MD.550 gpm,2825 psi.SO 52K. 4/21/2016 4/21/2016 0.25 COMPZN WELLPR REAM P Wash and ream f/8650'MD t/8829' 8,650.0 8,829.0 23:15 23:30 MD. 10 rpm,5K tq, PU 120K SO 52K ROT 75K. 4/21/2016 4/22/2016 0.50 COMPZN WELLPR SVRG P Service rig.Circulate @ 550gpm, 8,829.0 8,829.0 23:30 00:00 2800 psi. 4/22/2016 4/22/2016 1.25 COMPZN WELLPR REAM P Wash and ream f/8829'MD t/9018' 8,829.0 9,018.0 00:00 01:15 MD.520 gpm, 10 rpm,6K tq,52%FO. PU 145K SO 40K ROT 75K. 4/22/2016 4/22/2016 0.50 COMPZN WELLPR CIRC P Circulate out foamy emulsified crude 9,018.0 9,018.0 01:15 01:45 and sand out of hole followed by hi-vis sweep returns. 4/22/2016 4/22/2016 0.25 COMPZN WELLPR WASH P Wash down f/9018'MD t19112'MD. 9,018.0 9,112.0 01:45 02:00 500 gpm,2400 psi,55%FO.PU 135K SO 45K Page 4/12 Report Printed: 5/18/2016 • • Operations Summary (with Timelog Depths) :_ aWeils 1J-182 ConocoPhillips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/22/2016 4/22/2016 0.25 COMPZN WELLPR OWFF P Observed complete loss of returns. 9,112.0 9,112.0 02:00 02:15 Line up on kill line and pump 65 bbls into IA at 6 bpm. Unable to fill hole. Shut down pump. 4/22/2016 4/22/2016 2.50 COMPZN WELLPR OWFF P Allow fluid level to stabilize. Pull above 9,112.0 9,052.0 02:15 04:45 hook hanger to 9052'MD.Shoot fluid level w/echometer. Fluid at 780'MD. Second shot taken 30 min's later shows fluid level at 780'. 4/22/2016 4/22/2016 0.50 COMPZN WELLPR WASH P Wash down f/9052'MD t/9266'MD 9,052.0 9,266.0 04:45 05:15 Doyon 141 RKB.Tag bottom of SBE. 250 gpm,225 psi,PU 130K SO 45K. Attempt to rotate thru SBE.Top drive stalling out at 7K torque.Three attempts made to rotate. 4/22/2016 4/22/2016 0.25 COMPZN WELLPR TRIP P POOH to 9206'MD. Blow down top 9,266.0 9,206.0 05:15 05:30 drive. 4/22/2016 4/22/2016 4.75 COMPZN WELLPR TRIP P Drop 1.90"OD drift.POOH f/9206'MD 9,206.0 225.0 05:30 10:15 t/225'MD. PU 145K SO 45K. Pump 2x pipe displacement into well bore. 4/22/2016 4/22/2016 0.25 COMPZN WELLPR OWFF P Shoot fluid level. Fluid at 834'MD. 225.0 225.0 10:15 10:30 4/22/2016 4/22/2016 1.50 COMPZN WELLPR BHAH P PJSM-Lay down clean out BHA.Calc 225.0 0.0 10:30 12:00 disp=54.33 bbls Act disp=138.54 bbls. 4/22/2016 4/22/2016 0.75 COMPZN WELLPR BHAH P PJSM-Clean and clear rig floor. 0.0 0.0 12:00 12:45 4/22/2016 4/22/2016 1.25 COMPZN WELLPR RURD P PU Baker slim hole tools and GBR 0.0 0.0 12:45 14:00 tongs.Spot GBR hyd power unit and rig up double stack tongs. 4/22/2016 4/22/2016 4.50 COMPZN WELLPR BHAH P PJSM-Pick up and make up LEM 0.0 280.0 14:00 18:30 assy w/slim hole MWD.Scribe and orient LEM w/MWD.TFO=124°. 4/22/2016 4/22/2016 1.00 COMPZN WELLPR TRIP P PJSM-RIH w/LEM assy on drillpipe to 280.0 1,695.0 18:30 19:30 1695'MD.PU 60K SO 59K. 4/22/2016 4/22/2016 0.50 COMPZN WELLPR DHEQ P Shallow test MWD. 140 gpm, 190 psi. 1,695.0 1,695.0 19:30 20:00 Good test.Blow down TD. 4/22/2016 4/23/2016 4.00 COMPZN WELLPR TRIP P PJSM-RIH w/LEM assy on drillpipe 1,695.0 6,620.0 20:00 00:00 f/1695'MD t/6620'MD.PU 115K SO 47K.Fill pipe capacity every 20 stands. Pump 6 bbls down annulus every 1/2 hr. Daily downhole losses=785 bbls 4/23/2016 4/23/2016 1.50 COMPZN WELLPR TRIP P PJSM-RIH w/LEM assy on drillpipe 6,620.0 8,510.0 00:00 01:30 f/6620'MD t/8510'MD. PU 115K SO 47K. Fill pipe capacity every 20 stands. Pump 6 bbls down annulus every 1/2 hr. 4/23/2016 4/23/2016 1.00 COMPZN WELLPR SVRG P Service rig. 8,510.0 8,510.0 01:30 02:30 4/23/2016 4/23/2016 11.00 COMPZN WELLPR RGRP T Hydraulic manifold on top drive 8,510.0 8,510.0 02:30 13:30 cracked.Replace manifold. Pump 5 bbls down annulus every 1/2 hr. 4/23/2016 4/23/2016 0.75 COMPZN WELLPR TRIP P PJSM-RIH w/LEM assy on drillpipe 8,510.0 9,076.0 13:30 14:15 f/8510'MD t/9076'MD. PU 145K SO 43K. Page 5/12 Report Printed: 5/18/2016 r 0 = lig Operations Summary (with Timelog Depths) > ,&Wells 1J-182 conocoPhiliips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)'. 4/23/2016 4/23/2016 2.00 COMPZN WELLPR OTHR P Break circ. 120 gpm.Attempt to orient 9,076.0 9,076.0 14:15 16:15 between 120°to 70°L.Would not orient past 27°L. Put 180°right turn to orient at 90°R.Put 90°R turn and orient at 120°R.Put 90°right turn and tool face flopped to 27°L. 4/23/2016 4/23/2016 1.00 COMPZN WELLPR RGRP T Replace SS hyd sensor on top drive 9,076.0 9,076.0 16:15 17:15 4/23/2016 4/23/2016 0.50 COMPZN WELLPR WASH P Wash down to 9249'MD. 120 gpm, 9,076.0 9,249.0 17:15 17:45 300 psi,PU 147K SO 50K.Oriented at 27°L. At 9545'MD observed indication of seal assy entering SBE. Lost down weight at 9249'MD. 4/23/2016 4/23/2016 2.50 COMPZN WELLPR OTHR P PU to hoist wt at 145K. Put 270°right 9,249.0 9,249.0 17:45 20:15 turn.Tool face oriented to 90°R.Slack off and tag at 9249'MD. Put 45°right turn.Tool face oriented to 120°L. Slack off and tag at 9249'MD.Consult with RWO Engineer. 4/23/2016 4/23/2016 1.50 COMPZN WELLPR TRIP T POOH w/LEM assy f/9249 MD 9,249.0 7,755.0 20:15 21:45 t/7755'MD.PU 150K. 4/23/2016 4/23/2016 1.50 COMPZN WELLPR CIRC T Pump and spot 116 bbl Safe Lube pill. 7,755.0 7,755.0 21:45 23:15 141 gpm,450 psi. 4/23/2016 4/24/2016 0.75 COMPZN WELLPR TRIP T RIH f/7755'MD t/8132'MD. SO 45K. 7,755.0 8,132.0 23:15 00:00 Daily downhole losses=1049 bbls 4/24/2016 4/24/2016 0.50 COMPZN WELLPR TRIP T PJSM-RIH f/8132'MD t/8510'MD. 8,132.0 8,510.0 00:00 00:30 4/24/2016 4/24/2016 0.50 COMPZN WELLPR PULD T Pick up 17 jts 4"XT-39 HWDP 8,510.0 8,968.0 00:30 01:00 4/24/2016 4/24/2016 0.50 COMPZN WELLPR OTHR T Orient tool face from 171°L to 69°L. 8,968.0 8,968.0 01:00 01:30 120 gpm,400 psi. PU 155K SO 50K 4/24/2016 4/24/2016 0.50 COMPZN WELLPR WASH T Wash down f/8968'MD t/9242'MD. 8,968.0 9,242.0 01:30 02:00 110 gpm,300 psi. 4/24/2016 4/24/2016 1.00 COMPZN WELLPR OTHR T 'PU working single DP. RIH f/9242'MD 9,242.0 9,245.0 02:00 03:00 t/9249'MD.Tag up and set down 15K @ 9249'MD. 110 gpm,300 psi. Toolface @ 79°L.Pick up to 9245' MD.Observe indications of seal assy entering and exiting SBE.Consult w/Workover Engineer. 4/24/2016 4/24/2016 0.25 COMPZN WELLPR RURD T Blow down top drive.Lay down 9,245.0 9,245.0 03:00 03:15 working single DP. 4/24/2016 4/24/2016 4.50 COMPZN WELLPR TRIP T POOH f/9245'MD t/280'MD.Pump 9,245.0 280.0 03:15 07:45 double pipe displacement plus 5 bbls every 1/2 hr down annulus. Pump total of 104.5 bbls 4/24/2016 4/24/2016 0.50 COMPZN WELLPR BHAH T Break off X-O and inspect packer. 280.0 280.0 07:45 08:15 4/24/2016 4/24/2016 0.75 COMPZN WELLPR BHAH T Rig up tbg tongs. Break and back out 280.0 225.0 08:15 09:00 packer. 4/24/2016 4/24/2016 0.25 COMPZN WELLPR RURD T Rig up false table and double stack 225.0 225.0 09:00 09:15 tongs. 4/24/2016 4/24/2016 0.75 COMPZN WELLPR BHAH T Lay down slim hole MWD as per SLB 225.0 225.0 09:15 10:00 rep. 4/24/2016 4/24/2016 0.25 COMPZN WELLPR RURD T Rig down false table.Shoot fluid level. 225.0 225.0 10:00 10:15 Fluid @ 350'. Page 6/12 Report Printed: 5/18/2016 • • • Operations Summary (with Timelog Depths) :,4 &Wells 1J-182 ConocoPhiiiips Rig: DOYON 141 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 MtkKS)'. 4/24/2016 4/24/2016 0.75 COMPZN WELLPR BHAH T Lay down LEM assy as per Baker rep. 225.0 0.0 10:15 11:00 Recovered 5 broken pieces of stainless steel band on packe and LEM assy. 4/24/2016 4/24/2016 1.00 COMPZN WELLPR RURD T Rig down casing tongs.Clean and 0.0 0.0 11:00 12:00 clear rig floor. 4/24/2016 4/24/2016 0.50 COMPZN WELLPR BHAH T Mobilize clean out run#2 BHA tools to 0.0 0.0 12:00 12:30 rig floor. 4/24/2016 4/24/2016 1.50 COMPZN WELLPR BHAH T PU clean out BHA.MU jetted 0.0 217.0 12:30 14:00 bullnose,polish reamer,extensions,5 jts 4"DP, string magnet,bumper sub and jar as per Baker Fishing Hand. 4/24/2016 4/24/2016 3.25 COMPZN WELLPR TRIP T RIH on 4"DP w/clean out assy to 217.0 9,089.0 14:00 17:15 9089'MD. PU 125K SO 65K. 4/24/2016 4/24/2016 0.50 COMPZN WELLPR CIRC T Break circ.Stage pump up to 254 9,089.0 9,089.0 17:15 17:45 gpm.600 psi, Pump 100 bbls 3% KCL slick water w/.06%Safe Lube down DP. No returns. 4/24/2016 4/24/2016 0.50 COMPZN WELLPR CIRC T Close annular preventer. Bull head 9,089.0 9,089.0 17:45 18:15 200 bbls 3%KCL slick water w/.06% Safe Lube down annulus and DP.8 bpm,200 psi. 4/24/2016 4/24/2016 0.25 COMPZN WELLPR OWFF T Shut down and monitor well.52 psi on 9,089.0 9,089.0 18:15 18:30 drill pipe. Bleed off and open annular. Hole full but dropping in annulus. 4/24/2016 4/24/2016 1.25 COMPZN WELLPR REAM T Obtain parameters. PU 120K SO 65K 9,089.0 9,240.0 18:30 19:45 ROT 90K,4 bpm,300 psi,20 rpm,6K tq.Wash and ream f/9089'MD t/9240' MD.Getting returns at surface w/120 bph loss rate. 4/24/2016 4/24/2016 0.75 COMPZN WELLPR CIRC T Close annular preventer.Bull head 9,240.0 9,240.0 19:45 20:30 200 bbls 3%KCL slick water w/.06% Safe Lube down annulus and DP.8 bpm,225 psi. 4/24/2016 4/24/2016 0.50 COMPZN WELLPR OWFF T Shut down.Monitor well. 100 psi on 9,240.0 9,240.0 20:30 21:00 drillpipe. Bleed off pressure.Gained 7.8 bbls back.Open annular.Fluid level dropping in annulus. 4/24/2016 4/24/2016 1.00 COMPZN WELLPR REAM T Break circ.Wash and ream f/9240' 9,240.0 9,184.0 21:00 22:00 MD t/9266'MD.4 bpm,300 psi,20 rpm,6-7K tq,Tag bottom of SBE @ 9266'MD.Back ream up to 9240'MD. Slide down to 9266'MD and pull up to 9240'MD w/pump on.Slide down to 9266'MD and pull up to 9240'MD w/pump off.PU 108K SO 65K.Pick up to 9184'MD and stand back one stand DP. 4/24/2016 4/24/2016 0.50 COMPZN WELLPR OWFF T Monitor well. Fluid level dropping in 9,184.0 9,184.0 22:00 22:30 annulus.Blow down TD and kill line. Drop 1.9"OD rabbit. 4/24/2016 4/25/2016 1.50 COMPZN WELLPR TRIP T POOH f/9184'MD t/6367'MD filling 9,184.0 6,367.0 22:30 00:00 hole w/double pipe displacement.PU 100K Daily downhole losses=972 bbls 4/25/2016 4/25/2016 3.00 COMPZN WELLPR TRIP T POOH f/6367'MD t/217'MD filling 6,367.0 217.0 00:00 03:00 hole w/double pipe displacement plus 5 bbls every 1/2 hr. Page 7/12 Report Printed: 5/18/2016 • • • Operations Summary (with Timelog Depths) { Drilling+ 1J-182 Con©coPhiltips Rig: DOYON 141 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(ftKS)i 4/25/2016 4/25/2016 1.25 COMPZN WELLPR BHAH T PJSM-Lay down clean out BHA as per 217.0 0.0 03:00 04:15 Baker rep. 4/25/2016 4/25/2016 0.50 COMPZN WELLPR BHAH T Clean and clear rig floor. 0.0 0.0 04:15 04:45 4/25/2016 4/25/2016 0.50 COMPZN WELLPR RURD T PJSM-Pick up and rig up casing 0.0 0.0 04:45 05:15 equipment. 4/25/2016 4/25/2016 2.50 COMPZN WELLPR BHAH T PJSM-Pick up and make up LEM 0.0 280.0 05:15 07:45 assy w/slim hole MWD.Scribe and orient LEM w/MWD.TFO=220°. 4/25/2016 4/25/2016 0.75 COMPZN WELLPR TRIP T RIH w/LEM assy on drillpipe to 1510' 280.0 1,510.0 07:45 08:30 MD. 4/25/2016 4/25/2016 0.50 COMPZN WELLPR DHEQ T Shallow test MWD. 120 gpm,250 psi. 1,510.0 1,510.0 08:30 09:00 PU 60K SO 60K 4/25/2016 4/25/2016 6.50 COMPZN WELLPR TRIP T RIH w/LEM assy on drillpipe f/1510' 1,510.0 9,059.0 09:00 15:30 MD t/9059'MD. Fill pipe every 20 stands.PU 110K SO 70K. 4/25/2016 4/25/2016 1.00 COMPZN WELLPR CIRC T Break circ. 105 gpm,250 psi.Orient 9,059.0 9,059.0 15:30 16:30 toolface to 128°L. 4/25/2016 4/25/2016 4.00 COMPZN WELLPR OTHR T Wash down to 9106'MD.Tag top of 9,059.0 9,242.0 16:30 20:30 hook hanger.PU and put 25°right turn.Orient to 8°L.Wash past tag and orient to 128°L.Wash down to 9249' MD.Tag up and set down 15K twice. Observe 3-5K drag as seals enter and exit SBE.Put 180°right turn and orient to 8°L.Wash down and tag at 9249'MD twice. Put 45°right turn and orient to 178°R.Wash down and tag at 9249.Consult with Workover engineer and Baker Oil Tool supervisor. Put 90°right turn.Orient to 14°L.Wash down and tag at 9249'MD twice.Turn pump off and tag at 9249' MD. Pick up to 9241'MD.Returns to surface while pumping w/71 bph losses. 4/25/2016 4/25/2016 1.75 COMPZN WELLPR WAIT T Wait on orders.Consult w/Workover 9,242.0 9,242.0 20:30 22:15 Engineer and Baker Oil Tools. Sim- ops/Repair iron roughneck. 4/25/2016 4/26/2016 1.75 COMPZN WELLPR TRIP T PJSM-Blow down TD.Lay down 9,242.0 7,471.0 22:15 00:00 working single. POOH w/LEM assy. f/9242'MD t/7471'MD filling w/double pipe displacement plus 5 bbls every 1/2 hr. Daily downhole losses=749 bbls 4/26/2016 4/26/2016 4.00 COMPZN WELLPR TRIP T PJSM-TOH f/7471'-280'MD,fill hole 7,471.0 280.0 00:00 04:00 w/5.5 bbls every 5 stands and 5 bbls every 30 min. 4/26/2016 4/26/2016 2.50 COMPZN WELLPR BHAH T PJSM-pull packer to floor,laying 280.0 0.0 04:00 06:30 down packer&pack off sub. Lay down slim hole tools&LEM assembly per Baker Rep.Total losses 162 bbls. 4/26/2016 4/26/2016 0.50 COMPZN WELLPR BHAH T Clear&clean rig floor. 0.0 0.0 06:30 07:00 4/26/2016 4/26/2016 1.25 COMPZN WELLPR SLPC T PJSM-slip&cut 60'of drill line. 0.0 0.0 07:00 08:15 4/26/2016 4/26/2016 0.50 COMPZN WELLPR SVRG T Service rig 0.0 0.0 08:15 08:45 Page 8/12 Report Printed: 5/18/2016 • • • • Operations Summary (with Timelog Depths) &Wis v{ 1J-182 ConocoPhhiitllips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/26/2016 4/26/2016 3.25 COMPZN WELLPR WAIT T Confer with town&decide to make 0.0 0.0 08.45 12:00 string mill clean out run. Baker fishing to fabricate smooth OD mills to 6.75" &7.125".SIMOPS Clean rig&work on MP2's. 4/26/2016 4/26/2016 6.00 COMPZN WELLPR WAIT T Wait on Baker fishing to fabricate 0.0 0.0 12:00 18:00 smooth OD mills to 6.75"&7.125". SIMOPS Work on MP2's for Top Drive &drawworks,clean dead man& inspect.Shim up pit door&inspect air slips. 4/26/2016 4/27/2016 6.00 COMPZN WELLPR WAIT T Wait on Baker fishing to fabricate 0.0 0.0 18:00 00.00 smooth OD mills to 6.75"&7.125". SIMOPS gather up available parts of BHA&tally pieces.Clean in pits, mezzanine,&drawworks. Inspect brake pins&linkage of drawworks. 4/27/2016 4/27/2016 0.50 COMPZN WELLPR WAIT T PJSM,Wait on milling assembly tools 0.0 0.0 00:00 00:30 from Baker fishing.Continue rig projects. 4/27/2016 4/27/2016 0.75 COMPZN WELLPR RURD T Mobilize milling tools to rig floor. 0.0 0.0 00:30 01:15 4/27/2016 4/27/2016 3.25 COMPZN WELLPR BHAH T Make up milling/cleanout BHA as per 0.0 295.0 01:15 04:30 Baker rep. 4/27/2016 4/27/2016 0.25 COMPZN WELLPR CIRC T P/U 1 stand,obtain pump pressures 295.0 295.0 04:30 04:45 @ 295'MD, 1 bpm=100 psi,2 bpm=200 psi,3 bpm=450 psi. 4/27/2016 4/27/2016 3.25 COMPZN WELLPR TRIP T RIH from 295'MD to 9072'MD 295.0 295.0 04:45 08:00 pumping pipe volume every 20 stands to ensure Snozzelator not plugging. Filling annulus with 5 bbl every 30 min. 4/27/2016 4/27/2016 0.25 COMPZN WELLPR CIRC T Obtain parameters,rotate 20 rpm,4- 295.0 9,072.0 08:00 08:15 5K Tq, P/U=110k,S/O=70k. 4/27/2016 4/27/2016 0.75 COMPZN WELLPR REAM T Wash and rean down @ 2 bpm,200 9,072.0 9,163.0 08:15 09:00 psi,28%flow out from 9072'MD to 9163'MD,placing bottom mill @ 9107' MD. 4/27/2016 4/27/2016 3.00 COMPZN WELLPR MILL T Mill/Swage through tight spot from 9,163.0 9,183.0 09:00 12:00 9107'MD-9127'MD with both 6.75' and 7.125'smooth OD string mills @ 4 bpm,800-1500 psi,observing pressure increase©4 bpm.Rotate 40 rpm,7-8k Tq.Work both mills through Hook Hanger twice @ 40 rpm, then drift through without rotation. Total losses for tour=423 bbl 4/27/2016 4/27/2016 0.50 COMPZN WELLPR WASH T Slide mills through tight spot twice 9,183.0 9,264.0 12:00 12:30 from 2-4k wt.P/U=110k,S/O=70k. P/U single and wash down to 9263.72 bullnose depth, no-go observed with pressure increase and began injecting fluid.Set 7k down twice on no-go.P/U 5'and circulate. 4/27/2016 4/27/2016 0.50 COMPZN WELLPR OWFF T Blow down top drive,lay down single. 9,264.0 9,264.0 12:30 13:00 Monitor well for flow,observe fluid level dropping. 4/27/2016 4/27/2016 5.25 COMPZN WELLPR TRIP T POOH from 9,260'to 200'. 9,264.0 200.0 13:00 18:15 Page 9/12 Report Printed: 5/18/2016 0 • Drilling Operations Summary (with Timelog Depths) ::,' &Wells 1J-182 conocoPhd frps Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/27/2016 4/27/2016 3.00 COMPZN WELLPR BHAH T Laid down Clean out BHA. Upper Mill 200.0 0.0 18:15 21:15 went in at 7 1/8"and came out at 7 1/16". 4/27/2016 4/27/2016 0.75 COMPZN WELLPR BHAH T i Cleared Rig Floor. 0.0 0.0 21:15 22:00 4/27/2016 4/27/2016 0.25 COMPZN WELLPR SFTY T PJSM for running LEM. 0.0 0.0 22:00 22:15 4/27/2016 4/28/2016 1.75 COMPZN WELLPR BHAH T PU and RIH with LEM BHA to 165'. 0.0 165.0 22:15 00:00 4/28/2016 4/28/2016 2.00 COMPZN WELLPR BHAH T Finish PU LEM BHA Mix and put in 165.0 280.0 00:00 02:00 Pal Mix.Made up XO to DP. 4/28/2016 4/28/2016 0.75 COMPZN WELLPR TRIP T RIH with LEM on DP from 280'to 280.0 2,172.0 02:00 02:45 2,172'. 4/28/2016 4/28/2016 0.50 COMPZN WELLPR DHEQ T Shallow tested MWD. 2,172.0 2,172.0 02:45 03:15 4/28/2016 4/28/2016 4.25 COMPZN WELLPR TRIP T RIH with LEM on DP from 2,172"to 2,172.0 9,059.0 03:15 07:30 9,059'.Filling every 20 stands. 4/28/2016 4/28/2016 0.50 COMPZN WELLPR CIRC T Broke Circulation 120 GPM @ 340 9,059.0 9,059.0 07:30 08:00 PSI.Attempt to orient tool face to-90, Tool face rolling+6 high or 180 low. 4/28/2016 4/28/2016 0.75 COMPZN WELLPR WASH T Washed down from 9,059'to 9,254' 9,059.0 9,254.0 08:00 08:45 tagged up and set down 15 K 2 times without engageing.Pumping 120 GPM @ 340 PSI. 4/28/2016 4/28/2016 0.50 COMPZN WELLPR WAIT T Confered with Anchorage Drilling 9,254.0 9,254.0 08:45 09:15 Team. 4/28/2016 4/28/2016 0.75 COMPZN WELLPR OTHR T Worked pipe up and down tagging up 9,254.0 9,254.0 09:15 10:00 and set down 25 K without engageing.Pumping 120 GPM @ 340 PSI. 4/28/2016 4/28/2016 0.50 COMPZN WELLPR WAIT T Confered with Anchorage Drilling 9,254.0 9,254.0 10:00 10:30 Team. 4/28/2016 4/28/2016 0.75 COMPZN WELLPR OTHR T Worked pipe up and down tagging up 9,254.0 9,254.0 10:30 11:15 and set down 50 K several times with tool face-18 left engaged LEM..Over pulled 7 K confirm engaged. Pumping 120 GPM @ 340 PSI. 4/28/2016 4/28/2016 0.50 COMPZN WELLPR SFTY P PJSM for packer set. 9,254.0 9,254.0 11:15 11:45 4/28/2016 4/28/2016 1.75 COMPZN WELLPR PACK P Dropped ball and set Packer 9,254.0 8,989.0 11:45 13:30 pressured up to 2700 psi for 3 miniutes then to 4000 psi.Checked packer set and confirmed release. Tested Packer 1500 psi for 10 Miniutes.POOH laid down 4 Jts.Top of Packer 8,989.08'. 4/28/2016 4/28/2016 0.50 i COMPZN WELLPR OWFF P Observed well. Fluid level falling. 8,989.0 8,989.0 13:30 14:00 4/28/2016 4/28/2016 7.25 COMPZN WELLPR PULD P POOH laying down Drill Pipe. 8,989.0 165.0 14:00 21:15 4/28/2016 4/28/2016 1.00 COMPZN WELLPR RURD P Cleared Rig floor and picked up 165.0 165.0 21:15 22:15 clamps and spooler. 4/28/2016 4/28/2016 1.00 COMPZN WELLPR BHAH i P Layed down Running tool and MWD. 165.0 0.0 22:15 23:15 4/28/2016 4/29/2016 0.75 COMPZN RPCOMP WWWH P Pulled Wear Ring and washed 0.0 0.0 23:15 00:00 Wellhead and BOP Stack. 4/29/2016 4/29/2016 1.00 COMPZN RPCOMP RURD P Clean and clear rig floor,send Baker 0.0 0.0 00:00 01:00 running tools out beaver slide. Page 10/12 Report Printed: 5/18/2016 • • Drilling' Operations Summary (with Timelog Depths) { &Wells 1J-182 ConocoPhiiiips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/29/2016 4/29/2016 0.50 COMPZN RPCOMP RURD P Mobilize Baker Centrilift tools and 0.0 0.0 01:00 01:30 equipment to rig floor 4/29/2016 4/29/2016 0.75 COMPZN RPCOMP RURD P R/U GBR casing equipment and 0.0 0.0 01:30 02:15 Centrilift equipment. 4/29/2016 4/29/2016 0.25 COMPZN RPCOMP SFTY P PJSM on running 4W 12.6#L-80 IBT- 0.0 0.0 02:15 02:30 M Gas lift tubing string 4/29/2016 4/29/2016 0.50 COMPZN RPCOMP PUTB P P/U seal assembly, 1 joint tubing and 0.0 75.0 02:30 03:00 Baker Centrilift Gauge carrier. 4/29/2016 4/29/2016 1.25 COMPZN RPCOMP OTHR P M/U gauge to carrier and make TEC 75.0 75.0 03:00 04:15 wire connection,test same. 4/29/2016 4/29/2016 7.75 COMPZN RPCOMP PUTB P Run 4'V2"tubing from 75'MD to 3706' 3,706.0 3,706.0 04:15 12:00 MD, P/U GLM#3 installing cannon clamps on every connection.Test TEC wire every 1000',fill hole with 5 bbl every 30 minutes. (Total losses for tour 119 bbl) 4/29/2016 4/29/2016 7.75 COMPZN RPCOMP PUTB P Continue RIH with 4W IBTM tubing 3,706.0 8,500.0 12:00 19:45 string from 3706'MD to 8,500'MD, installing cannon clamps on every connection,above and below GLM's, testing TEC wire every 1000'MD. 4/29/2016 4/29/2016 1.00 COMPZN RPCOMP WAIT T Baker did not have enough pins to 8,500.0 8,500.0 19:45 20:45 meet the clamp requirement for control line. 4/29/2016 4/29/2016 1.00 COMPZN RPCOMP PUTB P Continue RIH with 4'/2'IBTM tubing 8,500.0 8,989.0 20:45 21:45 string from 3706'MD to 8,500'MD, installing cannon clamps on every connection,above and below GLM's, testing TEC wire every 1000'MD. 4/29/2016 4/30/2016 2.25 COMPZN RPCOMP RCST P Tagged Packer @ 8,989'.Worked 8,989.0 8,989.0 21:45 00:00 pipe to orient Half Mule Shoe to enter Packer.Working torque down hole. 4/30/2016 4/30/2016 1.00 COMPZN RPCOMP RCST P Continued working torque donw hole 8,989.0 8,989.0 00:00 01:00 to get into Packer. 4/30/2016 4/30/2016 1.50 COMPZN RPCOMP HOSO P Located in Packer and laid down 4 Jts. 8,989.0 8,779.0 01:00 02:30 Spaced out with 3 Pups 9.82,9.81,& 4/30/2016 4/30/2016 0.75 COMPZN RPCOMP THGR P Make up Tubing Hanger and 8,779.0 8,959.0 02:30 03:15 Terminate TEC Line 4/30/2016 4/30/2016 2.75 COMPZN RPCOMP CRIH P RU and Pumped total of 510 Bbls of 8,959.0 8,959.0 03:15 06:00 Inhibited Brine to Annulus.3BPM @ 10 PSI 4/30/2016 4/30/2016 1.00 COMPZN RPCOMP THGR P Landed Hanger and run in Lock down 8,959.0 0.0 06:00 07:00 bolts. 4/30/2016 4/30/2016 4.25 COMPZN RPCOMP THGR T Working with Lockdowns,several 0.0 0.0 07:00 11:15 were not correct for wellhead resulting in some galling.Decision was made not to shear out the SOV or diplace Freeze Protect. 4/30/2016 4/30/2016 0.75 COMPZN RPCOMP PRTS P Test Tubing by Casing Annulus 2500 0.0 0.0 11:15 12:00 PSI for 1/2 Hour on chart.Test Good. 4/30/2016 4/30/2016 0.50 COMPZN WHDBOP MPSP P Set TWC. 0.0 0.0 12:00 12:30 4/30/2016 4/30/2016 1.75 COMPZN WHDBOP NUND P ND BOP 0.0 0.0 12:30 14:15 4/30/2016 4/30/2016 1.75 COMPZN WHDBOP NUND P NU Tree and changed Adapter 0.0 0.0 14:15 16:00 Flange. Page 11/12 Report Printed: 5/18/2016 S r , Drilling Operations Summary (with Timelog Depths) 1J-182 ConocoPhittips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/30/2016 4/30/2016 0.75 COMPZN WHDBOP PRTS P Terminated TEC line in Tree and 0.0 0.0 16:00 16:45 Tested Line.OK. 4/30/2016 4/30/2016 0.50 COMPZN WHDBOP PRTS P Tested Tree to 5,000 PSI Good Test 0.0 0.0 16:45 17:15 4/30/2016 4/30/2016 0.75 COMPZN WHDBOP OTHR P Rigged down Test lines and dressed 0.0 0.0 17:15 18:00 tree.Secured Well. 4/30/2016 5/1/2016 6.00 DEMOB MOVE RURD P Clean Pits and RD.Rig released 2400 0.0 0.0 18:00 00:00 Hrs.ASRC had no other trucks to send for hauling off fluid from pits. Used 1 ASRC(Clean)and 2 Peak Trucks. Page 12/12 Report Printed: 5/18/2016 0,, KUP OD • 1J-182 ConocoPhillips 3Well Attri Max Angle&MD TD Al 1910,1I',', Wellbore API/UWI Field Name Wellbore Status Inc'(3 MD(ftKB( Act Bye(ftKB) Gorwco7�h.0$ 500292332100 WEST SAK PROD 95.65 16,968.37 17,844.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date 1J-182,511912016 11 37 05 AM SSSV:NONE 50 8/11/2015 Last WO: 4/30/2016 43.51 11/17/2006 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag' Rev Reason:GLV C/O,H2S pproven 5/6/2016 Casing Strings HANDER;35.5 �`r'�Ail Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len p...Grade Top Thread CONDUCTOR Insulated 20 19.250 43.0 120.0 120.0 94.00 K-55 r r .r Casing Description OD(in) ID(in) Top(MB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread SURFACE 133/8 12.415 42.9 3,673.4 2,151.3 68.00 L-80 Buttress _ Thread r r r �� Casing Description OD(in) SID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread INTERMEDIATE 95/8 8.835 37.1 9,831.0 3,433.0 40.00 L-80 BUTT Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread s CONDUCTOR Insulated.Oso-- LEM#1 and ZX PACKER 4 1/2 3.958 9,000.9 9,269.2 3,371.7 12.60 L-80 IBTM 120.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND),.. Wt/Len(1...Grade Top Thread ' D-SAND LINER HH 41/2 3.476 9,118,0 9,358.0 3,383.9 11.60 L-80 BTC GAS LIFT,1,989.8 Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) J-. 9,118.0 3,351.0 82.49 HANGER BAKER MODEL B FLANGED HOOK HANGER 7.540 (INSIDE CASING) 9,138.6 3,353.8 82.36 HANGER BAKER MODEL B FLANGED HOOK HANGER 7.000 SURFACE,42 (OUTSIDE CASING) 9,145.3 3,354.7 82.32 XO BUSHING CROSSOVER BUSHING 3.880 SLOTS,4.829.0-4,913.0 9,176.5 3,358.9 82.14 ECP BAKER PAYZONE EXTERNAL CASING PACKER 3.900 Casing Description 100(in) I1O lin) 'Top(ftKB) !Set Depth(ftKB) I Set Depth(TVD)...WtlLen(I...Grade Top Thread B-SAND LINER 4 1/2 3.476 9,224,5 17,839 0 3,360.9 11.60 L-80 Buttress GAS LIFT:5,339.1 4.; Thread Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(3 Item Des Comm (in) 9,224.5 3,365.5 82.07 PACKER HRD ZXP LINER TOP PACKER 7.500 9,243.1 ' 3,368.1 82.05 NIPPLE 'RS'PACKOFF SEAL NIPPLE 6.190 9,245.9 3,368.4 82.05 HANGER FLEXLOCK LINER HANGER 6.230 if GAS LIFT 6,914.4 9,255.7 3,369.8 82.04 XO BUSHING CROSSOVER BUSHING 4.900 9,257.1 3,370.0 82.04 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 9,276.8' 3,372.7 82.02 XO BUSHING CROSSOVER 5.5"x 4.5" 3.890 GAUGE,8970.1 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) set Depth(ft. Set Depth(ND)1...Wt(Ib/R) Grade Top Connection TUBING WO 2016 1 4 1/2 3.958) 35.51 9,036.01 3,340.31 12.601 L-80 (I B T M Completion Details ° Nominal ID LOCATOR;8,017.9 . Top((MB) Top(TVD)(RCB) Top!noir) Item Des Corn (in) 'MA.' 35.5 35.5 0.00 HANGER Vetco Gray 11"x 4-1/2"Hgr w/4.909"MCA Top Conn. 3.958 8,970.1 3,331.0 81.72 GAUGE Baker Centrilift Discharge Gauge/TEC wire to surface 3.958 SEAL ASSY;9,018.6 ir 9,017.9 3,337.8 81.98 LOCATOR Baker Mechanical locator 4.000 *f 9,018.6 3,337.9 81.98 SEAL ASSY Baker 190-47 Seal Assembly I 3.870 ir Perforations&Slots Is Shot Dens ' -IF Top(ND) Btm(ND) (shots/ Top(RKB) Btm(ftKB) (ftKB) (ftKB) Zone Date R) Type Corn II 9,282.0 10,018.0 3,373.4 3,445.0 WS D,WS C, 11/1/2006 32.0 SLOTS ALL PERFS IN WS B,1J-182 WELLBORE:Alternating solid/slotted pipe- 0,125"x2.5"@ 4 p' circumferential adjacent � rows,3"centers 1 N,i I f staggered 18 deg,3'non I' '1 -slotted ends 10,020.0 17,585.0 3,445.1 3,359.5 WS B,1J-182 11/1/2006 32.0 SLOTS 17,708.0 17,794.0 3,358.7 3,359.4 WS B,1J-182 11/1/2006 32.0 SLOTS i 'm Mandrel Inserts St N Top(ND) Valve Latch Port Size TRO Run _ Top(ftKB) (ftKB) Make Madel 09 (inl Sery Type Type (in) (psi) Run Date Coo -::,,a1,- , 1 1,989.8 1,707.2 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/3/2016 2 5,339.2 2,528.4 Camco KBMG 1 GAS LIFT GLV BK-5 0.188 1,431.0 5/3/2016 i 3 8,914.4 3,322.9 Camco KBMG 1 GAS LIFT OV BK 0.313 0.0 5/4/2016 • I Notes:General&Safety End Date Annotation 11/14/2006 NOTE:MULTI-LATERAL WELL. 1J-182(B-SAND),1J-182L1(D-SAND) LEM#1 and ZX PACKER; 9,000.9-9,269.2 - , 2/3/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 D-SAND LINER HH;9,118.0 11 - 9,358.0 SLOTS;9,282.0-10,018.0 INTERMEDIATE;37.1-9,831.0 Rim- SLOTS;10,020.0-17,5855.0 -_ SLOTS;17,708.0-17,784.0 B-SAND LINER;9,224.5- 17,839.0 • 2-.0to- 32 • ZGo�� WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. March 4, 2016 Attn.: Makana Bender RECEIVED 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 MAR 0 S 201u $ ,q /2014 g M.K.BENDER AOGCC RE: Gas lift survey: 1J-182 Run Date: 1/21/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1.1-182 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-23321-00 SCANNEC f.^ e 1 015 Gas lift survey(Field Print) '� 1 color log 50-029-23321-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: Image Project 11'llell I~li~1:~r°y I^ile ever I~ege XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspecfiian of the file. p~©~ - ~~~ Well History File Identifier Organizing (donel ^ Two-sided III ~III IIIIIII ~IIII ^ Rescan Needed III II~IIIIIII III III RESCAN DIGI L DATA OVERSIZED (Scannable) ^ Color Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~(~- Q ©g /s/ Project Proofing I II I III II VI II I I II I BY: Maria Date: ( 3f~ D lsl Scanning Preparation x 30 = D~~ + ~U =TOTAL PAGES r ~~ BY: ~ Maria Date:'.,,, ~~ ~ ~ (Count does not include cover sheet) /s/ ~ , Production Scanning Stage 7 Page Count from Scanned File: __~~ (Count does include cove heet) Scanning is complete at this point unless rescanning is required. Page Count Matches Number in Scanning Preparation: YES _ BY: Maria Date: /~ ~/~O D Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: NO lsl NO "iiiumuuumii ReScanned BY: Maria Date: lsl Comments about this file: o , ~e~,ea iuiiiimuumi 10/6/2005 Well History File Cover Page.doc i STATE OF ALASKA • ALA.OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other gr, ESP to Gas Lift Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other IV Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F7 Exploratory r 206-132 ' 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-23321-00 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025661,ADL0025662,ADL0380058 1J-182 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): =" Kuparuk River Field/West Sak Oil Po 11.Present Well Condition Summary: NOV 2 2 2013 Total Depth measured 17844 feet Plugs(measured) None AOGCC true vertical 3361 feet Junk(measured) None AOGCC Effective Depth measured 17837 feet Packer(measured) 0 - true vertical 3360 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR IN 77 20 120 120 0 0 SURFACE 3631 13.375 3673 2151 0 0 INTERMEDIATE 9794 9.625 9831 3432 0 0 B-SAND LINER 8615 8.43 17839 3361 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 9282-10018,10020-1785,17708-17794 True Vertical Depth: 3373-3445,3445-3360,3359-3359 Tubing(size,grade,MD,and TVD) 4.5, L-80, 8038 MD,3122 TVD Packers&SSSV(type,MD,and TVD) I Packer=HRD ZXP Liner top packer-does not isolate IA MD= 9225 TVD=3365 SSSV=None 12.Stimulation or cement squeeze summary: . Intervals treated(measured): 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 736 132 94 175 203 Subsequent to operation 760 398 129 652 221 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development P' ' Service r Stratigraphic r 16.Well Status after work: Oil J'• Gas r WDSPL r Daily Report of Well Operations_X GSTOR VVINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Bob Christensen/Darrell Humphrey Email n1139(a)conocophillips.com Printed Name Darrell R. Hum hrey ( � Title NSK Production Engineering Specialist Signature c ,o-..a1,�A(� Il \ " l " " Phone:659-7535 Date `t t � 11 ' Z-o ' 1-3 VLF , ( 7 5 RBDMS NOV 2 5 0(\- Form 10-404 Revised 10/2012 `Z /` 1/3 Submit Original Only r � 1J-182 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/23/1310pen Well- Return to gas lifted production 10/21/13I(AC EVAL) MIT-OA PASSED TO 1200 PSI. 09/29/13IPulled TTCESP f/Deployment Flange. JOB Complete. 09/28/13 ENGAGE AND PULL ESP PUMP AT 7987' CTMD. POOH, HANG ESP IN PANCAKE FLANGE AT SURFACE. PANCAKE LOCK DOWN SCREWS AT 5-1/2 TURNS EACH. READY FOR SLICKLINE. KUP PROD • 1J-182 ConocoPhillips I Well Attributes Max Angle&MD TD Alaska,(3':'.. Wellbore API/UWI Field Name Wellbore Status Ind(°) MD(ftKB) Act Btm(ftKB) terraerinwkps 500292332100 WEST SAK PROD 95.65 16,968.37 17,844.0 - ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1J-182,11/11/2013628.08 PM SSSV:NONE 0 8/14/2012 Last WO: 7/7/2010 43.51 11/17/2006 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:GLV C/O lehallf I 11/11/2013 f �ngStrings HANGER.35.4 II I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread L"( I CONDUCTOR Insulated 20 19.250 43.0 120.0 120.0 94.00 K-55 _..-, Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 133/8 12.415 42.9 3,673.4 2,151.3 68.00 L-80 Buttress Thread Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread Ill INTERMEDIATE 95/8 8.835 37.1 9,831.0 3,433.0 40.00 L-80 BUTT Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread D-SAND LINER HH 4 1/2 3.476 9,118.0 9,358.0 3,383.9 11.60 L-80 BTC • Liner Details CONDUCTOR Insulated; Nominal ID 120 Top(ftKB) Top(ND)(ftKB) Top Ind(°) Item Des Corn (in) P19118.0 3,351.0 82.49 HANGER BAKER MODEL B FLANGED HOOK HANGER 7.540 (INSIDE CASING) 9,138.6 3,353.8 82.36 HANGER BAKER MODEL B FLANGED HOOK HANGER 7.000 ESP Mandrel;1,975.6 4 (OUTSIDE CASING) al 9,145.3 3,354.7 82.32 XO BUSHING CROSSOVER BUSHING 3.880 9,176.5 3,358.9 82.14 ECP BAKER PAYZONE EXTERNAL CASING PACKER 3.900 Casing Description IOD(in) IID(in) -Top(ftKB) I Set Depth(ftKB) !Set Depth(ND)... WtlLen(l...1 Grade !Top Thread B-SAND LINER 41/2 3.476 9,224.5 17,839.0 3,360.9 1160 L-80 Buttress Thread ?:i Liner Details Nominal ID SURFACE;42.93,6734 Top(ftKB) Top(ND)(ftKB) Top Ind(1) Item Des Corn (in) CMF SHOE;2,6730, 9,224.5 3,365.5 82.07 PACKER HRD ZXP LINER TOP PACKER 7.500 9,243.1 3,368.1 82.05 NIPPLE 'RS'PACKOFF SEAL NIPPLE 6.190 9,245.9 3,368.4 82.05 HANGER FLEXLOCK LINER HANGER 6230 9,255.7 3,369.8 82.04'XO BUSHING CROSSOVER BUSHING 4.900 SLOTS;4.829.04,913.0 9,257.1 3,370.0 82.04 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 • • 9,276.8 3,372.7 82.02 XO BUSHING CROSSOVER 5.5"0 4.5" 3.890 Tubing Strings DISCHARGE;7,962.3 A= Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING WO 41/2 3.958 35.4 8,092.2 3,134.8 12.60 L-80 IBTM Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inc!(1) Item Des Corn (in) • 35.4 35.4 0.00 HANGER Vetco Gray 11"x 4-1/2"Hgr w/4.909"MCA Top Conn. 5.700 • • Made • 7,962.3 3,104.0 75.87 DISCHARGE Unique Discharge Sub 3.833 ESP INTAKE;8,038.3 I 8,038.3 3,122.2 76.36 ESP INTAKE Perforated Xover Intake TTC ESPCP(5.13"OD) -..xxxi- SEAL Upper;8.049.0 8,049.0 3,124.7 76.42 SEAL Upper Upper Tandem Seal GSB3DB FER HL SSCV H6 SB/SB ilii PFSA SEAL Lower;80660 • 8,055.9 3,126.3 76.45 SEAL Lower -Lower Tandem Seal GSB3DB FER HL SSCV H6 SB/SB ESP MOTOR;8.0620 .. . PFSA SENSOR;8,0882 8,062.8 3,127.9 76.48 ESP MOTOR Motor 418 HP KMH(2610 v/98 amp)(5.62"0.D.) Centralizer;8,0903 ) 8,088.2 3,133.9 76.59 SENSOR A-Well I-Pump Sensor(4.375"OD) 8,090.3 3,134.3 76.60 Centralizer Motor Centralizer(5.85"0.13.) 4.500 Perforations&Slots Shot Dens •=1•1 (TVD( Btm(ND) (shotsk Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Cant 9,282.0 10,018.0 3,373.4 3,445.0 WS D,WS C, 11/1/2006 32.0 SLOTS ALL PERFS IN WS B,1J-182 WELLBORE:Alternating solid/slotted pipe- > 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non -slotted ends 10,020.0 17,585.0 3,445.1 3,359.5 WS B,1J-182 11/1/2006 32.0 SLOTS MI 17,708.0 17,794.0 3,358.7 3,359.4 WS B,1J-182 11/1/2006 32.0 SLOTS Mandrel Inserts st °- ati C on Top(TVD) Valve Latch Port Size TRO Run No Top(ftKB( (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m 1 1,975.6 1,701.2 CAMCO KBMG 1 ESP DMY BK 0.000 0.0 11/1/2013 Notes:General&Safety End Date Annotation D-SAND LINER HH;9,118.0- ' i, 11/14/2006 NOTE:MULTI-LATERAL WELL: 1J-182(B-SAND),1J-182L1(D-SAND) 9,358.0' SLOTS;9,282.0.10,018.0 2/3/2009 NOTE:VIEW SCHEMATIC w/Alaska Schemetic9.0 INTERMEDIATE;37.1-9,831 0 - SLOTS;10,020.0-17,585.0 SLOTS;17,708.0-17,7949 B-SAND LINER;9.224.5- A IL 17,839.0 • ��o��jy� s9 THE STATE Alaska Oil and Gas `�'� °fALAS� Conservation Commission wet GOVERNOR SEAN PARNELL 333 West Seventh Avenue C).'ALA91°.' Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 t MJ Loveland spNN n ED �� "` 2 WI Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 o b — 13P> Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-182 Sundry Number: 313-496 Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair, ommissioner DATED this27 day of September, 2013. Encl. RECEIVED STATE OF ALASKA AIL OIL AND GAS CONSERVATION COM SION SEP 1. 7 2013 APPLICATION FOR SUNDRY APPROVALS mss. ) Z7 ),3 20 AAC 25.280 ,AO G C 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other:Pump OA cmt shoe 17' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development Ft- 206-132 • 3.Address: Stratigraphic r Service r 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23321-00 7. If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 1J-182 i 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025661,ADL0025662,ADL0380058 Kuparuk River Field/West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 17844 - 3361, 17837' . 3360'. None none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 120' 120' SURFACE 3630 13.375 3673' 2151' INTERMEDIATE 9794 9.625 9831' 3432' B-SAND LINER 8615 4.5 17839' 3361' Perforation Depth MD(ft):. Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9282-10018, 10020-17585, 17708-17794 3373-3445, 3445-3360, 3359-3359 4.5 L-80 8038 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) HRD ZXP liner top packer -Does not isolate IA 9225'RKB and 3365'TVD. NO SSSV MD= TVD= 12.Attachments: Description Summary of Proposal . 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development F . • Service r 14.Estimated Date for Commencing Operation 10/10/13 15. Well Status after proposed work: Oil l,�/J Gas r WDSPL r Suspended r 16.Verbal Approval: Date: W1NJ �r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Martin Walters Email: nn1878 @cop.com Printed Name MJ Lov Ian e: WI Project Supervisor Signature ,, �l Phone:659-7043 Date 7/`y r Commission Use Only Sundry Number: Lr Conditions of approval: Notify Commission so that a representative may witness t3 T - '(1(Q Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r tBr s OCT 1 0 26,1)1.-- Other: Spacing Exception Required? Yes ❑ No [1( Subsequent Form Required: /o —40 P APPROVED BY Approved by: p r pp 'cation is vARIYIN m�nths from triAS6 l 0I9r18val. Date: Z 7'�...� Form 10-403(Revise 10/2012) ORIGINAL Submit Forma d Attach ents in Duplicate TO,e VLF9/x4 /13 ,r y` • RECEIVED SEP 172013 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 September 14, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 1J-182, PTD 206-132 surface casing cement shoe. Please call MJ Loveland or Martin Walters at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska,Inc. West Sak Well 1J-182 (PTD 206-132) SUNDRY NOTICE 10-403 REQUEST 09-14-13 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to pump a cement shoe in the surface casing West Sak Packerless ESP Well 1J-182. A surface casing cement shoe was not pumped at the time of original completion in 2006. The cement shoe is required in order to perform a pressure test to confirm production casing and surface casing barriers. With approval, the OA cement shoe will require the following general steps: 1. Pump cement designed for a 1000' linear shoe in the OA. 2. Displace cement with freeze protection fluids 3. Wait 48 hrs on cement 4. MITOA to 1800 psi and/or establish LLR. 5. Submit 10-404 to AOGCC. WI Project Supervisor 9/14/2013 . v.- KUP 1J-182 �' Cjjjjps Well Attributes Max Angle&MD TD Alaska Inc. ? .9.-. Wellbore API/UWI Field Name Well Status Ind(°) MD(ftKB) Act Btm(ftKB) conocovn,IUps ' 500292332100 WEST SAK PROD 95.65 16,968.37 17,844.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date "' SSSV:NONE 0 7/10/2009 Last WO: 7/7/2010 43.51 11/17/2006 Well Confer-1J-162,7/11/20101:07:15 PM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WORKOVER Imosbor 7/11/2010 Casing Strings HANGER,35 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd CONDUCTOR 20 19.250 43.0 120.0 120.0 94.00 K-55 Insulated ! --- Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd ' I E SURFACE 13 3/8 12.415 42.9 3,673.4 2,151.3 68.00 L-80 Buttress Thread Casing Description String 0... String ID...Top(f t(B) Set Depth(L..Set Depth(TVD)...String Wt...String...String Top Tried INTERMEDIATE 95/8 8.835 37.1 9,831.0 3,433.0 40.00 L-80 Buttress Thread i Casing Description String 0... String ID...Top(ftK8) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd , D-SAND WINDOW 95/8 8.000 9,121.0 9,138.2 3,353.8 Casing Description String 0... String ID...Top(11KB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd I '1- B-SAND LINER 4 1/2 4.000 9,224.5 17,839.0 3,360.9 11.60 L-80 Buttress Thread II Liner Details Top Depth CONDUCTOR (TVD) Top Inc! Nomi... Insulated, - Top(ftK8) (RKB) (°) Item Deaeription Comment 170.5(1) 43-120 9,224.5 3,365.4 81.95 PACKER HRD ZXP LINER TOP PACKER 7.500 9,243.1 3,368.0 81.97 NIPPLE 'RS'PACKOFF SEAL NIPPLE 6.190 ESP Mandrel, 9,245.9 3,368.4 81.98 HANGER FLEXLOCK LINER HANGER 6.230 1,976 �...: IF 9,255.7 3,369.8 81.99 XO BUSHING CROSSOVER BUSHING 4.900 III 9,257.1 3,370.0 81.99 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 9,276.8 3,372.7 82.02 XO CROSSOVER 5.5"x 4.5" 3.890 Tubing Strings Tubing Description String 0... String ID...Top(ttKB) Set Depth(f...I Set Depth(TVD).. String Wt...String... String Top Thrd TUBING 41/2 3.958 35.4 8,092.2 i 3,135.0 12.60 L-80 IBTM Completion Details l Top Depth SURFACE. (TVD) Top Incl Nomi... 43-3,673 Top(MB) MB) 11 Item Description Comment ID(in) 35.4 35.4 -0.03 HANGER Vetco Gray 11'5 4-12"Hgr w/4.909"MCA Top Conn.Made 5.700 7,962.3 3,104.0 75.87 DISCHARGE Unique Discharge Sub 3.833 8,038.3 3,122.2 76.36 ESP INTAKE Perforated Xover Intake TTC ESPCP(5.13"OD) 8,049.0 3,125.4 77.05 SEAL Upper Upper Tandem Seal GSB3DB FER HL SSCV H6 SB/SB PFSA 8,055.9 3,126.9 77.04 SEAL Lower Lower Tandem Seal GSB3DB FER HL SSCV H6 SB/SB PFSA DISCHARGE,____ _ 8,062.8 3,128.4 77.02 ESP MOTOR Motor 418 HP KMH(2610 v/98 amp)(5.62'0.0.) 7'962 8,088.2 3,134.1 76.95 SENSOR A-Well I-Pump Sensor(4.375"OD) 8,090.3 3,134.5 76.95 Centralizer Motor Centralizer(5.85"O.D.) 4.500 Perforations&Slc Shot ESP INTAKE_ - Top(TVD) Bier(TVD) Dens 8,038- """-� Top Btm(ftKBI (ftK8) (RKB) Zone Date (sh... Type Comment SEAL Upper _ 9,282 10,018 3,373.4 3,445.0 WS D,WS C, 11/1/2006 32.0 SLOTS ALL PERFS IN WELLBORE: cots { WS B,1J-182 Alternating solid/slotted pipe- SEAL Lower, 8.056 "I`.41 0.125"x2.5"@ 4 circumferential adjacent ESP MOTOR9,06... _ 1 18 deg,3' centers staggered non-slotted ends SENSOR,___ ! 10,020 17,585 3,445.1 3,360.3 WS B,1J-182 11/1/2006 32.0 SLOTS ALL PERFS IN WELLBORE: I Centralizer, J! Alternating solid/slotted pipe- D-SAND adjacent owns,3'circumferential centers staggered WINDOW. 18 deg,3'non-slotted ends D-SAND HH.H, S.118-9,358 17,708 17,794 3,358.7 3,359.3 WS B,1J-182 11/1/2006 32.0 SLOTS ALL PERFS IN WELLBORE: I Alternating solid/slotted pipe- 0.125"02.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non-slotted ends At Notes:General&Safety - to Annotation 11/14/2004/200 6 NOTE:MULTI-LATERAL WELL: 1J-182(B-SAND),1J-182L1(D-SAND) 2/3/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 i I SLOTS. 9282-10,018 I I= NTERMEDIATE, 37-9,831 - 6-1 .„_, M_a_ndrel Details Top Depth Top Port = (TVD) Inc! OD Valve Latch Size TRO Run Stn Top(ftKB) (MB) 1°) Make Model (in) Sere Type Type (in) (psi) Run Date Com... 1 1,975.6 1,700.7 64.70 CAMCO KBMG 1 ESP SOV BEK 0.000 0.0 7/72010 SLOTS. a. r 10,020-17,565 i >m 1 1LI 1 I@ SLOTS, 17,708-17,794 E 1 1 M B-SAND I LINER, 9,22417,639 TD(1J-182), 17,844 STATE OF ALASKA ALASKf~ AND GAS CONSERVATION COMMIS~I REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ~"` Repair w ell Plug Perforations Stimulate (°" Other ~'° Alter Casing ~ Pull Tubing ~' Perforate New Pbol "` Waiver ~ Time Extension '°" Change Approved Program Operat. Shutdow n Perforate ~"°" Re-enter Suspended Well ~"" 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory 206-132 3. Address: Stratigraphic ~°` Service .API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23321-00 7. Property Des~gnation~ ~~ 8. Well Name and NunZber. ~ ADL 25662, 380058 '~'~ ~ ~ ~~d , 1J-182 9. Field/Pool(s): ~ est Sak Oil Pool Kuparuk River Field / 10. Present Well Condition Summary: Total Depth measured 17844 feet Plugs (measured) None true vertical 3361 feet Junk (measured) None Effective Depth measured 17837' feet Packer (measured) .9225 true vertical 3360 feet (true vertucal) 3365 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 121 121' SURFACE 3630 13.375 3673 2151 INTERMEDIATE 9794 9.625 9831 3432 B-SAND LINER 8615 4.5 17839 3361 Perforation depth: Measured depth: 9282'-10018', 10020'-17585', 17708'-17794' True Vertical Depth: 3373'-3445', 3445'-3360', 3359'-3359' A ~ ~ Q ~ 2 ~ ~ U Alaska t'~I ~C Gas Cerua• Omission ....... ~i91G~'iflt3Qe Tubing (size, grade, MD, and TVD) 4.5, L-80, 8092 MD, 3135 TVD ~ ~"' ~ '"-" Packers 8 SSSV (type, MD, and TVD) HRD ZXP liner top packer @ 9225' MD, 3365' TVD no SSSV 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable *.,P,~~~j}°.`~ ,~ (, rr ~,~+Z:.i Treatment descriptions including volumes used and final pressure: 12, Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 580 41 29 -- 201 Subsequent to operation 897 70 17 -- 201 13. Attachments 14. Well Class after proposed work: t Copies of Logs and Surveys run Service Exploratory Developmen 15. Well Status after work: ~ Oil ~' Gas WDSPL ~°` Daily Report of Well Operations XXX GSTOR '~"" WAG ("-" GASINJ ~""` WINJ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Erik Nelson 263-4693 Printed Name Erik Nels Title Wells Engineer Phone: 263-4693 Date~~~ ~~/j ~~ Signature .~' ~ ~ ~~ - RBDMS Ate 0 ~ ~.~- ~- ~ -ro Form 10-404 Revised 7/2009 ~~~1/~~ Submit Original Only -"~~~ KUP ~ 1J-182 ~OEl4)CU~'11{fi~J~ ~ li Well Attributes Max Angle ~ MD T_D ~ s^,1 ~ _ Wellbore APIlU WI _ ,~ 500292332100 . ~ Fieltl Name '.WEST SAK Well Status Intl (°) MD (ftKB) ~'IPROD 95.65 I 16,968.37 Act Btm (ftKB) 17,844.0 C 1 KB-G 43ft j n End D Rig Release Date ~~~ ~ SS _ ONE 009 LdSt WO 7/7/2010 ~ 61 11/17/2006 We9 confg 1J 7p.27ntl2 su,emae Aan .01.07 5'M 0 al P ( ) t9 of De th HKB E dD~e Annotatio (Last MOd .. End Date i Last Ta_ __ Imosbor 7/1 112 01 0 Rev Reason: WORKOVER w Casing 3tnn s ~ HANGER. 35 - - -- 3 ' ing Descnpt~on String 0... String ID ... Top (ftKB) Set D pth (f... Set Depth (ND) ...I String Wt... String .. IString Top Thrd I CONDUC I OR 20 ~, 19 250 43.0 120.0 120.0 94.00 K 55 - --~~' I lnsulatetl I ~ - - - - - - - - - - -' - - - -- - . `n - - - - - - - - 1 Casing Description String 0... String ID . .. Top (ftKB) Set Depth (F... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 13 3/8 12 415 42.9 3,673 4 2,151.3 68.00 L-80 Bunress Thread ;,~ ~~ Casing Description String O... ,String lD . .. Top (ftKe) Set Depth (f... SetDepth(ND).. String Wt... String... String Top Thrd "s '~ IN I ERMEDIATE ~ 9 5/8 8.835 37-1 9,831.0 3 433 0 40.00 L-80 Bunress Thread Casing Descr ption ,String 0... I String ID -. Top (ftKB) Set Depth (f... Set Depth (ND) .. String Wt... String ... String Top Thrd D-SAND WINDOW 95/8 8.000 9,121.0 9,1382 3,353.8 ~;' Casing Description 'String O._ '' String ID . .. Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String .. String Top Thrd &SAND LINER i 4 1/2 ~ 41700 9,224.5 17,839.0 3,360 9 11 60 L-80 Buttress T hread ' I Liner Details - '. Top Depth CONDUCTOR ' (TVD) Top Intl Nomi... Inwlatxd, TOp (ftKB) (ftKB) (") Item Descnpt ion Comment ID (in) a3-1zo 9,224.5 3,365.4 81.95',PACKER FIRD ZXP LINER TOP PACKER 7.50C ESP Marnlrxl, _ 1,976 BUSHING x .... ...... ... __...a ...... __...a ... ....a ._~. 135.0 II 12.60 L-80 IBTM SURFACE, _. 43-3,6]3 DISCHARGE, ].562 ESP INTAKE, 8,038 SEAL UPPxr, _ . ___ B.W9 SEAL Lower, 8,056 ESP MOTOR,- - ___ 6,063 SENSOR,- _ __ 6,088 Centralizeq- - 8,090 D-SAND WINDOW.- 9,121~9.138 D-SAND HH, 9,118-9,358 - SLOTS, _ _ _. _ _ 9,282-10,018 ' PI ERMEDLITE, ~~` 3]-9.631 I ' y sLOrs, - 10,020-17.585 ~.` I +_ __I l~ SLOTS, "!' 17]08-1]194 ..41 (,~"` D-SAND LINER, 9,224-1],639 TD (1 J-182). 1],844 3ER '. vetco Gray 11 "x 4-112" Hgr w/ 4.909" A ~HARGE '',Unique Discharge Sub INTAKE ,Perforated Xover Intake TTC ESPCP (. _ Upper ~U pper Tantlem Seal GS63U6 FER HL _ Lower Lower Tandem Seal GS63D6 FER HL MOTOR Motor 418 HP KMH (2610 v / 98 amp) i SOR A-Well I-Pump Sensor (4.375" OD) 8,090.3 3,134.5 ' Top (TVD) Btm (TVD) uens Top (ftKB) Btm (ftKB( (kKB) (ftKB) Zone Date ish"' Type Comment 9,282 10,018 3,373.4 3,446.01, WS D, WS C, 71/1/2006 32.0 SLOTS ALL PERFS IN WELLBORE: ~'~ WS B, 1J-182 Alternating solid/slotted pipe - ' ~ 0.125"x2.5" @ 4 circumferential ~i adjacent rows. 3" centers staggered 18 deg, 3' non-slotted entls ----. - --__ t I _ - 10,020 17,585 3,445.1 3,360.3 WS B, 1J-182 111/112006 32.0 SLOTS 'ALL PERFS IN WELLBORE: 'Alternating solid/slotted pipe - ~0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non slotted ends 17,708 17,794 3,358.7 3,359.3 WS B, 1J-182 11/1/2006 32.0 SLOTS ALL PERFS IN WELLBORE: Alternating solid/slotted pipe - 0.125"x2.5 @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends Notes: General & Safety _ _ __ End Date _ Annotation ~_ 1 111 4120 06 NOTE: MULTI-LAT ERAL WELL 1J-182 (B-SAND). 1J-182L1 (D-SAND) 2,'3/2009 NOTE: VIEW SCI IEMA HC w/Alaska Schernatic9-0 Mandrel Details Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run Top.(ftK6) (ttK6) (') Make Model I (in) Serv TYPe TYPe (ini (psi) 1 1,975.6 1,700.7 64.70 CAMCO~.KBMG 1 ESP SOV BEK 0 OOOi 0 0 1J-182 Pre and Post Rig. Summary DATE SUMMARY 4/22/10 REPLACED 2000 PSI SHEAR VAL~@ 2036' RKB. READY FOR CTU. 4/25/10 CLEAN OUT THICK CRUDE TO TOP OF SLIP STOP @ 7992' CTMD W/SLICK DIESEL & DIESEL GEL. NO SOILDS NOTICED IN RETURNS, IN PROGRESS. 4/26/10 PULL 4.5" SLIP STOP & PACK OFF @ 7992' CTMD. IN PROGRESS. 4/27/10 PULLED 48.65' FC 600 ESP FROM 8011 CTMD, WASHED PUMP WITH 50 BBLS DIESEL DOWN BACKSIDE, SET IN DEPLOYMENT FLANGE IN TREE. READY FOR S/L. 5/4/10 PULLED 48', 4-1/2 TTCESP PUMP IN DEPLOYMENT SUB IN TREE, SHOOK OFF NEW 47.88' OAL 4-1/2 TTCESP IN TBG @ 860' SLM, RDMO. READY FOR COIL. 5/5/10 INSTALLED 4-1/2 TTC ESP @ 8806 CTMD, RAN PACKOFF ASSEMBLY & SLIP STOP ON TOP OF PUMP. READY FOR S/L TO REPLACE SOV. 5/7/10 PULLED SOV @ 2036' RKB, " IT WAS NOT SHEARED", SET NEW 2000# SOV @ 2036' RKB, COMPLETE. 5/14/10 PULLED 4.5" SLIP STOP @ 7992' CTMD. PULLED 4.5" PACK OFF @ 7995' CTMD. NOTE: PULLED W/OUT JARRING, ELEMENT WAS NOT SET. JOB IN PROGRESS. 5/15/10 SET 4.5" PACK OFF (W/ 4' EXT PUP, DETAILS ABOVE) @ 8004' CTMD. PT TO 440 PSI, GOOD. SET 4.5" SLIP STOP ON PACK OFF @ 7991' CTMD. WELL STILL DIESEL PACKED. JOB COMPLETE. 6/20/10 PERFORM PASSING WEEKLY BOP TEST. TAG SLIP STOP @ 7991' CTMD, NO FILL APPARENT. WASH HEAVY CRUDE OUT OF TBG W/SLICK DIESEL & DIESEL GEL. IN PROGRESS. 6/21/10 PULL 4.5" SLIP STOP @ 7992' CTMD. PULL 4.5" PACKOFF @ 7996' CTMD. IN PROGRESS. 6/22/10 PULLED 48.65' TTC ESP FROM 8003 CTMD, SET IN DEPLOYMENT FLANGE IN TREE. READY FOR S/L. 6/25/10 PULLED 48' x 4-1/2" TTCESP f/ DEPLOYMENT FLANGE. SET CATCHER. PULLED SOV @ 2036' RKB. SET DV ~ SAME. PULLED CATCHER. COMPLETE. 7/1/10 PRE RWO T-POT BONNET( FAILED), T-PPPOT BONNET (PASSED ), T-POT UPPER BODY PASSED ), T-PPPOT UPPER BODY.( PASSED ), T-POT LOWER BODY (PASSED ), T-PPPOT LOWER BODY (PASSED ), IC POTS PASSED, FT-LDS ALL NORMAL. 7/5/10 FISHED ~6' x 3' PIECE OF ABSORB @ 798' SLM. SET 4.5" ESP PUMP (OAL= 52') @ 312' SLM. SET D&D PACKOFF @ 260' SLM (TOP @ 252' SLM/ OAL= 8' 4"). TESTED PACKOFF TO 1000#. ***PASS***. SET 4.5" TBG STOP @ 252' SLM. JOB COMPLETE. 7/6/10 ""RIG JOB "", CHANGE OUT SV FROM IA X TUBING, TO 2000# TUBING X IA SV n ~~ ConocoPhillps Time Log & Summary We/fview YYe6 Reporiirtg Report Well Name: 1J-182 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 7/3/2010 2:30:00 PM Rig Release: 7/7/2010 8:00:00 AM Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 7/02/2010 24 hr Summary Completed 36-14 Well. RDMO. Begin Rig move to next Location. 16:30 00:00 7.50 MIRU MOVE MOB P Start moving rig from 3B pad toward 1 J ad. 7/03/2010 Continue moving Rig to 1 J-Pad. MIRU. Rig up Lines. Pull BPV. Bullhead kill Well. 00:00 13:30 13.50 MIRU MOVE MOB P Continue moving Rig to 1J-Pad. Moving slower because DTH short handed and movin ri mats slow. 13:30 14:00 0.50 MIRU RPCOM RURD P Spot rig on double mats. Rig up containment (Handy Berm). Acccepted Nordic 3 rig @ 1400 hrs. 7-3-2010 14:00 18:30 4.50 MIRU RPCOM RURD P Set kill tank and hook up hard line. Set cuttings box and berm up containment. LRS heating fluids and loading pits with 160° SW w/6% KCL. Pull 4" Type H BPV. TP = 300 psi, IAP = 300 psi, OA = 100 si. 18:30 20:00 1.50 COMPZ RPCOM KLWL P Rig up Lines in Celler. Pressure test lines at 250/2,500 psi. Good. Continue to off-load fluids in Ri Pits. 20:00 22:00 2.00 COMPZ RPCOM KLWL T Waiting for third Vac Truck to arrive on location with remaining hot Sea Water. 22:00 00:00 2.00 COMPZ RPCOM CIRC P PJSM. Bullhead 125 bbls down the Tubing at 4.0 bpm/80 psi. Then Bullhead down the IA at 7.0 bpm/500 si. 7/04/2010 ND Tree. NU BOPE. Test BOPE. Begin to POOH with 4 1/2" ESP Completion. 00:00 02:00 2.00 COMPZ RPCOM CIRC P Finish Bullhead killin IA. Monitor Well. However, had some gas at surface in tubing and then some on the IA. Shut in Well. Tbg = 120 psi IA = 220 psi. Line up to pump down the Tubing and route IA gas through the Choke to the Tiger Tank. Pump down the Tubing at 4.0 bpm/70 psi. Gas bled down to "0" psi in just a couple of minutes. Continue to pump a Tubing volume (125 bbls). Monitor Well. Both sides on a vacuum. 02:00 03:30 1.50 COMPZ RPCOM NUND P Set BPV. Nipple down Tree. Inspect top Hanger Threads. Good. Set Blanking Plug. Function all LDS. Page 1 of 4 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:30 07:30 4.00 COMPZ RPCOM NUND P Nipple up BOPE. 07:30 12:00 4.50 COMPZ WELCTL BOPE P Function & Pressure Test ROPE and choke 250!2500 psi. Test good. the Stare's right to witness the test was waived b J. Jones. 12:00 14:00 2.00 COMPZ RPCOM NUND P Pull blanking plug, pull BPV. Pumped 100 bbls down tubing 7 BPM @ 90 psi, 100 bbls down IA 7 BPM 260 si 14:00 17:00 3.00 8,099 COMPZ RPCOM NUND P BOLDS. Unset tubing hanger with 200K. Pulled hanger to rig floor at 115K. Well on slight vacumm. Remove Penetrator. LD tubing han er, strin flat cable over sheave. 17:00 00:00 7.00 800 COMPZ RPCOM PULL P POOH with ESP Completion, standing back 4 1/2" tubing, removing cannon clamps and s oolin u flat cable. 7/05/2010 Complete POOH with 4 1/2" Completion. Pick up and service new ESP Completion Assembly. RIH with new 4 1/2" Com letion. 00:00 02:00 2.00 800 63 COMPZ RPCOM PULL P Finish POOH with 4 1/2" ESP Completion. Pull ESP Cable over Sheave. Wrap ESP Cable Reel and prep for crane lift. Recovered 231 Cannon clamps, 3 Protectors, 2 ea 6-ft Flat Guard. Recovered 5 SS Bands. Lost 7 in the hole. The entire Tubing String looked good. Pull samples off of ESP sections. Initial findings. Water in Motor. Burnt Oil. 02:00 04:00 2.00 63 0 COMPZ RPEOPI PULD P PJSM. Spot crane and pick used ESP Cable/Reel off of Rig floor. Lift new ESP Cable and set on Ri floor. 04:00 05:30 1.50 0 COMPZ RPCOM PULD P Continue breaking down and lay down ESP sections. Take oil sam les, LD & BD ESP. 05:30 07:30 2.00 COMPZ RPCOM PULD P Clean rig floor. Box up ESP equip. and move out of i e shed. 07:30 11:00 3.50 COMPZ RPCOM RCST P PJSM. PU& service motot section and PU motor. Centrilift Tech. using absorb for hole cover around split table. When lowering motor in hole pulled absorb downhole and absorb dropped down hole. Pulled motor section back out and stand back out of wa . 11:00 13:00 2.00 COMPZ RPCOM FISH T PJSM with slickline crew. RU slickline and RIH w/4 prong wire grab with 6" OD. Grabbed fish (absorb) @ 750' and POOH. Recovered all of absorb. RD slickline. Page 2 of 4 r~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 13:00 15:00 2.00 COMPZ RPCOM RCST P PJSM. PU motor centralizer, A-well I-pump Sensor, and motor and place assembly in hole. Record breakaway & rotational shaft torque of the motor. PU the tandem seal section, check and record it's breakaway and rotational shaft torque. Assemble seal section to motor. Service the seal section and then check & record the shaft torque values of the entire assembl . 15:00 15:30 0.50 0 355 COMPZ RPCOM RCST P MU the first 2 jts of the 4 1/2" tbg to the handling pup. Install a Cannon cross-coupling cable clamp. Install the Unique discharge pressure sub and connect the discharge pressure capillary tubing and test. Continue RIH w/the ESP com letion to 335'. 15:30 19:30 4.00 355 355 COMPZ RPCOM RCST P PJSM. RU HES Slickline. RIH w/ESP pump w/gas separator. Set pump. Set packoff on top of pump and PT to 1000 psi. for 15 min. Set sli sto and RDMO HES slickline. 19:30 00:00 4.50 355 3,700 COMP2 RPCOM RCST P Continue RIH with ESP Assembly on 4 1/2" Tubing. Install Cannon Clamps. Perform electrical checks eve 1,000-ft. 7/06/2010 Complete R~I-I with 4 1/2" ESP Completion. ND BOPE. NU Tree and test. RU S-line. 00:00 04:30 4.50 3,700 7,500 COMPZ RPCOM RCST P Continue RIH ESP Assembly on 4 1/2" Tubing from 3,700-ft. Pick-up Camco 4 1/2" x 1" KBMG w/DCK-2 Shear Valve. Continue with 4 1/2" Tubing. Stop to splice in additional ESP Cable. 04:30 05:30 1.00 7,500 7,500 COMPZ RPCOM RCST P PJSM. Spot Crane. Prep to swap out ESP Reels. Pull empty ESP Reel off of floor. Pick-up Reel with additional ESP Cable a set in S ooler on Ri floor. 05:30 09:00 3.50 7,500 7,500 COMPZ RPCOM OTHR P Splice in additional length of ESP Cable and test - ood. 09:00 09:30 0.50 8,057 8,057 COMPZ RPCOM TRIP P RIH f/ 7,500' to 8,057' 09:30 10:00 0.50 8,057 8,057 COMPZ RPCOM OTHR P PU and MU hanger -prep for final s lice. 10:00 12:00 2.00 8,057 8,057 COMPZ RPCOM OTHR P Make final splice and connect to penetrators. Surface test guages (PI- 978 psig, DP - 1,002 psig, IT - 60.1degrees) and ESP cable (P\P - 2.6, P\Grd - 1.0 thru enatrators. Page 3 of 4 " ~ • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:00 13:30 1.50 8,057 8,092 COMPZ RPCOM HOSO P Land hanger (115k up wt / 52k do wt) w/ tail @ 8,092', RILDS, and test upper and lower pack offs - 250/5,000 psig for 10 minutes. 230 - 4.5" X-cplg clamps 6 - SS Bands 3 - Protectrolizers 1 - 5.13" x 4 .5" X-cplg clamp 4 - 5.13" Cannon clam 13:30 14:00 0.50 8,092 36 COMPZ WELCTL MPSP P Back out landing jt and install BPV 14:00 16:00 2.00 36 0 COMPZ WELCTI NUND P Change UPR's f/ 4.5" to 3.5", ND ROPE - Test guages and ESP cable - ood test 16:00 18:00 2.00 0 0 COMPZ WELCTL NUND P Set test plug and NU Tree - 4.063" 5M Horizontal Producer. Test void @ 5,000 psi and Test tree @ 250/5,000 si. Good test. 18:00 18:45 0.75 0 COMPZ WELCTt MPSP P Lubricate out TWC. Lay down same. 18:45 00:00 5.25 COMPZ RPEQPI SLKL T PJSM. Rig up HES Slick Llne Unit. RIH with Catcher Sub. Had problems setting Catcher Sub. RIH and pull DCK-2 Shear Valve from GLM at 1.975-ft. 7/07/2010 Ru S-Line and pull SOV. Lil' Red Freeze Protect Well. S-Line set SOV. 00:00 00:30 0.50 COMPZ RPEQPI T Recovered DCK-2 Valve from GLM at 1,975-ft. S-Line stand-b . 00:30 03:00 2.50 COMPZ RPCOM FRZP P PJSM to Freeze Protect Well. Lil' Red Pump down the Tubing with Diesel at 2.0 bpm/400 psi. Total Diesel pumped 215 bbls. RD Hot Oil Unit. 03:00 06:00 3.00 COMPZ RPEQPI SLKL T S-Line RIH and attempt to set SOV back in GLM at 1,975-ft. Having troubles locating pocket. Set SOV. PUII Catcher Sub. Ri down S-line. 06:00 07:00 1.00 COMPZ WELCTt MPSP P Set BPV and dress tree 07:00 07:30 0.50 COMPZ MOVE RURD P Move rig off well 07:30 08:00 0.50 COMPZ MOVE OTHR P Clean up well area and move matting. Sign off well to Production. Nordic Rig 3 released @ 08:00 hrs on 7-7-10. Page 4 of4 • .~ ; .a ~ ~ ~ .. ~ ._. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, June 28, 2010 1:28 PM To: 'NSK Well Integrity Proj ;Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: RE: 1 J-182 (PTD 206-132) Report of failed ESP motor Page 1 of 2 MJ, As per our conversation conversion to GL doesn't need a 403 sundry for this ESP producer. This well has an OA that can be monitored (although it has an open shoe). You also stated the RWO was scheduled in less than a month. Please submit a 10-404 after conversion to gas lift. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) _ __.. __ From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Saturday, June 26, 2010 7:50 AM To: Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: RE: 1J-182 (PTD 206-132) Report of failed ESP motor Tom/Jim/Guy, We are still waiting for word whether we need a 10-403 to gas lift this failed ESP well. As stated previously a 10- 404 was all that was required for similar prior wells. However, since many other requirements have recently changed we want to ensure we have the proper approvals before bringing this well online on gas lift. It is currently SI waiting for approval. Please Advise. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 i Well Supv 15, 2010 10:48 AM L (DOA); 'Maunder, Thomas E (DOA)'; Regg, James B (DOA) Jell Supv (PTD 206-132) Report of failed ESP motor Guy, Tom, Jim West Sak ESP producer 1 J-182 (PTD 206-132) was reported to have a failed ESP motor due to a downhole short. The repair will require a RWO. It is ConocoPhillips intention to produce the well with gas lift while awaiting a RWO. Does a 10-403 need to be submitted or is a 10-404 sufficient? In the recent past, a 10-404 for change in 6/28/2010 . Page 2 of 2 lift service has been acceptable. Please let us know which paperwork needs to be filed. Attached is a 90 day TIO plot and a schematic. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 « File: 1J-182 schematic.pdf» « File: 1J-182 90 day TIO plot.jpg » 6/28/2010 Regg, James B (DOA) • Page 1 of 1 ~(~°i3~ From: NSK Problem Well Supv [n1617@conocophillips.com] ~ ` ~~~~`~~ Sent: Tuesday, June 15, 2010 10:48 AM ~ t To: Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 1 J-182 (PTD 206-132) Report of failed ESP motor Attachments: 1J-182 schematic.pdf Guy, Tom, Jim West Sak ESP producer 1J-182 (PTD 206-132) was reported to have a failed ESP motor due to a downhole short. The repair will require a RWO. It is ConocoPhillips intention to produce the well with aas lift while awaiting a RWO. oes~403 need to be submitted or is a 10-404 sufficient? In the recent past, a 10-404 for change in lift service has been acceptable. Please let us know which paperwork needs to be filed. Attached is a 90 day TIO plot and a schematic. '~ Brent Rogers/Martin Walters Problem Welfs Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 .~k:?'~~.~% .~:U~~ '.; top 2(~?~ 7/20/2010 KRU 1 J-182 PTD 2061320 6/15/2010 TIO Pressures Plot TIIIO Plot -1J-182 350 300 250 _ 200 N a 150 100 50 0 y ~ -~ ~ l ~,+ ~ + ~~ ~~ ti~ ~ ... i.... ....... ...I .................. ... .... ....~ ......... _.._ , .. ( ', ',, ~ , ,~ ~ I~~ ~~ ,i ~ ,7 ~~~ _ ---~_ ~°+- -, 01-Apr-10 01-May-10 Date 01-Jun-10 200 150 a E as 100 Y O t V 50 0 ,~ ~~ ,~ KUP +~ 1J_-182 ~ 1 ~OI"fOCO~~"II~~I~S `~ ell Attributes _. .Max Angle & MD TD ~'. ~ Wellborc APllUWI Fieltl Nam __._ - e __ _ Well S __ tatue Inel (`) MD (ttKB} :.ct Btm (ttKB) ` ~ ~ ~ ~ 500292332100 WEST SAK PROD 95.65 16,968.37 17,844.0 _ C mmeM H251ppm) Date Anhotation End Date KB13rtl (ft) Rig Release Date SSSV NONE 0 12/26/2007 Last WO: 43.51 11/17/2006 _ wenw ea 1J 1ezs1 noioeg53z nM ~ y tre, ai'~c n I i A ~ , Depth (ttKB) End Dete Mnotation last Mod ... Entl Date _ _ _ ~!Lasl ~.i - _ Rev Reason: RESETPUMPASSEMBLY Imosbor 5/1_6/2010 Casing Stnngs _ - - _ - -- , , ,_. _ _ oasng Oescnption 'String 0.. . String ID ... Top (ttKB) ~ Set Depth (f... Set D pth (TVD) .. String Wt... St i g .. . String Top Thrd HANGER, 35 _ , ,, ,"„"5.. CONDUCTOR 20 19.250 0.0 120.0 120.0 94.00 K 55 ~-----~ ~ Insulated Casing Description String 0.. . String ID ... Top (ttKB) Set Depth (f... Set Depth (ND) ... String Wt_. String .. . String Top Thrd E-. I ~ SURFACE 13 3/8 12.415 42.9 3,673.4 2,151.3 68.00 L-80 Buttress Thread ''s (` ~` - Casing Description String 0.. . String ID ... Top (ttKB) Set Depth If... Set Depth (ND) ... String Wt... String .. . String Top Thrtl INTERMEDIATE 95/8 8.835 37.1 9,831.0 3,433.0 40.00 L-80 Buttress Thread Casing Description String 0.. . String ID ... Top (ttKB) Set Depth If... Set Depth (ND) ... String Wt... String .. . String Top Thrd ` D-SAND WINDOW 95/8 8.000 9,121.0 9,138.2 3,353.8 ' _; Casing Descriphon String 0.. . String ID ... Top (ttKB) Set Depth (f... Set Depth (ND) ... String Wt... String .. . String Top Thrtl ~- B-SAND LINER -~ -~_- 4 1/2 4.000 9.224.5 17.839.0 _ _ 3,360.9 11.60 -- L-80 Buttress Thread -~ - - - Liner Details ~ ~ - --- CONDUCTOR Insulated, 0.120 ~ op (ttKB) Top Depth (ND) (ftK8) op Inel (^) m cnoN te pe on Comment I NpmL.. ID In ( ) - ~ 9,224.5 3,365.4 81.9! EsP MANDREL, ~ -~) 9,243.1 3,368.0 81.9 z,o3s -• - - 9,245.9 3,368.4 81.9! -~ - 9,255.7 3,369.8 81.9! 9,257.1 3,370.0 81.9! 9,276.8 3,372.7 82.0: Tubing Strings _ ~ ~, Tubing Descr pt on ~., St g O.. Str ng ID ... rTop (ftK8) Set Depth (f.-. Set Depth (ND) .. String Wt... St ng .. Stri 1g Top Thrtl r, ~ TUBING i 11/2 ~'I 3958 351 80991 ~ 31365 ~ 12.60 ~ L80~ _ SURFACE, ~ Completion Details ... - -T _ - _. -- --_ 43-3,673 • Top Depth F ~ (ND) Top Incl Nomi... Too IttK81 (ttKB) (°) Item Description Comment ID (in) 7.%1 SLIPSTOP, 7,990 PACKOFF, -7,991 PUMP, 9,004 INTAKE, 8,037 SEAL, 9,047 SEAL. 8.054 MOTOR, B,O6t GAUGE, 8.095 9,11 SLOTS, 9,28210,018 8,094.8 3,135.6 76.94 GAUGE A-Well Pump Sensor 8,096.9 3,136.0 76.93 CENTRALIZER MOTOR CENTRALIZER 4.000 Other In Hole (Wireline retrievable plugs valves, pumps, fish, etc ~ m _ I.--T _.__ ". _ .__ _." T p D p[h (ND) lop Incl Too ITtKBI IRKBI (°) Descnption Comment _ Run Date ID (in) Perfora tions & Slots Shot Top (ND) Btm (ND) Dens Top (ttKB) Btm (ttKB) (ftK8) (RKB) Zona Date Ich... Type Comment 9,282 10,018 3,373.4 3,445.0 WS D, WS C, 11/1/2006 32.0 SLOTS ALL PERFS IN WELLBORE: WS B, 1J-182 Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 10,020 17,585 3,445.1 3,360.3 WS B, 1J-182 11/1/2006 32.0 SLOTS ALL PERFS IN WELLBORE: Alternating solid/slotted pipe- 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 17,708 17,794 3,358.7 3,359.3 WS B, 1J-182 11/1/2006 32.0 SLOTS ALL PERFS IN WELLBORE: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-sloped ends i" `{~~yl i ~'.7 f ~ I Notes: General & Safety rel Details -~-- - - -T- - .- Top Depth Top Port (ND) Incl OD Valve Latch Size 7R0 RUn IttKg1 (ttKB) I (°) Make I Model (in) I Serv TYPe Type IIN (psi) Run Date Com... I ( i I SLOTS, 10,020.17,585 ~ I 'F 7 8 ,- sLOrs, - 17.70&17.794 1 ! B-SAND LINER 9,22417,939 TD I1 J-182), 17,844 ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 12, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: ®6J 4c~M F ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRil). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped February 9`" & 10~', 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. • RE~~' V GD FEB 1 6 2010 Alaska 0~ ~ bas ~~• Cumrnisson Anchorage ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date Pad 1 H 1 J& 1 R Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ff al 1 H-15 50029223280000 1930030 23" n/a 23" n/a 4.2 2/9/2010 1 H-16 50029223150000 1921310 25" n/a 25" n/a 4.8 2/9/2010 1 H-19 50029223120000 1921280 22" n/a 22" n/a 4 2/10/2010 1 H-20 50029223130000 1921290 25" n/a 25" n/a 4.6 2/10/2010 1H-22 50029223640000 1930600 22" n/a 22" n/a 4.2 2/9/2010 1H-105 50029207270100 2042280 3" n/a 3" n/a 3.4 2/9/2010 1 J-180 50029233290000 2061500 18" n/a 18" n/a 3.8 2/9/2010 1J-182 50029233210000 2061320 17.5" n/a 17.5" n/a 3.8 2/9/2010 1 R-21 50029222110000 1911130 24" n/a 24" n/a 4.6 2/9/2010 17 /~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 10/13/2008 Permit to Drill 2061320 Well Name/No. KUPARUK RIV U WSAK 1J-182 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23321-00-00 MD 17844 TVD 3361 Completion Date 11/17/2006 Completion Status 1-OIL REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments ED D Asc Directional Survey Rpt 14517 /LIS Verification QED C Lis 14517 Induction/Resistivity ~I-~D C 1590 nduction/Resistivity Well Cores/Samples Information: Current Status 1-OIL UIC N 0 17844 Open 1/29/2007 3638 17844 Open 3/16/2007 LIS Veri, GR, FET, ROP 3638 17844 Open 3/16/2007 LIS Veri, GR, FET, ROP 120 3361 Open 2/6/2008 MD and TVD of EWR and DGR in PDF, EMF and CGM graphics 31-Oct-2006 Directional Survey Yes Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? ~~/ N `~~ ( Y// N Chips Received? '4'7'h}' Formation Tops ~v L~~ Analysis -~1.Pd~ Received? Comments: Compliance Reviewed By: Date: WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1 J-182+L 1 +L 1 PB 1 AK-MW-4665704 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-182+L1+L1PB1: Digital Log Images 50-029-23321-00,60,70 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. An~5$:=. Date: ~ r,~ n ~ 7n~~ ~~ -; 3a ; S 9v a Y ' Sued: ~0~-~33 ~s`Sv3 p3 r r 5`~0~/ WELL LOG TRANSMITTAL • To: State of Alaska February 09, 2007 Alaska 0i1 and Gas Conservation Comm. Attn.: Librarian 333 West 7r" Avenue, Suite 100 Anchorage, Alaska RE: M`VD Formation Evaluation Data: 1J-182, L1 PB1 & L1, AK-MW-4665704 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23321-00, 70 & 60 '~1 I I~~ =[.~' 1 • ~ ~""`._ ~-_ PLEASE ACK1vOWZEDGE RECEIPT BY SIGNING Ai11D RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~ ~ .: ~, 5j Date: ;~, '~ a"~ ~ j~~ ~ f (~ ~ ' i1 ~ : -, ~66 u•(~~ ~ a ~: - :-, is \ 4~G.t ~Y4~ _ (~t" r ~ ~~ L_IIUT/ ~~ Signed:' 1~` ~" JGL ~ ~ '`-'' :' ~ ~' ~?U~ ~r~3 i~-rS~~ RE: i J-182 407 Subject: RE: 1J-182 407 From: "Allsup-Drake, Sharon K" <Sharon.K.Allsup-Drake@conocophiilips.com> Date: Thu, Ol Mar 2007 09:32:10 -0900 To: Thomas Ntaundcr ~~~ totr~ toaunder(cr~admin.sEate.ak.us> .,~ ~. ~- ~ ~ ~- Tom - _._-.._...... ~~ ~....., that test might have been bad. Amore recent test, date 2/20/07 shows oil =958, water=39 and gas =1184, Flow tubing pressure = 195, choke is 100% and test length is 7 hours, 20 minutes. Thanks, Sharon office phone: 263-4612 !, fax: 265-6224 ~.`~ ~`SV ~® ~`~~ ~rj~ ~ ~~~ ~(~~ -----Original Message----- ~~~ From: Thomas Maunder [railto :tom maunder~~~ad?tiin.stat.e.ak.us] Sent: Wednesday, February 28, 2007 2:04 PM To: Allsup-Drake, Sharon K Subject: Re: 1J-182 407 Thanks Sharon. I will make the changes. No need to send a new form. On the operations report, I don't know if you have the ability to select a specific hour or just the day. Having a little overlap in time is not a problem. This will still get rid of a lot of sheets. Only other issue (not a biggy) is about the reported flow rates. I still can't make heads or tails of the numbers. They don't relate mathematically. Tom Allsup-Drake, Sharon K wrote, On 2/28/2007 1:54 PM: I Tom - ', I'm sending you a new 'B' sand liner detail sheet which is attached to this email. The answer to your second question about the ', sx or bbls for the 9-5/8" cement volume is it should be BBLS. Do you '; want me to send over a corrected version of the completion report or do '; you just want to scratch off the sx and put bbls on your copy? As to your third question - yes, it sounds great. I don't want to make any more copies than necessary, so I will print out only what pertains to the laterals on subsequent completion reports. Does this answer all your questions about 1J-182? Thanks, Sharon office phone: 263-4612 fax: 265-6224 -----Original Message----- From: Thomas Maunder [mailt~o:tom rlaunder:~admin.si:ate.ak.us Sent: Thursday, February 22, 2007 12:41 PM To: Allsup-Drake, Sharon K Subject: Re: 1J-182 407 Sharon, ', I am further reviewing the 407 for this well. Were you able to 1 of 3 3/2/2007 9:35 AM Re: 1 J-182 407 Subject: Re: 1 J-182 407 From: Thomas Maunder <toin_maunder@admin.state.ak.us> Date: Thu, 22 Feb 2007 12:41:08 -0900 ~ ~ (~ ~-- ~ ~ ~ To: "Allsup-Drake, Sharon K" <Sh~iron.h_~Ilsup-Drake~'e~~nocophilli]~s.conr> Sharon, I am further reviewing the 407 for this well. Were you able to reconcile the production numbers from my earlier note? I don't find a reply. As I noted, the math doesn't work just switching the numbers. 1. Could you send a copy of the B sand slotted liner detail. The copy we have is offset and looks like 2 pages were copied together. I looked closer at this sheet and the L1 lateral and I can see what was intended, however "clean" sheets would be appreciated. If it takes 2, it takes 2. Not sure what latitude you have on sizing. 2. On the 9-5/8" cement volume. On the 407 sheet it says 267 sx. In the report (page30) it says 266.7 bbls. According to the plan, 610 sx @ 2.25 ft3/sx or -245 bbls was planned. would you confirm the cement volume? 3. With these laterals a lot of pages are needed to cover the rig operations. In order to save some trees, Steve Davies and I feel it is acceptable to provide the full summary for the motherbore and then only the work done in the actual laterals for the lateral 407s. In this case I see the "break" as being on page 46 where the window milling begins. It is also acceptable to consider "starting" the lateral summary when the whipstock is picked up. It would make for 45 or so less pages to submit. Will that work for you? Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 1/30/2007 1:48 PM: Sharon, I wondered about that too, but if you multiply the smaller numbers by 24 / 22.5 ', you don't get the higher numbers. Tom Allsup-Drake, Sharon K wrote, On 1/30/2007 10:13 AM: Tom - you are correct. The test period rate is reversed with the 24 hour rate. Do you want me to send a revised first page? Thanks, Sharon office phone: 263-4612 fax: 265-6224 ', ' -----Original Message----- ', From: Thomas Maunder [mailto:tom maunders?admin.state.ak.us] Sent: Tuesday, January 30, 2007 10:03 AM ', To: Allsup-Drake, Sharon K ', Subject: 1J-182 407 ', ' Sharon, We are reviewing the completion reports for -182 and 182L1. Where the production rate date is reported, the 24 hour rate is less than the 22.5 hour tested rate. Could you confirm what rates should be there? Thanks, ', Tom Maunder, PE AOGCC 1 of 2 3/2/2007 9:38 AM ConocoPhillips January 15, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1J-182 and 1J-182L1 Dear Commissioner: Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 :1~~ ,~fa,~~~ ~du ~? , n ,. ~ r ~s~tr:r,Q ~r ~,, .rJ, ~ ~ .7 ~_. ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak wells 1 J-182 and 1 J-182L1. If you have any questions regarding this matter, please contact me at 265-6830 or David Nugent at 265-6862. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ~~~~ . c f~-5 STATE OF ALASKA ~~?~ _~ ~ f ~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REP(~I~F~- ~O~t~fnission 1a. Well Status: Oil O Gas Plugged Abandoned ^ Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Clas . s Development ^ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: November 17, 2006 12. Permit to Drill Number: 206-132 ! 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: October 7, 2006 13. API Number: 50-029-23321-00 4a. Location of Well (Governmental Section): Surface: 1570' FSL, 2434' FEL, Sec. 35, T11 N, R10E, UM ~ 7. Date TD Reached: October 28, 2006 ~ 14. Well Name and Number: 1J-182 • At Top Productive Horizon: 1207' FNL, 1053' FWL, Sec. 11, T10N, R10E, UM 8. KB Elevation (ft): 40' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 1269' FSL, 1165' FWL, Sec. 14, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): 17837' MD / 3360' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558780 y- 5945382 ~ Zone- 4 10. Total Depth (MD + TVD): • 17844' MD / 3361' TVD 16. Property Designation: ADL 25662, 380058 TPI: x- 557057 y- 5937313 Zone- 4 Total Depth: x- 557241 - - 5929231 ~ Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 2177, 4604 18. Directional Survey: Yes ^~ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 3670' MD 2i. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 62.6# H-40 40' 121' 40' 121' 42" 380 sx AS 1 13.375" 68# L-80 40' 3673' 40' 2151' 16" 720 sx ArcticSet Lite, 185 sx LiteCRETE 9-5/8" 40# L-80 40' 9831' 40' 3432' 12.25" sx LiteCRETE ~j(,1 4.5" 11.6# L-80 9224' 17839' 3365' 3361' 6.75" slotted liner 23. Pertorations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 8099' 9224' slotted liner from 17794'-17707', 17584'-10019', 10018'-9281' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production December 21, 2006 Method of Operation (Flowing, gas lift, etc.) ESP Lift Oil producer -shares production with 1J-182L1 Date of Test 1 /4/2007 Hours Tested 22.5 hours Production for Test Period --> OIL-BBL 1546 GAS-MCF 1067 WATER-BBL 48 CHOKE SIZE 31 % GAS-OIL RATIO 690 Flow Tubing press. 250 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 1536 , GAS-MCF 964 ~ WATER-BBL 46 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". . _. s //-7~~ NONE ~ ~,~~ a a-,-....---,~...~«~, w,.,1 - ~ Form 10-407 Revised 12/2003 -' 4' \ t x~ ~ CONTINUED ON REVERSE ~ ,,, ~ /. /~j.07 ~ ~~ tr `~ 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 J-182 Top West Sak B 9734' 3424' Base West Sak B 17844' 3361' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Casing Detail Sheets 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Nugent @ 265-6862 Printed Nams-__„ Ran Thomas Title: Greater Kugaruk Area Drillino Team Leader ~ in ~ lca~ ` Signature lam `--- _-°-~=°hone -~ ~. 5-- ~^ ,Z• ~ ~ Date INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken. indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 • 1J-182'B' Sand Liner Detail well: 1J-182 '~ 4 1/2" Slotted and Blank Liner Date: 11/1/2006 Conlocc~P~i![ps i4taslca, ins. DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS 5" DP to Surface =_> Liner Runnin Tool 5" Does not sta in hole 11.28 9213.21 "HRD" ZXP Liner Top Packer 9-5/8" (7.50" X 8.43") 18.60 9224.49 "RS" Packoff Seal Nipple 7.00" (6.19" ID x 7.65" OD ~ 2.84 9243.09 Flexl_ock Liner Hanger 7"x 9-5/8" 6.23" X 8.34") 9.7a 9245 93 XO Bushing 4.90" ID, 7.67" OD .1.40 9255.71 190-47 Casing Seal Bore Ext. 4.75"ID x 6.31" OD 19.70 9257.11 XO Bushin 3.89" ID, 5.99" OD 1.34 9276.81 Pup Jt. - 4-1/2", 12.6 f, L-80, Hydril 521 3.70 9278.15 Jts 184 to 201 18 Jts > .; Y4:>: <. >:: :;:. `..::<:.;:« ::::..' ." :> :; .: ::. ,.. 736.55 9281.8 4-1/2" Hydrit 521 box x 4-1 /2" BTC pin Crossover 1.54 10018.40 Jts 6 to 183 178 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 7564.98 10019.94 Jts 3 to 5 3 Jts 4-112", 11.6 ppf, L-80, BTC Blank Casing 122.61 17584.92 Jts 1 to 2 2 Jts 4-112",11.6 pf, L-80, BTC Slotted Casin s6.67 17707.53 4-1/2", 11.6 p f, L-80, BTC Blank Casing 43.51 17794.20 4-1 /2" BTC Silver Bullet Float Shoe 1.29 17837.71 Bttm of Tail =_> 17839.00 TD 6 3/4" hole 17,844' MD f 3,361' TVD 4-1/2" Shoe 17,839" MD / 3,361' TVD {5.00' Rathole) Intermediate 9- 5/8 Shoe 9,831' MD/ 3,432' TVD Total Parts used: 17 S iro liders ~ 185 stop rings 168 H droFORM Centralizers. Run 1 s iroglider per jt floating with a stop ring in center of each jt. f/ Jt#1 thru Jt#17 (4.5" X 6.5") Run 1 HydroFORM er jt floating with a stop ring in center of each jt. f/ Jt#18 thru Jt#187 (4.5" X 6.13") Coverage of Centralizers f/ 17,774' to 9,870' DO NOT RUN CENTRALIZERS ON CONSTRICTOR JOINTS Total of 2 Constrictor Packers ran ~ 17,685',17,605'. Ran total of 3 jts Blank= 122.61' and 198 jts Slotted= 8,388.20" ,Slots are Up Wt 300K w! (32) 2.5" long x .125" 4 Circumferential adjacent rows, 3" Centers Dn Wt ???K sta gered 18 deg., 3 ft. non-slotted ends Block Wt 70K Used Run-N-Seal thread compound on all connections. Rot Wt 140K Drifted casing to 3.833" w/ teflon rabbit. Liner Wt 65k Torque Rings Installed in joints #84 Thru #183 Supervisors: Fred Herbert / Granville Rizek Halliburton Company Survey Report r Company: ConocoPhillips Alaska Inc. Date: 12/21/2006 'Time: 09:51:38 Pagc: l Field: Kuparuk River Unit Co-ordinate(NE) Reference: WeIC 1 J-182, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-182: 121.3 Well: 1J-182 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-182 Surrey Calculation Method: Minimum Curvature Db: Oracle ____ ___ -- Field: Kuparuk River Unit - --_ North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2006 Well: 1 J-182 Slot Name: Well Position: +N/-S -537.96 ft Northing: 5945381.64 ft Latitude: 70 15 40.967 N +E/-W -14.46 ft Easting : 558779.69 ft • Longitude: 149 31 29.427 W Positron Uncertainty: 0.00 ft Wellpath: 1J-182 Drilled From: Well Ref. Point 500292332100 Tie-on Depth: 40.30 ft Current Datum: 1 J-182: Height 121.30 ft Above System Datum: Mean Sea Level Magnetic Data: 10/4/2004 Declination: 24.63 deg ~~ Field Strength: 57562 nT Mag Dip Angle: 80.75 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.30 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 12/17/2004 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 100.00 891.00 1J-182 gyro (100.00-891.00) CB-GYRO-SS Camera based gyro single shot 965.65 17809.76 1J-182 (965.65-17809.76) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey 11ID ft 40.30 "100.00 200.00 300.00 400.00 496.00 515.00 604.00 i 696.00 ', 796.00 ~ 891.00 965.65 1059.65 'I 1155.97 ~ 1250.69 I 1346.86 1441.92 1536.64 1631.87 1726.65 1821.56 1916.82 2012.04 2108.02 ~~ 2202.30 2297.82 2392.80 4 2488.25 2583.30 Intl lzim deg deg 0.00 0.00 0.46 219.18 1.28 161.70 3.71 160.11 5.02 173.55 4.32 196.16 4.27 202.60 6.22 210.98 9.33 212.56 11.10 214.50 13.12 207.22 17.65 204.41 23.06 203.22 25.75 204.96 28.41 205.71 33.42 206.63 39.62 206.72 44.17 205.50 48.85 206.13 51.15 206.14 57.81 204.82 62.86 202.74 66.37 201.40 70.76 197.96 73.96 195.11 74.95 193.03 74.79 191.54 74.98 191.95 73.42 192.50 'FVD Sys TVD ft ft 40.30 -81.00 100.00 -21.30 199.99 78.69 299.89 178.59 399.60 278.30 495.29 373.99 514.23 392.93 602.86 481.56 694.00 572.70 792.41 671.11 885.30 764.00 957.25 835.95 1045.35 924.05 1133.06 1011.76 1217.39 1096.09 1299.87 1178.57 1376.23 1254.93 1446.72 1325.42 1512.24 1390.94 1573.16 1451.86 1628.27 1506.97 1675.41 1554.11 1716.22 1594.92 1751.30 1630.00 1779.87 1658.57 1805.47 1684.17 1830.26 1708.96 1855.15 1733.85 1881.03 1759.73 - NIS _ __ _ F,/W _ iMapN ft ft ft 0. 00 0 .00 5945381. 64 -0. 19 -0 .15 5945381. 45 -1. 56 -0 .05 5945380. 08 -5. 66 1 .40 5945375. 99 -13. 05 2 .99 5945368. 61 -20. 70 2 .46 5945360. 96 -22. 04 1 .98 5945359. 62 -29. 23 -1 .77 5945352. 40 -39. 79 -8 .35 5945341. 79 -54. 56 -18 .17 5945326. 95 -71. 69 -28 .28 5945309. 74 -89. 54 -36 .84 5945291. 83 -119. 45 -49 .99 5945261. 81 -155. 76 -66 .26 5945225. 38 -194. 73 -84 .73 5945186. 28 -239. 04 -106 .54 5945141. 80 -289. 57 -131 .92 5945091. 08 -346. 36 -159 .72 5945034. 08 -408. 53 -189 .81 5944971. 68 -473. 71 -221 .79 5944906. 26 -543. 42 -254 .97 5944836. 30 -619. 15 -288 .30 5944760. 32 -698. 86 -320 .60 5944680. 37 -782. 96 -350 .64 5944596. 04 -869. 08 -376 .19 5944509. 74 -958. 34 -398 .55 5944420. 32 -1047. 92 -418 .06 5944330. 59 -1138. 14 -436 .82 5944240. 24 -1227. 52 -456.18 5944150. 71 MapE Tool ft 558779.69 TIE LINE 558779.54 CB-GYRO-SS 558779.65 CB-GYRO-SS 558781.13 CB-GYRO-SS 558782.78 CB-GYRO-SS 558782.31 CB-GYRO-SS 558781.85 CB-GYRO-SS 558778.15 CB-GYRO-SS 558771.65 CB-GYRO-SS 558761.95 CB-GYRO-SS 558751.97 CB-GYRO-SS 558743.56 MWD+IFR-AK-CAZ-SC 558730.63 MWD+IFR-AK-CAZ-SC 558714.65 MWD+IFR-AK-CAZ-SC 558696.50 MWD+IFR-AK-CAZ-SC 558675.03 MWD+IFR-AK-CAZ-SC 558650.05 MWD+IFR-AK-CAZ-SC 558622.69 MWD+IFR-AK-CAZ-SC 558593.09 MWD+IFR-AK-CAZ-SC 558561.62 MWD+IFR-AK-CAZ-SC 558528.99 MWD+IFR-AK-CAZ-SC 558496.26 MWD+IFR-AK-CAZ-SC 558464.58 MWD+IFR-AK-CAZ-SC 558435.20 MWD+IFR-AK-CAZ-SC 558410.34 MWD+IFR-AK-CAZ-SC 558388.67 MWD+IFR-AK-CAZ-SC 558369.86 MWD+IFR-AK-CAZ-SC 558351.81 MWD+IFR-AK-CAZ-SC 558333.15 MWD+IFR-AK-CAZ-SC ~' Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 12/21/2006 Time: 09:51:38 Page: 2 '' Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-182, True North Site: Kuparuk 1J Pad Vertical(TVll) Refecence: iJ-182: 121.3 Wrll: 1 J-182 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) ~Vellpath: 1J-i82 Surce~ Calculation Method: Minimum Curvature Db: Oracle Sonev ___ 1ViD Incl :1zim TVll Sys'["VD N/S E/W MapN JIapE Tool ft deg deg ft ft ft ft ft ft 2677. 40 75. - 11 190 .79 _ - 1906 - _ .55 1785 .25 - -1316. -- 22 -474 .46 5944061. 88 558315. 57 __ MWD+IFR-AK-CAZ-SC 2773. 73 75. 91 190 .11 1930 .65 1809. 35 -1407. 94 -491 .37 5943970. 04 558299. 37 MWD+IFR-AK-CAZ-SC 2868. 62 76. 05 191 .13 1953 .64 1832. 34 -1498. 43 -508 .34 5943879. 43 558283. 11 MWD+IFR-AK-CAZ-SC 2964. 60 74. 05 189 .95 1978 .40 1857. 10 -1589. 59 -525 .31 5943788. 15 558266. 86 MWD+IFR-AK-CAZ-SC 3060. 06 74. 55 188 .86 2004 .23 1882. 93 -1680. 25 -540 .32 5943697. 39 558252. 55 MWD+IFR-AK-CAZ-SC 3153. 82 75. 48 190 .85 2028 .48 1907. 18 -1769. 48 -555 .83 5943608. 05 558237. 75 MWD+IFR-AK-CAZ-SC 3250. 26 79. 82 193 .03 2049 .10 1927 .80 -1861. 62 -575 .32 5943515. 77 558218. 97 MWD+IFR-AK-CAZ-SC 3343. 91 77. 81 193 .02 2067 .27 1945. 97 -1951. 12 -596 .03 5943426. 12 558198. 97 MWD+IFR-AK-CAZ-SC 3439. 43 75. 29 193 .97 2089 .49 1968. 19 -2041. 45 -617 .70 5943335. 63 558178. 00 MWD+IFR-AK-CAZ-SC ~ 3534. 69 73. 75 193 .01 2114 .91 1993. 61 -2130. 71 -639 .12 5943246. 21 558157. 28 MWD+IFR-AK-CAZ-SC 3627. 32 75. 85 192 .86 2139 .20 2017. 90 -2217. 83 -659 .13 5943158. 95 558137. 96 MWD+IFR-AK-CAZ-SC 3674. 33 73. 59 192 .99 2151 .58 2030 .28 -2262. 03 -669 .27 5943114. 68 558128. 16 MWD+IFR-AK-CAZ-SC 3728. 38 73. 03 193 .90 2167 .11 2045 .81 -2312. 38 -681 .31 5943064. 24 558116. 52 MWD+IFR-AK-CAZ-SC 3767. 32 74. 03 195 .01 2178 .15 2056 .85 -2348. 54 -690 .63 5943028. 01 558107. 48 MWD+IFR-AK-CAZ-SC 3814. 35 75. 20 195 .04 2190 .62 2069 .32 -2392. 33 -702 .38 5942984. 13 558096. 07 MWD+IFR-AK-CAZ-SC 3862. 80 76. 55 195 .54 2202 .45 2081 .15 -2437. 65 -714 .77 5942938. 72 558084. 03 MWD+IFR-AK-CAZ-SC 3957. 65 75. 95 195 .37 2224 .99 2103 .69 -2526. 45 -739 .33 5942849. 74 558060. 18 MWD+IFR-AK-CAZ-SC 4051,61 76. 29 195 .25 2247 .53 2126 .23 -2614. 43 -763 .41 5942761. 58 558036. 78 MWD+IFR-AK-CAZ-SC 4146. 61 77. 59 195 .02 2269 .00 2147 .70 -2703. 76 -787 .57 5942672. 07 558013. 32 MWD+IFR-AK-CAZ-SC 4193. 74 77. 89 195 .13 2279 .01 2157 .71 -2748. 23 -799 .55 5942627. 51 558001. 69 MWD+IFR-AK-CAZ-SC 4242. 12 75. 85 195 .08 2290 .00 2168 .70 -2793. 72 -811 .83 5942581. 94 557989. 77 MWD+IFR-AK-CAZ-SC 4338. 69 76. 70 195 .04 2312 .91 2191 .61 -2884. 31 -836 .20 5942491. 17 557966. 11 MWD+IFR-AK-CAZ-SC 4432. 61 78. 83 194 .61 2332 .81 2211 .51 -2973. 03 -859 .68 5942402. 27 557943. 32 MWD+IFR-AK-CAZ-SC ~~ 4528. 23 77. 20 194 .15 2352 .67 2231 .37 -3063. 63 -882 .91 5942311. 50 557920. 80 MWD+IFR-AK-CAZ-SC 4623. 98 77. 65 191 .67 2373 .52 2252 .22 -3154. 72 -903 .79 5942220. 27 557900. 64 MWD+IFR-AK-CAZ-SC 4719. 02 78. 38 189 .93 2393 .25 2271 .95 -3246. 04 -921 .21 5942128. 82 557883. 93 MWD+IFR-AK-CAZ-SC 4813. 42 76. 99 192 .60 2413 .39 2292 .09 -3336. 48 -939 .22 5942038. 25 557866. 63 MWD+IFR-AK-CAZ-SC 4908. 79 77. 71 191 .02 2434 .28 2312 .98 -3427. 56 -958 .26 5941947. 04 557848. 30 MWD+IFR-AK-CAZ-SC 5004. 18 77. 33 190 .46 2454 .89 2333 .59 -3519. 06 -975 .62 5941855. 41 557831. 66 MWD+IFR-AK-CAZ-SC 5100. 11 77. 80 192 .08 2475 .55 2354 .25 -3610. 93 -993 .92 5941763. 41 557814. 08 MWD+IFR-AK-CAZ-SC 5194. 97 78. 19 191 .09 2495 .28 2373 .98 -3701. 83 -1012 .56 5941672. 38 557796. 15 MWD+IFR-AK-CAZ-SC 5245. 05 76. 50 191 .04 2506 .25 2384 .95 -3749. 78 -1021 .93 5941624. 36 557787. 15 MWD+IFR-AK-CAZ-SC 5289. 86 76. 35 191 .57 2516 .77 2395 .47 -3792. 49 -1030 .47 5941581. 59 557778. 95 MWD+IFR-AK-CAZ-SC 5383. 69 76. 38 189 .94 2538 .89 2417 .59 -3882. 07 -1047 .49 5941491. 88 557762. 63 MWD+IFR-AK-CAZ-SC 5480. 30 76. 88 192 .49 2561 .23 2439 .93 -3974. 26 -1065 .77 5941399. 56 557745. 07 MWD+IFR-AK-CAZ-SC 5575. 36 77. 14 193 .16 2582 .60 2461 .30 -4064. 58 -1086 .33 5941309. 10 557725. 22 MWD+{FR-AK-CAZ-SC ~' 5670. 51 76. 90 195 .02 2603 .97 2482 .67 -4154. 50 -1108 .90 5941219. 01 557703. 36 MWD+IFR-AK-CAZ-SC 5765. 44 77. 68 195 .42 2624 .86 2503 .56 -4243. 86 -1133 .21 5941129. 48 557679. 75 MWD+IFR-AK-CAZ-SC 5853. 39 77. 20 194 .23 2643 .99 2522 .69 -4326. 84 -1155 .18 5941046. 33 557658. 43 MWD+IFR-AK-CAZ-SC 5955. 75 77. 69 193 .94 2666 .24 2544 .94 -4423. 75 -1179 .49 5940949. 24 557634. 88 MWD+IFR-AK-CAZ-SC 6050. 97 78. 73 191 .38 2685 .70 2564 .40 -4514. 69 -1199 .91 5940858. 16 557615. 17 MWD+IFR-AK-CAZ-SC 6146. 72 78. 04 192 .62 2704 .97 2583 .67 -4606. 42 -1219 .41 5940766. 28 557596. 39 MWD+IFR-AK-CAZ-SC 6242. 35 78. 50 193 .52 2724 .42 2603 .12 -4697. 63 -1240 .59 5940674. 92 557575. 93 MWD+IFR-AK-CAZ-SC 6336. 27 78. 57 193 .82 2743 .08 2621 .78 -4787. 07 -1262 .34 5940585. 33 557554. 87 MWD+IFR-AK-CAZ-SC 6431. 97 78. 50 192 .15 2762 .11 2640 .81 -4878. 46 -1283 .41 5940493. 78 557534. 52 MWD+IFR-AK-CAZ-SC 6524. 99 77. 16 190 .37 2781 .72 2660 .42 -4967. 63 -1301 .17 5940404. 48 557517. 46 MWD+IFR-AK-CAZ-SC 6621. 26 76. 62 189 .01 2803 .56 2682 .26 -5060. 05 -1316 .95 5940311. 95 557502. 40 MWD+IFR-AK-CAZ-SC 6716. 43 74. 40 190 .42 2827 .37 2706 .07 -5150. 86 -1332 .50 5940221. 03 557487. 57 MWD+IFR-AK-CAZ-SC 6811. 74 77. 45 192 .82 2850 .55 2729 .25 -5241. 40 -1351 .13 5940130. 36 557469. 65 MWD+IFR-AK-CAZ-SC 6904. 44 76. 02 192 .77 2871 .82 2750 .52 -5329. 38 -1371 .11 5940042. 23 557450. 35 MWD+IFR-AK-CAZ-SC 6997. 68 76. 41 193 .79 2894 .03 2772 .73 -5417. 51 -1391 .91 5939953. 95 557430. 24 MWD+IFR-AK-CAZ-SC ' , 7093. 73 75. 76 193 .05 2917 .13 2795 .83 -5508. 20 -1413 .55 5939863. 11 557409. 31 _ __ _ __ MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report __ Company: ConocoPhillips Alaska Inc. llntes 12/21/2006 Time: 09:51:38 Page: 3 ', Field: Kuparuk River Unit Co-ordinate(NF) Reference: Well: 1J-182, True North ', Site: Kuparuk 1J Pad Vertical (I'VD) Reference: 1J-182: 121.3 Well: 1J-182 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-182 Survey Calculation Method: Minimum Curvature Db: Oracle __ _ __ Sunev __ _ - MD [ncl lzim TVD Sys TVD ~/S E/W MapN 11apE llx,l '; ft deg deg ft ft ft ft ft ft '; 7189.72 78.20 193.38 2938.76 2817.46. -5599.23 -1434.93 5939771.91 557388.65 MWD+IFR-AK-CAZ-SC 7285.02 77.69 194.25 2958.66 2837.36 -5689.74 -1457.18 5939681.25 557367.10 MWD+IFR-AK-CAZ-SC 7379.64 78.08 193.35 2978.52 2857.22 -5779.58 -1479.25 5939591.25 557345.74 MWD+IFR-AK-CAZ-SC i 7428.90 77.88 193.93 2988.78 2867.48 -5826.40 -1490.61 5939544.35 557334.75 MWD+IFR-AK-CAZ-SC I '; 7475.83 77.03 193.04 2998.97 2877.67 -5870.94 -1501.29 5939499.72 557324.41 MWD+IFR-AK-CAZ-SC ' i, 7570.60 77.46 193.06 3019.89 2898.59 -5960.99 -1522.16 5939409.53 557304.25 MWD+IFR-AK-CAZ-SC i 7665.02 79.31 195.11 3038.91 2917.61 -6050.68 -1544.67 5939319.67 557282.44 MWD+IFR-AK-CAZ-SC 7759.52 78.16 193.79 3057.37 2936.07 -6140.43 -1567.80 5939229.75 557260.01 MWD+IFR-AK-CAZ-SC 7854.47 76.57 194.10 3078.14 2956.84 -6230.34 -1590.13 5939139.67 557238.39 MWD+IFR-AK-CAZ-SC 7949.97 75.79 194.98 3100.95 2979.65 -6320.11 -1613.41 5939049.74 557215.82 MWD+IFR-AK-CAZ-SC I 8044.86 76.40 194.48 3123.75 3002.45 -6409.19 -1636.83 5938960.49 557193.10 MWD+IFR-AK-CAZ-SC 8140.30 76.82 194.35 3145.85 3024.55 -6499.11 -1659.94 5938870.40 557170.69 MWD+IFR-AK-CAZ-SC 8234.16 76.58 192.88 3167.45 3046.15 -6587.88 -1681.44 5938781.47 557149.88 MWD+IFR-AK-CAZ-SC 8328.34 76.86 191.83 3189.08 3067.78 -6677.42 -1701.05 5938691.79 557130.97 MWD+IFR-AK-CAZ-SC 8424.91 76.83 189.84 3211.06 3089.76 -6769.78 -1718.73 5938599.31 557114.02 MWD+IFR-AK-CAZ-SC 8519.95 75.60 190.23 3233.71 3112.41 -6860.66 -1734.81 5938508.30 557098.65 MWD+IFR-AK-CAZ-SC 8615.82 76.46 187.81 3256.85 3135.55 -6952.54 -1749.39 5938416.33 557084.78 MWD+IFR-AK-CAZ-SC 8710.90 75.76 187.09 3279.68 3158.38 -7044.06 -1761.36 5938324.72 557073.53 MWD+IFR-AK-CAZ-SC 8806.01 76.27 184.22 3302.67 3181.37 -7135.89 -1770.45 5938232.83 557065.16 MWD+IFR-AK-CAZ-SC 8901.29 81.57 183.62 3320.97 3199.67 -7229.14 -1776.84 5938139.54 557059.50 MWD+IFR-AK-CAZ-SC 8996.39 81.78 182.06 3334.74 3213.44 -7323.12 -1781.50 5938045.54 557055.57 MWD+IFR-AK-CAZ-SC 9090.74 82.65 180.59 3347.52 3226.22 -7416.57 -1783.66 5937952.08 557054.14 MWD+IFR-AK-CAZ-SC 9182.57 82.10 180.05 3359.71 3238.41 -7507.59 -1784.17 5937861.08 557054.35 MWD+IFR-AK-CAZ-SC 9278.71 82.02 180.17 3372.99 3251.69 -7602.81 -1784.35 5937765.87 557054.91 MWD+IFR-AK-CAZ-SC 9374.37 82.15 180.54 3386.16 3264.86 -7697.55 -1784.94 5937671.13 557055.06 MWD+IFR-AK-CAZ-SC 9471.69 84.74 180.99 3397.27 3275.97 -7794.22 -1786.23 5937574.46 557054.52 MWD+IFR-AK-CAZ-SC 9566.97 84.39 180.38 3406.30 3285.00 -7889.06 -1787.36 5937479.62 557054.13 MWD+IFR-AK-CAZ-SC 9661.22 83.71 179.13 3416.07 3294.77 -7982.80 -1786.96 5937385.90 557055.26 MWD+IFR-AK-CAZ-SC 9756.64 84.45 178.63 3425.91 3304.61 -8077.70 -1785.11 5937291.03 557057.86 MWD+IFR-AK-CAZ-SC 9836.37 84.68 180.24 3433.46 3312.16 -8157.06 -1784.33 5937211.68 557059.26 MWD+IFR-AK-CAZ-SC 9931.13 86.29 181.99 3440.92 3319.62 -8251.50 -1786.17 5937117.24 557058.16 MWD+IFR-AK-CAZ-SC 10024.81 88.46 185.81 3445.21 3323.91 -8344.84 -1792.53 5937023.86 557052.52 MWD+IFR-AK-CAZ-SC 10121.76 93.60 188.82 3443.47 3322.17 -8440.95 -1804.87 5936927.67 557040.94 MWD+IFR-AK-CAZ-SC 10216.92 93.69 184.71 3437.42 3316.12 -8535.23 -1816.05 5936833.31 557030.49 MWD+IFR-AK-CAZ-SC ~; 10311.75 92.33 180.83 3432.44 3311.14 -8629.80 -1820.62 5936738.72 557026.65 MWD+IFR-AK-CAZ-SC 10406.56 90.47 176.69 3430.12 3308.82 -8724.53 -1818.57 5936644.02 557029.44 MWD+IFR-AK-CAZ-SC 10501.91 89.18 176.65 3430.41 3309.11 -8819.72 -1813.03 5936548.88 557035.73 MWD+IFR-AK-CAZ-SC ', 10596.61 90.49 178.17 3430.68 3309.38 -8914.32 -1808.75 5936454.33 557040.74 MWD+IFR-AK-CAZ-SC 10692.44 89.68 178.71 3430.54 3309.24 -9010.11 -1806.15 5936358.57 557044.10 MWD+IFR-AK-CAZ-SC 10787.22 91.11 178.13 3429.89 3308.59 -9104.85 -1803.53 5936263.86 557047.45 MWD+IFR-AK-CAZ-SC 10881.83 91.91 177.00 3427.39 3306.09 -9199.34 -1799.51 5936169.42 557052.21 MWD+IFR-AK-CAZ-SC 10977.47 90.16 176.59 3425.67 3304.37 -9294.81 -1794.17 5936074.00 557058.30 MWD+IFR-AK-CAZ-SC 11067.74 88.56 178.08 3426.67 3305.37 -9384.97 -1789.97 5935983.88 557063.20 MWD+IFR-AK-CAZ-SC 11166.88 91.43 181.96 3426.68 3305.38 -9484.08 -1790.01 5935884.79 557063.94 MWD+IFR-AK-CAZ-SC 11261.90 89.61 182.94 3425.82 3304.52 -9579.01 -1794.07 5935789.84 557060.61 MWD+IFR-AK-CAZ-SC 11356.54 89.37 181.45 3426.66 3305.36 -9673.57 -1797.69 5935695.26 557057.73 MWD+IFR-AK-CAZ-SC 11452.13 89.50 182.76 3427.61 3306.31 -9769.09 -1801.20 5935599.73 557054.96 MWD+IFR-AK-CAZ-SC 11547.25 89.81 180.24 3428.18 3306.88 -9864.17 -1803.69 5935504.64 557053.22 MWD+IFR-AK-CAZ-SC 11641.72 91.42 177.86 3427.16 3305.86 -9958.61 -1802.13 5935410.22 557055.52 MWD+IFR-AK-CAZ-SC 11737.40 92.65 173.78 3423.77 3302.47 -10053.95 -1795.16 5935314.95 557063.23 MWD+IFR-AK-CAZ-SC 11831.89 89.72 170.40 3421.81 3300.51 -10147.50 -1782.16 5935221.51 557076.96 MWD+IFR-AK-CAZ-SC 11927.19 92.04 172.54 3420.35 3299.05 -10241.72 -1768.03 5935127.41 557091.82 MWD+IFR-AK-CAZ-SC 12022.60 89.79 167.93 3418.82 3297.52 -10335.71 -1751.85 5935033.57 557108.73 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report - ___ _ __ Company: ConocoPhillips Alaska lnc. Date: 12/21/2006 Time: 09:51:38 Page: d Field:. Kuparuk River Unit Co-ordinate(NE)Reference: Well: 1J-182, True North Site: Kuparuk 1J Pad Vertical (1'VD) deference: 1J-182: 121.3 '~' W'ell: 1J-182 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-182 Survey Calculation Method: Minimum Curvature Db: Oracle Sunev ----- - __ - MD Incl Azim TVD Sys TVD ~/S E/W A1upN itapE Tool ft deg deg ft ft ft ft ft ft 12117.16 89.37 167.10 3419.52 3298.22 -10428.03 -1731.41 5934941.42 557129.89 MWD+IFR-AK-CAZ-SC 12212.99 88.38 168.58 3421.40 3300.10 -10521.69 -1711.23 5934847.93 557150.80 MWD+IFR-AK-CAZ-SC '; 12307.69 88.70 172.82 3423.81 3302.51 -10615.09 -1695.93 5934754.66 557166.82 MWD+IFR-AK-CAZ-SC 12402.19 90.99 175.94 3424.07 3302.77 -10709.12 -1686.68 5934660.71 557176.81 MWD+IFR-AK-CAZ-SC 12497.57 92.60 177.36 3421.08 3299.78 -10804.28 -1681.11 5934565.60 557183.12 MWD+IFR-AK-CAZ-SC 12591.52 95.57 177.07 3414.39 3293.09 -10897.87 -1676.56 5934472.06 557188.40 MWD+IFR-AK-CAZ-SC 12690.34 92.44 174.11 3407.49 3286.19 -10996.13 -1668.98 5934373.87 557196.75 MWD+IFR-AK-CAZ-SC 12785.67 87.87 174.94 3407.23 3285.93 -11091.00 -1659.88 5934279.08 557206.58 MWD+IFR-AK-CAZ-SC I 12879.86 87.27 179.17 3411.22 3289.92 -11184.96 -1655.05 5934185.17 557212.15 MWD+IFR-AK-CAZ-SC 12973.68 87.65 181.83 3415.38 3294.08 -11278.68 -1655.87 5934091.46 557212.06 MWD+IFR-AK-CAZ-SC ~ 13070.68 90.13 185.70 3417.26 3295.96 -11375.42 -1662.23 5933994.68 557206.45 MWD+IFR-AK-CAZ-SC I, 13165.00 89.68 183.29 3417.42 3296.12 -11469.45 -1669.63 5933900.61 557199.80 MWD+IFR-AK-CAZ-SC 13259.88 92.72 182.35 3415.43 3294.13 -11564.18 -1674.29 5933805.86 557195.87 MWD+IFR-AK-CAZ-SC 13353.75 91.09 180.77 3412.31 3291.01 -11657.96 -1676.85 5933712.07 557194.05 MWD+IFR-AK-CAZ-SC 13451.26 94.02 181.94 3407.96 3286.66 -11755.33 -1679.15 5933614.69 557192.51 MWD+IFR-AK-CAZ-SC 13547.13 89.47 180.71 3405.04 3283.74 -11851.10 -1681.36 5933518.91 557191.04 MWD+IFR-AK-CAZ-SC 13643.00 91.48 178.11 3404.25 3282.95 -11946.95 -1680.38 5933423.08 557192.78 MWD+IFR-AK-CAZ-SC 13738.16 89.42 173.40 3403.50 3282.20 -12041.82 -1673.33 5933328.29 557200.56 MWD+IFR-AK-CAZ-SC 13833.60 89.87 172.23 3404.09 3282.79 -12136.50 -1661.40 5933233.71 557213.23 MWD+IFR-AK-CAZ-SC 13928.00 87.50 173.25 3406.26 3284.96 -12230.11 -1649.47 5933140.20 557225.89 MWD+IFR-AK-CAZ-SC 14022.90 90.87 177.94 3407.61 3286.31 -12324.68 -1642.19 5933045.70 557233.91 MWD+IFR-AK-CAZ-SC 14118.10 89.99 180.66 3406.90 3285.60 -12419.86 -1641.02 5932950.54 557235.81 MWD+IFR-AK-CAZ-SC 14212.93 90.49 182.74 3406.50 3285.20 -12514.65 -1643.84 5932855.75 557233.74 MWD+IFR-AK-CAZ-SC 14307.72 91.97 185.05 3404.46 3283.16 -12609.19 -1650.27 5932761.17 557228.04 MWD+IFR-AK-CAZ-SC 14401.70 91.59 183.87 3401.54 3280.24 -12702.83 -1657.58 5932667.48 557221.47 MWD+IFR-AK-CAZ-SC 14496.58 90.97 183.36 3399.42 3278.12 -12797.50 -1663.56 5932572.77 557216.23 MWD+IFR-AK-CAZ-SC 14591.03 88.99 184.26 3399.46 3278.16 -12891.74 -1669.83 5932478.50 557210.69 MWD+IFR-AK-CAZ-SC 14687.59 91.24 178.98 3399.26 3277.96 -12988.22 -1672.56 5932382.01 557208.71 MWD+IFR-AK-CAZ-SC 14782.87 89.92 176.20 3398.30 3277.00 -13083.40 -1668.56 5932286.88 557213.46 MWD+IFR-AK-CAZ-SC ~ 14872.38 88.19 176.49 3399.78 3278.48 -13172.71 -1662.85 5932197.62 557219.86 MWD+IFR-AK-CAZ-SC 14970.82 88.01 179.09 3403.04 3281.74 -13271.01 -1659.06 5932099.36 557224.42 MWD+IFR-AK-CAZ-SC i ~ 15064.66 90.19 184.43 3404.51 3283.21 -13364.76 -1661.94 5932005.60 557222.27 MWD+IFR-AK-CAZ-SC 15158.89 92.28 186.17 3402.48 3281.18 -13458.55 -1670.64 5931911.75 557214.31 MWD+IFR-AK-CAZ-SC 15253.07 93.52 184.34 3397.72 3276.42 -13552.21 -1679.26 5931818.04 557206.42 MWD+IFR-AK-CAZ-SC I~ 15343.60 92.45 183.94 3393.00 3271.70 -13642.38 -1685.78 5931727.83 557200.60 MWD+IFR-AK-CAZ-SC 15443.73 93.20 179.22 3388.07 3266.77 -13742.32 -1688.54 5931627.88 557198.62 MWD+IFR-AK-CAZ-SC I, I 15539.21 88.85 176.53 3386.36 3265.06 -13837.69 -1685.00 5931532.55 557202.91 MWD+IFR-AK-CAZ-SC 15632.04 89.93 177.22 3387.35 3266.05 -13930.38 -1679.94 5931439.91 557208.69 MWD+IFR-AK-CAZ-SC 15728.64 90.98 176.46 3386.58 3265.28 -14026.82 -1674.62 5931343.52 557214.77 MWD+IFR-AK-CAZ-SC 15825.17 90.17 177.14 3385.61 3264.31 -14123.20 -1669.23 5931247.20 557220.91 MWD+IFR-AK-CAZ-SC 15920.04 89.99 177.69 3385.48 3264.18 -14217.97 -1664.95 5931152.47 557225.93 MWD+IFR-AK-CAZ-SC 16016.54 89.62 174.54 3385.81 3264.51 -14314.24 -1658.41 5931056.27 557233.21 MWD+IFR-AK-CAZ-SC 16113.30 92.22 179.70 3384.25 3262.95 -14410.82 -1653.55 5930959.74 557238.83 MWD+IFR-AK-CAZ-SC 16207.64 90.41 180.86 3382.09 3260.79 -14505.13 -1654.01 5930865.44 557239.10 MWD+IFR-AK-CAZ-SC 16303.60 90.92 182.94 3380.97 3259.67 -14601.02 -1657.19 5930769.53 557236.67 MWD+IFR-AK-CAZ-SC 16397.62 91.54 185.85 3378.95 3257.65 -14694.73 -1664.40 5930675.77 557230.20 MWD+IFR-AK-CAZ-SC 16493.67 91.72 185.41 3376.22 3254.92 -14790.28 -1673.81 5930580.16 557221.53 MWD+IFR-AK-CAZ-SC 16588.33 92.71 184.76 3372.56 3251.26 -14884.50 -1682.20 5930485.90 557213.88 MWD+IFR-AK-CAZ-SC i 16683.19 91.90 180.94 3368.75 3247.45 -14979.15 -1686.91 5930391.22 557209.91 MWD+IFR-AK-CAZ-SC 16777.48 89.29 181.45 3367.77 3246.47 -15073.40 -1688.88 5930296.96 557208.68 MWD+IFR-AK-CAZ-SC 16873.42 90.37 183.65 3368.05 3246.75 -15169.24 -1693.14 5930201.11 557205.16 MWD+IFR-AK-CAZ-SC i 16968.37 95.65 180.47 3363.07 3241.77 -15263.95 -1696.56 5930106.38 557202.49 MWD+IFR-AK-CAZ-SC A Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. 1}ate: 1 212 1 /2 00 6 Time: 09:51:38 ___ __ Page: 5 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-182, T rueNorth Site: Kuparuk 1J Pad Vertical ('CVD) Reference: 1J-182: 121.3 Well: 1J-182 Section (VS} Reference: Well (O.OON,O.O OE,180.OOAzi) Wellpath: 1J-182 Survey Calculation,llethod: Minimum Curvature Dbc Oracle Survev - MD ^icl Azim TV17 Sys'I'VD __ N/S E/W _ MapN ilapE Tool ft deg deg ft ft ft ft ft ft I ~ 17063.92 90.83 175.45 3357.67 3236.37 -15359.23 -1693.15 5930011.14 557206.63 MWD+IFR-AK-CAZ-SC 17158.02 89.24 175.79 3357.61 3236.31 -15453.05 -1685.97 5929917.39 557214.55 MWD+IFR-AK-CAZ-SC 17253.56 90.24 176.28 3358.04 3236.74 -15548.36 -1679.36 5929822.14 557221.90 MWD+IFR-AK-CAZ-SC 17347.56 89.80 181.55 3358.01 3236.71 -15642.31 -1677.58 5929728.22 557224.41 MWD+IFR-AK-CAZ-SC 17443.12 90.92 182.07 3357.41 3236.11 -15737.82 -1680.60 5929632.70 557222.14 MWD+IFR-AK-CAZ-SC ~ ', 17538.42 87.93 178.27 3358.37 3237.07 -15833.08 -1680.88 5929537.44 557222.60 MWD+IFR-AK-CAZ-SC 17632.88 90.81 176.34 3359.40 3238.10 -15927.42 -1676.44 5929443.15 557227.78 MWD+IFR-AK-CAZ-SC 17729.91 90.17 177.56 3358.57 3237.27 -16024.31 -1671.28 5929346.32 557233.69 MWD+IFR-AK-CAZ-SC j 17809.76 88.00 176.49 3359.85 3238.55 -16104.03 -1667.14 5929266.63 557238.46 MWD+IFR-AK-CAZ-SC ~ 17844.00 88.00 176.49 3361.04 3239.74 -16138.19 -1665.04 5929232.50 ^ 557240.82 ~ PROJECTED to TD I ?age 1 u; ~9 Conoc Philips Time Log Summary We1N+ew Web Reporting - ----- - -- -- --- Well Name: 1J-182 Job Type: DRILLING ORIGINAL - -- --_ _ _ _ _ - - Time Lo s 9-- ___ __ - - - ~ Date From__To____ Dur_ __ S. nth Epepth Phase CocJe Subco~e T C_OP~4 _ ' 10/05/2006 00:00 02:00 2.00 120 120 MIRU MOVE DMOB P Prepare rig floor for kid. R/D choke line, air ,water and steam lines between sub and pit module. Clean out cellar box. R/D rockwasher f/ movin . 02:00 02:15 0.25 120 120 MIRU MOVE SFTY P PJSM on skidding rig floor and rigging down rockwasher for move to 1 J-182. 02:15 03:00 0.75 120 120: MIRU MOVE SKID P Skid rig floor for moving. sub. Rig down rockwasher f/ moving away f/pit com lex. 03:00 03:15 0.25 120 120 MIRU MOVE SFTY P PJSM f/ moving pits and sub modules, 03:15 06:00 2.75 120 120 MIRU MOVE DMOB P Turn tires on pit and sub modules. Lay. dunage (Ramp) for walking off of mats. Inspect moving system. Move break ~ -- shack. Move rockwasher. Remove _ _ handi-berms from around pits and sub. Raise stomper feet on sub. Clean up around location. 06:00 08:00 2.00 120 120. MIRU MOVE DMOB P Swap power on the pit module to the 399 cat. Removin electrical lines. 08:00 12:00 4.00 120 120 MIRU MOVE MOB P Moving pit module away f/drilling module. Move drilling module off of hole 1J-102 . 12:00 16:00 4.00 120 120 MIRU MOVE MOB P Move sub module to otherside of pad. 16:00 16:30 0.50 120 120 MIRU MOVE RGRP P PJSM on picking up derrick windwall and placing on drilling module roof. PU wall and secure on roof. 16:30 18:00 1.50 120 120 MIRU MOVE MOB P Continue moving drilling module to: Well 1 J-182. T8:00 21:30 3.50 120 120 M1RU MOVE MOB P Continue moving drilling module. Set module down and remove drag link equalizer bars and turn tires to crab. Crab sub into position to back over 1J-182. Set drilling module down, turn tires. Install drag link equalizer bars, line up drilling module to spot over well. Module is about 50' f/ over hole. Read to han windwall 21:30. 00:00 2.50 120 120 MIRU MOVE MOB P Move pit module around to the other side of pad.. Spot module next to mats pre set f/ 1J-182. Set module down, remove drag link equalizer bars, turn tires to crab onto the mats. Lay more mats, Lay dunage (Ramp) to walk onto mats. Time_Loc~s_ _ Code Subcode T COM Depth Phase ur Depth E D S Date Eror.~ Te 10/06/2006 00:00 _ 04:30 . _ _ 4.50 , 120 _ _._ 120 _ _ MIRU _ MOVE MOB P _ _ _ Spot module next to mats pre set f/ 1J-182. Set module down, remove drag link equalizer bars, turn tires to crab onto the mats. Lay more mats, Lay dunage (Ramp) to walk onto mats. Stop 15' from drilling module. Work on ri h draulic s stem. 04:30 04:45 0.25 120 120 MIRU MOVE RGRP P PJSM on hanging windwall ~ derrick board. 04:45 08:30 3.75 120 120 MIRU MOVE RGRP P Hang windwall @ derrick board. 08:30 10:00 1.50 120 120 MIRU MOVE PSIT P PJSM, then spot rig over well 1J-182. Close cellar doors. 10:00 12:00 2.00 120 120 MIRU MOVE PSIT P Move pit module into position. Set down. 12:00 13:15 1.25 120 120 MIRU .MOVE SKID P PJSM, then skid rig into drilling osition. 13:15 15:00 1.75 120 120 MIRU MOVE RURD P Move rockwasher into place. PU drilling nipple. Connect steam, mud and air lines. -15:00 16:30 1.50 120 120 MIRU MOVE KURD P Conriect steam, mud and air lines. 16:30 17:00 0.50 120 120 MIRU WELCT NUND P Install one joint of diverter line. Orient - Diverter system to exit cellar through _ _ hole in windwall. Weld on beaver slide. Hooking uP flowline between drilling and it module. 17:00 18:00 1.00 120 120 MIRU WELCT NUND P Install drilling nipple. RU flowline, attatch turnbuckles. Attatch hole fill. 18:00 23:00 5.00 120 120 MIRU WELCT NUND P Continue nippling up diverter equipment. Bring water into pits to begin mixing spud mud. Install auger shaft f/ cuttings tanks in rockwasher. Continue NU Diverter system. Put steam, air and water on line to pit complex: Measure RKB. Berm around sub. Install 4" valves to oulets on conductor. 23:00 00:00 1.00 120 120 MIRU MOVE RGRP P Install auger shaft in rockwasher to cuttings tanks. Continue mixing spud mud. Load BHA in pipe shed. Change saver sub on top drive f/ 4" XT-39 to 4-1/2"IF. 10/07/2006 00:00 01:00 1.00 0 0 MIRU MOVE RGRP P Install 4" valves and plugs on (2) 4" outlets on 20" conductor. Continue mixing spud mud. Load BHA in pipe shed. Changing saver sub on top drive f/ 4" XT-39 to 4-1/2" IF, Measure rig floor to ground level. PU and organize around ri . Page 2 of 6~ ~ ! Time Low ~ -- - To Dur S_ ~ePth E DEpth Fhase Code___Subcode T _ COM _, __ __i Date From _ 10/07/2006 01:00 06:00 5.00 0 0 MIRU MOVE ' RGRP P Load 44 joints of 5"drill pipe into pipe shed. Continue installing auger in rockwasher. Spot cuttings tanks, berm around tanks and rockwasher. Continue berming around rig. Continue mixing spud mud. Continue PU and cleaning around rig. Note: Ri acce ted 0300 hrs 10/7/06. 06:00 07:30 1.50 0 0 MIRU MOVE KURD P Continue berming rig and rockwasher. Strap pipe in derrick. Getting spud mud ready and work on rig acce tance checklist. 07:30 09:30 2.00 0 0 MIRU DRILL PULD P UDjars in derrick and replace w/ new ones: Put more.. 5" dp in pipe shed. Finish pre spud cheek list. PU tools and equipment thafwere used on rig move. 09:30 1200 2.50 0 0 MIRU DRILL PULD P PU 5"drill pipe, strap in derrick. Rig went on Hi-Line 1000 hrs.. 12:00 15:15 3.25 0 0 MIRU .DRILL PULD P Continue PU 5" drill pipe. Strap pipe in derrick. Rabbit pipe to 2.91". Picked up 43 stands. Total of 64 stands 5" in derrick. 15:15 16:15 1.00 0 0 MIRU DRILL PULD P PU/MU 4 stands of 5" HWDP, rabbit to 2.33". Strap in derrick. Total of 7 stands 5" HWDP in derrick (includes ars . 16:15 16:45 0.50 0 0 MIRU WELCT BOPE P RIH to 92', Function test diverter system. Annular takes 30 seconds to close, 3 sec f/ knife valve to open. Test as alarms. 16:45 17:00 0.25 0 0 MIRU WELCT ROPE P PU 16" bit, bit breaker, and misc. subs while performing accumulator test. Starting pressure 2950 psi. Manifold pressure 1300 psi after closing. 200 psi builup in 32 seconds. Full charge in 2 min 13 seconds. 5 Nitrogen bottles, average presssure 2400 si. 17:00 17:15 0.25 0 0 SURFA DRILL SFTY P PJSM on rig up Sperry Sun gyro. Han sheave in derrick. 17:15 17:30 0.25 0 0 SURFA DRILL RURD P Rig up Sperry Sun gyro: Hang sheave in derrick. 17:30 17:45 0.25 0 0 SURFA DRILL SFTY P PJSM on picking up BHA #1. 17:45 19:30 1.75 0 0 SURFA DRILL PULD P PU/MU BHA #1: MU 16" Hughes MX-1 bit, 8" Sperry Sun SperryDrill lobe 4/5-5.3 stage w/ 1.83 deg bend, 12-1/4" Welded blade stabilizer, 8" directional, NM UBHO, NM Float sub, x-o, then 5"HWDP. 19:30 20:15 0.75 0 0 SURFA DRILL SFTY P Review and hold diverter drill with all personal on rig. Response time 1 min 35 sea 20:15 21:15 1.00 0 0 SURFA DRILL CIRC P Fill conductor w/water. Check surface equipment for leaks. Pressure test mud line to 3500 si. -- -- - P~ge 3 of 69 t- -- --- - --- _ ___ ___ __- __ _ - -- _ _ ________-____ Time Loss -~ - - -- __ _ ~' Date From To Dur S._Depth_ E De~th_Phase Code __ Subcode T CQM _ I 10/07/2006 21:15 21:30 0.25 0 0 SURFA DRILL CIRC P RIH and tag bottom @ 11T, clean out conductor to 121', swap to 8.7 ppg s ud mud w/ 350 vis. 21:30 00:00 2:50 0 189 SURFA DRILL DRLG P Drill 16" surface hole f! 121.' to 489'. 121' to 160': Pumping 550 gpm w/ 1100-1200 psi. Rotate 40 rpm w! 2k ft Ib torque. 160' to 189': Pumping 550 gpm w/ 1150-120 psi. Sliding. Bit hours 1.99 hrs, ADT= 1.99 hrs, ART= .80 hrs, AST = 1.19 hrs, total 'ar hours =88.78 hrs 10/08/2006 00:00 01:15 1.25 189 250 SURFA DRILL DRLG P Directional Drill 16"surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend-f/ 189' to 250' (61') Bit hours= 3.02, Jar hours = 88.78, ART .81 hrs, AST .22 hrs, WOB 4-10k, 0-40 rpm, 550 gpm.@ 1200 psi on bottom and 1150 psi off bottom. Torque = 2k ft-Ibs on botttom and 2k ft-Ibs off bottom. P/U = 85k, S/O = 85k, Rot= 85k w/pumps off. Note: KOP @ 160'. Rotate f/ 121' to 160', slide f/ 160' to 225', rotate f/ 225' to 250'. Running Sperry Sun gyro's, w/ Sperry Sun wireline unit 3/16" wireline . 01:15 01:45 0.50 250 67 SURFA DRILL TRIP P Monitor well. POOH f/ 250' to 6T. Stand back 2 stands of 5" HWDP. 01:45 02:15 0.50 67 67 SURFA DRILL PULD P Break out and UD x-o, float sub, and UBHO sub. 02:15 02:45 0.50 67 67 SURFA DRILL PULD P PJSM for handling and working w/ S er Sun EMS surve tool 02:45 04:30 1.75 67 250 SURFA DRILL PULD P PU/MU Sperry EMS tool, antenna, x-o, UBHO sub, (3) NMDC's, jars and 2 5" HWDP. 04:30 06:00 1.50 250 335 SURFA DRILL DDRL P Directional Drill 16" surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 250' to 335' (85') Bit hours= 3.66, Jar hours = 89.42, ART 0 hrs, AST .64 hrs, WOB 20-30k, 0 rpm, 500 gpm @ 1300 psi on bottom and 1150 psi off bottom: Torque = 2k ft-Ibs on botttom and 2k ft-Ibs off bottom. P/U = 85k, S/O = 85k, Rot= 85k w/ pumps off: Note: KOP @ 160'. Running Sperry Sun gyro's, w/ Sperry Sun wireline unit (3/16"wireline). - - - ', _-__i~a~e ~ of 63- • Time Lois - - -. Date From To Dur De th- S E Depth Phasa Code Subcode T COM 10/08/2006 06:00 12:00 6.00 . 335 570 SURFA DRILL DDRL P Directional Drill 16"surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 335' to 570'. (85') Bit hours= 5.56, Jar hours = 91.32, ART 1.09 hrs, AST .81 hrs, WOB 20-25k, 50 rpm, 513 gpm @ 1400 psi on bottom and 1350 psi off bottom. Torque = 2-3k ft-Ibs on botttom and 3-4k ft-Ibs off bottom. P/U = 115k, S/O = 110k, Rot= 110k w/pumps off. Note: KOP @ .160'. Running Sperry Sun gyro's, w/ Sperry Sun wireline unit (3/16" wireline). Last gyro questionable, run again to verify 1st. No si nificant chan e. 12:00 13;15 1.25 570 570 SURFA DRILL CIRC T Circ, wait on orders. Pumping 516 gpm w/ 1440 psi, rotate 50 rpm w/ 2-3 ft Ibs for ue. 13:15 13:45 0.50 570 570 SURFA DRILL OTHR T Blow down top drive. Tie back block han in line in derrick. 13:45 14:30 0.75 570 265 SURFA DRILL TRIP T PJSM. Pull out of hole to take gyro surveys. POOH to jars. Jars hung on conductor. La down 'ars. 14:30 16:30 2.00 265 0 SURFA DRILL TRIP T POOH w/ BHA #1. 16:30 17:00 0.50 0 0 SURFA DRILL PULD T Break off bit. UD motor and MWD. 17:00 17:30 0.50 0 0 SURFA DRILL OTHR T Clean and clear rig floor. PU bit sub. 17:30 17:45 0.25 0 0 SURFA DRILL SFTY T PJSM on picking up BHA #2. 17:45 19:15 1.50 0 570 SURFA DRILL TRIP T PU/MU BHA #2, RIH to 570', taking gyro surveys @ 100', 200', 300', 400', 450', 500', 54T. PJSM f/ POOH w/ BHA #2. 19:15 21:15 2.00 570 0 SURFA DRILL TRIP T POOH. w/ BHA #2 after running gyro surve s. Grade bit. 21:15 21:30 0.25 0 0 SURFA DRILL SFTY T PJSM on picking up BHA #3. 21:30 22:15 0.75 0 112 SURFA DRILL PULD T PU/MU BHA #3: Bit, sperryDrill motor w/ 1.83 deg bend, 12-1 /4" welded blade stabilizer, MWD, nm flaot sub, 8" NMDC, nm x-o, Sperry Sun 8" EMS survey tool, 8" antenns, nm x-o to 112': Stabbing board platform fell to floor, hit a floorhand. 22:15 00:00 1.75 112 112 SURFA DRILL SFTY T Take-care of injured employee, called f/ambulance. and took injured to KOC medical facility. Incident investigation of accident w/CPAI co man, DDl tool pusher, DDI drilling supt, CPAI drilling Safet re ,DDI HSE re . I ~dt,1~ 1^J Uf I Time Logs ,Date From To Dur S. D~h_E. De th °hase r/cde-. Subcode T_COM __ __ ~ 10/09/2006 00:.00 06:00 6.00 112 112 SURFA RPCOly SFTY T Take care of injured employee, called f/ambulance and took injured to KOC medical facility. Incident investigation of accident w/CPAI co man, DDI tool pusher, DDI drilling supt, CPAI drilling Safet re ,DDI HSE re ; 06:00 07:30 1.50 112 112 SURFA RPGOh SFTY T Safety stand down with both drilling crews and sere co re s. 07:30 08:30 1.00 112. .112 SURFA DRILL OTHR T Build and replace damaged floorplate on ri floor. 08:30 09:30 1.00 112 360 SURFA DRILL TRIP T Continue MU BHA #3. RIH w/flex DCs, orient UBHA, trip in to 360'. PU wt 105k, SO wt 90k. 09:30 10:00 0.50 360 360 SURFA DRILL OTMR T Fill pipe, break circ, survey. 10:00 16:30 6.50 360 570 SURFA DRILL REAM T Trough/ream hole to knock down angle of hole f/ 420' to 570'. Trough and ream 16"surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 420' to 570' (150') Total hrs on bit= 5.56 hrs, WOB 10-20k, 50 rpm, 640 gpm @.1900 psi on bottom and 1850 psi off bottom. . Torque = 3k ft-Ibs on botttom and 2k ft-Ibs off bottom. P/U = 110k, S/O = 110k, Rot= 110k w/ um soff. 16:30 18:00 1.50 570 700 SURFA DRILL DDRL P Directional drill 16" surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 570' to 700' (130') Total hrs on bit= 6.71 hrs, Bit hours this run = 1.15, Jar hours = 1.15, ART .25 hrs, AST .90 hrs, WOB 20-30k, 50 rpm, mtr rpm 165, 634 gpm @ 2080 psi on bottom and 2000 psi off bottom. Torque = 4k ft-Ibs on botttom and 3k ft-Ibs off bottom.. P/U = 110k, S/O = 110k, Rot= 110k w/ um soff. 18:00 21:45 3.75 700 920 SURFA DRILL DDRL P Directional drill16" surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 700' to 920' (220') Total hrs on bit= 8.35 hrs, Jar hours = 2.79 hrs, ART .43 hrs, AST 1.21 hrs, WOB 20-30k, 50 rpm, mtr rpm 175, 675 gpm @ 2070 psi on bottom and 2000 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 3k ft-Ibs off bottom. P/U = 125k, S/O = 125k, Rot= 110k w/ um soff. 21:45 22:00 0.25 920 740 SURFA DRILL TRIP P Pull a stand to 740' to wipe hole to decrease a 7.5 de do le . 22:00 00:00 2.00 740 820 SURFA DRILL REAM P Trough hole f/ 73T to 820' to decrease hole an le. 10/10/2006 00:00 01.:00 1.00 820 920 SURFA DRILL REAM P Trough hole f/ 820' to 920' to decrease hole an le. -.------ -------...----- --....... _.._---_ __. r~dtji~ b i7t UQ • • Time Logs ~-Date From To Dur S:.Je~th E.De th Phase _ Code Subcode_ _ T COM ' _ - - 1 0/1 0/2006 01:00 02:00 1.00 920 1,015 SURFA DRILL DDRL P Directional drill 16" surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 920' to 1015' (95') ND = 1003'.Total hrs on bit= 9.5 hrs, Jar hours = 3.8 hrs, ART .43 hrs, AST .67 hrs,. WOB 20-30k, 50 RPM, Motor RPM - 175, 675 gpm @ 21.00 psi on bottom and 2040 psi off bottom. Torque = 3-4k ft-Ibs on botttom and 3k ft-Ibs off bottom. P/U = 140K, S/O = 125K, ROT WT= 110K w/pumps off. Mud. Wt = 9.2 PPG, Visc = 275, YP = 56, PV = 32. 02:00 02:45 0.75 1,015 1,015 SURFA DRILL SRVY P WLIH with GYRO survey. Obtain final GYRO survey as per DD. Bit depth = 1015' MD. WLOH. RD wireline & GYRO unit, while change out & clean. screens on both mud um s. 02:45 06:00 3.25 1,015 1,277 SURFA DRILL DDRL P Continue Directional drill 16" surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 1015' - 1277 MD (262') ND = 1240':Total hrs on bit= 11.10 hrs, Jar hours = 5.54 hrs, ADT = 3,58 HRS, ART .83 hrs, AST 2.75 hrs, WOB 20-35K, 50 RPM, Motor RPM - 161, 620 gpm @ 2290 psi on bottom and 2000 psi off bottom.. Torque = 3-4k ft-Ibs on botttom and 3k ft-Ibs off bottom. P/lJ = 135K, S/O = 125K, ROT WT= 130K w/pumps off. AVG Gas observed = 20 Units. Mud Wt = 9:2 PPG Visc = 250 YP = 53 PV = 33 Gels @ 35/67/75. Crew Chan e 06:00 07:00 1.00 1,277 1,339 SURFA DRILL DDRL P Continue Directional drill 16" surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 1277 1339' MD (62') ND _ 1293':Total hrs on bit= 11.70 hrs, Jar hours = 6.14 hrs, ADT = .60 HRS, ART .18 hrs, AST .42 hrs, WOB 20-30K, 50 RPM, Motor RPM -164, 630 gpm @ 2100 psi on bottom and 2050 psi off bottom. Torque = 3-5k ft-Ibs on botttom and 3k ft-Ibs off bottom. P/U = 135K, S/O = 125K, ROT WT= 130K w/ pumps off. AVG Gas observed = 26 Units. Mud Wt = 9.3 PPG, Visc= 360, YP = 56 PV = 32 Gels @ 35/67!75. Survey @ 1250.69' MD 121T ND, INC = 28.41 DEG, AZ = 206.24 bEG. 07:00 07:30 0.50 1,339. 1,339 SURFA DRILL CIRC P Circulate & condition mud due to thick mud and clay. Pumps at 650 GPM's 2200 PSI. Reciprocate & rotate drill strip while um in . - -- - Pag~ 7 c,f 59 • Time Logs ' F T r D S De th De th E Phase Cede Subcode T COM -Date 10/10/2006 rorn 07:30 o 12:00 u 4.50 : p 1,339 _ 1,770 -. SURFA . DRILL DDRL _ _ P _ _ _ Continue Directional drill 16" surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 1.339' - 1770' MD (431') ND = 159T.Total hrs on bit= 14.76 hrs, Jar hours = 9.20 hrs, ADT = 3.06 HRS, ART 1.06 hrs, AST 2.00 hrs, WOB 25-30K, 50 RPM, Motor RPM - 169, 650 GPM's @ 2600 psi on bottom and 2500 psi off bottom. Torque = 6-7K ft-Ibs on botttom and 4-5K ft-Ibs off bottom. P/U = 135K, S/O = 125K, ROT WT= 130K w/.pumps off. AVG Gas observed = 66 Units. Mud Wt = 9.2 PPG, Visc = 360 YP = 56 PV = 33 Gels 35/67/75. Survey @ 1726.° MD 1573° ND, INC = 51.,15 DEG, AZ = 206,72 DEG. 12:00 18:00 6.00 1,770 2,289 SURFA DRILL DDRL P Continue Directional drill 16" surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 1770' - 2289' MD (b19') ND = 1801'.Total hrs on bit= 18.36 hrs, Jar hours = 12.80 hrs, ADT = 3.60 HRS, ART 1.28 hrs, AST 2.32 hrs, WO6 25-30K, 50 RPM, Motor RPM - 176, 680 GPM's 2350 psi on bottom and 2300 psi off bottom. Torque = 7-8K ft-Ibs on botttom and 4-5K ft-Ibs off bottom. P/U = 145K, S/O = 115K, ROT WT= 122K w/ pumps off, AVG Gas observed = 72 Units. Mud Wt = 9.3 PPG, Visc = 340 YP = 50 PV = 30 Gels @ 23/62/80. Survey @ 2202.30' MD 1780' ND, INC = 73.96 DEG, AZ = 195.42 DEG. 18:00 00:00 6.00 2,289 2,793 SURFA .DRILL DDRL P . Continue Directional drill 16" surface hole w/ 8"SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 2289' - 2793' MD (504') TVD = 1934'.Total hrs on bit= 22.09 hrs, Jar hours = 16.53 hrs, ADT = 3.73 HRS, ART 2.31 hrs, AST 1.42 hrs, WOB 25-30K, 50 RPM, Motor RPM - 176, 680 GPM's @ 2350 psi on bottom and 2300 psi off bottom. Torque = 8-9K ft-Ibs on botttom and 6-7K ft-Ibs off bottom. P/U = 135K, S/O = 110K, ROT WT= 120K w/ pumps off. AVG Gas observed = 71 Units. Mud Wt = 9.5 PPG, Visc = 220 YP = 54 PV = 30 Gels @ ' 23/62!80. Survey @ 2488.25' MD 1855' ND, INC = 74.98 DEG, AZ = 192.26 DEG. Crew Chan e - Pale 3 of 69_; ~ - -- _- __ _ - ----------- __ _ ---------- -- ---- • • Time Lo s ~ Date _ From. To- Dur S. Depth E. tt~ ~Phase_ _ Code _Subcode T COM 10/11/2006 00:00 06:00 6.00 2,793 3,113 SURFA DRILL DDRL P Continue Directional drill 16"surface hole w/ 8"SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 2793' - 311.3' MD (320') ND = 2018'. Total hrs on bit=25.71 hrs, Jar hours = 20:15 hrs, ADT = 3.62 HRS, ART 2.53 hrs, AST 1.09 hrs, WOB 10-30K, 50'RPM, Motor RPM - 176, 680 GPM's @ 2420 psi on bottom and 2300 psi off bottom. Torque = 8-9K ft-Ibs on botttom and 7-8K ft-Ibs off bottom. P/U = 145K, S/O = 110K, ROT WT= 122K w/pumps off. AVG Gas observed = 82 Units: Mud Wt = 9:5 PPG, Visc = 220 YP = 54 PV = 30. Survey @ 3060.06` MD 2004' ND,: INC = 74.55 DEG, AZ = 188.86 DEG. 06:00 12:00 6:00 3,113 3,400 SURFA DRILL DDRL P- Continue Directional drill 16" surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 3113° - 3400'. MD (28T) ND = 2079'. Total hrs on bit= 29.98 hrs, Jar hours = 23.88 hrs, ADT = 3.73 HRS, ART 2.31 hrs, AST 1.42 hrs, WOB 10-30K, 50 RPM, Motor RPM - 176, 680 GPM's @ 2425 psi on bottom and-2300 psi off bottom. Torque = 8-9K ft-Ibs on botttom and 7-8K ft-Ibs off bottom. P/U = 145K, S/O = 109K, ROT WT= 122K w/ pumps off. AVG Gas observed = 69 Units. Mud Wt = 9.35 PPG, Visc = 220 YP = 54 PV = 30. Survey @ 3343.91° MD 2067 ND, INC = 77.81 DEG, AZ = 193.02 DEG: 12:00 17:00 5.00 3,400 3,690 SURFA DRILL DDRL P Continue Directional drill 16" surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 3400'- 3690' MD (290') ND = 2153'. Total hrs. on bit= 32.00 hrs, Jar hours = 26.44 hrs, ADT = 2.52 HRS, ART :31 hrs, AST 2.21 hrs, WOB 10-30K, 50 RPM, Motor RPM -176, 680 GPM's @ 2425 psi on bottom and 2300 psi off bottom. Torque= 8-9K ft-Ibs on botttom and 8-9K ft-Ibs off bottom. P/U = 165K, S/O = 95K, ROT WT= 125K w/'pumps off. AVG Gas observed = 80 Units. Mud. Wt = 9.25 PPG, Visc = 200 YP = 50 PV = 28. Survey @ 3627.32' MD 2139' ND, INC = 75.85 DEG, AZ = 192.86 DEG. TD @ 3690' MD as er DD & Co. Re . - - - Page 9 cif 89~ -- Time L~ _ --__ --- -----1 'Date From To _ Dur S _ Depth E_ Depth _ Phase Cody Suhcode _ T C0~:1-__ _ ' - -_ - - _ - 10/11/2006 17:00 18:00 1.00 3,690 = 3,690. SURFA DRILL CIRC P Reciprocate & rotate drill string while circulating & conditioning hole for casing run. Pumps @ 680 GPM's - 2100 PSI. Rotating @ 50 RPM's. UP WT = 145K, SO WT = 120K, ROT WT = 126K. Torque = 8-10K. Crew Chan e. 18:00 20:30 2.50 3,690 2,730 SURFA DRILL REAM P BROOHfrom 3690' - 2730' MD of 35 -45 FT/Min: with pumps at 680 GPM's - 2100 PSI. 50 RPM's Observe hole in good shape with avg upweight of 135K. Pro er hole fill 20:30 21:45 1.25 2,730 2,730 SURFA RIGMN RGRP T Remove old Totco screen from drilling console as it failed. Install new one. .Communicate with town rep to reset & calibrate unit to communicate with main frame. Reciprocate & rotate dill string. with-full pumps @ 680 GPM's while moving up, cutting back to 350 GPM's when slacking off. Observe 10 BBIs loss in 1.25 HRS: 21:45 00:00 2.25 2,730 1,779 SURFA DRILL REAM P Continue BROOH from 2826' -1779' MD at 35 -45 FT/Min. with pumps at 680 GPM's - 2100 PSI. Observe hole in good shape with avg upweight of 135K. Pro er hole fill. 10/12/2006 00:00 01:15 1.25 1,779 1,209 SURFA DRILL REAM P Attempt to POOH on elevators, observe swabbing. Work Drill string. Could not pull on elevators. Continue BROOH 5 more stands from 1779' - 1209' MD. 50 RPM's with pumps at 300 GPM's - 780. PSI. 01:15 03:30 2.25 1,209 214 SURFA DRILL TRIP P Monitor well -static. Blow down Top drive & lines. POOH on elevtators from 1209' - 214' MD. Rack back 20 - 5" HWDP 614.46' . 03:30 04:15 0.75 214 68 SURFA DRILL PULD P Raek back Dai-ey Combo Drilling Jars (40.27). rack back 3 - 8" Non Mag Flex drill Collars. (92.71'). Braeak out & lay down 8" UBHO Sub (3.39'), Non Mag Crossover Sub (2.75'), 8"Antenna (3.16'), EMS Survey Tool (2.09'), Non Ma Crossover Sub 2:51' . 04:15 04:30 0.25 68 68 SURFA DRILL PULD P Plug in and download MWD assembl . 04:30 06:00 .1.50 68 0 SURFA DRILL PULD P Continue POOH breakout & lay down 8" Non Mag Float Sub (2.40'), 8'° Directional MPT (4.93'), 8" Welded Blade Stabilizer (4.93'), 8" SperrDrill lobe 4/5 5.3 Stage (30.82'), and 16" Hughes MX-1 bit (1:39'). Inspect & grade bit to 3/3MIT/A/E/1/8/ER/TD. Clean & clear Ri Floor area. - _ - Page °i~ of 9 • Time Logs ~> Dafe From To Dur 5. Depth E Dzpt_h Phase Code _Subcode T__COM _ _. 10/12!2006 06:00 12:00 6.00 0 0 SURFA CASIN( RURD P Continue clean & clear rig floor. Rig up stabbing board in derrick, and pull casing equipment to rig floor. Rig all 13 3/8" casing running equipment as per GBR rep. Change out bales on Top Drive to long bales. Make up Franks fill u tool 12:00 12:30 0.50 0 0 SURFA CASIN( KURD P Continue prep rig floor for 13 3/8" casin run. 12:30 12:45 0.25 0 0 SURFA CASWC SFTY P Held PJSM with entire rig crew,.TP, Co. Rep, &GBR reps. Discuss safety issues and procedures for making Up, and runnin 13 3/8" casin . 12:45 18:00 5.25 0 1,088 SURFA CASINC RNCS P Make up 13 3/8"joint with Weather ford model 303 Float Shoe, 2 -joints 13 3/8" casing with Weatherford Model 402 Float collar installing Bow spring centralizers on shoe track joints. Continue make up & RIH with 13 3/8" casing installing centralizers on each joint up to # 17 as per detail, observing tagging up and trouble getting pipe in hole without pumping joints down. Observed lots of cuttings across shakers, pumping at 5 BPM to get i e in hole. 18:00 00:00 6.00 1,088 3,210 SURFA CASIN( RNCS P Continue make up & run 13 3/8" casing working string when tagging up, filling each joint, with continued circulation. Observed hanging up on either the bottom of the 20" .conductor, or in the diverter adapter assembly when working string. Obtain up & down weights every 5 joints as per rig engineer. We had to pull up to 70K over a couple of times to free the collar from the bottom of the conductor, Run casing from 1088' - 3210'. Observe 52 BBIs loss while runnin in hole.. 10/13/2006 00:00 03:00 3.00. 3,210 3,677 SURFA CASINC RNCS P Continue make up & run 13 3/8" casing working string when tagging up, filling each joint, with continued circulation. Observed hanging up on either the bottom of the 20" conductor, or in the diverter adapter assembly when working string. Obtain up & down weights every 5 joints: as per rig engineer. We had to pull up to 70K over a couple of times to free the collar from the bottom of the conductor. Make up Casing hanger & landing joint as per Vetco Gray reps. Run casing from 3210' - 3677 MD. Casing landed" in hanger @ 0300 HRS. Observe 52 BBIs loss while runnin in hole. _- _-- ' Page 11 e~<09_ • Time Los _ ( Date From To ^ur S Cie th E:_Depth_ Phase__Code Subcode T COM __ __ 10/13/2006 03:00 04:00 1.00 3,677 3,677 SURFA CASINC RURD P Rig down GBR casing equipment & clear floor area. Rig down Franks fill up tool, installing loaded cement head & lines. 04:00 06:00 2.00 3,677 3,677 SURFA CASIN( CIRC P With casing landed in hanger, establish circulation, begin pumping mud at 2 BPM - 180 PSI, staging to 3 BPM - 250 PSI, 4 BPM - 300 PSI, 5 BPM - 275 PSI, 6.5 BPM - 300 PSI. Attempt to work casing string in a 10' stroke after pumping 100 BBL& observing pipe hanging up. Leave casing landed until bottoms up with conditioned mud in hole. Mud @ 9.4 PPG, Visc = 54, YP = 17. On bottoms up, work casing string in small increments to gain 10 ft strokes. Hole condition good, but observed hanging up mechanically in the conductor. 06:00 06:15 0.25. 3,677 3,674 SURFA CASINC CIRC P Continue Circulate & reciprocate casing string in 10 foot strokes with pumps at 6.5 BPM.- 300 PSI. No Fluid loss while pumping. Observe casing hung up 4' off bottom and efforts to gef hanger back in slips failed. Movement of strin ceased. 06:15 10:15 4.00 3,674 3,674 SURFA CASINC CIRC P Continue circulate & condition mud for cement job. Mud properties = 9.2 PPG, 16 YP, viscosity = 50 with Gels @ 6/7. Rate @ 4 BPM - 225 PSI. 10:15 10:30 0.25 3,674 3,674 SURFA CEME~ SFTY P Held PJSM with entire rig crew and Schlumberger cemenf crew with all truck drivers. Designate a spill champion, discussing safety & spill issues and procedure for pumping cement 'ob. 10:30 11:00 0.50 3,674 3,674 SURFA CEMEh CIRC P Contniue circulating conditioning mud for cement job while Cementers ri in u and batch mixin . __ __._ P~ge'1~of69 Time Low __ - _ _ -- --~ _ _ Date From -- To Dur S De th E Depth Phase Code Subcode - T COM _ __ __ _ _ __ -~ 10/13/2006 _ _ 11:00 _ _ 13:30 2.50 3,674 3,674 SURFA CEMEM1 DISP P Turn rig over to Dowell Cementers. Fill lines and pump 5 BBLs CW100 @ 5 BPM - 45 PSI. Pressure test lines to 3500 PSI -good test. Continue pump 35:5 BBLS of CW100 @ 5 BPM - 65 PSI. Pump 50 BBLs of 10.5# Mudpush @ 5 BPM - 75 PSI. Drop bottom plug. Pump 575 BBLS of lead cement 10.7 PPG @ 6.5 BPM -150 PSI. Continue pump 94 BBLS of Tail Cement 12.0 PPG @ 6.9 BPM - 120 PSI .Shut down Drop Top Plug. pump 20 BBLS of 8.3 PPG fresh water to flush lines. Turn over to rig for displacement. Once again, no movement on casing string while. um in . 13:30 15:15 1.75 3,674 3,674 SURFA CEME~ DISP P With rig pump, displace cement with 514.5 BBLS -bumping plug at 5110 Strokes. pumps were slowed to 3 BPM - 750 PSI before bump, bump plug and continue pressure to 1300 ' PSI, shut down -hold pressure 15 minutes. Bleed pressure and check floats. Floats held. Observed a total of 185 BBLS of cement to surface with a good cementjob. Cement in place @ 14:52 HRS. 15:15 18:00 2.75 0 0 SURFA CEME~ RURD P Bleed all pressure and drain lines. Rig down cement head, wash & clean same. Nipple down Diverter line, and continue rig up equipment to nipple down to set emergency slips.Crew Chan e 18:00 22:30 4.50 0 0 SURFA CEME~ RURD P H3eld PJSM with rig crew & Vetco reps. Discuss safety issues and procedure for rigging & nippling down for setting slips. Continue rig up equipment, back out set screws on diverter head. Lift Riser &Diverter system with bridge cranes. Clean off cement in bowl, wash & remove fluids from cellarbox. Rig up Porta Power rams with pump to push Casing string to center of bowl with 300K pulled on string with Top Drive & Blocks. Set Slips, slack weight off to zero as per Vetco Gra re s. 22:30 00:00 1.50 0 0 SURFA CASIN( RURD P Rig down Casing elevators, and rig up on landing joint with Tugger. Obtain Hot Work Permit. With Rig Welder, make casing cut 9" above shoulder. Pull and lay down landing joint. Rig down equipment used to center string and casing equipment. Breakout & lay down han er on landin 'oint. --- _ rage 13 ~f 69 ~ Time Logs -- _. Dur S_ Depth_ E-De th Phase Code _ Subcode T COM _ - To 'Date From _ _ 10/14/2006 00:00 03:30 3.50 0 0 SURFA CASINO RURD P Breakout & lay down Riser. remove from cellar. Set Diverter system on wellhead with adapter. Re-rig slings. Pick up and reposition diverter system in the back of the cellar. 03:30 06:00 2.50 0 0 SURFA CASIN( NUND P Break connections on Diverter system. With Rig welder, dress top of conductor for welding adaptor head on. Set transition nipple on wellhead and weld up nipple as per rig welder & Vetco rep. Firewatch hand on standby. SIMOPS: Clean pits, and clean & clear rig. floor area. Lay down elevators and long bales. Rig up Short bales. Crew Chan e 06:00 09:30 3.50 0 0 SURFA CASIN( NUND P Continue ND Diverter system. Breaking connections on Knife valve. "T"spool and on annular. Complete welding on transition nipple for wellhead. Continue clean & clear rig floor area and rig. up to pick up 5" DP for intermediate hole section. Inspect and adjust pipe skate, and lubricate chain. 09:30 12:00 2.50 0 0 SURFA CASINO RURD P Pick up 5"drill pipe frompipe shed: Rack back in derrick. Waiting on transition ni le to cool. off. 12:00 13:45 1.75 0 0 SURFA CASIN( RURD P Pick up 5" drill pipe from pipe shed. Waiting on transition nipple to cool off. Total of 36 more stands of 5" picked up and racked in derrick for a total of 100 stands. . 13:45 14:00 0.25. 0 0 SURFA RIGMN SFTY P Held PJSM with rig crew: Discuss safety issues and procedure for servicing Top Drive, and performing a Derrick ins ection. 14:00 16:00 2.00 0 0 SURFA RIGMN SVRG P Service Top Drive. Perform Derrick ' inspection. Allow transition nipple to cool 16:00 16:45 0.75 0 0 SURFA CASIN( NUND P Installl7etco Gray Socket weld adapter & test same as per Vetco rep. Test to 1800 PSI, hold for 10 minutes. 16:45 17:15 0.50 0 0 SURFA CASINO NUND P Held PJSM: Discuss safety issues and procedure for instating head. Set Vetco Gray Multibowl wellhead in the cellar. 17:15 18:00 0.75 0 0 SURFA CASIN( NUND P Install Vetco Gray Multi bowl wellhead on the transition nipple. Orient wellhead. Test Locator seal ring as per Vetco rep to 5000 PSI for 10 minutes. Good test. Crew Chan e -- Time Logs --' Date From To Dur S. Depth E-_Depth Pnase _Code Subcod_e_ T COM __ 10/14/2006 18:00 22:00 4.00 0 0 SURFA WELCT NUND P Held PJSM with crew. Discuss safety issues and procedure for changing out bridge crane cable and nippling up BOP's. Rig up and change out cable on drillers side bridge crane. in cellar.. Install Spacer pup on choke line. Pull Flow nipple, wear bushing,-test plug, and wear bushing puller to rig floor. Nipple up high pressure riser to drilling s ool. 22:00 00:00 2.00 0 0 SURFA WELCT NUND P Held PJSM. Discuss safety issues for NU BOP's. Pick up and nipple up BOP's. 10!15!2006 00:00 03:30 3.50 0 -0 SURFA WELCT NUND P Continue nipple up BOP stack & lines. Nipple up annulus valves on drilling spool. Pull 7 5/8" rams out, install 9 5/8" rams in top set. inspect wear plates in body- good. Install mousehole. 03:30' 06:00 2.50 0 0 SURFA WELCT NUND P Rig up flowlines, hole fill line and turnbuckles. Rig up chart recorder and pressure lines to test BOP's. Crew Chan e. 06:00. 07:00 1.00 0 0 SURFA WELCT NUND P Continue-rig up lines for testing. Install test plug with test joints per Vetco Gra re .RILDS. 07:00 09:30 2.50. 0 0 SURFA WELCT ROPE P Test BOP's with 5" DP. & floorbalves. Low pressure test to 300 PSI, High - pressure test to 3000 PSI. AOGCC rep John Crisp waived witness of test 1900 HRS 10/14/06. 09:30 10:15 0.75 0 0 SURFA WELCT BOPE P - Pull 5" test joint. Make up 9 5/8" casing to test lower rams. test 9 5/8 rams to 300 PSI low pressure, 3000 PSI for hi h ressure. 10:15 12:00 .1.75 0 0 SURFA WELCT BOPE P Complete BOP testing with all test recorded on chart. perform Accumulator draw down test. Accumulator bled to 1600 PSI when equipment functioned. Build pressure to 1800 PSI in 40 seconds and then full pressure to 2925 PSI in 2 minutes 42 seconds. Record average nitrogen bottle pressure,of 5 bottle @ 2375 PSI each. 12:00 14:15 2.25. 0 -0 SURFA WELCT NUND P Pull Belay down test joint & test plug. Install wear bushing as per Vetco Gray rep. RILDS. Rig down all testing equipment. Rig up and fill hole with mud checking forany system leaks in flowlines. All good. Clear & clean rig floor. Pull all tools to rig floor for BHA make u . 14:15 14:30 0.25 0 0 SURFA DRILL SFTY P Held PJSM with crew, Sperry Sun reps. Discuss safety issues and rocedure for makin u BHA #4. -- Page 15 of 69 Time Logs - - Date From To D_ur S D~th _E_ Depth Phase _ Code. _ Su_bco~e T _ - COM _ _- _ - - - -- - - 10/15l2006 14:30 16:45 2.25 0 89 SURFA DRILL PULD P Make up BHA #4 as per DD's and MWD reps. Make up 12 1/4" Hughes HCR605 Bit with jets of 3x13's, 4x14's for a TFA of .990 sq. in. (1.14'), 8" SperryLobe 4/5 - 5.3 stage with 1.5 Deg Bend (30.80'), 8" Welded Blade stabilizer (7.02')8" Non-Mag XO /PSI (2.03'), 8" MWD DM-HOC (8.79'), MWD RLLw/ DGR+EWR+PWD 27.78' ,MWD Pulsar 11.45' . 16:45 17:15 0.50 89 89 SURFA .DRILL PULD P Plug in and upload MWD assembly.. All ood. 17:15 18:00. 0.75 89 280 SURFA DRILL PULD P Continue MU BHA #4. Make. up 8" NonMag Float sub (2.40'), 1 -jnt NonMag Flex Drill collar (31.01'), Non Mag XO sub (2.51'), 8" EMS Survey Tool (2.09'), 8" Antenna (3.16'), Non Mag XO Sub (2.75'), 2 -jnts Non Mag Flex Drill Collars (61.70'),. Crew Chane 18:00 19:45 1.75 280 389 SURFA DRILL PULD P Continue make up Dailey 8" Combo drilling Jars (40.27) and 5 - jnts 5" HWDP (154.01'). Total BHA = 388.91'. Install corrosion ring on top ofjars as er Ml re . 19:45 20:30 0.75 389 2,202 SURFA DRILL TRIP P Trip in hole from 389' - 2202' MD. UP WT 140K, SO WT = 105K. Observe ro er hole fill 20:30 21:30 1.00 2,202 2,202 SURFA DRILL CIRC P Fill Drill string.. Trouble shoot noise for. MWD on mud pumps. Clean all suction screens and check pulsation dampener pressure. Both @ 900 PSI. Perform Shallow pulse test @ 500 GPM - 1300 PSI. Good test. 21:30 22:30 1.00 2,202 3,538 SURFA DRILL TRIP P Continue trip in hole from 2202' - 3538' MD. UP WT = 150K, SO WT = 90K. Fill Drill string. keeping bit off of Float collar 3589'. 22:30 23:30 1.00 3,538 3,538 SURFA DRILL CIRC P Circulate bottoms up while reiprocate & rotate drill string @ 25 RPM's, - 500 GPM's -1300 PSI, torque @ 5-9K, UP WT = 150K, SO WT = 90K, ROT WT = 120K. Pum total of 4200 Strokes. 23:30 00:00. 0.50 3,538 3,538 SURFA DRILL DHEQ P PJSM -Testing casing: Blow down Top Drive & lines. Rig up surface equipment with chart recorder. Pump through all lines to fill. Position drill string. Close Pipe Rams: Fill Lines. Perform 13 3/8" casing test to 3000 PSI for 30 minutes. Record on chart. 10/16/2006 00:00 00:45 0.75 3,538 3,538 SURFA DRILL DHEO P Contirue Perform 13 3/8" casing test to 3000 PSI for 30 minutes. Record on chart. Pressure to 3000 PSI in 65 strokes. O PSI Bleed off. Bled back 6.5 BBLS. 00:45 01:00 0.25 3,538 3,538 SURFA DRILL DHEQ P Rig down all testing equipment. - - i rags 't b c : C~ Time Logs - --- ~~D~te_ -From To Dur S. Depth E Depth Phase Code_Subcode_ T_ COM _ _____ __ -__ ~ 10/16/2006 01:00 01:1.5 0.25 3,538 3,538 SURFA DRILL OTHR P Transfer 5 stands of 5" HWDP from one side of derrick to the. other for ro er order of DP run. 01:15 01:30 0.25 3,538 3,588 SURFA DRILL TRIP P Trip in hole from 3538' - 3588' to tag cement or FC. Float collar expected 3589'MD. Measurements correct. 01:30 04:00 2.50 3,690 3,711 SURFA CEMEh DRLG P Drill cemsrit & float collar from 3588' - 3711' MD 2158' TVD. Pumps @ 600 GPM's - 1500 PSI. 50 RPM's with 6-9K torque. Observe Both cement plugs at surface on shakers with cement returns. Observed little or no bit weight needed in soft open hole. Pumps @ 615 GPM's - 1550 PSI. 7-10K torque on bottom, WOB = 2-6K, UP WT = 170K, SO WT = 95K, ROT WT = 130K. Total Bit Hrs = .10, Total Jar Hrs = 26.54, ART = .10 Hrs, ADT .10 Hrs, AST = 0.0 Hrs 04:00 05:30 1.50 3,711. 3,711 SURFA DRILL CIRC P .Circulate & condition mud for planned LOT. Pumps @ 600 GPM's - 1550 PSI. Reciprocate & rotate drill string while circulating. Final mud weight in & out = 9.0 PPG; with a 36 viscosity. Held PJSM while pumping discussing. RU for LOT. .05:30 06:00 0.50 3,711 3,711 SURFA DRILL LOT P Rack back 1 stand to position bit @ 3628' MD. Rig up lines and chart recorder for performing LOT. Crew Chan e 06:00 07:00 1.00 3,711 3,711 SURFA DRILL LOT P Continue rig up lines and chart recorder for LOT. Fill lines. Mud wt = 9.0 PPG, Visc = 38, Gels @ 12/14. Perform LOT to EMW of 13:5 PPG calculated. Bled back 1.5 BBLS of 7.5 pumped. Shoe depth = 3673 MD ND = 2154'. 10 minute bleed back from 700 PSI - 310 PSI. Bleed al (pressure. Ri down and blow down all lines. 07:00 07:15 0.25 3,711 3,711 INTRM1 DRILL SFTY P PJSM with rig crew and all truck drivers. Discuss safety issues. and procedure for displacing well with 9.0 PPG LSND mud. Designate Spill cham ion. 07:15 09:15 2.00 3,711 3,711 INTRM1 DRILL CIRC P Displace well with 9.0 PPG LSND mud. Nos ills or incidents. 09:15 10:15 1.00 3,711. .3,711 INTRM1 DRILL CIRC P Obtain SPR's with new mud. obtain Baseline ECD as per MWD rep at 9.2 PPG. 10:15 10:30 0.25 3,711. 3,711 INTRM1 DRILL OWFF P Monitor well - static Blow down Top Drive & Lines. 10.30 12:00 1:50 3,711 3,711 INTRM1 RIGMN SVRG P Held PJSM with crew. Discuss. Safety issues and procedure for Slipping and cutting driling line, Hang Blocks and slip & cut 95' od drilling line. Inspect & service Top Drive: Inspect and adjust brakes on draw works. -- - - - - - r---- Page 17 of ~9 r ~ i - __ - , Time Lis ~ _Dur S De~th_ E. Depth .Phase Cod~__ Subcode T__ C(7f~1 _ __ _ _ _ Date From To _ 10/16!2006 12:00 15:30 3.50 3,711 3,711 INTRM1 RIGMN SVRG P Inspect Saver Sub. Install Floor safety valve in drill string. Rig up and change out saver sub on To Drive uill. 15:30 18:00 2.50 3,711 3,910 INTRM1 DRILL. DDRL P Continue Directional drill 12 1/4" Intermediate hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.50 deg bend f/ 3711' - 3910' MD (199') TVD = 2211'. Total hrs on bit= 1.33 hrs, Jar hours = 27.:77 hrs, ADT = 1.23 HRS, ART,44 hrs, AST .79 hrs, WOB 15-20K, 80 RPM, Motor RPM - 161, 600 GPM's @ 1275 psi on bottom and 1225 psi off. bottom. Torque = 6-8K ft-Ibs on botttom and 5-6K ft-Ibs off bottom. P/U = 150K, S/O = 95K, ROT WT= 105K . AVG Gas observed = 17 Units. ECD = 9.44 PPG. Mud Wt = 9.0 PPG, Visc = 62 YP = 23 PV = 15, Gels @ 10/12/14. Survey @ 3862.80' MD 2202' TVD, INC = 75.95 DEG, AZ = 195.58 DEG. Obtain SPR's @ 3671' MD 2150' ND. Pump#1 - 20 SPM - 110 PSI, 30 SPM - 140 PSI. Pump #2 - 20 SPM - 110 PSI, 30 SPM - 150 PSI. Crew Chan e 18:00 21:00 3.00 3,910. 4,194 INTRM1 DRILL DDRL. P . Continue Directional drill 12 1/4" Intermediate hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.50 deg bend f/ 3910' - 4194' MD (284') ND = 2257. Total hrs on bit= 2.94 hrs, Jar hours = 29.43 hrs, ADT = 1.66 HRS, ART .76 hrs, AST .90 hrs, WOB 4-6K, 80 RPM, Motor RPM - 161, 600 GPM's @ 1250 psi on bottom and 1180 psi off bottom. Torque = 5-6K ft-Ibs on botttom and 4-6K ft-Ibs off bottom. P/U = 145K, S/O = 105K, ROT WT= 125K . .AVG Gas observed = 50 Units. ECD = 9.43 PPG. Mud Wt = 9.0 PPG, Visc = 62 YP = 23 PV = 15, Gels @ 10/12/14. Survey @ 4193.74' MD 2279' TVD, INC = 77.89 DEG, AZ = 194.55 DEG. 21:00 22:45 1.75 4,194 4,194 INTRM1 DRILL REAM P Obtain repeated surveys indicating 5 deg dogleg. Ream hole from 4194'- 4006' to reduce hole angle. Pumps at 775 GPM's - 1900 PSI with ECD's @ 9.43 PPG. Obtain corrected surveys indicatin do le one. - - --- Page 18 caf 69„J ~ ~ i, Time Logs Date 10/16l2006 Froi~i 22:45 To 00:00 Dur 1.25 S Depth 4,194 E. Depth 4,32 Phase INTRM1 Code DRILL Subcode DDRL T P COf~1 _______- Continue Directional drill 12 114" Intermediate hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.50 deg bend f/ 4194' - 4302' MD (108') TVD = 2306'. Total hrs on bit= 3.55 hrs, Jar hours = 29.99 hrs, ADT = .56 HRS, ART .39 hrs, AST .17 hrs, WOB 4-6K, 80 RPM, Motor RPM - 161, 620 GPM's @ 1390 psi on bottom and 1300 psi off. bottom. Torque = 7-8K ft-Ibs on botttom and 4-6K ft-Ibs off bottom. P/U = 145K, S/O = 105K, ROT WT= 122K . AVG Gas observed = 50 Units. ECD = 9.56 PPG. Mud Wt = 9.0 PPG, Visc = 62 YP= 25 PV = 15, Gels @ 12/15. Survey @ 4242.12' MD 2289' TVD, INC = 75.85 DEG, AZ = 195.57 DEG. 10/17/2006 00:00 06:00 6.00 4,302 4,882 INTRM1 DRILL DDRL P Continue Directional drill 12 1/4" Intermediate hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.50 deg bend f/ 4302' - 4882' MD (580') TVD = 2428'. Total hrs on bit= 7.34 hrs, Jar hours = 33.45 hrs,. ADT = 3.96 HRS, ART 1.49 hrs, AST 2.47 hrs, WOB 4-10K, 80 RPM, Motor RPM - 169, 650 GPM's @ 1600 psi on bottom and 1530 psi off bottom. Torque = 8-9K ft-Ibs on botttom and 6-10K ft-Ibs off bottom. P/U = 155K, S/O = 105K, ROT WT= 127K .AVG Gas observed = 50 Units. ECD = 9.70 PPG. Mud Wt = 9.0 PPG, Visc = 63 YP = 25 PV = 15, Gels @ 12/15. Survey @ 4813.42' MD 2413' TVD, INC = 76.99 DEG, AZ = 192.60 DEG. Crew Chan e 06:00 12:00 6.00 4,882 5,562 INTRM1 DRILL DDRL P Continue Directional driN 12 1/4" Intermediate hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.50 deg bend f/ 4882' - 5562' MD (680') TVD = 2581'. Total hrs on bit= 10.96 hrs, Jar hours = 37.40 hrs, ADT = 3.62 HRS, ART 2.15 hrs, AST 1.47 hrs, WOB 10-20K, 80 RPM, Motor RPM - 171, 660 GPM's @ 1700 psi on bottom and 1610 psi off bottom. Torque= 9-10K ft-Ibs on botttom and 7-10K ft-Ibs off bottom. P/U = 170K, S/O = 102K, ROT WT= 132K ..AVG Gas observed = 62 Units. ECD = 9.58 PPG. Mud Wt = 9.0 PPG, Visc = 63 YP = 27 PV = 14, Gels @ 12/19. Survey @ 5480.30' MD 2561' TVD, INC = 76.88 DEG, AZ = 192.49 DEG.. Pale 19 of 89 ~`- Time Loc,~s _ _ _ _ _ - _ ___ - - _ Da_te 10/17/2006 _ From 12:00 To 18:00 Dur _ 6.00 S De~th__ 5,562 E. Depth _ 6,202 Phase INTRM1 Code DRILL Sut~code DDRL T _ P COM _ _ - - Continue Directional drill 12 1/4" Intermediate hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.50 deg bend f/ 5562' - 6202` MD (640') TVD = 2716'. Total hrs on bit= 14.73 hrs, Jar hours = 41.45 hrs, ADT = 4.05 HRS, ART 1.98 hrs, AST 2.07 hrs, WOB 10-20K, 80 RPM, Motor RPM - 171, 660 GPM's @ 1700 psi on bottom and 1600 psi off bottom. Torque. = 10-12K ft-Ibs on botttom and 8-9K ft-Ibs off bottom. P/U = 175K, S/O = 102K, ROT WT= 132K . AVG Gas observed = 31 Units. ECD = 9.68 PPG. Mud Wt = 9.0 PPG, Visc = 63 YP = 27 PV = 14, Gels @ 12/19. Survey @ 6146.72 MD 2705' TVD, INC = 78.04 DEG, AZ = 192.62 DEG. Crew Chan e 18:00 00:00 6.00 6,202 6,709 INTRM1 DRILL DDRL P Continue Directional drill 12 1/4" Intermediate hole w/ 8"SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.50 deg bend #/ 6202' - 6709' MD (508') TVD = 2824'. Total hrs on bit= 17.85 hrs, Jar hours = 44.29 hrs, ADT = 3.12. HRS, ART 1.76 hrs, AST 1.36 hrs, WOB 6-15K, 80 RPM, Motor RPM - 179, 690 GPM's @ 1900 psi on bottom and 1750 psi off bottom. Torque = 9-12K ft-Ibs on botttom and 6-1 OK ft-Ibs off bottom. P/U = 170K, S/O = 105K, ROT WT= 135K .AVG. Gas observed = 77 Units. ECD = 9.82 PPG. Mud Wt = 9.0 PPG, Visc = 63 YP = 26 PV = 14, Gels @ 12/19. Survey @ 6621.26 MD 2803' TVD, INC = 76.62 DEG, AZ = 189.19 DEG. 10/18/2006 00:00 06:00 6.00 6,709 7,134 INTRM1 DRILL DDRL P Continue Directional drill 12 1/4" Intermediate hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.50 deg bend f/ 6709' - 7134' MD (425') TVD = 2925'. Total hrs on bit=20.85 hrs, Jar hours = 47.29 hrs, ADT = 1.62 HRS, ART 1.38 hrs, AST 1.62 hrs, WOB 6-15K, 80 RPM, Motor RPM - 179, 690 GPM's @ 1920 psi on bottom and 1830 psi off bottom. Torque = 11-12K ft-Ibs on botttom and 6-10K ft-Ibs off bottom. P/U = 170K, S/O = 105K, ROT WT= 135K . AVG Gas observed = 80 Units. ECD = 9.82 PPG. Mud Wt = 9.1 PPG, Visc = 63 YP = 30 PV 15, Gels @ 14/20. Survey @ 7093.73 MD 2917 TVD, INC = 75.76 DEG, AZ = 193.05 DEG. Obtain SPR's @ 6478 MD 2771 TVD. Pump #1 - 20 SPM =180 PSI, 30 SPM = 220 PSI, Pump #2 - 20 SPM = 180 PSI, 30 SPM = 220 PSI. Crew Chan e ---- - Fk~ge 2f! or ~i9 Crime Lodi s 10/18/2006 From 06:00 To _- 12:00 _Dur _ 6.00 S Depth 7,134 E_ C~pt_h 7,551 Phase -- INTRM1 Co~e__ DRILL _Subco~+e DDRL _T_ P CC)M - - - __ - _ Continue Directional drill 12 1/4" Intermediate hole w/ 8"SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.50 deg bend f/ 7134' - 7551' MD (417') TVD = 3016'. Total hrs on bit= 24.17 hrs, Jar hours = 50.61 hrs, ADT = 3.31 HRS, ART 1.74 hrs, AST 1.57 hrs, WOB 10-20K, 80 RPM, Motor RPM - 179, 690 GPM's @ 1900 psi on bottom and 1900 psi off bottom. Torque = 11-12K ft-1bs on botttom and 9-13K ft-1bs off bottom. P/U = 185K, S/O = 105K, ROT WT= 140K .AVG Gas observed = 38 Units. ECD = 9.91 PPG. Mud Wt = 92 PPG, Visc = 64 YP = 30 PV = 15, Gels @ 14/20. Survey @ 7475.83 MD 2999' TVD, INC = 77.03 DEG, AZ = 193.04 DEG. 12:00 18:00 6:00 7,551 .8,006 INTRM1 DRILL DDRL P Continue Directional driG 12 1/4" Intermediate hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.50 deg bend f/ 7551' - 8006' MD (455') TVD = 3115'. Total hrs on bit= 27.38 hrs, Jar hours = 53.82 hrs, ADT = 3.22 HRS, AR7 1.91 hrs, AST 1.31 hrs, WOB 10-20K, 80 RPM, Motor RPM - 179, 690 GPM's @ 2100 psi on bottom and 2000 psi off bottom. Torque = 12-13K ft-Ibs on botttom and 10-13K ft-Ibs off bottom. P/U = 200K, SIO = 105K, ROT WT= 140K .AVG Gas observed = 181 Units. ECD = 10.1 PPG. Mud Wt = 9.1 PPG, Visc = 63 YP = 30 PV = 14, Gels @ 15/23. Survey @ 7949.97 MD 3101' TVD, INC = 75.79 DEG, AZ = 194.98 DEG.. Obtain SPR's @ 7330 MD 2968 TVD. Pump #1 - 20 SPM =200 PSI,. 30 SPM = 240 PSI, Pump #2 - 20 SPM = 200 PSI, 30 SPM = 240 PSI. Crew Chan e - --- - ' Wage 21 of 69 ~ , _ Time Lis Date 10/18/2006 f-rcm 18:00 To__ 00:00 Dur __ 6.00 S Doh 8,006 E. Depth 8,284 Phase INTRM1 Code DRILL Subcode DDRL T P COM __ Continue Directional drill 12 1/4" Intermediate hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.50 deg bend f/ 8006' - 8284' MD (278') TVD = 3179'. Total hrs on bit= 30.08 hrs, Jar hours = 56.52 hrs, ADT = 2.70 HRS, ART .88 hrs, AST 1.82 hrs, WOB 8-14K, 80 RPM, Motor RPM - 171, 660 GPM's @ 1850 psi on bottom and 1550 psi off bottom. Torque = 15K ft-Ibs on botttom and 13K ft-1bs off bottom. P/U = 190K, S/O = 105K, ROT WT= 142K . AVG Gas observed = 17 Units. ECD = 9.86 PPG. Mud Wt = 9.2 PPG, Visc = 64 YP = 30 PV = 14, Gels @ 12/15. Survey @ 8234.16 MD 3167 TVD, INC = 76.58 DEG, AZ = 192.88 DEG. Observed difficulty in sliding, pumped nut plug sweep that enabled better sliding but suspect up hole Ghost reamer as part of the difficulty. Decision to BROOH 11 stands to Ghost reamer de th. .10/19/2006 00:00 02:30 2.50 8,284 7,050 INTRM1 DRILL REAM P Decision to BROOH as sliding became difficult & torque increased to 15K. BROOH from 8284' - 7240' MD: Backream rate @ 10 Ft/Min for bottoms up and then 50 Ft/Min to 7240' MD. Pumps at 800 GPM's - 2200 PSI. 80 RPMs -with 11 K torque. Observed good clean hole. Pulled 2 more stands on elevators from 7240' - 7050'. Hole looked good with little or no dra .Monitor well -static. 02:30 03:00 0.50 7,050 8,284 INTRMI DRILL TRIP P Trip back in hole from. 7050' - 8284'. Observed good hole conditions and proper hole fill. MAke Top Drive connection. - - - 1 i~ag: 22 of ~~ 1 "~ Tirne Lo ~_ _ _ -- Date From To Dur S Deptfi E. De~h P'~ase Code Suhcode T__ COM _ __ __ _ - __ " 10/19/2006 03:00 06:00 3.00 8,284 8,428 INTRM1 DRILL DDRL P Continue Directional drill 12 1/4 Intermediate hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.50 deg bend f/ 8284' - 8428' MD (144') TVD = 3211'. Total hrs on bit= 31.50 hrs, Jar hours = 57.94 hrs, ADT = 1:42 HRS, ART .76 hrs, AST .66 hrs, WOB 8-10K, 80 RPM, Motor RPM - 179, 690 GPM's @ 2040 psi on bottom -and 1880 psi off bottom. Torque = 15K ft-Ibs on botttom and 13K ft-Ibs off bottom. P/U = 195K, S/O = 105K, ROT WT= 142K . AVG Gas observed = 14 Units. ECD = 9.92 PPG. Mud Wt = 9.2 PPG, Visc = 64 YP = 30 PV = 14, Gels @ 12/15. Survey @ 8424.91 MD 3211` TVD, INC = 76.83 DEG, AZ = 189.84 DEG. Observed sliding parameters became better with quicker response to bit and less reactive torque. Crew Chan e 06:00 12:00 6.00 8,428 8,826 INTRM1 DRILL DDRL P Continue Directional drill 12 1/4" Intermediate hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.50 deg bend f/ 8428'.- 8826' MD (398') TVD = 3308'. Total hrs on bit= 34.72 hrs, Jar hours = 61.15 hrs, ADT = 3.21 HRS, ART 1.83 hrs, AST 1.38 hrs, WOB 10-20K, 80 RPM, Motor RPM - 169, 650 GPM's @ 1900 psi on bottom and 1820 psi off bottom. Torque = 13-15K ft-Ibs on botttom and 12-13K ft-Ibs off bottom. P/U = 210K, S/O = 105K, ROT WT= 146K . AVG Gas observed 60.9 Units. ECD = 10.1 PPG. Mud Wt = 9.2 PPG, Visc = 64 YP = 30 PV = 14, Gels @ 12/15. Survey 8806.01 MD 3302' TVD, INC = 76.27 DEG, AZ = 184.22 DEG. .Page 23 ~f a9 Tirne Logs - - --- -- - - --- - -- - Date Fro~~i To Dur S D~th E De~th _Phase _ Code SuLicod_e_ T _ COM __ ___ _ _ _ __ __- 10/19/2006 12:00 __ _ 18:00 8.00 _ 8,826 9,087 INiRM1 DRILL DDRL P Continue Directional drill 12.1/4° Intermediate hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.50 deg bend f/ 8826' - 9087 MD (261'} TVD = 3348'. Total hrs on bit= 38.23 hrs, Jar hours = 64.68 hrs, ADT = 3.53 HRS, ART 1.94 hrs, AST 1.59 hrs, WOB 10-20K, 70-80 RPM, Motor RPM - 171, 660 GPM's @ 2000 psi on bottom and 1900 psi off bottom. Torque= 13-15K ft-Ibs on botttom and 12-13K ft-Ibs off bottom. P/U = 215K, S/O = 108K, ROT WT= 148K .AVG Gas observed = 57 Units. ECD = 9.9 PPG. Mud Wt = 9.2 PPG, Visc = 63 YP = 30 PV = 14, Gels @ 15/24. Survey @ 8996.39 MD 3375' TVD, INC = $1.78 DEG, AZ = 182.06 DEG. Obtain SPR's @ 9087 MD 3347 TVD. Pump #1 - 20 SPM =290 PSI, 30 SPM = 330 PSI, Pump #2 - 20 SPM = 280 PSI, 30 SPM = 330 PSI. Crew Chan e 18:00 00:00 6.00 9,087 9,426 INTRM1 DRILL DDRL P Continue Directional drill 12 1/4" Intermediate hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1,50 deg bend f/ 9087 - 9426' MD (339'} TVD = 3393'. Total hrs on bit= 41.04 hrs, Jar hours = 67.48 hrs, ADT = 2.80 HRS, ART 1:52 hrs, AST 1.28 hrs, WOB 10-20K, 80 RPM, MotorRPM -179, 690 GPM's @ 2050 psi on bottom-and 2000 psi off bottom. Torque = 18K ft-Ibs on botttom and 16K ft-Ibs off bottom. P/U = 200K, S/O = 102K, ROT WT= 145K .AVG Gas observed = 14 Units. ECD = 9.94 PPG. Mud Wt = 9.2 PPG, Visc = 61 YP = 30 PV = 14, Gels @ 15/24. Survey @ 9374.37 MD 3386' TVD, INC. = 82.15. DEG, AZ = 182.54 DEG. _ I a'ac~~24'cta9 -- ____ _, 3~_~_~_ - __ ____ ___ - -~ Time Logs -- - - - --- - - - - - - D_ate _ 20 6 From 0 00 To 06 00 Dur___ 00 6 S. Depth_ 426 9 E Depth _ 804 I 9 Phase NTRM1 Code -_ DRILL Sub~ode _ DDRL T P COM _ _ _ __ ' Continue Directional drill 12 1i4" 10/20/ 0 : 0 : . , , Intermediate hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.50 deg bend f/ 9426' - 9804' MD (378') TVD = 3430'. Total hrs on bit= 44.18 hrs, Jar hours = 70.62. hrs, ADT = 3.14 HRS, ART= 1.93 hrs, AST= 1.21 hrs, WOB 10-20K, 80 RPM, Motor RPM - 171, 660 GPM's @ 1980 psi on bottom and 1700 psi off bottom. Torque = 15K ft-Ibs on botttom and 15K ft-Ibs off bottom. P/U = 200K, S/O = 105K, ROT WT= 145K . AVG Gas observed = 140 Units. ECD = 10.09 PPG. Mud Wt = 9.2 PPG, Visc = 64 YP = 32 PV = 14, Gels @ 16/26. Survey. @ 9756.64 MD 3426' TVD, INC = 84.45 DEG, AZ = 178.63 DEG. Pump 10 PPB Nut plug sweeps as needed for cleaning hole to aid sliding.. Crew Chan e 06:00 07:00 1.00 9,804 .9,836 INTRM1 DRILL DDRL P Continue Directional drill 12 1/4" Intermediate hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.50 deg bend f/ 9804' - 9836' MD (32') TVD = 3433'. Total hrs on bit= 44.85 hrs, Jar hours = 71.35 hrs, ADT = .67 HRS, ART= 0 hrs, AST= .67 hrs, WOB 10-12K, 80 RPM, Motor RPM - 171, 670 GPM's @ 1930 psi on bottom and 1850 psi off bottom. Torque = 17K ft-Ibs on botttom and 15K ft-Ibs off bottom. P/U = 200K, S/O = 108K, ROT WT= 142K . AVG Gas observed = 129 Units. ECD = 10.23 PPG. Mud Wt = 9.2 PPG, Visc = 64 YP = 32 PV =,14, Gels @ 16/26. Survey @ 9836:00 MD 3432' TVD, INC = 86.15 DEG, AZ = 178.00 DEG. Pump final 10 PPB Nut lu swee while drill down last 'oint. 07:00 09:30 2.50 9,836 9,514 INTRM1 DRILL REAM P Circulate on bottom 10 minutes. BROOH slow @ 10 ft/min until acheived bottoms up from 9836' - 9514' MD, 80 RPM's , 14K Torque with um sat 800 GPM's - 1900 PSI. 09:30 12:00 2.50 9,514 _7,623 INTRM1 DRILL REAM. P Continue BROOH from 9514'-- 7623' MD, 80 RPM's , 14K Torque with pumps at 800 GPM's - 1900 PSI. BROOH with one stand @ 50 ft/min , then pull one on the elevators until observed hole loading up, then. BROOH each stand. -. --1 F'~g~ 25' of 68' Time Loc,~s _ -- _ _ __ - -- - -- - - Da~e__ - From _ To_ D~ir S_ De(Jth E D_~th Phase _ Code ~ubcode_ T_ _ COM _ _ - 10/20/2006 12:00 14:00 2.00 7,623 6,006 INTRM1 DRILL REAM P Continue BROOH from 7623' - 6006' MD, 80 RPM's , 14K Torque with pumps aY800 GPM's - 1900 PSI. BROOH with one stand @ 50 ft/min, then pull one on the elevators until observed-hole loading up, then BROOH each stand. 14:00 18:00 4.00 6,006 4,050 INTRM1 DRILL REAM P Continue BROOH from 6006' - 4050' MD, 80 RPM's , 14K Torque with pumps at 800 GPM's - 1900 PSI. BROOH with one stand @ 50 ft/min, then pull one on the elevators until observed hole loading. up, then BROOH each stand. Use extra caution as Ghost reamer pass through shoe area. Observed hole unloading at 6006', pulling 10 ft/min until cleaned u .Crew Chan e 18:00 18:45 0.75 4,050 3,673 INTRM1 DRILL REAM P Continue BROOH from 4050' - 3673' MD into the shoe. 80 RPM's , 12K Torque with pumps at 800 GPM's - 1750 PSI. BROOH with one stand @ 50 ft/min, then pull one on the elevators until observed hole loading up, then BROOH each stand. Use extra caution as Ghost reamer passed through shoe area. Observed hole unloading at 6006', pulling 10 ft/min until cleaned u .Crew Chan e 18:45 20:30 1.75 3,673 3,673 INTRM1 DRILL CIRC P Circulate bottoms up 3 times, pumping a 30 BBL Hi Visc weighted sweep: Observed hole unload with 30% increase in cuttings on shakers when sweep returned. Continue circulate until clean. Reciprocate & rotate drill string with pumps @ 800 GPM's -1750 PSL 20:30. 23:00 2.50 3,673 388 INTRM1 DRILL TRIP P Monitor well -static. Pump dry job, blow down Top Drive and all lines. POOH on elevators from 3673' - 388'. Obtain SLM on all DP stands while POOHe No corrections made to tally. Observe proper hole fill. Breakout & lay down Ghosf Reamer. obsered GR out of au eat almost 2" under. 23:00 00:00 1.00 388 127 INTRM1 DRILL PULD P Rack back 1 stand 5" HWDP. LAy' down 2 joints 5" HWDP. Breakout & lay down 8" Dailey Combo drilling jar (40.27). 2 Non Mag flex Drill collars (61.70'), Non Mag XO sub (2.75'), and 8" Antenna 3.16' . 10/21/2006 00:00 00:30 0.50 127 92 INTRM1 DRILL PULD P Continue POOH, Breakout & lay down 8" EMS Survey Tool (2.09'), Non Mag XO Sub (2.51'), 1 -Non Mag Flex Drill Collar (31.01'), and 8" Non MAg Float Sub 2.40' . Paq~ , ~i S9~ __- - --- - Tirne Logs... _ _ _ To Dur -S-Depth E_D~pth Phase Code_ Subco_de T COM __ -__ __-.. Fmm Date _ _ 10/21/2006 00:30 01:15 0.75 92 92 INTRM1 DRILL PULD P Plug in and download MWD assembl . 01:15 02:30 1.25 92 0 INTRM1 DRILL PULD P Continue POOH breakout & lay down 8" MWD pulsar (11.45'), 8" MWD RLL w/ DGR/EWR/PWD (27.78'), 8" MWD DM-HOC (8.79'), 8" Non Mag XO / PSI (2.03'), 8" Welded Blade stabilizer (7.02'), Sperrylobe 4/5-5.3 stage (30.80') and Hughes 12 1/4" Bit (1.14'). Inspect & grade bit to 3/4/BT/A/X/8/ERlTD. Observe motor stabilizer in gauge @ 12", and welded blade stabilizer under gauge @ 10:250" . 02:30 03:00 0.50 0 0 INTRM1 DRILL OTHR P Clear & clean rig floor area. Send tools outside. Begin working mud system in its to re cement arameters. 03:00 03:30 0.50 0 0 INTRM1 DRILL OTHR P Rig up W6. Puller on test joint. BOLDS. RIH engage WI3. POOH lay down same. Lay down puller & test , 'oint. 03:30 04:00 0.50 0 0 INTRM1 CAStN( SFTY P Hels PJSM with crew & GBR reps. Discuss safety issues and procedure / plan to rig up casing equipment for 9 5/8"intermediate casing run. We will rig up with side door elevators to run to the shoe, utilizing a fill up hose. No Franks Fill up tool to start. Assign S ill Cham ion to monitor fill u line. 04:00 04:45 0.75 0 0 INTRM1 CASIN( RURD P Rig up all 9 5/8" casing equipment. Casing tongs, side door elevators, with short bails, with spiders. Rig up fill up hose. 04:45 06:00 1.25 0 165 INTRM1 CASIN( RNCS P Make up 9 5/8" Shoe joint, & thread lock joints. Make up Float collar joint. Fill with mud, Check Floats -Good. Continue RIH with 9 5/8" Casing as per detail installing Tandem Rise Centralizers on each joint, with 1 each above and below FC, 10 ft, and 1 10 ft above shoe joint. Observe make up torque 8000 -8500 Ft/Ibs. Fill casing eve 5 'oints. Crew Chan e --- ~~~~ ~7 ~~~~_ 1 ' Time Logs. -- _ _ _ _ _ ~ Date From T~ Dur S_De~h E D~th Phase Code__ Subcode T_ COM _ _ __ - __- " 10/21/2006 06:00 12:00 6.00 165 3,380 INTRM1 GASIN( RNCS P casing as per Continue run 9 5/8 detail with side door elevators from 165' - 3380'. Fill every joint and topping off string on every 5 joints with fill up line. Continue install tandem rise centralizers on each joint from # 3 - # I?3 (coverage 9738' - 7282'). Install tandem Rise centralizers every 30' as planned from joints # 64-#79 (coverage 7282'-6628'). No centralizer installed on window joint planned for a depth of 9107 MD. Obtain Torque & drag parameters as per rig engineer, every 10 joints while in casing and every 10 joints in open hole. Shoe depth = 3673' MD. 12:00 13:00. 1.00 3,380 3,380 INTRM1 CASIN< RURD P Rig down side door elevators. Lay down short bails on Top drive. Send. tools outside & pull tools to rig floor. 350 ton elevators, casing pickup sling, Long bails, and all Gator Back e i ment. 13:00 13:15 0.25 3,380 3,380 INTRM1 CASIN( SFTY P Hold PJSM with crew & Gator Back reps. Discuss safety issues and procedure for rigging up and installing Gator Backe ui ment on To Drive. 13:15 13:30 0.25 3,380 3,380 INTRM1 CASIN( OTHR P Stab into 9 5/8" casing with Gator Back CRT Tool. Function tool 13:30 14:15 0.75.. 3,380 3,380. INTRM1 CASIN( RURD. P Rig up long bails, pick up sling, and 350 Ton Elevtors. 14:15 14:30 0.25 3,380 3,380 INTRM1 CASIN( SFTY P PJSM with crew. Discuss safety issues and procedure for rigging up & operating stabbing board "new crew", and casin ton s. 14:30 15:00 0.50 3,380 3,380 INTRMI GASIN( RURD P Rig up new stabbing board, casing tongs & scaffo-ding for GBR casing ton o erator. 15:00 15:45 0.75 3,380 3,658 INTRM1 CASING RNCS P Run 9 5/8" casing with Gator Back CRT tool. from 3380' - 3658'. Observe tool workin ro erl , no issues. 15:45 16:45 1.00 3,658 3,658 INTRM1 CASING OTHR P Stab & lock into 9 5/8" casing with. CRT tool. Pick up casing string with tool. Establish circulation with pumps at 3.5 BPM - 250 PSI. Reciprocate string slowly in 25' increments obtaining bottoms up. UP WT = 171 K, SO WT = 131 K. Increase rate to 4 BPM - 325 PSI, 5 BPM.- 475 PSI, continuing to reciprocate casing string. After obtaining bottoms up, attempt to rotate 9 5/8" casing string, setting max torque limit to 8K ft'Ibs. Observed casing stalled out but we were able to rotate string with downward movement: CRT Tool worked well: Note: Make up torque on - casin strin 8000 ft/Ibs. ~'~c~e 8 ref 69 Time Logs - -- -- -' To Dur S Depth E. D~th Phase -Code- Sub~.ode T COM__ _ __ __ _ _ _- Frorn Date -- - -- _ -_ _ 10/21/2006 16:45 17:15 0.50 3,658 3,658 INTRM1 CASIN( RURD P Bleed a-I pressure and rig down all Gator back CRT tools & e ui ment. 17:15 17:45 0.50 3,658 3,658 INTRM1 CASIN( RURD P Make up 9 5/8" franks Fill up tool on To Drive. 17:45 18:00 0.25 3,658 3,751 INTRM1 CASIN( RNCS P Continue run 9 578" casing string from 3658' - 3751' into open hole. Note: 13 3/8 Casing shoe depth = 3673' MD. Mud wt = 9.4 PPG, VISC = 44, YP = 18. Obtain Torque & drag parameters as per rig engineer, every 10 joints while in casing and every 10 joints in o en hole. Crew Chan e . 18:00 20:00 2.00 3,751 4,927 INTRMI CASIN< RNCS P Continue run 9 5/8" casing from 3751' - 4927 in open hole: Observe string-with weight loss and circulating joints down at 492T. Up WT = 220K, SO WT = 90K. Obtain Torque & drag parameters as per rig engineer, every 10 joints in o en hole. 20:00 21:45 1.75 4,927 5,348 INTRM1 CASIN( CIRC P Circulate, washing down with Franks Fill Up tool from 4927 - 5348'. Staging Pumps @ 5 BPM - 300 PSI. Up WT = 230K, SO WT = 75K. Obtain Torque & drag parameters as per rig en ineer, eve 10 'oints in o en hole. 2'1:45 22:15 0.50 5,348 5,348 INTRM1 CASIN< CIRC P Circulate bottoms up with Franks Fill Up tool. Staging -Pumps @ 5 BPM - 425 PSI. reciprocate Casing string in 25' increments. Up WT = 250K, SO WT = 100K. Observed shakers clean. Obtain Torque & drag parameters as per rig engineer, every 10 joints in o en hole: 22:15 OOs00 1.75 5,348 6,034 INTRM1 CASIN( RNCS P Continue run, washing down 9 5/8" easing from 5348' - 6034' in open hole. Observed hole conditions good but drag allowed loss of weight and we continued to have to pump casing string in hole with down weights of 75 - 85K. Note: Torque and drag modeling. weights following actual T&D close. Obtain Torque & drag parameters as per rig engineer, every 10 joints. in o en hole. 10/22/2006 00:00 00:15 025 6,034 6,184 INTRM1 CASIN( RNCS P Continue. run 9 5/8" casing washing down from 6034' - 6184' MD. Circulate while reciprocate casing string. Pum s 4.5 BPM - 250 PSI. 00:15 01:00 0.75 6,184 6,184 INTRM1 CASIN( CIRC P Circulate while reciprocate casing strin . Pum s 4.5 BPM - 250 PSI. 01:00 05:15 4.25 6,184 8,167 INTRMI CASIN( RNCS P Continue run 9 5/8" casing from 6184' - 8167 MD .Washing down joints as needed. Installing 9 5/8" Lo-Drag Centralizers floating on each joint from. joint # 155 - #247. (Coverage from 3607 to surface). Continue obtain T&D arrameters as er ri en ineer. - - --- i~~y~ 29 of 69 _, Time Loc,~s _ -- - -- ~ - -- - - - I Date From To Dur S_ Depth- E De~th_Phase-_Code Subeode T -_COM - -_ 663 INTRM1 CASIN( RNCS P Observed casing going in hole with 167 8 75 8 0 0 06 , , . :0 10/22/2006 05:15 better downweights. Continue run 9 5/8" casing from 8167 - 8663'. Obtain T&D parameters as per rig engineer. Fill casing string every 5 joints run. Crew Chan e. 06:00 07:30 1.50 8,663 9,763 INTRM1 CASIN( RNCS P Continue run 9 5/8" casing from 8663' - 9763' MD. Fill casing. string every 5 j oints run, and obtain T&D parameters as er ri en ineer. Hole looked ood. 07:30 07:45 0.25 9,763 9,763 INTRM1 CASIN( CIRC P Break circulation on joint # 249, while pulling pups to rig floore Pumps @ 4 BPM - 500 PSI. 07:45 08:15 0.50 9,763 9,836 INTRMI CASIN( RNCS P Makeup 2 - 9 5/8" casing pups for space out to rig floor. Make up jnt # 250, RIH to tag bottom'observing tagging @ 8.8 deeper @ 9844.8'. POOH, breakout & la down 'nt # 250. 08:15 10:00 1.75 9,836 9,836 INTRM1 CASIN( CIRC _ P Insert Franks fill up tool in pup joint. Break circulation @ 4 BPM, staging pumps to 6 BPM - 600 PSL Reciprocate casing string in 30 ft increments while circulating & conditioning mud. Dowell cementers on location, ri in u . 10:00 11:45 1.75 9,836 9,836 INTRM1 CEME~ CIRC P Breakout & lay down Franks fill up tool. Make up cement head, with plugs installed. Continue circulate & condition mud @ 6 BPM - 600 PSI, while reci rocatin casin strip . 11:45 12:00 0.25 9,836 9,836 INTRM1 CEME~ SFTY P Held PJSM with entire rig team, truck drivers and cementers. Discuss safety issues and procedure for pumping cement job and displacing with OBM. Desi Hate 2 s ill cham ions. 12:00 13:45 1.75 9,836 9,836 INTRM1 CEME~ bISP P Turn rig over to Dowell cementers @ 1200 HRS. Fill liries, pump 10 BBLS of 8.3 PPG CW 100 preflush @ 3.5 BPM - 220 PSI. Shut down, test lines to 3500 PSI -good test. Continue pump 40 BBLS of 8.3 PPG CW 100 @ 6.3 BPM - 270 PSI. Continue pump 75 BBLS of 11.0 PPG Mudpush @ 6.2 BPM - 270 PSI. Drop bottom plug. Pump 266.7 BBLS of 12.5 PPG Tail cement @ 5.5 BPM - 60 PSI. Drop Top Plug, Pump 10 BBLS of 8.3 water to flush lines, shut down Dowell Reciprocate casing string in 30 ft increments while pumping. UP WT = 300, SO WT = 112K. F's~~~ 30 of 69 Time Loc,~s - - -_ - .. ...____. --- - - -~ ~~ Date From T o D ur S. Depth EDe~th Phase -- Code Subco~e T __COM - _ _ -- _ - .-_ - 10/22/2006 _ 13:45 _ _ _ 15:30 ___ 1.75 9,836 9,836 1 NTRM1 CEME~ DISP P Turn over to rig pumps. Displace cement with 9.0 PPG OBM @ 6.9 BPM with pump pressure from 400 PSI staging up to 1000 PSI. Reciprocating casing string in smaller increments down to 10'. Stop reciprocating casing string at 5245 strokes with 57 BBLS of cement around shoe, setting string on depth for a shoe depth as planned at 9831', MD. Continue pump slowing pumps to 3 BPM observing plug bump @.7192 Strokes. CIP @ 1530 HRS 10/22/06. Pressure to 1500 PSI. Hold for 10 Minutes, Bleed pressure and check floats. Floats held. 15:30 18:00 2.50 9,836 9,836 INTRM1 CEME~ RURD P Rig down cement head and-all lines. lay down casing slips, Franks fill up ool. Vac out mud from inside of 9 5/8" .casing for cut. ND BOP's, lift stack for settin sli s. Crew than e. 18:00 19:00 1.00 0 0 INTRM1 CASIN( RURD P Continue ND BOP's and Rig up to lift stack. 19:00 23:30 4.50 0 0 INTRM1 CASIN( RNCS P Install 9 5/8" emergency slips as per Vetco Gray Reps with 190K pulled on casing. Rig up WACHSpneumatic casing cutter & cut casing. Cut off joint = 28.73 laved down. RD Casing running equipment. Dress top of stump, and attempt to install packoff. Observeed damaged seals when install packoff. Remove packoff. Change out seals, Rig up and run packoff on running tool with stand of 5" HWDP. 23:30 00:00 0.50 0 0 INTRM1 CASINC NUND P Set BOP's down over packoff, nipple u BOP's. Ti hten flan a bolts. 10/23/2006 00:00 00:30 0.50. 0 0 INTRM1 CASIN( DHEQ P Rig up lines & pump forpackoff test. Test 9 5/8" packoff & BOP flange to 80% of burst at 2475 F SI. Hold pressure 15 Minutes. Good test witnessed by Co. Rep. Bleed pressure and rig down pump & lines. Rig up lines to perform Annular infectivity test. 00:30 01°15 0.75 0 0 INTRM1 CASIN< DHEQ P Load lines to annulus. Perform Annular infectivity test to observe break over at 400 PSt for and EMW of 13.0 PPG calculated. Continue pump a total of 40 BBLS of water, with pressureto 860 PSI @ 2.5 BPM. Shut in pressure = 820 PSI. Blow down lines. 01:15 02:15 1.00 0 0 INTRM1 CASIN ( NUND P Continue nipple up remaining BOP's installing turnbuckles and flowlines. Clean & clear cellar area. Page 3'1 of m9 Time Logs - _ . -_ _ - --- -- - --- _ -_ _ - - _ Date From To Dur -S__D~th E_Dz~th Phase_ Code__Subco~e_T_ _COM_ _ -_.----- INTRM1 CASIN( RURD P Contiue loaed last of 4" Drill pipe in 10/23/2006 02:15 03:00 0.75 0 0 shed. Strap same. Rig up on floor to pickup 4" DP. Install mousehole in rota table. 03:00 03:15 0.25 0 0 I NTRMI CASINC SFTY P PJSM with crew. Discuss safety " i ssues and procedure for picking up 4 DP from shed in stands and racking back in derrick. Discuss pumping annular volume of a total of 438 BBLS down 9 5/8" x 13 3/8" annulus. 03:15 06:00 2.75 0 0 I NTRM1 CASIN( RURD P Pick up 4" DP from pipe shed: Rack` stands in derrick. NOTE: Started pumping remaining volume into. annulus staging pump to 5 BPM - 1000 PSI: Pump a total of 438 BBLS down annulus.Final Circulating pressure = 620 PSI @ 5 BPM. Shut in pressure = 550 PSI. Picked up a total of 25 stands, 4" DP. Crew.., Chan e 06:00 07:45 1.75 0 0 INTRM1 CASINC RURD P Install Seal around bell nipple in floor . pan. Blow down injection line. Rig up - Little Red Services to freeze rotect. 07:45 12:00 4.25 0 0 INTRM1 CASINC RURD P Continue pick up 4" DP from pipe shed, building stands and racking back in derrick. SIMOPS: With little Red, Fill & test lines to 1800 PSI. Open annulus and pump 130 BBLS of freeze protect diesel. down 9 5/8" x 13 3/8" annulus @ 3 BPM - 300 PSI, @ 65 BBLS away pressure = 750 PSI, FCP = 850 PSL. Shut in annulus, observe pressure fora 10 minute bleed off to 225 PSI. Rig down & release Little Red Sevices. RD alt annular injection a ui ment. 12:00 13:30 1:50 0 0 INTRM1 .CASINC RURD P Continue pickup 4" DP from shed, building stands and racking back in derrick for a total of 85 stands. 13:30 14:45 1.25 0 0 INTRM1 CASIN( RURD P Clean & clear rig floor. Pull mouse hole from rotary table. Change out elevators. Pick up test joint, make up wear bushing tool. Install wear bushin . RILDS. ID of W6 = 9". 1.4:45 15:45 1.00 0 0 INTRM1 RIGMN SVRG P PJSM with crew. Discuss safety issues and procedure for rigging up. and testing stabbing board with Tuboscope magna flux inspection. Discuss Service Top Drive & draw works. Rig up Tuboscope rep. Magna flux stabbing board as per Tuboscope re .Ins ection results - ood. 15:45 16:45 1.00 0 0 INTRM1 RIGMN SVRG P Service Top Drive & draw works. Service crown section. ----- I'~g~ 32,c~f S9 i - - - -- - -_ -_ -- -~ __ -_- Time Logs - - - - - - -- - - --- Date_- From To _ Dur S. Depth _E. D~th Phase- Code_ _Subcode T_ _ _ _ _ -- --- 0 INTRM1 RIGMN SVRG P Hold PJSM. Discuss safety issues 10/23/200616:45 18:00 1.25 0 and procedure for slip & cut drilling line. Rig up & slip & cut 110' of drilling line. Crew than e 18:00 19:00 1.00 0 0 I NTRM1 RIGMN SVRG P Continue slip & cut 110' drilling line. 19:00 20:30 1.50 0 0 I NTRM1 RIGMN SVRG P Adjust brakes on draw works. Work on equalizing bar adjustment. Pull tools to ri floor. 20:30 21:30 1.00 0 587 I NTRM1 DRILL PULD P Held PJSM. Discuss safety issues and procedure for making up BHA. MAke up BHA#5. Make up 8 1/2" Hycalog TC10C bit with 3 x 16's, 1 x13 jets for a TFA of .581 sq. in.(.85'), 6 3/4" Near bit stabilizer with float (4.20'), 15 - 5" HWDP (460.49'), 6 1/4" Dailey drillingg jars (30.06'), 3 - 5" HWDP 92.36' .Total BHA = 587.96' 21:30 22:15 0.75 587 1,063 INTRM1 DRILL TRIP P Trip in hole from 58T - 1063' with 5" DP installing super sliders on each 'oint in the middle of the 'oint. 22:15 00:00 1.75 1,063 4,772 INTRM1 DRILL TRIP P Continue trip in hole with 5" Slick DP from 1063' - 4772'. Crew Chan e 10/24/2006 00:00 05:45 5.75 4,772 9,715 INTRM1 DRILL. TRIP P Continue trip in hole with 5" DP from 4772' - 9715' .Install Super sliders on joints from #45-#78. Fill Drill String every 25 stands. Observe proper hole fill 05:45 06:30 0.75 9,715 9,715 INTRM1 DRILL CIRC P Circulate bottom's up @ 9715'. Pump 717 m w/ 920 si. 06:30 07:00 0.50 9,715 9,715 INTRM1 DRILL RURD P RU to test 9-5/8" casing. 07:00 08:15 1.25 9,715 9,715 INTRM1 DRILL DHEQ P Test 9-5/8" casing to 3000 psi f/ 30 min. Chart test: Test with bit 9715'. 08:15 08:30 0.25 9,715 9,715 INTRM1 DRILL RURD P Rig-down testing equipment. 08:30 10:00 1.50 9,715 9,836 INTRM1 CEME~ DRLG P Drill float collar @ 9748' and cement to shoe @ 9831', then 12.25" rat hole to 9836'. Pumping 575 gpm w/ 2390 psi, rotate 80 rpm w/ 9-12k ft Ib torque. WOB 10-15k. 10:00 10:15 0.25 9,836 9,856 INTRM1 DRILL DRLG P Drill 20' of new hole f/ 9836' to 9856'. Rotate 80-100 rpm w/ 10-11 k ft Ib torque, 575 gpm w/ 1880 psi. WOB 10-15k. ADT= .12 hrs. Jar hrs. 61.6 hrs. 10:15 11:30 1.25 9,856 9,805 INTRM1 DRILL CIRC P Stand back a stand. Circulate bottoms up. Rotate 120 rpm w/ 10k torque. Pump 650 gpm w/ 2950 psi. Pump 745 bbls total 11:30 11:45 0.25 9,805 9,805 INTRM1 DRILL RURD P Blow down top drive. RU f/ LOT. 11:45 12:30 0.75 9,805 9,805 INTRM1 DRILL LOT P Peiform LOT. MW= 9.Oppg @ 3432' TVD w/ 810 si. EMW= 13.5 12:30 12:45 0.25 9,805 9,805 PROD1 DRILL CIRC P Pump dry job. - -- - Page: 33 of 69 ~~. I_ _____- Time Lo s - _ - _ - -----~ _ -_- - Dur SDepth E. De~h_ Phase -_ Code Subcode _T COM _ _ __ _ _- _- - To From ~ Date _ _ - 10/24/2006 12:45 13:00 0.25 9,805 9,805 PROD1 DRILL OTHR P Blow down top drive. 13:00 18:00. 5.00 9,805 0 PROD1 DRILL TRIP P POOH, UD jars, break bit off. Graded bit: 1,1,no, a,E,I,no,TD 18:00 18:30 0.50 0 0 PROD1 DRILL PULD P Clean and clear rig. floor. Change elevators to 4". 18:30 20:15. 1.75 0 87 PROD1 DRILL PULD P PU/MU BMA#6:MU6-3/4"Security fMF 36412 bit w/ (3) 20's, Sperry Sun . 5200 GeoPilot, geopilot flex drill collar, 4.75" DM HOC, Smart Stabilizer, 4.75" Gamma/Res, 4.75" PWD, 4.75" TM HOC w/ ulsar to 87.46' 20:15 20:45 0.50 87 87 PROD1 DRILL OTHR P Upload MWD. 20:45 21:15 0.50 87 126 PROD1 DRILL PULD P Continue PU/MU BHA #6:NM float sub, welded blade stabilizer, (1) NM flex drill collar to 18T. 21:15 21:45 0.50 1.26 126 PROD1 DRILL OTHR P Shallow test MWD and geopilot. Pump 300 gpm w/ 1200 psi. Rotate 25 m w/ 2k ft Ibs of for ue. 21:45 22:15 0.50 126 378. PROD1' DRILL PULD P Continue PU/MU BHA #6:(2) NM flex drill collars, x-o, (1) 4" HWDP, x-o, Baker circ sub, x-o, Drilling jar, (4) 4" HWDP to 378.67° 22:15 00:00 1.75 378 3,942 PROD1 DRILL TRIP P Trip. in hole w/ 4" drill pipe to 3942'. Fill. i e eve 25 stands. 10/25/2006 00:00 00:30 0.50 3,942 5,067 PROD1 DRILL TRIP P Trip in hole w/ 4" drill pipe from 3942' to 5067. Fill i e eve 25 stands. 00:30 01:00 0.50 5,067 5,067 PROD1 DRILL CIRC P Fill pipe. Check shot survey @ 5067 01:00 01:45 0.75 5,067 7,411 PROD1 DRILL TRIP. P Trip in hole w/ 4" drill pipe from 5067 to 7411'. Fill i e eve 25 stands. 01:45 02:00 0.25 7,411 7,411 PROD1 DRILL CIRC P Fill pipe. Check shot survey @ 7411' 02:00 03:00 1.00 7,411 8,823 PROD1 DRILL TRIP P Trip in hole w/ 4" drill pipe from 5067 to 8350', then 5"drill pipe to 8823'. Fill i e eve 25 stands. 03:00 03:15 0.25 8,823 8,823 PROD1 DRILL CIRC P Fill pipe. Check shot surrey @ 8823'. 03:15 03:45 0.50 8,823 9,776 PROD1 DRILL TRIP. P Trip in hole w/ 5"drill pipe from 8823' to 9776'. Fill i e eve 25 stands. 03:45 04:00 0.25 9,776. 9,856 PROD1 DRILL CIRC P MU-top drive, begin circulation. Pumping-280 gpm ECD's 9.48 ppg, 300 gpm ECD's= 9.55 ppg, 350 gpm ECD's = 9.58 ppg. Washing to bottom. Rotating 80-100 rpm w/ 8-9k ft Ibs for ue. ~_ -- P~c~e 34 of S ___ _, Time Lois - _- - -- --_ -- - -- ~ _ -- D_ate _ From 10/25/2006 04:00 To 06:00 ~ Dur _ _ 2.00 S._ De~th_ E- Depth Phase _ 9,856 10,060 PROD1 Code_ _ DRILL Suhcode DDRL T COM_ _ _ _ - P Drilling 6-3/4" production "B" lateral f/ 9856' to 10060' (204') (3445' ND) Bit hours= .70, Jar (#140-01019) hours= 43.44, ART= .70 hrs, WOB= 8k, 100 rpm, 280 gpm @ 2200 psi on bottom and 2200 psi off bottom. Torque = 7-9k ft-Ibs on botttom and 7-9k ft-Ibs off bottom. ECD= 9.48-9.58 ppg. Avg gas 25 units. P/U = 180-185k, S/O = 100-95k, Rot= 132-130k w/ um s off. 06:00 12:00 6.00 10,060 10,916 PROD1 DRILL DDRL P Drilling 6-3/4" production "B" lateral f/ 10060' to 10916' (856') (3425' ND) Bit hours= 4.52, Jar (#140-01019) hours= 47.26, ART= 3.82 hrs, WOB= 10-12k, 110-130 rpm, 280-340 gpm @ , 2200-3250 psi on bottom and 2200-3200 psi off bottom. Torque = 9-11 k ft-Ibs on botttom and 8-10k ft-Ibs off bottom. ECD= 9.69-10.1 ppg. Avg gas 55 units. P/U = 190-200k, S/O = 90-85k, Rot= 130-132k w/ um s off. 12:00 18:00 6.00 10,916 11,728 PROD1 DRILL DDRL P Drilling 6-3/4" production "B" lateral f/ 10916' to 11728' (812') (3424' ND) Bit hours= 8.07, Jar (#140-01019) hours= 50.81, ART= 3.55 hrs, WO6= 10-12k, 130-140 rpm, 340-348 gpm @ 3250-3520 psi on bottom and 3200-3500 psi off bottom. Torque = 10-12k ft-Ibs on botttom and 9-12k ft-Ibs off bottom. ECD= 10.19-10.45 ppg. Avg gas 100 units. P!U _ 200-205k, S/O = 85-SOk, Rot= 132-130k w/ pumps off. Pumped a 30 bbl Hi vis weighted sweep @ 11400'. Slight increase in cuttin s. 18:00 00:00 6.00 11,728 12,549 PROD1 DRILL DDRL P Drilling 6-3/4" production "B" lateral f/ 11728' to 12549' (821') (341.8' ND) Bit hours= 11.70, Jar (#140-01019) hours= 54.44, ART= 3.63 hrs, WO6= 4-40k, 140 rpm, 340-348 gpm @ 3450- 3500 psi on bottom and 3410-3450 psi off bottom. Torque = 11-13k ft-Ibs on botttom and 12-13k ft-Ibs off bottom. ECD= 10..45-10.68 ppg. Avg gas 100 units. P/U = 210-215k, S/O = 78-75k, Rot= 132-135k w/ pumps off. Pumped a 30 bbl Hi vis (180), weighted (10.9 ppg) sweep @ 11740'. Slight increase in cuttings. Pumped a 25 bbl Hi vis (185), weighted (10.9 ppg) sweep @ 12342'. No si nificant increase in cuttin s. - -- PacJa 'S of S9 ~ ~ Time Loc,~s - ____ -- { - ~ D~te From To Dur S_ Depth E Depth Phase_ _ Code Sub~ode T _ COM _ _ " 10/26/2006 00:00 06:00 6.00 12,549 13,010 PROD1 DRILL DDRL P lateral f/ Drilling 6-3/4"production "B 12549' to 13010' (461') (3418' ND) Bit hours= 16.17, Jar (#140-01019) hours= 58.91, ART= 4.47 hrs, WOB= 4-12k, 140-125 rpm, 340 gpm @ 3450-3470 psi an bottom and 3450-3460 psi off bottom. Torque = 12-14k ft-Ibs on botttom and 10-12k ft-Ibs off bottom. ECD= 10.78-10.6 ppg. Max gas 227 units. P/U = 210-215k, S/O = 75k, Rot= 132k w/ pumps off. Pumped a 25 bbl Hi vis (200), weighted (10.9 ppg) sweep @ 12872'. Sli ht increase in cuttin s. 06:00 12:00 6.00 13,010 13,507. PROD1 DRILL DDRL P Drilling 6-3/4" production"B" lateral f/ 13010' to 13507 (497) (3403' ND) Bit hours= 19.30, Jar (#140-01019) hours= 62.04, ART= 3.13 hrs, WO6= 6-10k, 140 rpm, 345-348 gpm @ 3320-3470 psi on bottom and 3350-3100 psi off bottom. Torque = 11-12k ft-Ibs on botttom and 13-14k ft-Ibs off bottom. ECD= 10.99-10.64 ppg. Avg gas 75 units. Max gas 250 units. P/U = 220-225k, S/O = 75-70k, Rot= 135-140k w/ um s off. 12:00 18:00 6.00 13,507 14,194 PROD1 DRILL DDRL P Drilling 6-314" production "B" lateral f/ 13507 to 14194' (687) (3407 ND) Bit hours= 23.55, Jar (#140-01019) hours= 66.29, ART= 4.25 hrs, WOB= 6-10k, 110-140 rpm, 350-346 gpm @ 3650-3500 psi on bottom and 3500-3600 psi off bottom. Torque = 11-13k ft-Ibs on botttom and 13-14k ft-Ibs off bottom. ECD= 10.02-10.86 ppg. Avg gas 75 units. Max gas 303 units. P/U = 235k, S/O = 70k, Rot= 140k w/ um s off. 18:00 00:00 6.00 14,194 15,032 PROD1 DRILL DDRL P Drilling 6-3/4" production "B" lateral f/ 14194' to 15032' (838') (3405' ND) Bit hours= 26.82, Jar (#140-01019) hours= 69.56, ART= 3.27 hrs, WO6= 6-12k, 140 rpm, 345 gpm @ 3600-3800 psi on bottom and 3560-3790 psi off bottom. Torque = 12-15k ft-Ibs on botttom and 14k ft-Ibs off bottom. ECD= 10.86-11.28 ppg. Avg gas 75 units. Max gas 324 units. P!U = 230-255k, S/O = 70k, Rot= 140-135k w/ pumps off. Pumped a 30 bbl weighted (10.9ppg) hi vis (200) sweep while drilling @ 14730' (3398' ND). Started losing mud @ approx 50 bph when sweep got to bit, while drillin 14820' 3398' ND . __ F'ac~e 3E of 69 ~ _ __ -- -- • L _ i ogs Time - -- - -- _- - -- -- - _ - - Date From To Dur De th S. P E_ DCpth Phase Code _ Subcode T COM __ ___ ' - -- __ YO/27/2006 00:00 06:00 __ _ 6.00 _ 15,032 15,606 PROD1 DRILL DDRL P Drilling 6-3/4".production"B" lateral f/ 15032' to 15606' (574') (3389' ND) Bit hours= 30.51, Jar (#140-01019) hours= 73.25, ART= 3.69 hrs, WOB= 8-12k, 140 rpm, 345 gpm @ 3550 psi on bottom and 3550 psi off bottom. Torque = 13-15k ft-Ibs on botttom and 14-15k ft-Ibs off bottom. ECD= 11.15-11.31 ppg. Avg gas 75 units. Max gas 324 units. P/U = 252k, S/O = 72k, Rot= 130k w/pumps off. Pumped a 30 bbl weighted (10.9ppg) hi vis (200) sweep while drilling @ 14730' (3398' ND). Started losing mud @ approx 50 bph when sweep got to bit, while drilling @ 14820' {3398' ND). @ 0600 hrs: Losses appear to be 32 bph. Fluid loss to well f/ 2230 hrs 10/26/2006 to midnight =103 bbls. Fluid loss. to well f/midnight to 0600 hrs = 154 bbls. Fluid lost to well total @ 0600 hrs = 257 bbls 06:00 12:00 6.00 15,606 15,950 PROD1 DRILL DDRL P Drilling 6-3/4" production "B" lateral f/ 15606' to 15950' (344') (3386' ND) Bit hours= 34.82, Jar (#140-01019) hours= 77.56, ART= 4:31 hrs, WOB= 10-12k, 110-130 rpm, 345-300 gpm @ 3700-2890 psi on bottom and 3700-2880 psi off bottom. Torque = 14-16k ft-Ibs on botttom and 14k ft-Ibs off bottom. ECD= 11.29-10.63 ppg. Avg gas 84 units. Max gas 300 units. P/U = 260-285k, S/O = 70k, Rot= 130-135k w/ pumps off. Losses appear to be 33 bph. Slowed flow rate to 300 m. 12:00 18:00 6.00 15,950 16,436 PROD1 DRILL DDRL P Drilling 6-3/4" production "B" lateral f/ 15950' to 16486' (486') (3378' ND) Bit hours= 38.26, Jar (#140-01019) hours= 81.0,. ART= 3..44 hrs, WOB= 10-12k, 90-110 rpm, 300 gpm @ 2870-3060 psi on bottom and 2900 psi off bottom. Torque = 15-16k ft-Ibs on botttom and 15k ft-Ibs off bottom. ECD= 10.46-10.63 ppg. Avg gas 100 units. Max gas 300 units. P/U = 285k, S/O = 70k, Rot= 145k w/ pumps off. Pumped 30 bbl LCM sweep @ 15985': 20 ppb safecarb 250. Losses appear to be 9 bph. Fluid lost f/ 0600 hrs to 1800 hrs = 100 bbls. Fluid loss to well total @ 1800 hrs = 357 bbls. ----- _- ' 63 r~~ge 37 of • Time Logs __ __ - - _ - - ` Date From To Dur S_ D~th_ E__Depth Phase - Code Subcode_ _T _ COM _ ___ -_ -- 10/27/2006 _ 18:00 _ 00:00 _ 6.00 16,436 16,717 PROD1 DRILL DDRL P Drilling 6-3/4"production "B" lateral f/ 16436' to 1671T (281') (3365' TVD) Bit hours= 42.93, Jar (#140-01019) hours= 85.67, ART= 4.67 hrs, WOB= 12-13k, 110 rpm, 303 gpm @' 2780-2830 psi on bottom and 2800 psi off bottom. Torque = 16-18k ft-Ibs on botttom and 16k ft-Ibs off bottom. ECD= 10.77-10.78 ppg. Avg gas 87 units. Max gas 273 units. P/U = 285k, 8/O = 70k, Rot= 150k w/ pumps off. Losses appear to be 4 bph avg. fluid lost f/ 1800 hrs to midnight=25 bbls Fluid lost f/day = 279 bbls Fluid Isot to well total = 382 bbls. 10/28/2006 00:00 06:00 6.00 16,717 17,079 PROD1 DRILL DDRL P Drilling 6-3/4" production "B" lateral f/ 16717 to 17079' (362') (3346' TVD) Bit hours= 47.26, Jar (#140-01019) hours= 90.00, ART= 4.33 hrs, WOB= 8-13k, 110-120 rpm, 300 gpm @ 2740-2800 psi on bottom and 2710 psi off bottom. Torque = 16-17k ft-Ibs on botttom and 16k ft-Ibs off bottom. ECD= 10.86-11.37 ppg. Avg gas 85 units. Max gas 224 units. P/U = 290k, S/O = 70k, Rot= 145Kw/ pumps off. Losses appear to be 4.2 bph avg. Fluid lost f/ midnight to 0600 hrs =26 bbls Fluid lost to well total = 408 bbls. 06:00 12:00 6.00 17,079 17,572 PROD1 DRILL DDRL P Drilling 6-3/4"production "B" lateral f/ 17079' to 17572' (493') (3353' TVD) Bit hours= 50.21, Jar (#140-01019) hours= 92.95, ART= 2.95 hrs, WOB= 10-12k, 120 rpm, 303 gpm @ 2740-2900 psi on bottom and 2750-2810 psi off bottom. Torque = 15-16k ft-Ibs on botttom and 16-17k ft-Ibs off bottom. ECD= 11.3-1.1.4 ppg. Avg gas 100 units. Max gas 157 units. P/U = 290-195k, S/O = 70k, Rot= 145-138k w/ um s off. 12:00 17:00 5.00 17,572 17,844 PROD1 DRILL DDRL P Drilling 6-3/4" production "B" lateral f/ 17572' to 17844' (272') (3359' TVD) Bit hours= 54.22, Jar (#140-01019) hours= 92.95, ART= 4.0196.96 hrs, WO6= 10-14k, 120 rpm, 300 gpm @ 2890-3000 psi on bottom and 2810-2900 psi off bottom. Torque = 15-16k ft-Ibs on botttom and 16-17k ft-Ibs off bottom. ECD= 11.4-11.3 ppg. Avg gas 100 units. Max gas 149 units. P/U = 295k, S/O = 70k, Rot= 140k w/ um s off. P~qe 3~ ~rf r39 -_ • • Time Loc,~s -- - - - - -- - --- - - _ _ l --- _ _ S Depth E_ D~th_Phase___ Code Sub_c_ode T COM _ _-- -_ __ - - From To Dur Date _ _ 10/28/2006 17:00 17:30 0.50 17,844 17,844 PROD1 DRILL CIRC P Take survey. Then circ @ 310 gpm w/ 3060 psi. Rotae 120 rpm w/ 18k ft Ib for ue. 17:30 18:00 0.50 17,844 17,844 PROD1 DRILL CIRC P Pump 45 bbl weighted (10.9 ppg) hi vis (200) sweep. Pumping @ 310 gpm w/ 3060 psi. Rotate 120 rpm w/ 18k ft Ib torque. Total fluid lost to well f/ 0600 hrs to 1800 hrs = 73 bbls 18:00 21:00 3.00 17,844 17,844 PROD1 DRILL CIRC P Circulate sweep out of hole plus another bottom's up. Pumping 310 gpm w/ 2900 psi. Rotate 110 rpm w/ 16k ft Ib torque. PU wt 295k, So wt 72k. Circulated a total of 1428 bbls. No si nificant increase in cuttin s. 21:00 21:15 0.25 .17,844 17,844 PROD1 DRILL OWFF P Monitor well. Static. 21:15 21:45 0.50 17,844 17,574 PROD1 DRILL TRIP P Pull 3 stands out of hole. f/ 17844' to 17574'. Hole a ears to be swabbin . 21:45 22:00 0.25 17,574 17,479 PROD1 DRILL REAM P Backream a stand out of hole f/ 17574' to 17479'. Pumping 300 gpm w/ 2900 psi. Rotate 120 rpm w/ 17-18k ft Ib for ue. 22:00 22:45 0.75 17,479 17,100 PROD1 DRILL TRIP P Pull out of hole on elevators 4 stands f/ 17479' to 17100'. PU wt 310-320k. A ears to be swabbin . 22:45 00:00 1.25 17,100 16,338 PROD1 DRILL REAM P Backream every other stand f/ 17100' to 16338'. Pumping 300 gpm w/ 2900-3000 psi. Rotate 110 rpm w/ 16-18 k ft Ib torque.. Total of 16 stands out of hole @ midnight. Total fluid lost f/ 1800 hrs to midnight = 37 bbls Total fluid lost to hole-today =.136 bbls. Total fluid lost to well = 518 bbls. 10/29/2006 00:00 02:00 2.00 16,338 15,481 PROD1 DRILL REAM P Backream out of hole, every stand f/ 16338' to 15481'. Pumping 310 gpm w/ 2750-2900 psi. Rotate 110. rpm w/ 16-18 k ft Ib torque. Total of 25 stands out of hole. 02:00 01:00 -1.00 15,481 15,481. PROD1 DRILL P Daylight savings time. 01:00 01:45 0.75 15,481 15,006 PROD1 DRILL REAM P Continue back ream every other stand f/ 15481' to 15006'. Pumping 300 gpm w/ 2900-3000 psi. Rotate 110 rpm w/ 16-18 k ft Ib torque. Total of 30 stands out of hole. 01:45 03:00 1.25 15,006 14,344 PROD1 DRILL REAM P Continue back ream every stand f/ 15006' to 14349'. Pumping 310 gpm w/ 2750-2900 psi. Rotate 110 rpm w/ 13-17 k ft Ib torque.. Total of 37 stands out of hose. 03:00 03:15 0.25 14,344 14,154 PROD1 DRILL TRIP P Pull stand #38 and stand # 39 out of hole f/ 14344' to 14154'. _ Is~€~c 3~ of 6?~ • • _ _ -- --- Time Lis - - - -- - - - - __ ___ _- _ _ ~ir S. Depth E, D pth Phase_ TCode _ Subcode T _ C - _ _ __ _ --- ----- o D From T Date _ _ _ _ 10/29/2006 03:15 04:00 0.75 14,154 13,488 PROD1 DRILL TRIP P Pull stand #40 thru 46 out of hole f/ 14154' to 13488' usin tri tank. i 04:00 04:30 0.50 13,488 13,488 PROD1 DRILL OWFF P x Monitor well„ static, clean floor, m d 'ob. 04:30 D5:00 0.50 13,488 13,392 PROD1 DRILL CIRC P Pump dry job. Blow down top drive. Pull stand #47 f/ 13488' to 13392'. d ' ' 05:00 06:00 1.00 13,392 10,920 PROD1 DRILL TRIP P (stan s to 10920 POOH f/ 13392 48-73). Note: Stand 55 out is the first stand t hat vre can go down (12632'). 130 stands in the hole Hole taking proper displacement. Fluid lost to well f/ midnight to 0600 hrs = 10.5 bbls HA #6 f/ 10920' 06:00 06:30 0.50 10,920 10,064 PROD1 DRILL TRIP. P Continue POOH w/ B to 10064'. Total of 82 stands out of hole. th # .03 i 06:30 07:15 0.75 1.0,064 10,055 PROD1 DRILL CfRC P e n 1 MU top drive on stand hole. Break circ, downlink to make geopilot zero deflected. Drop 1.88" OD ball rod to open Baker circ sub. Circ ball down @ 320 gpm w/ 2800-3000 psi, slow down to 282 gpm w/ 2600 psi prior to ball .rod getting to seat. Once sheared pressure fell off. Sheared @ 70 bbls pumped. While circulating @ 320 gpm, pressure is now 1500 psi. MWD now has no detection below. Circ sub is 224' above bit. Rotae @ 120 rpm w/ 10k ft Ib for ue. 07:15 09:30 2.25 10,055 9,589 PROD1 DRILL CIRC P Pump 38 bbl Hi weight (10.9 ppg) hi vis (200) sweep. Stage pumps up to 600 gpm w/ 4200 psi. Rotate 120 rpm w/ 10k ft Ib torque. Pump 600 bbls while ullin slow) f/ 10055' to 9589'. 09:30 11:00 1.50 9,589 9,589 PROD1 WELCT OTHR P Blow down #op drive. MU baker 9-5/8" - EA retrievamatic packer as a storm packer to perform weekly BOP test. MU to stand # 99. 11:00 11:30 0.50 9,589 9,664 PROD1 WELCT OTHR P RIH w/ storm packer and set 75' below. rig floor. Release and POOH. UD runnin tool 11:30 11:45 0.25 0 0 PROD1 WELCT SFTY P PJSM on pulling wear bushing. 11:45 12:00 0.25 0 0 PROD1 WELCT OTHR P PuIFVetco Gray 13-1/4" OD x 9" ID 38" Ion wear buskin . 12:00 12:30 0.50 0 0 PROD1 WELCT OTHR P Check wear on saver sub on top drive, Ok.MUtest'ointtoto drive. 12:30 12:45 0.25 0 0 PROD1 RIGMN SFTY P PJSM on cutting drilling line. 12:45 14:00 1.25 0 0 PROD1 RIGMN SVRG P Hang blocks to cut drilling line. Slip and cut 170' of 1-3/8" drillin line. 14:00 14:15 0.25 0 37 PROD1 WELC T OTHR P PJSM on testing RU to test. BOPE lu : t test t 14:15 14:30 0.25 37 37 PROD1 WELC T OTHR P g p , se RU test equipmen --- ---- -~- - €~~ge 4f7 of 69 I s • Time ~s - - Date From To Dur S Depth E, D_ epth Phase Code S_ubcode T_ CO_M_ _ _- _ _ 10/29/2006 14:30 15:00 0.50 37 37 PROD1 WELCT OTHR P Ru test equipemnt on floor. Fill choke manifold and BOPE stack with water. 15:00 15:15 0.25 37 37 PROD1 WELCT BOPE P PJSM on testing BOPE. 15:15 18:00 2.75 37 37 PROD1 WELCT BOPS P Test BOPE: Witness of test waived by AOGCC inspector Chuck Sheave.Test to 300 psi low and 3000 psi high. Hold each test 5 min, chart test.Test annular, top pipe rams (3-1/2" x 6"), choke manifold; kill line valves, choke line valves, top-drive IBOP, floor safety valves. Fluid lost to welFf/ 0600 hrs to 1800 hrs = 7 bbls. 18:00 18:30 0.50 37 37 PROD1 WELCT BOPE P Perform Koomey test. Test gas alarms. 18:30 19:00 0.50 37 0 PROD1 WELCT BOPE P Test blind rams and 3" demco mudline to 300 psi and 3000 psi, Hold each test 5 min. Chart test 19:00 19:30 0.50 0 0 PROD1 WELCT OTHR P Rig down test equipment. Blow down choke manifold and line. Blow down to drive. Blow down kill line. 19:30 20:15 0.75 0 0 PROD1 WELCT OTHR P Pull test plug. Set wear bushing. Lay down test'oint. 20:15 21:00 0.75 0 75 PROD1 WELCT BOPE P Lay down asingle f/ stand # 99, MU screw in cut lip guide to retrieve storm packer. RIH, engage Baker retrievamatic @ 75'. Equalize pressure. PU wt 180k, SO wt 11 K. Hole took 7,5 bbls to fill 21:00 21:30 0.50 75 9,589 PROD1 WELCT ROPE P POOH w/ storm packer f/ 9664' to 9589' 21:30 21:45 0.25 9,589 9,589 PROD1 DRILL OTHR P Clear and clean rig floor. 21:45 23:45 2.00 9,589 12,252 PROD1 DRILL TRIP P Trip in hole w/ BHA #6 f/ 9589' to 12252'. Record PU and SO wt's every 5 stands. Fill hole eve 20 stands. 23:45 00:00 0.25 12,252 12,422 PROD1 DRILL REAM P Lost down wt @ 12252' (stand 126 in hole). Ream in hole w/ 12252' to 12422'. Pumping 30 spm w/ 560 psi. Rotate 50 rpm w/ 8-12k ft Ib torque. Running speed 60-70 fUmin. Fluid lost to well f/ 1800 hrs to midnight = 7.5 bbls Fluid lost total for day = 25 bbls. Fluid lost to well total = 543 bbls 10/30/2006 00:00 06:00 6.00 12,422 17,005 PROD1 DRILL REAM- P Continue to ream in hole f/ 12422' to 17005'. Pumping 30 spm w/ 560-740 psi. Rotate 50 rpm w/ 15-18k ft'Ib torque. Running speed 60-70 ft/min. Fluid lost to well f/ Midnight to 0600 = 10 bbls Fluid lost to well total = 553 bbls 06:00 08:15 2.25 17,005 17,844 PROD1 DRILL REAM P Continue to ream in hole f/ 17005' to 17844': Pumping 30 spm w/ 740-780 psi. Rotate 50 rpm w/ 18k ft Ib torque. Runnin seed 15-30 ft/min. -- Page 41 csf fin -- --- m_____ ~-- _ - -- - __ Time ogs _ - _ - _ - - ~ - Dur S. DP t_h E. De th_Phase .Code Subcode T__ COM_ _ _ _ _ _ - To Date From ~ __ _ _ v _ Circulate up to 320 gpm, then drop 10/30/2006 08:15 10:45 2.50 17,844 17,844 PROD1 DRILL CIRC P back fo 300 gpm w/ 1880 psi. Pump 45 bbls weighted (10.8 ppg) hi vis (200) sweep, follow w/ 8.8 ppg OBM.Rotate 120 rpm w/ 16-17k ft Ib for ue. Pum ed 1015 bbls. 10:45 13:15 2.50 17,844 17,844 PROD1 DRILL CIRC P Sweep came back to surface, no significant increase in cuttings. Displace f/ 8.8 OBM to 8.8 SFOBM. Pump @ 310 gpm w/ 2030 psi. Rotate 120 rpm w/ 15-16k ft Ib torque. Fluid loss @ startof circulation = 8 bph. Total losses to formation = 22 bbls. Total losses to well @ 1315 hrs = 575 bbls. 13:15 13:30 0.25 17,844 17,844 PROD1 DRILL OWFF P Monitor well. Static. 13:30 13:45 0.25 17,844 17,763 PROD1 DRILL CIRC P Pump dry job. 13:45 14:00 0.25 17,763 17,763 PROD1 DRILL OTHR P Blow down top drive. 14:00 17:45 3.75 17,763 9,590 PROD1 DRILL TRIP P Pull out ofhole on elevators f/ 17763' to 9590'. Record PU and SO wt's eve 5. 17:45 18:00 0.25 9,590 9,590 PROD1 DRILL OWFF P Monitor well @ shoe. Static. Calculated fill 71.82, actual 100.5 bbls This is a total of 28.68 bbls over calculated. 18:00 23:15 5.25 9,590 380 PROD1 DRILL TRIP P Continue POOH f/ 9590' to BHA @ 380'. Record PU and SO wt's every 10 stands in cased hole. 23:15 23:30 0.25 380 380 PROD1 DRILL OWFF P Monitor well @ BHA. Static. Calculated fill 130.03 bbls, actual 181.5 bbls. This is a total of 51.47 bbls over calculated. 23:30 00:00 0.50 380 187 PROD1 DRILL PULD P Pull out of hole and lay down BHA #6 f/ 380' to 18T. Break out and lay down x-o, x-o, Baker circ sub, x-o, x-o, stand back 5 stands 4" HWDP w/ drilling jars. .Calculated displacement 135.03, actual 188.5 bbls. This is a total of 53.47 bbls over calculated. Total loss for the day 85.5 bbls. Total losses to the well = 628.5 bbls. 10/31/2006 00:00 00:30 0.50 187 92 PROD1 DRILL PULD P Continue laying down BHA #6 f/ 187'. Stand back stand of 4-3/4" nm flex drill collars to 92' 00:30 01:00 0.50 92 92 PROD1 DRILL OTHR P Download MWD .--_ -- _.._.~.--_ -Page 42 r,f 6~ I Time Lis __ - __ -_ _ - _ I Date From To ~Llf _ S. De~th_ E._D?~h Phase -- .Code _ Subcode_ - T_ COM_ _. __ - ~ -- 10/31l2006 01:00 02:15 1.25 92 0 PROD1 DRILL PULD P Continue POOH, UD, welded blade stab, nm float sub, TM HOC, PWD, Gamma/Res, smart stab, DM HOC, geopilot flex collar, 5200 geopilot ser no. TL025, and 6-3/4" security FMF 3641 Z bit. Bit graded 1 /OBC/N/X/I/ER/TD. Calculated fill on trip out was 138.58 bbls. Actual fill on trip out was 192.05 bbls. This is 53.5 bbls over calculated. Total fluid lost to hole f/ midnight to 0215 hrs = 0 bbls. Total fluid lost to well @ 0215 hrs = 628.5 bbls. 02:15 03:00 0.75 0 0 PROD1 DRILL OTHR P Clean floor 03:00 03:15 0.25 0 0 COMPZ CASIN( SFTY P PJSM on RU casing tools 03:15 04:30 1.25 0 0 COMPZ CASIN( RURD P RU casing tools f/ 4-1 /2" liner. 04:30 04:45 0.25 0 0 COMPZ CASINO SFTY P PJSM on running 4-1 /2" slotted liner. 04:45 -06:00 1.25 0 981 COMPZ CASIN( RNCS P Running 4-1/2" "B" lateral slotted blank lines Jt # 22 in the hole @ 0600 hrs. Record PU and SO wt's every 10 jts. Total fluid lost since trip out (0215 hrs to 0600 hrs).= 12 bbls Total fluid lost to well @0600 hrs = 640.5 bbls. 06:00 06:30 0.50 981 981 COMPZ CASIN( SFTY P PJSM on running 4-1/2" slotted/ blank. liner w/ new crew. 06:30 12:00 5.50 981 7,819 COMPZ CASIN( RNCS P Continue running 4-1/2" "B" lateral slotted/Blank liner f/ jt # 22 to jt 183. MU x-o f/ 4-1/2" BTC to 4-1/2" Hydril 521. Torque to 8500 ft Ib. Record PU and SO wt's every 10 jts while running inside of 9-5/8" casin 12:00 13:45 1.75 7,819 8,614 COMPZ CASIN( RNCS P Continue to run 4-1 /2" liner. Last 18jts are 4-1/2" L-80 11.6 ppf hydril 521 slotted, first four have Hydraform centering guides w/stop ring in center of joint. MU pup, x-o, 190-47 csbr, x-o bushing, flexlock liner hanger, RS packoff seal nipple, HRD ZXP liner top acker, liner runnin tool 13:45 14:15 0.50 8,614 8,614 COMPZ CASIN( RURD P Monitor well, static. UD casing e ui emnt. Clear and clean ri floor. - - - i }gage ~ o~ ~9 • • I Time Logs -- _ _- - ---- -- -- - Daie - 10/31/2006 From 14:15 To _- 18:00 Dur_- 3.75 S_Depth 8,614 E. D~th 12,338 Phase COMPZ Code CASIN( Subcode RUNL T_ COM _ _ - - - - - P Set torque to 8 k ft Ibs on top drive. Run Brier on 5"drill string f/derrick. Fill pipe every row (11 stands). Record PU and SO wt's every 5 stands for a while, then go to every row (11 stands). 39 stands total of 5" dp in hole @ 1800 hrs: of-which first 5 have super slideers, then 34 stands-slick.. Fluid lost to well f/ 0600 hrs to 1800 hrs = 12 bbls Total fluid lost to well @ 1800 hrs = 652.5 bbls. 18:00 20:00 2.00' 12,338 13,684 COMPZ CASINC RUNL P Continue run liner in hole on 5" dp f/ 12338' to 13684'. Record PU and SO wt's every 5 stands. Fill pipe every row 11 stands . 20:00. 20:45 0.75 13,684 14,237 COMPZ CASIN( RUNL P Continue running liner on 5" dp. Rotate down f/ 13684' to 13761', then R4H to 14237. Record PU and SO wt's every 5 stands. 20:45 00:00 3.25 14,237 16,327 COMPZ CASIN( RUNL P Rotate liner in hole. Rotate 30 rpm, running speed 60-70 ft/min. Monitoring torque as being run. Record PU-and so wt's approx every 10 stands. Surface torque @ 16042' is 11500 ft Ib. PU 230k, SO wt =block wt of 72k. Fluid lost to well f/ 1800 hrs to midnight = 9 bbls. Total fluid lost to well today = 33 bbls. Total fluid lost to well = 661.5 11/01/2006 00:00 02:45 2.75 16,327 17,844 COMPZ CASIN( RUNL P Rotate liner in hole f/ 16327' to 17844'. Rotate 30-50 rpm, running speed 40-50 ft/min. Monitoring torque as being run. Record PU and SO wt's approx every 10 stands. Surface torque @ 17831' is 13k-15k ft Ib. PU 300k, SO wt = block wt of 72k. Rotating wt= 140k. Drifted HWDP to 2.33". Rotate and to bottom 17844'. 02:45 03;00 0.25 17,844 17,831 COMPZ CASIN( OTHR P PU while rotating and break off single. Dro 1-3/4" ball 03:00 03:45 0.75 17,831 17,839 COMPZ CASINC CIRC P Pump ball down. Set liner on depth w/ shoe @ 17839', top of liner @ 9224.49'. Pumping 3 bpm w/ 350 psi, 4 bpm w/ 480 psi. pump till 1000 strokes, then slow to 30 spm w/ 350 psi. Ball on seat @ 345 hrs 1266 strokes. 03:45 04:00 0.25 17,839 17,839 COMPZ CASIN C OTHR P Pressure up to 200 psi to set hanger, slack off to 90k,pressure to 3000 psi to release liner, pressure to 4000 to nuetralize usher tool. 04:00 04:15 0.25 17,839 17,839 COMPZ CASIN C DHEQ P RU test equipment. Test annulus w/ annular. Pump into kill line. Test 1000 si f/ 5 min. -- - - l'a~e ~4 of ~S I -- --- _ _ ---- • • Time Logs _ ---- ---- - _ Date From- To__ _ Dur S_DC~th_E Depth_Phase_ ,Code- Subcode T_ _CO_M__ _ --_ -- UD single to pipe shed. Pull DRILL TRIP P POOH , 11/01/2006 04:15 04:30 0.25 17,839 9,172 COMPZ 45' on next stand. 04:30 05:30 1.00 9,172 9,172 COMPZ DRILL TRIP P Circulate bottoms up. Stage rate f/ 320 gpm w/ 760 psi, then to 400 gpm w/ 1050 psi, then to 500 gpm w/ 1500 si. 05:30 05:45 0.25 9,172 9,172 COMPZ DRILL OWFF P Observe well f/flow. Appears to be breathin , sli ht flow, slowin down. 05:45 06:00 0.25 9,172 9,172 COMPZ DRILL CIRC P Continue to circ @ 255 gpm w/ 420 psi, Mud lost to hole f/midnight to 0600 hrs = 9 bbls. 06:00 06:15 0.25 9,172 9,172 COMPZ DRILL OWFF P Monitor well. Static. 06:15 06:30 0.25 9,172 9,172 COMPZ DRILL OTHR P Pump 15 bbls dry job, blow down top drive, install stri in rubbers 06:30 11:15 4.75 9,172 0 COMPZ DRILL TRIP P POOH w/ Baker liner running tools f/ 9172' to surface. Record PU and SOO wt's every 5 stands. Monitoring well via tri tank_ 11:15 11:30 0.25 45 0 COMPZ DRILL PULD P Lay down Baker liner running tools. b f/to " 11:30 13:30 2.00 0 0 COMPZ RIGMN SVRG P p IF saver su Break off 4-1/2 drive and install a new saver sub. Bring whipstock assembly into pipe shed. 13:30 14:30 1.00 0 0 COMPZ RIGMN SVRG P Service top drive and crown. 14:30 15:30 1.00 0 0 COMPZ RIGMN SVRG P Inspect derrick. 15:30 15:45 0:25 0 0 COMPZ DRILL SFTY P PJSM on PU/MU whipstock assembly f/ "D" lateral 15:45 18:00 2.25 0 198 PROD2 STK PULD P PU/MU Whipstock BHA: 7-1/2" Seals, 8-1/4" OD stop sub,. x-o, unloader sub, (2) jts 5"HWDP, blank sub, bottom trip anchor, safety disconnect, drain sub, debris sub, whipstock (17.22' slide), starter mill (7-7/8" OD), lower watermelon mill (8"), flex joint (10.01'), upper watermelon mill (8-1/2"), 1 jt of 5" HWDP, float-.sub, MWD w/ Gamma/Res, lubricated bumper jars to 197.86'. Note: Rabbit HWDP to 2.5".Once sheared off of whipstock, BHA Length wilF be 94.32'. Fluid lost to hole f/ 0600 hrs to 1800 hrs = 12 bbls. embl k 18:00 23:15 5.25 198 5,030 PROD2 STK TRlP P y ass Trip in hole with whipstoc on 5" drill pipe to stand 51 in hole @ 5030°. Fill i e eve 2000'. _- - _ _ ---- f'~g~ 4~a of S9 L --- • Time Lomas -- _ - _- - _ E Depth_I?hase _ Cc~_e_ Subcod_ e__ T COM _ ____ __ ___ _ De~h Dur S From To I Date _ _ _ _ _ 11/01/2006 23:15 00:00 0.75 5,030 5,506 PROD2 STK TRIP P Continue trip in hole f/ 5030' to 5506' (stand #56 in hole. Checking torque and inspecting super sliders. Fluid lost to hole f/ 1800 hrs to midnight = 5 bbls Total fluid lost to hole today = 26 bbls. Total fluid lost to "B" lateral = 687.5 bbls. 11/02/2006 00:00 03:45 3.75 5,506 8,167 PROD2 STK TRIP P Continue trip in hole f/ 5506' to 58167'. Checking torque and inspecting super. sliders. Fill i e eve 20 stands. 03:45 04:15 0.50 8,167 8,548 PROD2 .STK TRIP P Coritmue RIH w/ 5"drill pipe w/o super sliders f/ 8167 to 8548' 04:15 05:15 1.00 8,548 8,605 PROD2 STK CIRC P Establish circ and MADD pass log f/ 8548' to 8605' no go depth. Logging de th 8385' to 8442'. 05:15 05:30 0.25 8,605 9,118 PROD2 STK TRIP P Continue RIH f/ 8605' to 9118'. 05:30 06:00 0.50 9,118 9,118 PROD2 STK CIRC P Break ci~c @ 9118': Orient whipstock. to 12 deg left. Pumping 505 gpm w/ 2000 psi. Fluid lost to well f/ midnight to 0600 hrs = 7 bbls Total fluid lost on trip in w/ whi stock = 12 bbls. 06:00 07:00 1.00 9,118 9,224 PROD2 STK TRIP P Continue to work string down to top of "B" lateral @ 9224'. Tag up, set anchor, attempt to shear off of whi stock, unsucessful. 07:00 07:30 0.50 9,224 9,224 PROD2 STK OTHR P PJSM on displacement f/ SFOBM to O BM. 07:30 09:00 1.50 9,224 9,224 PROD2 STK CIRC P Start displacement from 8.8 ppg SFOBM to 8.8 ppg OBM. Working string up to 220k and Down to block wt w/ 10k ft Ib torque. Finally broke shear bolt. 35k down to shear. Rotate @ 50 rpm after sheared. Stop rotation. Finish displacement of 600 bbls um ed 400 m w/ 1390 si. 09:00 12:45 3.75 9,121 9,139 PROD2 STK WPST P Start milling @ 9121' to 9138'. Rotate 80-90 rpm w/ 12-13k ft Ib torque. Max torque of 17k when upper mill @ top of window. Pumping 400 gpm w/ 1390 psi. Milled to 9139'. Rotating wt 135k, PU wt 220k, SO wt 100k. WOB 2-10k. Pumped @ 34 bbls hi vis weighted ~.~ swee while millin 9130'. I'~ge ' ~ of 69 ~ --- Time Lo s Date Froi~i To Dur S Depth E _~th .Phase. .Code _ Subcode T COM __ ____ ___ _ __ __ _ 11/02/2006 12:45 14:30 1.75 9,139 9,161 PROD2 STK WPST P Continue milling w/upper mill @ top of window, to bottom of window @ pilot mill depth of 9158.48', then continue milling to 9161' pilot mill depth. Upper mill 8-1/2" OD is 3' below bottom of window. Pumping 400 gpm w/ 1350 psi. Rotating 90 rpm w/ 10-17k ft Ib torque. Ream through window, then .. pass through with out rotation. Rotating weight 135k, PU wt 220k, SO wt 100k. WOB 2-6k. 14:30 18:00 1.50 9,161 9,161 PROD2 STK CIRC P Pump a 30 bbl hi vis weighted sweep. Work mill through window while pumping 400 gpm w/ 1350 psi. Rotate 120 rpm w/ 12k ft Ib torque. Circulate a total of 720 bbls. 16:00 16:15 0.25 9,161 9,161 PROD2 STK OWFF P Monitor well. Static 16:15 18:00 1.75 9,161 5,307 PROD2 STK TRIP P Blow down top drive, then pull out of hole w/milling assembly f/ 9161' to 5307. SPR @ 9161' : #1 @ 20 spm = 230 psi, 30 spm = 300 psi. #2 @ 20-spm = 230 si, 30 s m = 300 si. 18:00 20:30 2.50 5,307 647 PROD2 STK TRIP P Continue POOH w/milling assembly f/ 5307 to 64T 20:30 21:00 0.50 647 647 PROD2 RIGMN' SVRG P PJSM on slipping and cutting drilling line. 21:00 22:30 .1.50 647 647 PROD2 RIGMN SVRG P Slip and cut T15' of 1-3/8" drilling line. 22:30 00:00 1.50 647 0 PROD2 STK TRIP P Finish POOH w/milling assembly. Guage mills. Upper mill 8-1/2", middle miH 8", lower mill 7-5/8". Trip out talc 81 bbls, actual 98 bbls. Fluid lost total today = 24 bbls Total Fluid lost to well = 711.5 bbls. 11/03/2006 00:00 00:45 0.75 0 0 PROD2 STK PULD P Break and laydown Baker mills. 00:45 01:00 0.25 0 0 PROD2 STK OTHR P Clean and-clear rig floor. 01:00 02:00 1.00 0 0 PROD2 -STK OTHR P PU/MU stack washing tool, wash stack to remove any iron f/ milling f/ ram cavities. Lay down tool. Blow down to drive. 02:00 03:45 1.75 0 0 PROD2 RIGMN SVRG NP Remove cement hose and standpipe from off driller's derrick leg to extend stand i e. -- ~ P.~qe 4; of fi9~ 'Time Logs - - - _ __ - - - - --- -- - - -- Date From To Dur S Depth E_ Depth Phase - Code Subco_d_e T COP,1 __ _ __ _ __ - - _ ..- 11/03/2006 03:45 06:45 _ 3.00 0 372 PROD2 ()RILL PULD P PU/MU BHA #8: 6-3/4".Security FMF3641 Z ser no. 10891692 w/ a restrictor and (3)21/32" nozzles, Sperry Sun 5200 series geopilot (ser no. TL-034), geopilot flex collar, DM HOC, 6.625" Smart stabilizer, Gamma/Res, PWD, TM HOC, nm float sub, 6.437" welded blade stabilizer, (3) 4-3/4" nm flex drill ocllars, x-o, (1) 4" HWDP, Daily jars (ser no. 140-01019). (4) 4"HWDP. Total = 372.24'. Uploaded MWD @ 94', shallow pulse tested @ 280' w/ 320 gpm and 1450 psi, roated slow (25 rpm) to break in seals on eo ilot. 06:45 07;00. 0.25 372 372 PROD2 DRILL OTHR P Blow Sown top drive, choke manifold and kill line. 07:00 07:15 0.25 372 372 PROD2 DRILL SFTY P PJSM on picking up 15joints of 4"drill i e f/ i e shed. 07:15 08:00 0.75 372 840 PROD2 DRILL PULD P Rabbit to 2.25" and PU/MU/RIH 15 joints of 4" Weatherford S-135.15.7 ppf drill i e. 08:00 08:30 0.50 840 840 PROD2 DRILL OTHR P Clear and clean rig floor. 08:30 13:00 4.50 840 8,814 PROD2 DRILL TRIP P RIH w/ 4"drill pipe f! derrick f/840' to 8814.97. Added crossover to 5". 13:00 13:15 0.25 8,814 8,814 PROD2 DRILL TRIP P Change elevators f/ 4" to 5". Fill pipe. 13:15 14:00 0.75 8,814 9,161 PROD2 DRILL TRIP P RIH w/ 5"drill pipe,. install Centurian ball catcher and circ sub one joint above x-o, continue to and through window @ 9121' to 9161'. Did not see an thin while oin throu h window. 14:00 14:15 0.25 9,161 9,161 PROD2 DRILL CIRC P Circulate @ 300 gpm w/ 2580. psi. Rotate @ 40 rpm w/ 8-9k ft Ib torque. ECD's 9.36 ppg Baseline estimated ECD's w/ 8.8 ppg mud in hole, circ 300 gpm : If no hole made 9.38 ppg, 200 ft/hr=10.49 ppg, 250 ft/hr= 10.78 ppg, 300 ft/hr= 11.07 ~_ _.. _ _ ~_~_- Pie 4~ csf69 TimeLoc~s _-- - - --- - -- _ Date From To Dur S Depth E. Depth Phase Code Suf?cod_e , T _ COM _ __ _ _ - -- - _ - ___ 11/03/2006 - 14:15 18:00 3.75 9,161 9,493 ' PROD2 DRILL DDRL P Drilling 6-3/4" production' D" lateral f/ 9161' to 9493' (326') (3356' ND) Bit hours= 2.08, Jar (#140-01019) hours= 99.05, ART= 2.08 hrs, WO6= 5-7k, 40-90 rpm, 300 gpm @ 2580 psi on bottom and 2570 psi off bottom. Torque = 8-9k ft-Ibs on botttom and 8-10k ft-Ibs off bottom. ECD= 9.31-9.52 ppg. Avg gas 35 units. Max gas 138 units. P/U = 175-170k, S/O = 100k, Rot= 130k w/ pumps off. Baseline estimated ECD's @ 9298' w/ 8.8 ppg mud in hole, circ 300 gpm If no hole made 9.38 ppg, 200ft/hr=10.49 ppg, 250 ft/hr= 10.78 300 ft/hr= 11.07 18:00 00:00 6.00 9,493 10,471 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 9493' to 10471' (978') (3346' ND) Bit hours= 5.53, Jar (#140-01019) hours= 102.5, ART= 3.45 hrs, WOB= 2-8k, 90-120 rpm, 300-340 gpm @ 2580-3210 psi on bottom and 2570-2980 psi off bottom.. Torque = 8-10k ft-Ibs on botttom and 9-10k ft-Ibs off bottom. ECD= 9.66-10.1 ppg. Avg gas 35 units. Max gas 138 units. P/U = 170-190 k, S/O = 100-95 k, Rot= 130 k w/ um s off. 11/04/2006 00:00 04:30 4.50 10,471 11,181 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 10471' to 11181 `(710'). (3355' ND) Bit hours= 8.11, Jar (#140-01019). hours= 105.08, ART= 2.58 hrs,. WOB= 2-6k, 110-120 rpm, 340-330 gpm @ 3210-3090 psi on bottom and 3180-3050 psi off bottom. Torque = 9-10k ft-Ibs on botttom and 8-10k ft-Ibs off bottom. ECD= 10.1-10.3 ppg. Max gas 199 units. P/U = 1190-200 k,' S/O = 95 k, Rot= 130 k w/ um s off. 04:30 05:15 0.75 11,181 11,014 PROD2 DRILL CIRC P Backream out of hole f/ 11981' to 11014' pumping 330 gpm w/ 3050 psi, rotate 120 rpm w/ 9k ft Ib torque. PU wt 200k, SO wt 95k, Rot wt 130k. 05:15 05:30 0.25 11,014 11,181 PROD2 DRILL TRIP P RIHf/11014'to11209'. 05:30 06:00 0.50 11,181 11,209 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 11181' to 11209' (28') (3357 ND) Bit hours= 8.33, Jar (#140-01019) hours= 105.30, ART= .22 hrs, WOB= 2-6k, 120 rpm, 330 gpm @ 3090 psi on bottom and 3050 psi off bottom. Torque = 10k ft-Ibs on botttom and 8-9k ft-Ibs off bottom. ECD= 10.2 ppg. P/U = 200 k, S/O = 95 k, Rot= 130 k w/ um s off. ---- -,ar - ~ a of ~3 ~- Time Low - - -- - -- -- Date From To Dur S Depth E Depth Phase Code Subcoae_ T _ COP.1 _ _- _ _ _ - - 11/04/2006 06:00 12:00 6.00. _ 11,209 _ 11,966 PROD2 DRILL DDRL P Drilling 6-3/4" production"D" lateral f/ 11209' to 11966' (757) (3340' TVD) Bit hours= 12.49, Jar (#140-01019) hours= 109.46, ART= 4.16 hrs, WOB= 2-10k, 100-120 rpm, 330-295 gpm @ 3090-2460 psi on bottom and 3050-2400 psi off bottom. Torque = 10-12 k ft-Ibs on botttom and 10-12k ft-Ibs off bottom. ECD= 10.03-10.30 ppg. Avg gas 150 units. Max gas 365 units. P/U = 195-210 k, S/O = 95-90 k, Rot= 130-135 k w/ pumps off. 12:00 18:00 6:00 11,966 .12,822 PROD2 DRILL DDRL P Drilling 6-3/4"production "D""lateral f/ 11966' to 12822' (856') (3338' TVD) Bit. hours= 15.42, Jar (#140-01019) hours= 112.39, ART= 2.93 hrs, W06= 4-8k, 80-90 rpm, 260-283 gpm @ 2000-2390 psi on bottom and 1960-2350 psi off bottom. Torque = 11-13 k ft-Ibs on botttom and 12-13k ft-Ibs off bottom. ECD= 10.09-10.29 ppg. Avg gas 109 units. Max gas 405 units. P/U = 205-215 k, S/O = 88-83 k, Rot= 130-140 k w/ pumps off. 18:00 19:30 1.50 12,822 13,045 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 12822' to 13045' (223') (3334' TVD) Bit hours= 16.39, Jar (#140-01019) hours= 113.36, ART= .97 hrs, W06= 4-8k, 90 rpm, 270-260 gpm @ 22250-2180 psi on bottom and 2100-2130 psi off bottom. Torque = 13-14 k ft-Ibs on botttom and 14 k ft-Ibs off bottom. ECD= 10.35 ppg. Avg gas 109 units. Max gas 405 units. P/U = 215-220 k, S/0 = 80 k, Rot= 140-135 k w/pumps off. Pump a 9.8 ppg hi weight (9.8 ppg) hi vis sweep @ 12900', slight increase in cuttin s. 19:30 22:30 3.00 13,045 13,487 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 1304"5' to 13487 (442') (3338' TVD) Bit hours= 17.92, Jar (#140-01019) hours= 114.89, ART= 1:53 hrs, W06= 2-10k, 70-100 rpm, 320 gpm. @ 3070-3120 psi on bottom and 3100 psi off bottom. Torque = 12-13 k ft-Ibs on botttom and 14-13k ft-Ibs off bottom. ECD= 10.39-10.8 ppg. Avg gas 109 units. Max gas 405 units. P/U = 220 k, S!O = 80 k, Rot= 135 k w/ pumps off. Note: Decision was made to Sidetrack for Geolo 22:30 23:30 1.00 13,487 13,005 PROD2 STK CIRC T Backream out of hole for sidetrack . Backream f! 13487 to 13005'. Pumping 330 gpm w/ 3200 psi, rotate 120 r m w! 12k ft Ib for ue. r------ -- ~acJa ~(D caf ~9 Time Logs _ -- - _ _ - _ _- _ - ---- - - - -- From To Dur_ S. D~th EDe~th .Phase Code Subcode T CQM ___ _ -_ _ - _ - - Date _ - --- 11/04/2006 23:30 00:00 0.50 13,005 13,012, PROD2 DRILL DDRL T Trough f/ 13005' to 13012'. Pumping 330 gpm w/ 3200 psi. Rotate 95 rpm w/ 11 k ft lb for ue. 11/05/2006 00:00 00:30 0.50 13,012 13,045 PROD2 DRILL DDRL T Trough f/ 13012' to 13045'. Pumping 330 gpm w/ 3200 psi. Rotate 95 rpm w/ 11 k ft Ib for ue. 00:30 02:45 2.25 13,045 13,297 PROD2 DRILL DDRL T Drilling 6-3/4" production "D" lateral f/ 13045' to 13297 (252') (3340' TVD) Bit hours= 19.28; Jar (#140-01019) hours= 116.25, ART= 1.36 hrs; WO6= 2-10k, 100 rpm, 320 gpm ~~ ` a~ l ~ 3120-3080 psi on bottom and 3010-3080 psi off bottom. Torque = y'~~ S~ i3~ ~ 11-12 k ft-Ibs on botttom and 8-10k ft-Ibs off bottom. ECD= 10.5 ppg. 143 units. P/U = 210 k, S/O = 85 k, Rot= 140-135 k w/ um s off. 02:45 03:00 0.25 13,297 13,204 PROD2 DRILL REAM T Backream f/ 13297 to 13204'. Pumping 320 gpm w/ 2980 psi. Rotate 100 rpm w/ 11 k torque. PU wt 200k, SO wt 95k. Rotating wt 135k. Need to check out Varco TDS-8SA to drive. 03:00 03:30 0.50 13,204 13,204 PROD2 RIGMN SVRG T Check-out dim flashing oil pressure/temp light on Dritler's top drive anel. 03:30 03:45 0.25 13,204 13,297 PROD2 DRILL REAM T Make top drive connection and ream f/ 13204' to 13297: Pump 320 gpm w/ 2980 psi. Rotate 100 rpm w/ 11 k ft Ib torque. PU wt 200k, SO wt 95k, rotatin wt 135k. 03:45 05:00 1.25 13,297 13,487 PROD2 DRILL DDRL T Drilling 6-3/4" production "D" lateral f/ 13297 to 13487 (190') (3340' TVD) Bit hours= 20.26, Jar (#140-01019) hours= 117.23, ART= .98 hrs, WOB= 8-10k, 100 rpm, 320 gpm @ 2980 psi on bottom and 2930 psi off bottom. Torque = 12 k ft-Ibs on botttom and 10 k ft-Ibs off bottom. ECD= 10.7 ppg. Max gas 165 units. P/U =.210 k, S/O = 85 k, Rot= 135 k w/ um s off. 05:00 06:00 1.00 13,487 13,554. PRODZ DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 13487 to 13554' (6T) (3333' TVD) Bit hours= 20.81, Jar (#140-01019) hours= 117.78, ART= .55 hrs, WO6= 8-10k, 100 rpm, 320 gpm @ 2900 psi on bottom and 2850 psi off bottom. Torque = 12 k ft-Ibs on botttom and 13k ft-Ibs off bottom. ECD= 10.54 ppg. Max gas 96 units. P/U = 205 k, S/O = 85 k, Rot= 135 k w/ um s off. - Page ~1 of 69 Time Logs __ - _ Date Fror7i To Dur S Depth E. Depth Phase- Code Subcode T _ COM - - _ _ __ 11/05/2006 06:00 12:00 - -- 6.00 - - 13,554 13,867 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 13554' to 13867 (313') (3328' TVD) Bit hours= 25.50, Jar (#140-01019) hours= 122.47, ART= 4.69 hrs, WOB= 8-10k, 100 rpm, 320-315 gpm @ 2900-2800 psi on bottom and 2850-2750 psi off bottom. Torque = 42-13 loft-Ibs on botttom and 13-15k ft-Ibs off bottom. ECD= 10.54-10.4 ppg. Max gas 140 units. P/U = 215 k, S/O = 85-80 k, Rot= 130-135 k w/ um s off. 12:00 12:30 0.50. 13,867 13,867 PROD2 RIGMN SVRG T Tighten up Shot Pin assembly on top drive handlin rin assembl . 12:30 12:45 0.25 13,867 13,867 PROD2 RIGMN SVRG P Service wash pipe packing.. 12:45 18:00 5.25 13,867 14,560 PROD2 DRILL DDRL P Drilling 6-3/4" production"'D"lateral f/ 13867 to 14560' (693') (3310' TVD) Bit hours= 28.14, Jar (#140-01019) hours= 125.11, ART= 2.64 hrs,. WOB= 8-10k, 100 rpm, 315-305 gpm @ 2750-2925 psi on bottom and 2700-2900 psi off bottom. Torque = 13-15 k ft-Ibs on botttom and 14-15k ft-Ibs off bottom. ECD= 10.6-10.81 ppg. Max gas 140 units. P/U = 215-225 k, S/O = 80-75 k, Rot=.130 k w/ um s off. 18:00 00:00 6.00 14,560 15,387 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 14560' to 15387 (827) (3303' TVD) Bit hours= 31.10, Jar (#140-01019) hours= 128.07, ART= 2.96 hrs, WOB= 8-10k, 100-80 rpm, 310-258-320 gpm @ 2900-2170-3040 psi on bottom and 2825-2130-3040 psi off bottom. Torque = 14-16 k ft-Ibs on botttom and 14-15k ft-Ibs off bottom. ECD= 10.85-11.1 ppg. Max gas 140 units. P/U = 230-250 k, S/O = 72 k, Rot= 140-135 k w/ um s off. 11/06/2006 00:00 06:00 .6.00 15,387 16,301 PROD2 DRILL DDRL P . Drilling 6-3/4" production "D" lateral f/ 15387 to 16301' (914') (3290' TVD) Bit hours= 34.64, Jar (#140-01019). hours= 131.61, ART= 3.54 hrs, WOB= 8-10k, 80 rpm, 320-270 gpm @ 3111-2430 psi on bottom and 2940-2400 psi off bottom. Torque = 16-17 k ft-Ibs on botttom and 15k ft-Ibs off bottom. ECD= 11.29-11.06' ppg. Max gas 268 units.. P/U = 255 k, S/O = 72 k, Rot= 150 k w/ um s off. €'age 52 ofi 6 Time Lois -- - - __ - - _ - Date From To Dur S D~fh E D~th- Phase- Code Su_bcode, _ T COM- __ _ 11/06/2006 _ 06:00 12:00 6.00 _ 16,301 16,813 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 16301' to 16813' (512') (3287 TVD) Bit hours= 38.06, Jar (#140-01019) hours= 135.03, ART= 3.42 hrs, WOB= 8-10k, 1D0-90 rpm, 310-333 gpm @ 3010-3250 psi on bottom and 3000-3200 psi offbottom. Torque = 14-16 k ft-Ibs on botttom and 15-16k ft-Ibs off bottom. ECD= 11.39-11.53 ppg. Max gas 304 units. P/U = 255 k, S/O = 72 k, Rot= 140-135 k w/ um s off. 12:00 18:00 6.00 16,813 17,451 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 16813' to 17451' (638') (3281' TVD) Bit hours= 41.09, Jar (#140-01019) hours= 138.06, ART= 3.03 hrs, WO6= 10k, 90 rpm, 315-310 gpm @ 3000-3130 psi on bottom and 2950-3100 psi off bottom. Torque = 15-17 k ft-Ibs on botttom and 15-16k ft-Ibs off bottom. ECD= 11.54- 11.7 ppg. Max gas 304 units. P/U = 275 k, S/O = 72 k, Rot= 132 k w/ um s off.. 18:00 00:00 6.00 17,451 17,737 PROD2 DRILL DDRL P .Drilling 6-3/4" production "D"lateral f/ 17451' to 17737 (286') (3272' TVD) Bit hours= 45.84, Jar (#140-01019) hours=.142.81, ART= 4.75 hrs, WO6= 10k, 90 rpm, 30-312 gpm @ 3130-3150 psi on bottom and 3100-3110 psi off bottom.. Torque = 17 k ft-Ibs on botttom and 19-20k ft-Ibs off bottom. ECD= 11.7 ppg. Max gas 275 units. P/U = 270 k, S/O = 75 k, Rot= 135 k w/ um s off. 11/07/2006 00:00 01:15 1.25 17,737 17,757 PROD2 DRILL DDRL P Drilling 6-3/4"production "D" lateral f/ 17737 to 17757 (20') (3272' TVD) Bit hours= 46.77, Jar (#140-01019) hours= 143.74, ART= .93 hrs, WOB= 10k, 90 rpm, 30-312 gpm 3130-3150 psi on bottom and 3100-3110 psi off bottom. Torque = 17 k ft-Ibs on botttom and 19-20k ft-Ibs off bottom. ECD= 11.7 ppg. Max gas 275 units. P/U = 270 k, S/O = 75 k, Rot= 135 k w/ um s off. 01:15 04:00 2.75 17,757 17,757 PROD2 DRILL CIRC P Circ and recip 30' stroke.. Pumping 30 BBL 9.8 PPG sweep @ 286 gpm w/ 2800 psi. ECD's 11.7 ppg. Rotate 90 rpm w/ 16-17k ft Ib. UP WT = 270K, SO WT = 72K, ROT WT = 135K. 04:00 :04:45 0.75. 17,757 17,757 PROD2 DRILL CIRC P Breakout Single, drop 2 1/8" ball down string, make up single. Pump ball. down @ 3 BPM - 1070 PSI. Allow to seat, with 711 strokes, 1100 PSI. Continue pressure to 1900 PSI to o en Centurion circulatin valve. -- Page ~3 of ~9 C-__ _ - _ _ M,_ ~i • ~ Time LocJs - - ur S. Depth_ E De~h Phase _ Cod_e__ Subcode--T_ To D From Date COM - -- - __ _ _ _ _ 11/07/2006 04:45 06:00 1.25 17,757 17,757 PROD2 DRILL CIRC P Continue circulating with valve open @ 290 GPM's - 490 PSi. Stage pumps to 397 GPM - 770 PSI, 500 GPM - 1110 PSI, 656 GPM's 1730 PSI, 900 GPM - 2860 PSI. Continue circulate @ 900 GPM's with 2830 PSI observing good hole cleaning with increased cuttings at shakers. Pump until clean. Crew chan e 06:00 06:30 0.50 17,757 17,757 PROD2 DRILL CIRC P . Break single in string. Pump down. closing ball @ 3 BPM - 270 PSI. Observed 720 strokes to seat ball, and 2100 PSI to close valve: Confirmed valve closed with 68 SPM - 2800 PSI. 06:30 12:00 5.50 17,757 15,400 PROD2 DRILL REAM P BROOH from 17757.-15400' afdriJling parameters of 300 GPMs - 3050 PSI. 90 RPM's, ROT WT = 150K with 15K for ue. 12:00 16:30 4.50 15,400 13,078 PROD2 DRILL REAM P Continue BROOH from 15400' - 13078' at drilling parameters of 325 GPMs - 2950 PSI. 90 RPM's, ROT WT = 130K with 12K for ue, 16:30 16:45 0.25 13,078 13,078 PROD2 DRILL SRVY P Perform checkshot survey @ 13078' MD. Verify calculated top of sidetrack at a 3 de ree do le . 16:45 18:00. 1.25 13,078 12,253 PROD2 DRILL REAM P Continue BROOH from 13078' - 12253' at drilling parameters of 325 GPMs - 2950 PSI. 90 RPM's, ROT WT = 125K with 12K for ue. Crew Chan e 18:00 00:00 6.00 12,253 9,100 PROD2 DRILL REAM P Continue BROOH from 12253' - 9100' at drilling parameters of 325 GPMs - 2900 PSI. 80 RPM's, ROT WT = 120K with 10K torque. Pull throuh window area with no rotation. Observed no issues with assembly passing through. window area. TOW = 9121' MD. 11!08/2006 00:00 02:00 2.00 9,100 9,100 PROD2 DRILL CIRC P Circulate @ 330 GPM - 2850 PSI. No . reciprocation. Observe little increase in cuttings across shakers on bottoms u. 02:00 03:00 1.00 9,100 9,100 PROD2 RIGMN RGRP P PJSM with crew. Discuss safety issues and procedure to hang new extension in derrick and proper clamps. Install cement line standpipe extension. 03:00 04:15 1.25 9,100 9,100 PROD2 RIGMN SVRG P PJSM with crew. Discuss safety issues and procedure for slipping & cutting drilling line. Slip & cut 111' of drilling line. Inspect & adjust brakes on draw works. 04:15 06:00 1.75 9,100 9,100 PROD2 RIGMN SVRG P Service Top Drive, Change out filters and gear oil.lnspect shot pin assembly. Monitor well -static. Crew chan e 06:00 06:45 0.75 9,100 9,100 PROD2 RIGMN SVRG P Continue & complete servicing of Top Drive and inspection. of shot pin assembl . Monitor weN -static. ~-- ' Paej~ ~4 of S ~_____ ~ _-_ - . - • a ~I Time Lo s - - g---- -- - - - ~~~Date From To Dur S. Depth _E. Depth Phase_ Code_ Subco_de_ T COM _ 11/08/2006 06:45 10:30 3.75 9,100 13,450 PROD2 DRILL TRIP P Trip in hole from 9100' - 13450' on elevators. Observe run out of down weight. Obtain T&D parameters as per rig emgineer every 5 stands in open hole. Fill drill strip eve 25 stands. 10:30 12:00 1.50 13,450 15,012 PROD2 DRILL REAM P Wash & ream each stand from 13450' - 15012'. Pumps @ 300 GPM's - 2950 PSI. 50 RPM's with 12-13 K torque. ROT WT = 130K. 12:00 17:00 5.00 15,012 17,757 PROD2 DRILL REAM P Contirue Wash & ream each stand from 15012' -17757 MD. Pumps @ 135 GPM's -1100 PSI. 50 RPM's with 14-15 K for ue. ROT WT = 126K. 17:00 18:00 1.00 17,757 17,757 PROD2 DRILL CIRC P Circulate & condition mud pumping a 9.8 PPG, 40 BBL Hi Visc sweep @ 295 GPM's - 3100 PSI. 80 RPM's with 16-17K torque. UP WT = 145K, SO WT = 115K, ROT WT = 125K. Reciprocate & rotate drill string in 30' increments while pumping. Crew Chan e 18:00 20:00 2.00 17,757 17,757 PROD2 DRILL CIRC. P Continue circulate & condition mud pumping a 9.8 PPG, 40 BBL Hi Visc sweep @ 295 GPM's - 3100 PSI. 80 RPM's with 16-17K torque. UP WT = 145K, SO WT = 115K, ROT WT = 125K. Reciprocate & rotate drill string in 30' increments while pumping. Observed sweep returned with little or no increase in cuttin son shakers. 20:00 20:15 0.25 17,757 17,757 PROD2 DRILL CIRC P Break out single DP, and drop 2 1/8" ball down drill string for Centurion Circulating valve. Total of 3 - 2 1/8" balls in strip . 20:15 20:30 0.25 17,757 17,757 PROD2 DRILL CIRC P Allow ball to fall while pumping down drill string at 3 BPM - 1100 PSL Obsrve ball on seat with 748 strokes. pressue to 2000 PSI to observe ressure loss of 800 PSI. 20:30 20:45 0.25 17,757 17,757 PROD2 DRILL CIRC. P Pump down drill string observing CCV still in closed position. Pressure @ 3100 PSi with 295 GPM's. 20:45 21:00 0.25 17,757 17,757 PROD2 DRILL CIRC P Break out single DP,-and drop 2 1/8" ball down drill string for Centurion Circulating valve: Total of 4 - 2 1/8" balls in strip . 21:00 21:15 0.25 17,757 17,757 PROD2 DRILL CIRC P Pump-down drill string @ 3 BPM - 1100 PSI observing ball on seat with 758 strokes. Pressure to 2000 PSI to observe CCV in open position. Bleed ressure to zero i~~c~a,55 of ~a~ L__ Time Logs _ Date 11/08/2006 From 21:15 To -- 22:30 Dur 1.25 _S Depth 17,757 E. Depth - 17,757 Phase _ PROD2 Code DRILL Subcode _ CIRC T T P COM _ _- ___ __ ' Verify open CCV valve with 300 GPM - 570 PSI. 70 RPM's. 400 GPM's - 850 PSI, 70 RPM's. 500 GPM's - 1180 PSI, 70 RPM's. 600 GPM's - 1620 PSI, 70 RPM's. 700 GPM's - 2100 PSI, 70 RPM's. 800 GPM's - 2600 PSI, and 900 GPM's - 3100 PSI. Full flow @ 33 %, @ 70 RPM's. Continue circulate a total of 4 bottoms up observing hole clean with little or no increase in cuttings at shakers. ECD's @ 12.17 PPG. No fluid loss. Reci rocate drill strip while um in . 22:30 22:45 0.25 17,757 17,757 PROD2 DRILL CIRC P Break out singl,v DP, and drop 2 1/8" ball down drill string for Centurion Circulating valve. Total of 5 - 2 1/8" balls in strip . 22:45 23:00 0.25 17,757 17,757 PROD2 DRILL CIRC P Pump down drill string @ 3 BPM - 300 PSI observing ball on seat with 741 strokes. Pressure to 2000 PSI to observe CCV in closed position. Bleed ressure to zero. 23:00 23:15 0.25 17,757 17,757 PROD2 DRILL CIRC P Verify CCV valve in closed position pumping down drill string. @ 303 GPM's - 3200 PSI. 70 RPM's, and 17%flow. Reci rocate drill strip . 23:15 23:30 0.25 17,757 17,757 PROD2 DRILL SFTY P Continue circulating through bit with a closed CCV valve. Hold PJSM with entire crew and all truck drivers. Designate a spill champion. Discuss safety issues and procedure for displacing well with 8.7 PPG SFMOBM. 23:30 00:00 0.50 17,757 17,757 PROD2 DRILL CIRC P Displace well with 8.7 PPG SFMOBM @ 345 GPM's - 3900 PSI. 80 RPM's with 15K torque. 19 %flow. Reci rocate &. rotate drill strip . 11/09/2006 00:00 02:15 2.25 17,757 17,757 PROD2 DRILL CIRC P Continue Displace well with 8.7 PPG SFMOSM @ 345 GPM's - 3900 PSI. 80 RPM's with 15K torque. 19 %flow. Reciprocate & rotate drill string. ECD = 12.17 PPG. Final Circulating. pressure with SFMOBM in hole = 345 GPM's - 3650 PSI. ECD = 11.24 PPG. 02:15 02:30 0.25 17,757 17,757 PROD2 DRILL OWFF P Monitor well -static. 02:30 03:00 0.50 17,757 17,291 PROD2 DRILL TRIP P POOH on elevators from 17757' - 17291'. Observe clean hole hole, no swabbin . 5 stands. 03:00 03:30 0.50 17,291 17,291 PROD2 DRILL CIRC P Pump 30 BBC10.8 PPG-dry job. Chase with 10 BBLS SFMOBM. Blow down Top drive & lines. Monitor well - static. 03:30 06:00 2.50 17,291 10,500 PROD2 DRILL TRIP P Continue POOH on elevators from 17291' -10500'. Observe proper hole fill.. Record T&D parameters as per rig en ineer eve 5 stands. Crew Chan e Pa~~ ~£ of 69 ~ ~ Lo s_ _- _ -~ 9 - --- - -- --- - From To Dur S Depth E Depth. Phase _ Code _Subcode T _ COF.1 _ __ _ __ ___ - I ~a[e 11/09/2006 06:00 07:30 1.50 10,500 8,814 PROD2 DRILL TRIP P Continue POOH on elevators. from 10500' - 8814'. Observe proper hole fill. Record T&D parameters as per.. rig engineer every 5 stands. Observe no issues going through window area 9121' MD. 07:30 08:00 0.50 8,814 8,814 PROD2 DRILL PULD P Breakout & lay down Centurion Circulating valve. Recover 5 - 2 1/8" balls. Chan a elevators. 08:00 11:00 3.00 8,814 372 PROD2 DRILL TRIP P Continue POOH from 8814' - 372'. Observe proper hole fill. Monitor well - static. 11:00 11:45 0.75 372 87 PROD2 DRILL PULD P Breakout & lay down BHA #8. Lay down 4 - 4" HWDP (122:70'), 4 3/4" Drilling Jars (28.82'),1 - 4" HWDP (30.68'), Crossover sub (3.00'), 3 - 4 3/4" Non Mag Flex drill Collars (92.92'), 4 3/4" Welded Blade Stabilizer (4.45'), 4 3/4" Non Mag Float sub 2:18' . 11:45 12:00 0.25 87 87 PROD2 DRILL PULD P Plug in and download MWD assembl . 12:00 12:30 0.50. 87 87 PROD2 DRILL PULD P Continue-download MWD assembly. 12:30 13:30 1.00 87 0 PROD2 DRILL PULD P Continue breakout & lay down remaining BHA #8. Lay down 4 3/4" TM HOC (10.98'), 4 3/4" PWD (10.82'), 4 3/4" Gamma/Res (24.51'), 4 3/4" Smart Stabilizer (3.59'), DM HOC (8.53'), 4 3/4" Geo Pilot Flex Drill collar (11.55'), 5 1/4" 5200 series Geo Pilot (16.21'), and 8 3/4" Security bit FMF 36412 (1.30'). Inspect & grade bit to 1/1/Wf/C/X!I/NO/TD. Note: Calculated hole fill at 46.58 BBLS, Actual hole fill = 64.5 BBLS. 13:30 14:45 1.25 0 0 COMPZ CASINC RURD P . Clear & clean floor area. Rig up to run 4 1/2" slotted liner assembly: Rig up Tongs, slips elevators and double check running detail with equipment in shed. 14:45 15:15 0.50 0 0 COMPZ CASIN< SFTY P Held PJSM with-entire crew, BOT rep, GBR reps, Co man, & TP. Discuss safety issues & procedure for running 4 1/2" Slotted liner assembl . 15:15 18:00 2.75 0 4,732 COMPZ .CASINC RUNL P Makeup 4 1/2" Silver Bullet Shoe on a joint of 4 1/2" 11.6 PPF L80 BTC Slotted liner, and continue run 4 1/2" slotted liner as per detail. Make up torque =.3800 FT/Ibs, and 5000 ft/Ibs on joints with torque rings. Run finer to 4732' MD. Obtain T&D parameters as per rig engineer every 10 joints starting at 3000' MD. Crew than e. ~~--_-~ ~_...~_ -_____------- --- '- ^.~- Page 57 s~f 8~J I Time Logs - -- - - - Da~E From To Dur SDepth _ E De~h- Phase Code Subcode_ T _ COM _ _ _ - - ___ _ __ 11/Oy/2006 18:00 23:00 5.00 4,732 8,440 C,OMPZ CASINC RUNL P Continue run 4 1/2" L80 BTCslotted liner form 4732' - 8440' MD. Monitor well -static before picking up Hydril 521 liner joints. Run a total of 177 joints of 4 1/2" Slotted BTC liner, Crossover joint (41.50'), 18 joints of 4 1/2" 11.6 PPF L80 Hydril 521 Slotted, 5 1/2" hydril 521 x 4 1/2" BTC XO bushing, 1 -jnt 5 1/2" 15.5 PPF L80 Hydril 521 and Baker HR liner setting sleeve with Hydril 521 pup and running tool. Makeup 3 1/2 IF x 4 1/2 IF crossover to DP. Make. uptorque = 3800 FT/Ibs, and 5000 ft/Ibs on joints with torque rings. Obtain T&D parameters as per rig engineer every 10''oints. 23:00 00:00 1.00 8,440 8,440 COMPZ CASINC RURD P Rig down all GBR Liner running equipment. Clear & clean rig floor. Monitor well -static. 11/10/2006 00:00 04:15 4.25 8,440 13,487 COMPZ CASINC RUNL P Continue run 4 1/2" slotted liner on drill pipe from 8440' - 13487. Record T&D parameters as per rig engineer every 5 stands in open hole. At the window, UP WT = 125K, SO WT = 95K, ROT WT = 105K with 4500 ft/Ibs. 04:15 .06:00 1.75 13,487 15,199 COMPZ CASINC RUNL P Rotate liner in hole from 13487 - 15199' MD. 30 RPM's with 11-12K torque. UP WT = 230K, SO WT = 72K, ROT Wf = 120K. Crew Chan e 06:00 11:15 5.25 15,199 17,754 COMPZ CASINC RUNL P Continue rotate irr hole with 4 1/2" Slotted liner from 15199' - 17754' MD. 30 RPM's -11-12K Torque. Observed tight hole from 17591' - 17754' working strin to et to bottom. 11:15 11:30 0.25 17,754 17,754 COMPZ CASINC RUNL P Drop 29/32" ball in drill string. Make To Drive conection. 11:30 12`00 0.50 17,754 17,754 COMPZ CASINC CIRC P Circulate ball down @ 4 BPM - 710 PSI. Continue rotating liner @ 30 RPM's - 12K Torque. UP WT = 280K, SO WT = 72-K, ROT WT = 110K. 12:00 12:45 0.75 17,754 17,754 COMPZ CASINC CIRC P Continue circulate ba(I down @ 4 BPM - 710 PSI. Continue rotating liner @ 30 RPM's = 12K Torque. UP Wf = 280K, SO WT = 72K, ROT WT = 110K. Slow: pump rate to 2 BPM - 350 PSI. Allow ball to seat. - - - - -- a ~c~~ ~8 of S9 Time Low - - - - -- ~~ Date _ 11/10/2006 From 12:45 To 13:15 - - D__ur 0.50 S De~ith_ 17,754 E-_ D~th _ 17,754 ~Phas~_ CC)MPZ Code CASIN( S__ubcode_ _ RUNL T_ P COM Work torque out of liner string. Slack off to 90K with DP in compression. Pressure ~p to 4500 PSI to shear out of setting tool as per BOT rep. Leave liner. in hole with Guide shoe @ 17754' -and the top of the setting sleeve @ 9314'. The top of the setting sleeve is 176' out of the bottom of the window @ 9138' MD. Pick up on drill string to observe free of liner, breakout & lay down sin le of DP. 13:15 16:45 3.50 9,314 0 COMPZ CASIN( RUNL P POOH from 9314' -surface. Observe. ro er hole fill 16:45 17:30 0.75 0 0 COMPZ CASIN( RUNL P Inspect, breakout & lay down BOT settin tool. Tool intact. 17:30 18:00 0.50 0 0 COMPZ CASIN( OTHR P Clean & clear floor area ofall tools, and OBM. Pull tools to rig floor for next BHA. Crew Chan e. 18:00 18:15 0.25 0 0 COMPZ FISH SFTY P Held PJSM with rig crew. Discuss safety issues and procedure for makin h u whi stock retrievin BHA. 18:15 19:30 1.25 0 604 COMPZ FISH PULD P Make up Whipstock retrieving BHA. Make up Baker Whipstock retrieving Hook (8.30'), 1 - jnt 5 "HWDP (31.73'), 4 3/4" Oil Jar (11.54'), and 6 stands of 5" HWDP (552.85'). Total BHA length = 604.42'. 19:30 00:00 4.50 604 9,121 COMPZ FISH TRIP P Trip in hole with retrieving BHA #9 from 604' - 9121' MD. Observe DP filling good, and proper hole fill. UP WT = 205K, SO WT = 95K: Make Top Drive connection & obtain circulation @ 300 GPM's - 650 PSI. 11/11/2006 00:00 00:30 0.50 9,121 9,121 COMPZ FISH FISH P Establish circulation @ 300 GPM's - 650 PSI. Slack off to wash slot in slide rotating 1/4 turns in drill string. Locate & engage slot with hook. PU WT = 205K, SO WT = 100K. Pull over 95K to fire jars, repeat 3 times increasing pull weight to 110K over. until observe whipstock assembly coming free: Pull vp 45'. Observed wellbore fluid falling. Stand back 1 stand. 00:30 03:00 2.50 9,121 9,030 COMPZ FISH CIRC P Make Top drive connection, circulate @ 6 BPM - 550 PSI. Observe well took 23 BBLS initially to gain returns. Pump @ 6 BPM to observe 1 BPM loss. Circulate @ 5 BPM with .7 BPM loss. Circulate @ 4 BPM to observe only 1/2 BPM loss. Load pits with more SFMOBM form tank farm. Continue circulating bottoms up increasing rate to 7 1/2 BPM uritil observed losses down to little or none. 03:00 03:15 0.25 9,030 9,030 COMPZ FISH CIRC P Monitor well -static. Mix dry job to 2.0 ounds over. t -- -- i'a~e 59 of 59_ Time Lis ~' Date ___ From To ____Dur__S- Depth E. Degth Phase ,Code Su_bco_de T _ COM _ - 11/11/2006 03:15 03:30 0.25 9,030 9,030 COMPZ FISH CIRC P Pump 30 BBL dry job, 10.7 PPG, blow down To Drive and all lines. 03:30 06:00 2.50 9,030 2,826 COMPZ FISH TRIP P POOH with whipstock assembly, slow at first monitoring well for swabbing or losses. Pull from 9030' -2826'. Observed ro er hole fill Crew Chan e 06:00 07:15 1.25. 2,826 604 COMPZ FISH TRIP P Continue POOH with whipstock assembly from 2826' -BHA. Observed ro er hole fill Monitor well -static. 07;15 09:30 2.25 604 0 COMPZ FISH PULD P Breakout & lay down Baker Whipstock retrieving Hook (8.30'), 1 - jnt 5 "HWDP (31.73'), 4.3/4" Oil Jar (11.54'), and 6 stands of 5" HWDP (552.85'). Total BHA length = 604.42'. Continue Breakout & lay down Whipstock slide (20.56'), Debris Barrier sub (2.0'), Drain Sub (1.5'), Shear disconnect sub (2:72'), Bottom Trip anchor (2.8'), Blanking sub (.99'), 2 -jnts of 5" HWDP (61.62'), Unloader sub (6.4T), Crossover sub (3.0'), Stop sub with seal assembly (5.32'). Total. BHA la ed down = 103.54', 09:30 10:00 0.50 0 0 COMPZ CASINC RURD P Pull tools to rig floor. Rig up casing runin a ui ment. 10:00 10:15 0.25 0 0 COMPZ CASINC SFTY P Held PJSM with crew, GBR reps, and BOT reps. Discuss safety issues and procedure for making up Hook Hanger assembly with Super Slim MWD tools. 10:15 11:00 0.75 0 0 COMPZ CASIN( RUNL P Make up Hook Hanger assembly as per detail. Make up 4.1/2" 12.6# L80 Bent joint with Mule shoe (30.16'), 4 1/2" Crossoverjoint (42.98'), 2 - 4 1/2" 11.6# L80 Slotted joints (82.36'), Baker Payzone F~cternal Casin g Packer with pups (31.84'), 2 - 4 1/2" pups (20.09'), Baker Model B Flanged Hook Hanger with Crossover bushing and 4 1/2" pup (32.61'), and Hook Hanger running tool. Make up internal Super Slim MWD assembly with Baker ball catcher, and shear out sub. Orient MWD to Hook Han er Hook. 11:00 12:00 1.00 0 240 COMPZ CASIN( RUNL P Make up internal Super Slim MWD assembly with Baker ball catcher, and shear out sub. Orient MWD to Hook Hanger Hook. Total BHA length = 240.04'. 12:00 12:30 0.50 240 804 COMPZ CASINC RUNL P Trip in hole with Hook Hanger assembl from 240' - 804' MD. 12:30 12:45 0.25 804 804 COMPZ CASINC CIRC P Make Top Drive dconnection and perform shallow pulse test @ 3.5 BPM - 960 PSI. Good test. Blow down Top Drive and all lines. l7ag~ 6€~ of fig Time Logs _ ____ :Date From To Dur S_D~th E. Depth Phase _ _ Code_ Subcode T __ COM _ - -- - - - - - 11/11/2006 12:45 18:00 5.25 804 8,313 COMPZ CASIN( RUNL P Trip in hole with Hook Hanger assembly from 804' - 8313'. Trip speed at 50 ft/min as per BOT rep. Observe ro er hole fill. Crew than e. 18:00 19:00 1.00 8,313 9,275 COMPZ CASINC RUNL P Continue trip in hole with Hook Hanger assembly from 8313' - 9275'. Trip speed at 50 ft/min as per BOT rep. Observe proper hose fill. Pick up single of DP. UP WT = 230K, SO WT = 85K. Tag "B" Lateral .Liner top 9274'. Pull & stand back 2 stands. 19:00 20:15 1.25 9,275 . 9,374 COMPZ CASINC RUNL P Establish circulation @ 30 SPM - 780 PSI. Rotate drill string 3 RH turns, slack off to observe going through window @ 9121' - 9138' MD, and continue RIH to Hook Hanger @ 9138.5'. Set down 20K, pump up surveys to see 7 Degrees left of high side, repeat 3 times. Pull up orient Hook to 180 Degrees out, and slack off to tag crossover in setting sleeve @ 9374' (5' deep). Repeat with 10K set down wei ht. 20:15 21:45 1.50 9,374 9,374 COMPZ CASINC RUNL P Pull up orient Hook to 180 Degrees out, and slack off to tag crossover in setting sleeve @ 9374' (5' deep). Repeat with 10K set down weight. Pull up to rotate drill string once again 180. Degrees and orient Hook to land at 10 Degrees left of high side. Pump up numerous surveys to verify. Pull up to break connection and drop 1 3/4" ball. make conection. 21:45 22:30 0.75 9,138 9,138. COMPZ CASIN( CIRC P Circulate @ 126 GPM's - 800 PSI pumping ball down, increasing rate to 135 GPM's - 910 PSI observing MWD surveys indicating Hook still set at 10 Degrees left of high side. Slow pump to 86 GPM's - 450 PSI, observing ball seated with 1220 strokes pumped.. Pressure to 2000 PSI as per BOT rep. Bleed pressures. Pressure to 3000 PSI to inflate ECP, and observe pressure drop to 1700 PSI. Ho-d 10 minutes. Pressure to 3000 PSI with a total of 8 strokes, indicating .8 BBLS to fill ECP. Hold pressure to 4000 PSI - 5 minutes. Bleed all ressures. 22:30 23:00 0.50 9,138 9,169 COMPZ CASINC OTHR P Attempt to pull free of Hook Hanger observing 70K overpull. Slack off, RU & pressure to 1000 PSI. PU WT' _ 250K, SO WT = 72K. Bleed pressures. and work drilC string to release from Hook Hanger assembly. POOH and stand back 2 stands of DP. Monitor well -static. - -- f'~gn 61 ~sf ~~~ ~ ~ I Time Logs ---- _ _ _ _ --- - _ _ ~ Date From ., To Dur S. De +.h E. Depth Phase Code Subco~_e___ T COM _ _ 11/11/2006 23:00 00:00 1:00 9,169 9,T69 COMPZ RIGMN SVRG P Held PJSM with rig crew. Discuss safety issues and procedure for Slipping & cutting Drilling line. Continue monitor well -static. Rig up and slip & cut drilling line, Inspect & ad'ust draw works brakes. 11/12/2006 00:00 00:15. 0.25 9,169 9,169 COMPZ RIGMN SVRG P Complete Slip & cut drilliong line, and ad'ustin draw works. 00:15 06:00 5.75 9,169 2,611 COMPZ CASIN( OTHR P POOH with 5" DP racking in derrick. Remove 5" Super Sliders from string. WWT rep on rig floor. 114 Total remeoved. Continue POOH racK back 5" DP. Pull from 9169' - 2611' MD. Crew Chan e 06:00 07:15 1.25 2,611 251 COMPZ CASIN( OTHR P Continue POOH from 2611' - 251'. Remove remaining super sliders form DP for a total of 114 removed from drill strin .Observed ro er hole fill. 07:15 08:00 0.75 251 0 COMPZ CASINC OTHR P Breakout & lay down Baker & Sperry Sun Inner string for Hook Hanger. Lay down Su er Slim MWD assembl . 08:00 09:00 1.00 0 0 COMPZ WELCT BOPS P Close Blind rams. Clrear & clean rig floor area. Ri u fortestin BOP's. 09:00. 09:30 0.50 0 0 COMPZ WELCT BOPE P Open Blind Rams- monitor well - static. Drain stack, Make up test joint & crossovers. Pull wear bushing, and install test plug. Rig up test mainfolsd and chart for BOP test. 09:30 09:45 0.25 0 0 COMPZ WELCT SFTY P Held PJSM with crew. Discuss safety issues and procedure for testing BOP's. Install signs and announce BOP test. 09:45 12:00 225 0 0 COMPZ WELCT BOPE P Complete rigging up for BOP test. Test BOP's. BOP. test witnessed by Jeff Jones w/ AOGCC. Observed Choke side HCR valve failed test. Observed dart valves and floor safety valves failed tests of 250 PSI Low, and 3000 PSI Hi h. 12:00 14:00 2.00 0 0 COMPZ WELCT BOPE P Continue testing BOP's. Test Annular, Kill Line HCR, Manual Choke, Upper IBOP, Top rams 3 1/2" x 6" VBR's, Lower IBOP, Manual Kill. All test 250 PSI low, 3000 PSI hi h. 14:00 14:15 0.25 0 0 COMPZ WELCT SFTY P Held PJSM with floorhands. Discuss safety issues and procedure for chan in out Choke side HCR valve. 14:15 14:45 0.50 0 0 COMPZ WELCT BOPE P Blow down Top Drive &.lines. Blow down Choke & Kill -ines. 14:45 17:00 2.25 0 0 COMPZ RIGMN RGRP T Rig up and change out choke side HCR valve. Test gas detectors while chan in out valves. 17:00 18:00 1.00 0 0 COMPZ WELCT BOPE P Continue test BOP's. Test new HCR valve on choke side. Test to 250 PSt low, 3000 PSI hi h. Crew chan e: Page S2 of fig ~ ~ ', Time Logs _ _ ur _ _S Depth E. De t}~ rhasz_ Code _ Subcode~ T COM Cate FrorTi To D - -- __ _ 11/12/2006 18:00 20:00 2.00 0 0 COMPZ WELCT ROPE P Held PJSM with new crew. Discuss. safety issues and procedure for remaining test of BOP's. Continue test Choke manifold valves 1 - 15. Perform Accumulator draw down test. Pull test joint. Test blind rams. All tests 250 PSI low, 3000 PSI high, all tests recorded on chart. 20:00 21:00 1.00 0 0 COMPZ WELCT BOPE P Rig down test equipment. Blow down all linesincluding choke manifold and gas buster. RIH with test joint, and make up to test plug. Pull test plug. Complete hanging cement line support .brace. Note: Fluid loss to weel bore Burin BOP test = 10 BBLS. 21:00 00:00 .3.00 0 0 COMPZ WELCT BOPE NP Clean & clear floor area. Decision to install tubing hanger in and lock in same with BPV installed. Accumulator test indicated 2 failed valves, and AOGCC rep asked that they be repaired before completion run. Wait on tubing hanger.Pull all 4 1/2 IF pin protectors to rig floor for laying down DP. Install 5" Elevators. Rig up lines on upper annulus to fill hole and monitor well while la in down DP. 11/13/2006 00:00 00:30 0.50 0 0 COMPZ WELCT BOPE NP Continue wait on Tubing hanger for well head. Clean & clear rig floor. Prepare floor for laying down DP from derrick. Continue rig up lines to upper annulus for hole fill 00:30 02:30 2.00 0 0 COMPZ WELCT BOPE NP Pickup dummy tubing hanger to rig floor. Install BPV, make up to landing joint. RIH set tubing. hanger as per Vetco Gray reps. RILDS. Pull and lay down landin 'oint. 02:30 06:00 3.50 0 0 COMPZ RPCOh OTHR P Install mouse hole in rotary table. Lay down 5" & 4" DP from derrick. Monitor well via trip tank and lines to annulus. Observed 16 BBL fluid foss since midni ht. Crew Chan. e 06:00 11:30 5.50 0 0 COMPZ RPCOh OTHR P Continue lay down 5" DP from derrick. Monitor well via trip tank and lines to annulus. 11:30 12:00 0.50 0 0 COMPZ RPCOh OTHR P Pulfmouse hole from rotary table. RIH with 1 stand of 5" DP. RU for Accumulator test. §~~~~: ~3 ~f i~~ Time Lomas _ ___ Date Fror7i To Dur S Depth E. Depth Phase Code- Subcc~e _ T COM _ __-_ 11/13/2006 12:00 13:00 1.00 0 - 0 __ COMPZ RPCOh OTHR P Perform Accumulator draw down test. Observed initial pressures @ 2925 PSI, and after closing 1500 PSI. 200 PSi increase in 34 seconds, with full pressure observed at 2 minutes 45 seconds. Good test. Observed 5 nitrogen bottles with an average of 2300 PSI: Notify AOGCC of repaired Accumultor valves. Re-install mousehole in the rotary table for la in down DP. 13:00 15:30 2.50. 0 0 COMPZ RPCOh OTHR P Continue lay down 5" DP from derrick. Layed down a total of 106 stands - 5". Continue monitor well for losses. 15:30 16:00 0.50 0 0 COMPZ RPCOh OTHR P Change out elevators from 5" to 4" DP. Pull 4" XT39 thread protectors to rig floor. 16:00 18:00 2.00 0 0 COMPZ RPCOh OTHR P $reakout & lay down Dailey combo drilling jars, and 5 joints of 4" HWDP. Continue lay down 21 stands of 4" xt39 DP from derrick. Note: Fluid loss last 12 hrs = 8.5 BBLS. Crew Chan e. 18:00 00:00 6.00 0 0 COMPZ RPCOh OTHR P Continue breakout & lay down 64 stands of 4" xt39 DP from derrick. Monitor well for losses. 11/14/2006 00:00 00:30 .0.50 0 0 COMPZ RPCOh OTHR P Continue breakout & lay down 5 stands of 4" XT39 DP from derrick. Monitor well for losses. 00:30 01:00 0.50 0 0 COMPZ RPCOA OTHR P Clean & clear rig floor area. Pull joimnt of 5" DP to rig floor and breakout 10' u ~oint on bottom. La down same. 01:00 01:30 0.50 0 0 COMPZ RPCOh PULD P Change out elevators. Pull mousehole from rotary table and fay down same. Pull completion running equfpment to rig floor. Move jewelry in pipe shed as to run entire 4 1/2" completion string in hole. 01:30 02:15 0.75 0 0 COMPZ WELCT OTHR P Make up landing joint. Check well for any pressure. RIH, make up to dummy hanger. BOLDS. Pull dummy hanger to rig floor. Breakout, lay down hanger and landing joint. NOTE: It was observed that the dummy hanger did not seat completly in the wellhead. When the lock down. screws were run in, they did not engage correctly. The hanger was installed & removed as per Vetco G ra re s. 02:15 03:00 0.75 0 0 COMPZ RPCO6 PULD P Rig up completion running equipment, power tongs, elevators and Cavin tubing slips as per DDI casing rep. Observe the throttle shaft broke on the power tongs while testing. The power tongs were changed out with no issues. 03:00 03:30 0.50 0 0 COMPZ RIGMN SVRG P Service rig. Inspect & service Top Drive & draw works. -- --- -- - - F~~ge ~4 of S~ • Time Logs ,Date Fcorn To ___ Dur S D~th E D~th Phase _ Cod_e___ Subcocie T _COM 11/14/2006 03:30 03:45 0.25 0 0 COMPZ RPCOh SFTY P Held PJSM with rig crew&GBR Reps. Discuss safety issues and procedure for making up and running in hole with 4 1/2" Completion tubing. MOnitor well -static. 03:45 06:00 2.25 0 1,519 COMPZ RPCOh PULD P Make up 4 1/2" Mule Shoe (2.98'), on firstjoint, and continue RIH with 4 1/2" completion string. Make up torque = 3800 FbLBS. Ran 49 joints. Crew Chan e 06:00 11:00 5.00 1,519 7,905 COMPZ RPCOh PULD P Continue RfH with 4 1/2" completion string. Make up torque = 3800 FULBS. Ran a total of 255 joints.Obsenre ro er hole fill 11:00 12:00 1.00 7,905 7,905 COMPZ RPCOh PULD P Remove air slips from. table. Install stripping rubbers and RU to POOH standin back 4 1/2" tubin . 12:00. 13:00 1.00 7,905 7,905 COMPZ RIGMN RGRP T Service Rig. Check & repair leak on Top Drive. Remove ODS link Tilt c tinder for re air. 13:00 14:00 1.00 7,905 7,800 COMPZ RPCOh PULD. P POOH breakout & lay down joint # 253 with dams ed box. Re lace'oint. 14:00 14:30 0.50 7,800 7,800 COMPZ RPCOh CIRC P Make up TIW valve & crossover on tubing string. Pump dry job fro POOH. Pump 15 BBLS - 10.2 PPG. Lay down crossover & valve. Blow down Top Drive & lines. 14:30 16:15 1.75 7,800 3,522 COMPZ RPCOh PULD P POOH racking back 46 stands of 4 1/2" tubing in derrick. Install thread protectors on pin end. Observe proper hole fill 16:15 17:00 0.75. 3,522 3,522 COMPZ RIGMN RGRP T Install rebuilt Link tilt cylinder on Top Drive. Monitor well -static 17:00 18:00 1.00 3,522 825 COMPZ RPCO6 PULD P Continue POOH racking back 29 stands of 4 1/2" tubing. Observe ro er hole fill. Crew Chan e 18:00 18:45 0.75 825 0 COMPZ RPCOti PULD P Continue POOH racking back 1D stands of 41/2" tubing. Observe ro er hole fill 18:45 19:00 0.25 0 0 COMPZ RPCOh PULD P Clean & clear rig floor area of OBM. Send out all tools not needed: 19:00 22:15 3.25 0 0 COMPZ RPCOh PULD P Held PJSM with crew, GBR reps & Centrilift rep.Pick up ESP tools. Make Motor with A-Well 1-Pump & centralizer. Makeup Upper & lower tandem seal sections. Check Motor rotation & fill motor with Centrlift CL-5 oil. 22:15 23:45 1.50 0 0 COMPZ RPCOh PULD P Make up Joint #1 on ESP assembly. Rig up to run ESP cable. Install Big Sheave on tugger line with cable, raise sheave to running height and pull cable through sheave. Install wind break on beaver slide door. - --- F'~cJ~ fi5 oaf ~r9 ~ Time Logs - - -- _ _ - 'Date From To Dur S Depth E D_ e th P_ha_se Code Subcode_ T _ COM ~ ___ 11/14/2006 23:45 00:00 0.25 0 0 COMPZ RPCOh PULD P Install 1/4" control line on A-well I-Pump. Install ESP cable to motor. Check & record phase resistivities. RIH attaching Lasalle Protectolizers as er Centrilift re . . 11/15/2006 00:00 01:45 1.75 0 0 COMPZ RPCOh PULD P Terminate ESP cable to motor. Install pratectolizers, canon clamps as per Centrilift rep. RIH with a stand of 4 112" tubing. POOH breakout & lay down 2 'oints. 01:45 05:30 3.75 0 0 COMPZ RPCOh PULD P Held PJSM with crew, GBR reps,. Centrilift rep, and Halliburton Slicline reps. Discuss safety issues and procedure for pump installation. Rig up Slicline sheaves and line. Make up pumps to slickline connection, WLIH to set same. Release from pumps, WLOH. MAke up packoff assembly on slicline. WLIH to set and beat down to set packoff for test. WLOH. Make up crossover, valve & lines for testing inside tubing packoff. Pressure to 400 PSI as per Centrilift. Hold pressure for 5 minutes. Bleed pressure and rig down lines. Blow down same. Rig Down Halliburton slickline Unit. 05:30 06:00 0.50 0 0 COMPZ RPCOh PULD P Make up Unique Discharge valve with pups. Attach 1 /4" control line & install clamps as per Centrilift rep. Crew Chan e 06:00 12:00 6.00 0 3,300 COMPZ RPCOh PULD P Continue install 1/4" control line on dischsarge sub. Test line & connections. Continue RIH with 4 1/2" tubing from derrick. Test ESP cable. Continue RIH with tubing to 3300' MD, and test ESP cable every 1000'. Observe ro er hole fill 12:00 18:00 6.00 3,300 6,190 COMPZ RPCOh PULD P Continue RIH with 4 1/2" completion string from 3300' - 6190', Install clamps on every connection for ESP cable. Observe proper hole fill. Test ESP line every-1000' as per Centrilift re .Crew Chan e 18:00 18:30 0.50 6,190 6,190 COMPZ RPCOh PULD P Pull more ESP cable clamps to rig floor. Count same. Perform continuity test. 18:30 21:00 2.50 6,190 7,200 COMPZ RPCOh PULD P Continue RIH with 4 112" completion string from 6190' - 7200'. Install clamps on every connection for ESP cable. Observe properhole fill. Test ESP line every 1000' as per Centrilift. re . - - L----- -- - ~~~r~ ~S of 89, • Tirne Loc s -- - - -- -~ -- - -- ~ D~te_ _ From__ To Dur S Depth E De th Phase Code Subcode T COM _ __ _ 11/15/2006 21:00 00:00 3.00 7,.200 7;200 COMPZ RPCOCV OTHR P Install safety valve in Tubing string. Change out ESP cable. spools in spooling unit. It was observed that there wasn't enough cable to get to bottom and spool had to be changed out. After changing out spool Perform ESP cable splice & test as per Cenrilift re . 11/16/2006 00:00 02:30 2.50 7,200 7,200 COMPZ RPCOh OTHR P . Continue change out ESP cable spools in spooling unit. It was observed that there wasn't enough cable to get to bottom and spool had to be changed out. After changing out spool. Perform ESP cable splice & test as er Cenrilift re . 02:30 03:30 1.00 7,200 8,050 COMPZ RPCOh PULD P Continue RIH with 4 1/2" tubing from derrick installing ESP cable clamps on every other connection from the GLM. Observe proper hole fill. Make u tot ue = 3800 Fblbs. 03:30 04:00 0.50 8,050 8,050 COMPZ RPCOh PULD P Install 9.85' pup joint as per detail. Make up lastjoint with Vetco Gray 11" x 4 1/2" Tubing hanger. Make up landing joint. UP WT = 155K, SO WT = 95K: 04:00 06:00 2.00 8,050 8,050 COMPZ RPCOti OTHR P Install clamp below hangerjoint, lower hanger to rotary table. Install penetrator sub into the tubing hanger as per veteo Gray and tighten gland nut. Rig up Centrilift equipment on rig floor. Lower ESP cable sheave. Measure & cut- ESP cable. Perform ESP cable splice to penetrator pigtail as per centrilift rep. Monitor well - static. Obtain Hot work permit fro slicing operation. Crew change NOTE: Total fluid loss to date in this B lateral = 1089 BBLS. Total Fluid loss in the D lateral 202 BBLS. 06:00 08:30 2.50 8,050 8,050 COMPZ RPCOh OTHR P Continue perform Splice on ESP cable to pigtail and penetrator sub. Perform megger test. Drain stack, and flush load shoulder in well head. Blow down choke & kill lines. 08:30 09:30 1.00 8,050 8,099 COMPZ RPCOh PULD P Land tubing hanger as per Vetco rep. RILDS. Verify lock down screws run in correctly. Rig up and test hanger seals fo 250 PSI low, & 5000 PSf high ressure. Good test. 09:30 10:00 0.50 8,099 8,099 COMPZ RPCOh NUND P Backout & lay down landing joint. Install two way check in hanger as per vetco re . 10:00 11:00 1:00 8,099 8,099 COMPZ RPCOCV NUND P Vac out &-clean drip pans under rotary table, & remove turnbuckles from BOP stack. f a~E''#ai of 69 • • ! Time Lo s - - - __ - - - --- --- -- - -- P Date From To Dur S. De th E D~pth Phase Code Subco_d_e T COM ------- - 11/16/2006 11:00 11:15. 0.25 8,099 8,099 COMPZ RPCOh SFTY P Held PJSM with crew. Discuss safety issues and procedure for nipple down BOP stack & lines. Discuss Nipple up of tree with Vetco re s. 11:15 12:00 0.75 COMPZ RPCOh NUND P Nipple down BOP stack& Lines. 12:00 .14:30. 2.50 GOMPZ RPCOh NUND P Continue nipple down BOP stack & lines. Set stack back on stum . 14:30 16`30 2.00 COMPZ RPCOh NUND P Nipple up tree. Orient tree as per Vetco rep. Perform megger test on ESP cable after tree installed. Install win valves. 16:30 17:30 1.00 COMPZ RPCOh NUND P Rig up and fill tree with diesel for test. Test tree to 300 PSI low, and 5000 PSI for high test. Good. Bleed pressure. rig down test lines and um . 17:30 17:45 0.25 COMPZ RPCOh OTHR P Rig up Lubricator as per Vetco gray rep. Pull two way check from well head. No ressure. 17:45 18:00 0.25 COMPZ RPCOI~ FRZP P Rig up lines and Little Red services for freeze protecting well head. Rig up topump down 4 1/2" x 9 5/8" annulus, and take returns out of the tubing through the wing valve. Rig return line to the choke manifiold for holding back pressure when pumping. Test all lines to 1000 PSI with Little Red services. Crew Chan e. 18:00 18:30. 0.50 COMPZ RPCOh SFTY P Held PJSM with new crew and Little Red reps. Discuss safety issues and procedure for displacing SFMOBM and freeze protecting with diesel Double check all lines ri ed u . 18:30 23:30 5.00 COMPZ RPCOti FRZP P Displace well with freesze protect diesel taking returns through choke manifold initially. Observed only getting half the returns we were pumping at 3 BPM - 700 PSI. Rig up return lines straight to pits. Continue pumping diesel still observing only getting half of what we are pumping until observing a total of 637 BBLS pumped away and then getting diesel.. returns. Pump a total of 700 BBLS of diesel, with a total of 430 BBLS returned, including last 60 BBLS being clean diesel. These returns indicated a total of 270 BBLS pumped away into the wellbore. Final circulating pressure 3 BPM - 475 PSI. 23:30 23:45 0.25 COMPZ RPCOM1 FRZP P Bleed and blow down all lines with well shut in. Ri down Little red services. 23:45 00:00 0.25 COMPZ RPCOh OTHR P Remove tree cap, and rig up lubricator as er Vetco re s. I Pepe ~R of 63 ~ Time Low ~ Date From To Dur S De th E. De th Phase Code Subcode T COM 11/17/2006 00:00 01:15 1.25 COMPZ RPCOti OTHR P Install BPV as per Vetco Gray reps. with Lubricator. SIMOPS: Cleaning its. 01:15 02:00 0.75 COMPZ RPCOh OTHR P Rig down Lubricator. Secure Tree. Close all valves. Remove secondary valve on annulus. Install Blanking flange. Shut in pressure on tree = lower annulus = 150. PSI, Upper annulus = 700 PSI, and tubing = 600 PSI. BPV in place @ 0115 HRS. Continue with Cleanin its. 02:00 06:00 4.00 COMPZ RPCOh OTHR P Continue cleaning all. pits. Vac out cellar, clean & secure same. Prepare rig for move. Disconnect all mud, water, air & hydraulic lines. Skid rig floor as per TP. Rig Released @ 0600 H RS e'~t~~ Fig of 59 r • 29-Dec-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-182 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 17,844.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 ,/~ ~ ~ _ / , _ Date~~t,, o`,j~~ / Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) `~~ C~ - t ~ '2- =• - FRANK H. MURKOWSKI, GOVERNOR ~+ ~-~tt7r~laT ®~ t~lsi~+/~+Vr~-7 333 W. 7~" AVENUE, SUITE 100 C®~-7ER~Aii®1~ ~®~`II-7-7I®~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Randy Thomas FAX (so7~ 27s-7sa2 Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-182 ConocoPhillips Alaska, Inc. Permit No: 206-132 Surface Location: 1570' FSL, 2434' FEL, SEC. 25, Tl 1N, RlOE, UM Bottomhole Location: 1292' FSL, 1010' FWL, SEC. 14, T l ON, R 10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) ~-3607 (pager). N DATED this~day of September, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco hilli s ~ p Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com September 19, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Producer, 1J-182 and iJ-182 L1 Dear Commissioners: DECEIVED SEP 1 ~ 2006 Alaska Oit $ Gas Cons. Commission Anchorage ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore producer well, aduo-lateral horizontal well in the West Sak "B"and "D" sands. The main bore of the well will be designated 1J-182, and the lateral bore of the well will be designated 1J-182L1. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of iJ-182 is October 2, 2006. If you have any questions or require any further information, please contact David Nugent at 265-6862. Sincerely, Randy Thomas Greater Kuparuk Area Drilling Team Leader ~ • C~ivED STATE OF ALASKA `'/~ RG~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~'~~ PERMIT TO DRILL 20 AAC 25.005 SEP 1 9 2006 Alaska Qil & Gas Cans. `Commission 1a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone Q 1c. Specify if vfgll is prop Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: .r Blanket Single Well Bond No. 59-52-180 11. WeII Name and Number: 1J-182 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 17790' • TVD: 3325' ' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1570' FSL, 2434' FEL, Sec. 35, T11 N, R10E, UM ' 7. Property Designation: ADL 25662, 380058 West Sak Oil Pool Top of Productive Horizon: 1247' FNL, 1032' FWL, Sec. 11, T10N, R10E, UM 8. Land Use Permit: ALK 2177, 4604 13. Approximate Spud Date: 10/2/2006 Total Depth: 1292' FSL, 1010' FWL, Sec. 14, T10N, R10E, UM ' 9. Acres in Property: 2560 14. Distance to ~, Z ~•(~ Nearest Property: ~2.mile5- q.Z 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558780 - y- 5945382 Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Nearest well within Pool: 1J-152L1 , 135' @ 888'. 16. Deviated wells: Kickoff depth: 300 • ft. Maximum Hole Angle: 91° • deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1547 psig ~ Surface: 1169 psig • 18. Casing Program ifi ti S Setting Depth Quantity of Cement Size ons pec ca Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 40" 20" 62.5# H-40 Welded 80' 28' 28' 80' 80' 260 cf ArcticCRETE 16" 13-3/8" 68# L-80 BTC 3670' 28' 28' 3670' 2153' 710 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 9767' 28' 28' 9767' 3420' 610 sx DeepCRETE 6.75" 4.5" 11.6# L-80 BTCM 8023' 9767 3420' 17790' ~ 3325' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/S t r u ct u ra I Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee Q BOP Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Nugent @ 265-6862 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ ~ ~~ ~~~~,~ •~%~~~ j. Phone ~ 3.-4~}~ Date ~ jfr1 `~~~ 7 /~ r nAll Commission Use Only Permit to Drill / Number: sG..(/~-/ ~ ~- API Number: / 50-C/~/ ~~~~!'~ Permit Approval Date: . See cover letter for requirements ConditiOnS Of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed m ane, gas hydra , or s contained in shales: Samples req'd: Yes ^ No ~ req'd: Yes ^ No [~ Other: 3'000~sd ~7 ~5~ c.`~, ~~~fH2S measures: Yes [] No Ye nal eq'd: Yes [+~ No ^ P ED BY THE COMMISSION DATE: ~ ~` ~O ~ ,COMMISSIONER ~I Form 10-401 Revised 12/2005 ~ ~ ~ l; .,. ~ 1 ~ {~ ~ r V ~ y~ubmi~ ZufplicOat~ ,~~~~-~~ A~tion for Permit to Drill, Well 1 J-182 Revision No.O Saved: 18-Sep-06 Permit It -West Sak Well #1J-182 ""~ f.A +'l Application for Permit to Drill Document ~~~~~ MdxirttiixE 1M~11 tfalue Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (fl ............................................................................................................. 2 2. Location Summary ..................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ......................................................................................................... 2 Requirements of 20 AAC 25.050(b) ............................................................................................................. 3 3. Blowout Prevention Equipment Information ............................................................... 3 Requirements of 20 AAC 25.OOS(c)(3) ......................................................................................................... 3 4. Drilling 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) (S) ........................................................................................................ 3 6. Casing and Cementing Program ................................................................................. 4 Requirements of 20 AAC 25.005(c)(6) ......................................................................................................... 4 7. Diverter System Information ...................................................................................... 4 Requirements of 20 AAC 2S.OOS(c)(7) ......................................................................................................... 4 8. Drilling Fluid Program ............................................................................................... 4 Requirements of 20 AAC 25.005(c)(8) ......................................................................................................... 4 Surface Hole Mud Program (extended bentonite) ......................................................................................... 4 Intermediate Hole Mud Program (LSND) .................................................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) B, D sand laterals .................................................... 5 9. Abnormally Pressured Formation Information ........................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ........................................................................................................ 5 10. Seismic Analysis ......................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ...................................................................................................... 5 11. Seabed Condition Analysis .......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ...................................................................................................... 5 ~R161NAL 1 J-182 PERMIT 1 T Page 1 of 7 Prinfed: 18-Sep-06 A~tion for Permit to Drill, Well 1 J-182 Revision No.O Saved: 18-Sep-06 12. Evidence of Bonding ................................................................................................... 5 Re uirements o 20 AAC 25.005 c 12 ...................._........... 5 q ()( ) ...................................................................... 13. Proposed Drilling Program ......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ...................................................................................................... 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal-, ................................ 7 Requirements of 20 AAC 25.005 (c) (14) .......................................:......................':....................................... 7 15. Attachments ............................................................................................................. 7 Attachment 2 Directional Plan .................................................................................................................. 7 Attachment 3 Drilling Hazards Summary ................................................................................................... 7 Attachment 4 CemCADE Summary ............................................................................................:.............:.. 7 Attachment 5 Well Schematic .................................................................................................................... 7 1. Well Name Requirements of 20 AAC 25,005 (~ Poch well roust be identi, fzed liy a unique name designated by the operator and a ttnzque APL number assigned Irv the commzsszon ztnder 20 AAC 25.040(h). L%ar a well tirzth multiple well branches, each branch nzztst similarly be identrf ed by a unique name and.4F'I nurnher by adding a sut~ix to floe name designated for the weft by the operator and to the number assigned to tlae well by rize cornntission. The well for which this Application is submitted will be designated as 1J-182. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Perrrait to Drill must tze accorrapanied by each of the.~rlfowing items, except,for an uem alreadv on. file with the corrtrrzission and identified in the applicatzora: (2) a plat idcrat~~ing the property and thelrroper-tys owners and showing (A)che coordinates of the proposed location ~f the well at the surface, at the top of each objective forrnatiorr, and at total depth, referenced to governmental section lines. {L3} the coordinates oJ'tlae proposed location of the well at the surface, referenced to the state pfane coordinate system for this state as maintained by the National Geodetic Survev fn the Nationaf f3cearzic and Atm~osplzeric Administration; (C) the proposed depth of the welt at the top ref each obiective formation cznd at total depth; Location at Surface 1,570' FSL, 2434' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 121' AMSL Northings: 5,945,382 Eastings: 558,780 Pad Elevation 81' AMSL Location at Top of Productive Interval (West 1,247' FNL, 1,032' FWL, Section 11, T10N, R10E Sak "B" Sand ASP Z NA 2 Measured De th, RKB: 9,767 one 4 D 7 Coordinates Northin 272 Eastin s: 557 037 s: 5 937 Total Vertical De th, RKB: 3,420 g g , , , Total Vertical Depth, SS: 3,299 Location at Total Depth 1,292' FSL, 1,010' FWL, Section 14, T10N, R10E ASP Z Measured Depth, RKB: 17,790 one 4 NAD 27 Coordinates Northin 252 Eastin s: 557 086 s: 5 929 Total Vertical De th, RKB: 3,325 g g , , , Total Vertical Depth, SS: 3,204 and (I~} other information required by 20.9AC 25.0~0(h}; 1J-182 PERMIT IT Page 2 of 7 Printed: 18-Sep-06 ~~~G~~AL A~tion for Permit to Drill, Well 1J-182 Revision No.0 Saved: 18-Sep-06 Requirements of 20 AAC 25.050(b) Lf~a well is to fie intentionally deviaCect the application fur a Permit to I)r^ill (Form 1(1-101) must (7) include a p1aC, drawn to a suitctble scale, shotiving the luzth of the proposed weflbore, including all actlacenl a~eilbor'es within 200 feet afaray portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 J'eet of the proposed wellbore (A) list the names of tlae operators of tltase wells, Co the extent that these names c{re known or discoverable in public records, and show tl~tat each Harried aper•ator has been furnished a copy of Che application ley cerCifzed mail; or- (Z3j state Chat the aLrplicatst 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 fi7r a Permit to Dr°ill mrtst fie accompanied by each of the following items, except for an item already on file H+ith the comrnissian arad ident~ed in the application: (3j a diagram and descriptfon of the blowout prevention equipment (L30PE`j as required by 20 AAC 25.035, 20 AAC 2.5.036, or 20 AAC` 25.03', as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well IJ-182. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Perrrait to L1ril1 must he aceouapanied by each of the, following items, esctpt for can item atreaa!v on file with the corttntirsion and identified in the application: ('4) infortauttion ort drilling hazards, inc:htdireg (~j the maximum dowrahrrle pre-csure that may be encotantered, criteria used to determine ii, and maximurra prstentiaT .cu~ace presstare based ora rx methane gradient,' The expected reservoir pressure in the West Sak sands in the 1J-182 area is 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) is 1,169 psi. 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 3,438'. The MPSP is: MPSP = (3,438 ft)(0.45 - 0.11 psi/ft) =1,169 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. atarl (C) dtzta concerning potential causes of hole problems such as abnorn2ally geo-pressured strata, lost circulation tortes, and zones that have a propensity for differential sticking; Please see Attachment 2: 1J-182 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) An application for et Permit to L?rill must he accompanied by each of the.frrllowing items, except for an item alrearz'v an file with the cornrnission and identr,'f ed in the aplrlicatiora: (S) a description of Che procedure fcrr c+oraductirag fcrnraatiorx integrt{y Cests, as r•c:quired under 20 AAC 2.5.030{J); 1J-182 will be completed with 9-5/8" casing landed at the top of 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 ConcocoPhillips Alaska placed on file with the Commission. 1J-182 PERMIT IT Page 3 of 7 Printed: 18-Sep-O6 OR161NAL A~tion for Permit to Drill, Well 1 J-182 Revision No.O Saved: 18-Sep-06 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c) (6) Ar^t applioatiort,far aPermit to Drill roust be accompanied by each of the follmving hems, except for an item already on file with the commission and identified in the application: (6) a complete propased casing and ce»terating program as required by 20 AAC` 25.E130, and a dercriptiort of any slotted liner, pre-perforated liner, or screen to he installed; Casing and Cementing Program See also Attachment 3: Cement Summary ~~ "" ~ ~ 7 Hole Top Btm Csg/Tbg Size Weight Length MD/TVD tL~/TVD OD in in Ib/t) Grade Connection t) t t Cement Pro ram 20" 40" 62.5 H-40 Welded 80 28' / 28' 80' / 80' Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 13-3/8" 16" 68 L-80 BTC 3,670 28' / 28' 3,670' / 2,153' 710 sx ArcticSet Lite Lead, 220 sx Dee CRETE Tail Cement Top planned @ 6,226' 9-5/8" 12-1/4" 40 L-80 BTCM 9,767 28' / 28' 9,767' / 3,420' MD / 2,601' TVD. Cemented w/ 610 sx Dee CRETE 4-1/2 slotted 6-3/4" B Sand Lateral (l.r-182) 11.6 L-80 BTCM 8,023 9,767' / 3,420' .17,790' / 3,325' Slotted-no cement 4- 6-3/4" D Sand Lateral slotted (t1-182 Ll) 11.6 L-80 BTCM 8,630 9,159' / 3,359' 17,789' / 3,259' Slotted- no cement 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for u Permit to Drill rmast be ac,:omparai<;d by each of the following iterras, except for an item already ort,file with the commission and identified in tlae application: (7) a diagram and dcscr~ptinn of the diverier system as required by 20 AAC 25.03 5, males thin requirement is waived by the commission under- 20 A.4C?5.035(li)(2); A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 17- 182. Please see diagrams of the Doyon 15 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application frrr a Permit to Drill nttcst be accompar^aied 1>y each pf the following items, ea~cept f<~r an item atread3> on trle wr.'th the commission anil identified in the application: (8) a drilling fluid program, including a diagram and descriptinrt of the drillirag,fluidcystem, as required by 20 <R.2 (" 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Surface Casing Point Initial Value Final Value Inifial Value Finad Value Density (ppg) 8.5 9.2 9.2 9.6 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50-70 50-70 30-50 30-50 cP Plastic Viscosity 20-45 20-45 15-20 15-20 (lb/100 s pH 8.5-9.0 8.5-9.0 8.5-9.0 8.5-9.0 API Filtrate cc / 30 min)) NC-8.0 NC-8.0 5.0-7.0 5.0-7.0 *9.6 ppg if hydrates are encountered 1J-182 PERMIT IT Page 4 of 7 R ~ ~ ~ ~ ~ ~ Printed: 18-Sep-O6 0 Ap~tion for Permit to Drill, Well 1J-182 Revision No.O Saved: 18-Sep-06 Intermediate Hole Mud Program (LSND) 13-3/8"Casing Shoe to Intermediate Casing Point Initial Value Density (pp) 9.0-9.1 Funnel Viscosity 45-60 (seconds) Plastic Viscostiy (lb/100 s 12-18 Yield Point (cP) 26-3 5 API Filtrate 4-6 (cc / 30 min)) Chlorides (mg/l) <500 pH 9.0-9.5 MBT <20.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) B, D sand laterals Value Density (ppg) 9.0 Plastic Viscostiy (lb/100 s~ 15-25 Yield Point 18 28 (~P) HTHP Fluid loss (ml/30 min @ <4.0 200 si & 150° Oil /Water Ratio 80:20 Electrical Stabili >600 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions. of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for• a Permit to Drill rmrst he aecx~mparned by each cf the,follawing aterris, except for an item ah~ecady ort file with the commission grad identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of pr°edicted abnormally geo ~rresstrred strata as required by 2D.AAC 23.1133(f}; Not applicable: Application is not for an exploratory or stratigraphic test well. - 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) %In application for a Perrtait to I?rr.'ll must be accompanied by each of tlze.following items, except for an item already on. fide with the commission and idertified in the application: {IQ) for an exploratory or stratigraphic test well, a seismic rcfracxion or refection analysis as required by 2f1.AAC 25:f)61(aj; Not applicable: Application is not for an exploratory or stratigraphic test well. - 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill roust be aceompartic;d by each of the following aterns, exr,•ept for an item ab-eacty orz fide rorith the commission and identited in tha application: {II), for a Weil drilled from an offshore platform, rrtobile bottorrt founded structure, jack-up rig, or floating drilling vessel, can analysis of seabed conditions as reclrrired by 20 _AAC'S.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) _An application for a Permit to Drill must be accorstpanied by each of the following items, except for arz item already oiz fzle tr~ith the commission and identified in the applicc~tiora: {12) evidence showing that the requirements of 2lI AAC 25.25 {Bandingjlaave been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An apph~cation fiu^ a Pc;rmit to Drill roust be accompartic;d ley each of the•jollawing rterrzs, exc~ pt for an item alr-ecady ort_~le with ilze commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematics. 1J-182 PERMIT IT Page 5 of 7 Printed: 18-Sep-O6 ORIGINAL A~ition for Permit to Drill, Well 1J-182 Revision No.O Saved: 18-Sep-06. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 121' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon Rig 15. Insta1121-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 3,670' MD / 2,153' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface.' Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. 6. PU 12-1/4" drilling assembly, with MWD, LWD &PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. 8. Directionally drill to 9-5/8" casing point at 9,767' MD / 3,420' TVD, the prognosed top of the B sand. 9. Run 9-5/8", 40# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 6,226' MD / 2,601' TVD if Ugnu formation is not oil bearing. (Top of cement to be 500 feet (MD) above shallowest oil bearing sand if Ugnu is oil bearing). Pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 9-5/8" packoff and test to 5000 psi. 11. Flush 13-3/8" x 9-5/8" annulus with water, followed by diesel. 12. PU 6-3/4" drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. 14. Directionally dri116-3/4" hole to TD at +/- 17,790' MD / 3,325' TVD as per directional plan. 15. POOH, back reaming out of lateral. POOH. ~~ ~ ~~~`~ 16. PU and run 4-1/2" slotted liner. ,, 17. Land liner, set liner hanger @ +/- 9,259' MD / 3,372'. POOH. Note: Remaining operations are covered under the IJ--182 LI Application for Permit to Drill, and areprovided here for information only. 18. Run and set Baker WindowMaster whipstock system, at window point of 9,159' MD / 3,359'. TVD, near the top of the "D" sand. 19. Mi116-3/4" window. POOH. 20. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. 21. Drill to TD of "D" sand lateral at 17,789' MD / 3,259' TVD, as per directional plan. 22. POOH, back reaming out of lateral. POOH. 23. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 24. PU and run 4-1/2" slotted liner. 25. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 26. Release hanger running tool. POOH. 27. POOH, laying down drill pipe as required. 28. PU completion as required and RIH to depth. Land tubing. Set BPV. 1J-182 PERMIT IT Page 6 of 7 Printed: 18-Sep-O6 ORIGINAL Ation for Permit to Drill, Well 1J-182 Revision No.0 Saved: 19-Sep-06 29. Nipple down BOPE, nipple up tree and test. Pull BPV. 30. Freeze protect well with diesel by pumping into 4-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. 31. Set BPV and move rig off. 32. Rig up wire line unit. Pull BPV. 33. Set gas lift valves in mandrels. Operate well on gas lift until ESP facilities are ready. 34. Rig up wireline. Replace gas lift valves with blank dummy valves. 35. Place well on production with ESP. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An aphliccrtion for a Per-rnii to Drill musts 1+e accorrrpanied by each of the fi>Clowing items, excepi for ara iiem already on fale with the commission and identified in the appltcatiora: (1=1j a general description of hove the operator plans to dislaose of drilling mud and cuiting.c and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular dr+sposal operation ira the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J 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 1J Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads. and roads in the Kuparuk area in accordance with a permit from the State of Alaska. - - - ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 CemCADE Summary Attachment 4 Well Schematic 1J-182 PERMIT IT Page 7 of 7 ` . ~ ~ Printed: 19-Sep-06 ~ ~ Conoco~hillips Alaska Plan: 1 J-182 (wp11) illi Proposal Report -Geographic 13 September, 2006 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-182 -Slot 1J-182 1 J-182 Local Coordinate Origin Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Plan 1J-182 -Slot 1J-182 Plan RKB @ 121.OOft (Doyon 15 (40+81)) N True API - US Survey Feet .. .. -. _ Sperry drilling Services ORIGINAL Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-182 Wellbore: 1J-182 Plan: 1J-182 (wp11) CASING DETAILS No TVD MD Name Size 1 2153.00 3670.22 13 3/8" 13-3/8 2 3419.50 9766.78 9 5/8" 9-5/8 3 3325.30 17789.82 41/2" 4-1/2 I FORMATION TOP DETAILS I SHL @ 1570' FSL & 2434' FEL -Sec 35 - T11 N - R70 ~ KOP @ 300ft MD, 300ft TVD -Build @ 2.5°/100 i i ~ ~ Continue Build @ 4°/100ft , 702ft MD, 700ft N i i i ~ Sail @ 47°Inc : 1629ft MD, 1500ft~ i i ~ ~ - [Continue Build @ 5°/100ft , 1729ft MD, 1568ft N i - i~ ` ~ ' " ' "~_^' ~ ~ Casing@3670ftMD,2153ftTVD-692 133/8 FNL82160 FWL-Sect-T10N-R1 E ~"'~ 0 . ~ ,-' Sail @ 77.14°Inc & 192.81°Azi : 2365ft MD,1863ft TV , - " ~"" ° 0° _ _ - ' , - ' ~ Sail @ 80°Inc & 180.20°Azi : 9059ft MD, 3342ft TV ~ `~ .~~• c_'1000 - pp0 ~ , - Continue Build / Tum @ 3/100ft , 8636ft MD, 3258ft TV~ "~ Base Perm DA ,' - '~ ,-' ,-' i Continue Bu' 100ft 9326ft , 02000 Ki5 -------- ~ - ---- ° i ° ~/ - ----------------- ~ ------=--- o r3+ss0---- -----~ -----y - ^--o--- ° v ' UgnuC Ugnu6 UgnuA ~ o° i~ ----~~--- 1J-182(Wp11)~ ° ' ~ _ _ /100ft , 9900ft MD, 3431ft TVD - Geosteer in BSa~i ^ d ~ ~ ° ~ Continue Build @ 3 ~ a~3000 ~ - - - - _ _ °____---- ----K13 _ =____ - o - o -a- - - - a - - r - - - - _ _ _ _ _ _ _ _ _ _ro ~ o , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ ° "~ - ~J ~ z -- -_ - .. ______ ___- ___ ar-~ ---_ ___- °--- ------ -- - - ----- - - -~ ~ -} 41/2"-- __,- - ~~ WSAK D 1J-182 T1 {D-Sand Tap) {wp11 ~ ° 'o ° o g ° o 0 \~ / I 0 O P O I O ~ I I I I WSAK C _ I WSAK B 1J-182 T2 {wpi i~ li 1J-182 T4 {wp11 ,I 1J-182 T3 {wP11 i1J-182 TS {wP11 9 5/8" Casing @ 9767ft MD, 3420ft TVD -1247' FNL & 7032' FWL -Sec 11-T10N-R7 E ~, Ct 311 U CC- ~ x"11 ~ ~ 1' ~} S l~iBS 1000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 Lert~eal Sect[a?a cat 1£z;.OC° (1~t/0 ii.•`inl ~ ~~ a IJ a v ° / 1 G N o° ~ io c i ~ i ~ i i i ~ __ 1J_182 T6 {wp11 ~ 9J-182 T8 {Tae} {w}a11~ 1 J-182 T7 {wp11 1..1 Ctritting ar~cll ~Y~arrrwrvian Et/eluatlc~n 13000 14000 15000 16000 17000 CASING DETAILS 0 No TVD MD Name Size 1 2153.00 3670.22 13 3/8" 13-3/8 2 3419.50 9766.78 9 5/8" 9-5/8 1000 3 3325.30 17789.82 4 1 /2" 4-1 /2 Project: Kuparuk River Uni Site: Kuparuk 1J Pad Well: Plan 1J-182 Wellbore: 1J-182 Plan: 1J-182 (wp11) 13 3/8" _ 1g3o 30p0 SHL @ 1570' FSl & 2434' FEL -Sec 35 - T71 N - R70 ' - - - _ _ _ __ _ _ _ _ _ _ KOP @ 300ft MD, 300ft ND • Build @ 2.5°/100 - O~0 _ _ Continue Build @ 4°/100ft , 702ft MD, 700ft 2000 ' - - _ Sail @ 47° Inc : 1629ft MD, 1500ft N `' ~ ~ ~ Continue Build @ 5°/100ft , 1729k MD, 1568ft N -. (Sail @ 7 1417 cn & 192.81°Azi ; 2365ft MD, 1863ft~ 13 3/8" Casing @ 3670ft MD, 2153ft ND - 692' FNL 8 2160' FWL -Sec 2 - T10N - R1 E / i Continue Build / Tum @ 3/100ft , 8636ft MD, 3258ft 190o Sail @ 80°Inc & 180.20°Azi : 9059ft MD, 3342ft N Continue Build @ 3°/100ft , 9326ft MD, 3381ftN 1800 9 5/8" Casing @ 9767ft MD, 3420ft ND -1247' FNL & 1032' FWL -Sec 11-T10N-R1 E Continue Build @ 3°/100ft , 9900ft MD, 3431ft ND - Geosteer in BSar~d 180° :180° -1 ~ 1 J-182 T4 {w11) - - -12000. -13000 1J-182 (wp11} _. _ T M Azi3>~uthe to True No~iFr Magnetic North: 23.98° Magnetic Field Strength:57564.4nT -14000 Dip Angle: 80.78° Date: 9/1/2006 Model: BGGM2005 -15000 II1J-182 T {p11) - 1J-182 T7 {wp11) - ---~ 41/2•' ~i~~j ' -lsooo j:3S ~" ~a 1 J-182 T {Toe} {p11 } ~- 180° Palygon Describes a corridor 100' wide with a 50"°~!° allowance .from the praposed wellbore. 180° 180° 180° 180° ------1J 82(wp1 -7000 -6000 -5000 -4000 -3000 -2000 -1000 ORIGINAL 0 1000 2000 750 ft/inl t~At.~.t~u1~-a-~ Owiitipg anti 3'-'OI'IYTAtkeri ~w~tu~ti~~, 3000 4000 5000 • • Ph.lf . Halliburton Energy Services 5,945,381.64 ft Latitude: 558,779.69ft Longitude: ft Ground Level: OC 1 LpS Planning Report -Geographic ®rill'vng and t~armatian Alaska Eva(uatFcn Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-182 -Slot 1J-182 Company: ConocoPhillips Alaska, Inc. TVD Reference: Plan RKB @ 121.OOft (Doyon 15 (40+81 )) Project: Kuparuk River Unlt MD Reference: Plan RKB @ 121.OOft (Doyon 15 (40+81)) Site: ICuparuk 1J Pad North Reference: True Well: Plan 1J-182 Survey Calculation Method: Minimum Curvature Wel Ihore: 1 J-182 Design: 1J-182 (wp11) Project I par k River Init. North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 -Using geodetic scale factor Well flan 1J-182 -Slot 1J-182 Well Position +N/-S 0.00 ft Northing: +E/-W 0.00 ft Easting: Position Uncertainty 0.00 ft Wellhead Elevation: Wellbore 1,~-182 Magnetics Model Name Sample D2te BGGM2005 9/1/2006 Design 1J-182(wp11) Audit Notes: Version: Vertical Section: 1-iILILJTCr~I 70° 15' 40.967" N 149° 31' 29.427" W 81.00 ft Phase: Depth Front (TVD) (ftl 40.00 Declination (') 23.98 PLAN + N; -S (ft) 0.00 Dip Angle (`) 80.78 Tie On Depth: +Ei-W (ft) 0.00 Direction (') 180.00 Field Strength {nT) 57,564 40.00 9/13/2006 1:15:21 PM Page 2 of 11 QIGINAL COMPASS 2003.118ui1d 50 • • C Philli Halliburton Energy Services r~a~trc c o p s Planning Report - Geographic Drilling and Formation Alas ka Evaluation Database: EDM 2003.11 b48 Lo cal Co-ordinate Reference: `°tell Plan 1J-182 -Slot 1J-182 Company: Conoco Phillips Alaska , Inc. TVD Reference: P'an RKB @ 121 .OOft (Doyon 15 (40+81 )) Project: Kuparuk River Unit MD Reference: Flan RKB @ 121 .OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Wcll: Plan 1J- 182 Su rvey Calculation Method: Minimum Curvat ure Wellbore: 1J-182 Design: 1J-182 (wpll) - -- ~~ Plan Summary ~-- _..~~ ~~ Measured Vertical Dogleg Build Turn ~. Deptb Inclination Azimuth Depth ~N/_g +E/-W Rate Rate Rate TFO ~~ (ft) (') (') (ft) (ft) (ft) ('I100ft) (°/100ft) ('/100ft) (') 40.00 0.00 0.00 40.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00. 0.00 0.00 702.06 10.05 205.00 700.00 -31.88 -14.87 2.50 2.50 0.00 205.00 1,629.31 47.14 205.00 1,500.00 -427.13 -199.18 4.00 4.00 0.00 0.00 1,729.31 47.14 205.00 1,568.02 -493.57 -230.15 0.00 0.00 0.00 0.00 2,365.33 77.14 192.81 1,862,68 -1,020.76 -401.85 5.00 4.72 -1.92 -22.99 8,636.12 77.14 192.81 3,257.85 -6,982.19 -1,757.43 0.00 0.00 0.00. 0.00 9,058.91 80.00 180.20 3,341.94 -7,393.03 -1,804.05 3.00 0.68 -2.98 -78.30 9,158.91 80.00 180.20 3,359.30 -7,491.51 -1,804.39 0.00 0.00 0.00 0.00 9,325.58 85.00 180.20 3,381.05 -7,656.70 -1,804.97 3.00 3.00 0.00 0.00 9,899.98 85.00 180.20 3,431.11 -8,228.91 -1,806.96 0.00 0.00 0.00 0.00 , 10,090.92 90.73 180.10 3,438.22 -8,419.63 -1,807.47 3.00 3.00 -0.05 -0.96 10,882.11 90.73 180.10 3,428.18 -9,210.75 -1,808.90 0.00 0.00. 0.00 0.00 10,900.05 91.07 180.20 3,427.90 -9,228.69 -1,808.95 2.00 1.92 0.55. 15.82 10,900.08 91.07 180.20 3,427.90 -9,228.73 -1,808.95 3.00 2.98 -0.31 -5.95 12,987.71 91.07 180.20 3,388.79 -11,315.97 -1,816.29 0.00 0.00 0.00 0.00 12,999.63 90.72 180.24 3,388.60 -11,327.90 -1,816.34 3.00 -2.98 0.31 174.05 12,999.68 90.72 180.24 3,388.60 -11,327.95 -1,816.34 3.00 2.95 0.52 10.03 14,361.21 90.72 180.24 3,371.51 -12,689.36 -1,822.01 0.00 0.00 0.00 0.00 14,372.88 90.37 180.18 3,371.40 -12,701.03 -1,822.05 3.00 -2.95 -0.52 -169.97 14,373.24 90.37 180.18 3,371.40 -12,701.39 -1,822.06 3.00 -2.58 1.52 149.47 16,461.09 90.37 180.18 3,358.09 -14,789.19 -1,828.74 0.00 0.00 0.00. 0.00 16,500.16 91.37 179.59 3,357.50 -14,828.25 -1,828.66 3.00 2.58 -1.52 -30.53. 16,500.17 91.37 179.59 3,357.50 -14,828.26 -1,828.66 3.00 -2.90.. -0.77 -165.15 16,897.54 91.37 179.59 3,347.97 -15,225.50 -1,825.80 0.00 0.00 0.00 0.00. 16,900.36 91.46 179.61 3,347.90 -15,228.32 -1,825.78 3.00 2.90 0.77 14.85 17,789.83 91.46 179.61 3,325.30 -16,117.48 -1,819.72 0.00 0.00. 0.00 0.00 9/13/2006 1:15:21 PM Page 3 of 11 a~~~~~A~ COMPASS 2003.11 Build 50 • • Halliburton Energy Services CQn® ' 1p5 Planning Report -Geographic Alaska Database: EDM_2003.11_b48 Company: ConocoPhillips Alaska. Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-182 Wel Ihore: 1 J-182 Design: 1J-182 (wp11) , Planned Survey Orilitng and Formation Evetuation Local Go-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: '::'ell Pfan 1J-182 -Slot 1J-182 Plan RKB @ 121.OOft (Doyon 15 (40+81)) Plan RKB @ 121.OOft (Doyon 15 (40+81)) True i.'inimum Curvature Map Map MD Inclination Azimuth TVD SSTVD +N/-5 +Ei-W Northing Fasting DLSEV Vert Section ItU (") (`) (ft) (ft) (ft) (ft) (ft) (ft) ("I1DDft) (ft) 40,00 0.00 0.00 40.00 -81.00 0.00 0.00 5,945,381.64 • 558,779.69 • 0.00. 0.00 SHL @ 1570' FSL & 2434' FEL -Sec 35 - T11 N - R10E 100.00 0.00 0.00 100.00 -21.00 0.00 0.00 5,945,381.64 558,779.69 0.00 0.00 200.00 0.00 0.00 200.00 79.00 0.00 0.00 5,945,381.64 558,779.69 0.00 0.00 300.00 0.00 0.00 300.00 179.00 0.00 0.00 5,945,381.64 558,779.69 0.00 0.00 KOP @ 300ft MD, 300ft TVD -Build @ 2 .5°/100ft 400.00 2.50 205.00 399.97 278.97 -1.98 -0.92 5,945,379.66 558,778.78 2.50 1.98 500.00 5.00 205.00 499.75 378.75 -7.90 -3.69 5,945,373.71 .558,776.07 2.50 7.90 600.00 7.50 205.00 599.14 478.14 -17.77 -8.29 5,945,363.81 558,771.54 2.50 17.77 700.00 10.00 205.00 697.97 576.97 -31.56 -14.71 5,945,349.98 .558,765.22 2.50 31.56 702.06 10.05 205.00 700.00 579.00 -31.88 -14.87 5,945,349.65 558,765.07 2.50 31.88 Continue Bu ild @ 4°/100ft , 702ft MD, 700ft TVD 800.00 13.97 205.00 795.78 674.78 -50.35 -23.48 5,945,331.12 558,756.61 4.00 50.35 900.00 17.97 205.00 891.90 770.90 -75.28 -35.10 5,945,306.10 558,745.18 4.00 75.28 1,000.00 21.97 205.00 985.87 864.87 -106.22 -49.53 5,945,275.05 558,730.99 4.00 106.22 1,100.00 25.97 205.00 1,077.23 956.23 -143.03 -66.70 5,945,238.11 558,714.12 4.00 143.03 1,200.00 29.97 205.00 1,165.53 1,044.53 -185.53 -86.51 5,945,195.46 558,694.63 4.00 185.53 1,300.00 33.97 205.00 1,250.34 1,129.34 -233.51 -108.89 5,945,147.32 558,672.64 4.00 233.51 1,400.00 37.97 205.00 1,331.26 1,210.26 -286.73 -133.70 5,945,093.91 558,648.24 4.00 286.73 1,500.00 41.97 205.00 1,407.89 1,286.89 -344.93 -160.85 5,945,035.50 558,621.56 4.00 344.93 1,600.00 45.97 205.00 1,479.84 1,358.84 -407.84 -190.18 5,944,972.37 558,592.72 4.00 407.84 1,629.31 47.14 205.00 1,500.00 1,379.00 -427.13 -199.18 5,944,953.01 558,583.87 4.00 427.13 Sail @ 47° In c : 1629ft MD , 1500ft TVD 1,700.00 47.14 205.00 1,548.08 1,427.08 -474.09 -221.07 5,944,905.88 558,562.35 0.00 474.09 1,702.82 47.14 205.00 1,550.00 1,429.00 -475.97 -221.95 5,944,904.00 558,561.48- 0.00 475.97 Base Perm 1,729.31 47.14 205.00 1,568.02 1,447.02 -493.57 -230.15 5,944,886.34 558,553.42 0.00 493.57 Continue Bu ild @ 5°/100ft , 1729ft MD, 1568ft TVD 1,800.00 50.41 203.21 1,614.60 1,493.60 -542.10 -251.84 5,944,837.65 558,532.11 5.00 542.10 1,850.54 52.76 202.03 1,646.00 1,525.00 -578.65 -267.07 5,944,800.98 558,517.17 5.00 578.65 T3 1,900.00 55.07 200.95 1,675.13 1,554.13 -615.84 -281.70 5,944,763.68 558,502.83 5.00 615.84 2,000.00 59.78 198.93 1,728.95 1,607.95 -695.04 -310.39 5,944,684.26 558,474.77 5.00 695.04 2,100.00 64.51 197.09 1,775.67 1,654.67 -779.10 -337.68 5,944,600.00 558,448.13 5.00 779.10 2,200.00 69.26 .195.40 1,814.93 1,693.93 -867.38 -363.38 5,944,511.54 .558,423.12 5.00 867.38 2,300.00 74.02 193.81 1,846.42 1,725.42 -959.20 -387.29 5,944,419.55 558,399.94 5.00 959.20 2,365.33 77.14 192.81 1,862.68 1,741.68 -1,020.76 -401.85 5,944,357.87 558,385.86 5.00 1,020.76 Sail @ 77.14°Inc 8192.81 °Azi : 2365ft MD, 1863ft TVD 2,400.00 77.14 192.81 1,870.39 1,749.39 -1,053.72 -409.34 5,944,324.86 558,378.62 0.00 1,053.72 2,500.00 77.14 192.81 1,892.64 1,771.64 -1,148.79 -430.96 5,944,229.64 .558,357.75 0.00. 1,148.79 2,600.00 77.14 192.81 1,914.89 1,793.89 -1,243.86 -452.58 5,944,134.41 558,336.88 0.00 1,243.86 2,700.00 77.14 192.81 1,937.14 1,816.14 -1,338.92 -474.19 5,944,039.19 558,316.01 0.00 1,338.92 2,771.29 77.14 192.81 1,953.00 1,832.00 -1;406.70 -489.61 5,943,971.30 558,301.13 0.00 1,406.70 K15 9/13/2006 1:15:21PM Page 4 of 11 COMPASS 2003.11 Build 50 E ~ • • ^A^M^^1^^/~ t'3 E C17~1I'" 111 $ Alaska Database: _EDM_2003.11 b48 Company: ConocoPhillips Alaska, Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-182 Wellbore: 1J-182 Design: 1J-182 (wp11) Halliburton Energy Services a~a~L~°rr Planning Report -Geographic Ori€€€ng and ~nrmatian EVa€uat€an Local Co-ordinate Reference. We'J Plan 1J-182 -Slot 1J-182 TVD Reference: Plan RKB @ 121.OOft (Doyon 15 (40+81)) MD Reference: Pan RKB @ 121.OOft (Doyon 15 (40+81)) North Reference: T-ue Survey Calculation Method: C.linimum Curvature Planned Survey 1 1 ~ ;:I. 1 i' Map Map MD Inclination Azimuth TVD SSTVD +N/-5 +E;-W Northing Fasting DLSEV Vert Section (ft) 1.'I C') (ft) (ft) (ft) (ft? (ft) (ftl I"I1D9ft) ;ft, I 2,800.00 77.14 192.81 1,959.39 1,838.39 -1,433.99 -495.81 5,943,943.97 558,295.13 0.00 1,433.99 2;900.00 77.14 192.81 1,981.64 1,860.64 -1,529.06 -517.43 5,943,848.74 558,274.26 0.00 1,529.06 3,000.00 77.14 192.81 2,003.89 1,882.89 -1,624.12 -539.05 5,943,753.52 558,253.39 0.00 1,624.12 3,100.00 77.14 192.81 2,026.13 1,905.13 -1,719.19 -560.66 5,943,658.30 558,232.52 0.00 1,719.19 3,200.00 77.14 192.81 2,048.38 1,927.38 -1,814.26 -582.28 5,943,563.07 558,211.64 0.00 1,814.26 3,300.00 77.14 192.81 2,070.63 1,949.63 -1,909.32 -603.90 5,943,467.85 558,190.77 0.00 1,909.32 3,400.00 77.14 192.81 2,092.88 1,971.88 -2,004.39 -625.52 5,943,372.63 558,169.90 0.00 2,004.39 3,500.00 77.14 192.81 2,115.13 1,994.13 -2,099.46 -647.13 5,943,277.40 558,149.02 0.00 2,099.46 3,600.00 77.14 192.81 2,137.38 2,016.38 -2,194.52 -668.75 5,943,182.18 558,128.15 0.00 2,194.52 3,670.22 77.14 192.81 2,153.00 2,032.00 -2,261.28 -683.93 5,943,115.31 558,113.50 0.00 2,261.28 13 3/8" Casing @ 3670ft MD, 2153ft TVD - 692' FNL & 2160' FWL - Sec 2 - T10N - R10E - T3+550 -13 3/8" 3,700.00 77.14 192.81 2,159.63 2,038.63 -2,289.59 -690.37 5,943,086.95 558,107.28 0.00 2,289.59 3,800.00 77.14 192.81 2,181.87 2,060.87 -2,384.66 -711.99 5,942,991.73 558,0$6.41 0.00 2,384.66 3,900.00 77.14 192.81 2,204.12 2,083.12 -2,479.72 -733.60 5,942,896.51 558,065.53 0.00 2,479.72 4,000.00 77.14 192.81 2,226.37 2,105.37 -2,574.79 -755.22 5,942,801.28 558,044.66 0.00 2,574.79 4,100.00 77.14 192.81 2,248.62 2,127.62 -2,669.86 -776.84 5,942,706.06 558,023.79 0.00 2,669.86 4,200.00 77.14 192.81 2,270.87 2,149.87 -2,764.92 -798.46 5,942,610.84 558,002.92 0.00 2,764.92 4,300.00 77.14 192.81 2,293.12 2,172.12 -2,859.99 -820.07 5,942,515.61 557,982.04 0.00 2,859.99 4,400.00 77.14 192.81 2,315.37 2,194.37 -2,955.06 -841.69 5,942,420.39 557,961.17 0.00 2,955.06 4,500.00 77.14 192.81 2,337.62 2,216.62 -3,050.12 -863.31 5,942,325.17 557,940.30 0.00 3,050.12 4,600.00 77.14 192.81 2,359.86 2,238.86 -3,145.19 -884.93 5,942,229.94 557,919.42 0.00 3,145.19 4,700.00 77.14 192.81 2,382.11 2,261.11 -3,240.26 -906.54 5,942,134.72 557,898.55 0.00 3,240.26 4,800.00 77.14 192.81 2,404.36 2,283.36 -3,335.32 -928.16 5,942,039.50 557,877.68 0.00 3,335.32 4,900.00 77.14 192.81 2,426.61 2,305.61 -3,430.39 -949.78 5,941,944.27 557,856.81 0.00 3,430.39 5,000.00 77.14 192.81 2,448.86 2,327.86 -3,525.46 -971.40 5,941,849.05 557,835.93 0.00 3,525.46 5,100A0 77.14 192.81 2,471.11 2,350.11 -3,620.52 -993.01 5,941,753.83 557,815.06 0.00 3,620.52 5,200.00 77.14 192.81 2,493.36 2,372.36 -3,715.59 -1,014.63 5,941,658.60 557,794.19 0.00 3,715.59 5,300.00 77.14 192.81 2,515.61 2,394.61 -3,810.66 -1,036.25 5,941,563.38 557,773.32 0.00 3,810.66 5,400.00 77.14 192.81 2,537.85 2,416.85 -3,905.72 -1,057.87 5,941,468.16 557,752:44 0.00 3,905.72 5,500.00 77.14 192.81 2,560.10 2,439.10 -4,000.79 -1,079.48 5,941,372.93 557,731.57 0.00 4,000.79 5,600.00 77.14 192.81 2,582.35 2,461.35 -4,095.86 -1,101.10 5,941,277.71 557,710.70 0.00 4,095.86 5,700.00 77.14 192.81 2,604.60 2,483.60 -4,190.92 -1,122.72 5,941,182.49 557,689.83 0.00 4,190.92 5,800.00 77.14 192.81 2,626.85 2,505.85 -4,285.99 -1,144.34 5,941,087.26 557,668.95 0.00 4,285.99 5,900.00 77.14 192.81 2,649.10 2,528.10 -4,381.06 -1,165.95 5,940,992.04 557,648.08 0.00 4,381.06 6,000.00 77.14 192.81 2,671.35 2,550.35 -4,476.12 -1,187.57 5,940,896.82 557,627.21 0.00 4,476.12 6,100.00 77.14 192.81 2,693.60 2,572.60 -4,571.19 -1,209.19 5,940,801.59 557,606.33 0.00 4,571.19 6,200.00 77.14 192.81 2,715.84 2,594.84 -4,666.26 -1,230.80 5,940,706.37 557,585.46 0.00 4,666.26 6,300.00 77.14 192.81 2,738.09 2,617.09 -4,761.32 -1,252.42 5,940,611.15 557,564.59 0.00. 4,761.32 6,400.00 77.14 192.81 2,760.34 2,639.34 -4,856.39 -1,274.04 5,940,515.92 557,543.72 0.00 4,856.39 6,500.00 77.14 192.81 2,782.59 2,661.59 -4,951.46 -1,295.66 5,940,420.70 .557,522.84 0.00 4,951.46 6,600.00 77.14 192.81 2,804.84 2,683.84 -5,046.52 -1,317.27 5,940,325.48 557,501.97 0.00 5,046.52 6,672.64 77.14 192.81 2,821.00 2,700.00 -5,115.58 -1,332.98 5,940,256.31 557,486.81 0.00 5,115.58 Ugnu C 6,700.00 77.14 192.81 2,827.09 2,706.09 -5,141.59 -1,338.89 5,940,230.25 557,481.10 0.00 5,141.59 6,800.00 77.14 192.81 2,849.34 2,728.34 -5,236.66 -1,360.51 5,940,135.03 557,460.23 0.00. 5,236.66 6,900.00 77.14 192.81 2,871.59 2,750.59 -5,331.72 -1,382.13 5,940,039.81 557,439.35 0.00 5,331.72 7,000.00 77.14 192.81 2,893.83 2,772.83 -5,426.79 -1,403.74 5,939,944.58 557,41$.48 0.00 5,426.79 9/13/2006 1:15:21PM Page 5 of 11 .COMPASS 2003.11 Build 50 ORIGINAL • • onocoPhiiii Alaska Database: Company: Project: Site: Well: Wellbore: Design: _EDM_ 2003.11_b48 ConocoPhillips Alaska, Inc. I<uparuk River Unit Kuparuk 1J Pad Plan 1J-182 1 J-182 1J-182 (wp11) Halliburton Energy Services Planning Report -Geographic rm¢t~° Grilling and t=armation EY®iuatiar, Local Co-ordinate Reference: Well Plan 1J-182 -Slot 1J-182 TVD Reference: ', Plan RKB @ 121.OOft (Doyon 15 (40+81)) MD Reference: ' Plan RKB @ 121.OOft (Doyon 15 (40+81 )) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey ~ 112._ X 11) Map Map MD Inclination Azimuth TVD SSTV^ +N(-5 +E/-W Northing Fasting DLSEV Ver[ Section (ft) (') ~~) (ft) (ft) (ftl (ft) (ft) Ift) (°/100ftj (ftl 7,100.00 77.14 192.81 2,916.08 2,795.08 -5,521.86 -1,425.36 5,939,849.36 557,397.61 0.00. 5,521.86 7,200.00 77.14 192.81 2,938.33 2,817.33 -5,616.92 -1,446.98 5,939,754.14 557,376.73 0.00 5,616.92 7,300.00 77.14 192.81 2,960.58 2,839.58 -5,711.99 -1,468.60 5,939,658.91 557,355.86 0.00 5,711.99 7,400.00 77.14 192.81 2,982.83 2,861.83 -5,807.06 ,1,490.21 5,939,563.69 557,334.99' 0.00 5,807.06 7,472.68 77.14 192.81 2,999.00 2,878.00 -5,876.16 -1,505.93 5,939,494.48 557,319.82. 0.00 5,876.16 Ugnu B 7,500.00 77.14 192.81 3,005.08 2,884.08 -5,902.13 -1,511.83 5,939,468.47 557,314.12 0.00 5,902.13 7,600.00 77.14 192.81 3,027.33 2,906.33 -5,997.19 -1,533.45 5,939,373.24 557,293.24. 0.00 5,997.19 7,700.00 77.14 192.81 3,049.58 2,928.58 -6,092.26 -1,555.07 5,939,278.02 557,272.37 0.00 6,092.26 7,764.83 77.14 192.81 3,064.00 2,943.00 -6,153.89 -1,569.08 5,939,216.28 557,258.84 0.00 6,153.89 Ugnu A 7,800.00 77.14 192.81 3,071.82 2,950.82 -6,187.33 -1,576.68 5,939,182.79 557,251.50 0.00 6,187.33 7,900.00 77.14 192.81 3,094.07 2,973.07 -6,282.39 -1,598.30 5,939,087.57 557,230.63 0.00 6,282.39 8,000.00 77.14 192.81 3,116.32 2,995.32 -6,377.46 -1,619.92 5,938,992.35 557,209.75.. 0.00 6,377.46 8,100.00 77.14 192.81 3,138.57 3,017.57 '~ -6,472.53 -1,641.54 5,938,897.12 557,188.88 0.00 6,472.53 8,200.00 77.14 192.81 3,160.82 3,039.82 -6,567.59 -1,663.15 5,938,801.90 557,168.01 0.00 6,567.59 8,300.00 77.14 192.81 3,183.07 3,062.07 -6,662.66 -1,684.77 5,938,706.68 557,147.14 0.00 6,662.66 8,400.00 77.14 192.81 3,205.32 3,084.32 -6,757.73 -1,706.39 5,938,611.45 557,126.26 0.00 6,757.73 8,443.52 77.14 192.81 3,215.00 3,094.00 -6,799.10 -1,715.80 5,938,570.01 557,117.18 0.00 6,799.10 K13 8,500.00 77.14 192.81 3,227.56 3,106.56 -6,852.79 -1,728.01 5,938,516.23 557,105.39 0.00 6,852.79 8,600.00 77.14 192.81 3,249.81 3,128.81 -6,947.86 -1,749.62 5,938,421.01 557,084.52 0.00 6,947.86 8,636.12 77.14 192.81 3,257.85 3,136.85 -6,982.19 -1,757.43 5,938,386.62 557,076.98 0.00 6,982.19 Continue Buil d /Turn @ 3/100ft , 8636ft MD, 3258ft ND 8,700.00 77.54 190.89 3,271.85 3,150.85 -7,043.19 -1,770.23 5,938,325.52 557,064.66 3.00 7,043.19 8,800.00 78.19 187.89 3,292.88 3,171.88 -7,139.64 -1,786.18 5,938,228.97 557,049.47 3.00 7,139.64 8,900.00 78.86 184.91 3,312.77 3,191.77 -7,237.01 -1,797.10 5,938,131.52 557,039.31 3.00 7,237.01 9,000.00 79.57 181.94 3,331.49 3,210.49 -7,335.06 -1,802.96 5,938,033.44 557,034.21 3.00 7,335.06 9,058.91 80.00 180.20 3,341.94 3,220.94 -7,393.03 -1,804.05 5,937,975.47 557,033.58 3.00 7,393.03 Sail @ 80°Inc & 180.20°Azi : 9059ft MD, 3342ft ND 9,100.00 80.00 ,180.20 3,349.07 3,228.07 -7,433.49 -1,804.19 5,937,935.01 557,033.75 0.00 7,433.49 9,105.36 80.00 180.20 3,350.00 3,229.00 -7,438.77 -1,804.21 5,937,929.74 557,033.77 0.00 7,438.77 WSAK D 9,158.91 80.00 180.20 3,359.30 3,238.30 -7,491.51 -1,804.39 5,937,877.00 557,034.00 0.00 7,491.51 1J-182 T1 (D-Sand Top) (wp11) 9,200.00 81.23 180.20 3,366.00 3,245.00 -7,532.04 -'1,804.53 5,937,836.47 557,034.17 3.00 7,532.04 9,300.00 84.23 180.20 3,378.65 3,257.65 -7,631.23 -1,804.88 5,937,737.29 557,034.60 3.00 7,631.23 9,325.58 85.00 180.20 3,381.05 3,260.05 -7,656.70 -1,804.97 5,937,711.83 557,034.71 3.00 7,656.70 Continue Buil d @ 3°/100ft , 9326ft MD , 3381ft TVD 9,400.00 85.00 180.20 3,387.53 3,266.53 -7,730.83 -1,805.23 5,937,637.70 557,035.03 0.00 7,730.83 9,500.00 85.00 180.20 3,396.25 3,275.25 -7,830.45 -1,805.57 5,937,538.09 .557,035.46 0.00 7,830.45 9,508.61 85.00 180.20 3,397.00 3,276.00 -7,839.03 -1,805.60 5,937,529.51 557,035.50 0.00 7,839.03 WSAK C 9,600.00 85.00 180.20 3,404.96 3,283.96 -7,930.07 -1,805.92 5,937,438.48 557,035.89 0.00 7,930.07 9/13/2006 1:15:21PM Page 6 of 11 COMPASS 2003.11 Build 50 i 1 ~ • CO ~llll! S Alaska Halliburton Energy Services Planning Report -Geographic t>~~~.'R~ra Drilling and Formation Evacuation Database: _EDM 2003.11_b48 Local Go-ordinate Reference: =ell Plan 1J-182-Slot 1J-182 1 Company: Cono coPhillips Alas ka, Inc. ND Reference: L'!an RKB @ 121.OOft (Doyon 1 5 (40+81 )) Project: Kuparuk River Unit MD Reference: Plan RKB @ 121.OOft (Doyon 1 5 (40+g1 )) Site: Kuparuk 1J Pad North Reterenc e: flue Well: Plan 1J-182 Survey Calculation Method: P,linimum Curvature Wellbore: 1.1.182 Design: ~J-1 5~ r~.~11) Planned Survey 11-182 (~ I 1 1) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +Ei-W Northing Fasting DLSEV Vert Section (tt) (~') ~-) (ft) (fq (ft) (ft) (ft) (ft) j'./100ft) (ftl 9,700.00 85.00 180.20 3,413.68 3,292.68 -8,029.69 -1,806.27 5,937,338.87 557,036.32 0.00 8,029.69 9,766.78 85.00 180.20 3,419.50 3,298.50 -8,096.21 -1,806.50 5,937,272.35 557,036.61 0.00 8,096.21 9 5/8" Casing @ 9767ft MD, 3420ft TVD -1247' FNL & 1032' FWL - Sec 11-T10N-R10E - WSAK B - 9 518" 9,800.00 85.00 180.20 3,422.40 $,301.40 -8,129.31 -1,806.62 5,937,239.26 557,036.75 0.00. 8,129.31 9,898.72 85.00 180.20 3,431.00 3,310.00 -8,227.65 -1,806.96 5,937,140.93 557,037.18 0.00 8,227.65 1J-182 DD Pol y @ 95% (wp11) 9,899.98 85.00 180.20 3,431.11 3,310.11 -8,228.91 -1,806.96 5,937,139.67 557,037.18 0.00 8,228.91 Continue Buil d @ 3°/100ft , 9900ft MD, 3431ft TVD - Geosteer in B-Sand - 1J-182 T2 (wp11) 10,000.00 88.00 180.15 3,437.22 3,316.22 -8,328.73 -1,807.27 5,937,039.86 557,037.66. 3.00 8,328.73 10,090.92 90.73 180.10 3,438.22 3,317.22 -8,419.63 -1,807.47 5,936,948:97 557,038.17 3.00 8,419.63 10,100.00 90.73 180.10 3,438.11 .3,317.11 -8,428.71 -1,807.49 5,936,939.89 557,038.22 0.00 8,428.71 10,200.00 90.73 180.10 3,436.84 3,315.84 -8,528.70 -1,807.67 5,936,839.91 557,038.82 0.00 8,528.70 10,300.00 90.73 180.10 3,435.57 3,314.57 -8,628.70 -1,807.85 5,936,739.93 557,039.42 0.00 8,628.70 10,400.00 90.73 180.10 3,434.30 3,313.30 -8,728.69 -1,808.03 5,936,639.95 557,040.02 0.00. 8,728.69 10,500.00 90.73 180.10 3,433.03 3,312.03 -8,828.68 -1,808.21 5,936,539.97 557,040.62 0.00 8,828.68 10,600.00 90.73 180.10 3,431.76 3,310.76 -8,928.67 -1,808.39 5,936,439.99 557,041.22 0.00 8,928.67 10,700.00 90.73 180.10 3,430.49 3,309.49 -9,028.66 -1,808.57 5,936,340.01 557,041.82 0.00 9,028.66 10,800.00 90.73 180.10 3,429.22 3,308.22 -9,128.66 -1,808.75 5,936,240.03 557,042.42 0.00 9,128.66 10,882.11 90.73 180.10 3,428.18 3,307.18 -9,210.75 -1,808.90 5,936,157.94 557,042.91 0.00 9;210.75 10,900.08 91.07 180.20 3,427.90 3,306.90 -9,228.73 -1,808.95 5,936,139.97 557,043.00 2.00 9,228.73 1J-182 T3 (wp 11) 11,000.00 91.07 180.20 3,426.03 3,305.03 -9,328.63 -1,809.30 5,936,040.07 557,043.43 0.00 9,328.63 11,100.00 91.07 180.20 3,424.15 3,303.15 -9,428.61 -1,809.65 5,935,940.10 557,043.86. 0.00 9,428.61 11,200.00 91.07 180.20 3,422.28 3,301.28 -9,528.59 -1,810.00 5,935,840.13 557,044.29 0.00 9,528.59 11,300.00 91.07 180.20 3,420.41 3,299.41 -9,628.57 -1,810.36 5,935,740.16 557,044.72 0.00 9,628.57 11,400.00 91.07 180.20 3,418.53 3,297.53 -9,728.56 -1,810.71 5,935,640.19 557,045.14 0.00 9,728.56 11,500.00 91.07 180.20 3,416.66 .3,295.66 -9,828.54 -1,811.06 5,935,540.27 557,045.57 0.00 9,828.54 11,600.00 91.07 180.20 3,414.79 3,293.79 -9,928.52 -1,811.41 5,935,440.24 557,046.00 0.00 9,928.52 11,700.00 91.07 180.20 3,412.91 3,291.91 -10,028.50 -1,811.76 5,935,340.27 557,046.43 0.00 10,028.50 11,800.00 91.07 180.20 3,411.04 3,290.04 -10,128.48 -1,812.11 5,935,240.30 557,046.86 0.00 10,128.48 11,900.00 91.07 180.20 3,409.17 3,288.17 -10,228.46 -1,812.47 5,935,140.33 557,047.29 0.00 10,228.46 12,000.00. 91.07 180.20 3,407.29 3,286.29 -10,328.45 -1,812.82 5,935,040.35 557,047.72 0.00 10,328:45 12,100.00 91.07 180.20 3,405.42 3,284.42 -10,428.43 -1,813.17 5,934,940.38 557,048.15. 0.00 10,428.43 12,200.00 91.07 180.20. 3,403.54 3,282.54 -10,528.41 -1,813.52 5,934,840.41 557,048.57 0.00 10,528.41. 12,300.00 91.07 180.20 3,401.67 3,280.67 -10,628.39 -1,813.87 5,934,740.44 557,049.00 0.00 10,628.39 12,400.00 91.07 180.20 3,399.80 3,278.80 -10,728.37 -1,814.22 5,934,640.47 557,049.43 0.00 10,728.37 12,500.00 91.07 180.20 3,397.92 3,276.92 -10,828.36 -1,814.58 5,934,540.50 557,049.86 0.00 10,828.36 - 12,600.00 91.07 180.20 3,396.05 3,275.05 -10,928.34 -1,814.93 5,934,440.52 557,050.29 0.00 10,928.34 12,700.00 91.07 180.20 3,394.18 3,273.18 -11,028.32 -1,815.28 5,934,340.55 557,050.72 0.00 11,028.32 12,800.00 91.07 180.20 3,392.30 3,271.30. -11,128.30 -1,815.63 5,934,240.58 557,051.15 0.00 11,128.30 12,900.00 91.07 180.20 3,390.43 3,269.43 -11,228.28 -1,815.98 5,934,140.61 557,051.58 0.00 11,228.28 12,987.71 91.07 180.20 3,388.79 3,267.79 -11,315.97 -1,816.29 5,934,052.92 557,051.95 0.00 11,315.97 12,999.68 90.72 180.24 3,388.60 3,267.60 -11,327.95 -1,816.34 5,934,040.95 557,052.00 2.98 11,327.95 1J-182 T4 (wp 11) 13,000.00 90.72 180.24 3,388.60 3,267.60 -11,328.27 -1,816.34 5,934,040.63 557,052.00 0.00 11,328.27 13,100.00 90.72 180.24 3,387.34 3,266.34 -11,428.26 -1,816.75 5,933,940.65 557,052.36 0.00 11,428.26 9/13/2006 1:15:21PM Page 7 of 11 COMPASS 2003.11 Build 50 ORIGINAL • C c hiili s Alaska Dat rbase: EDM 2003.11 b48 Company- ~onocoPhillips Alaska, Inc. Protect Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-182 Wellbore: 1J-182 Design: 1J-182 (wp11) Planned Survey Halliburton Energy Services Planning Report -Geographic Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: E~° Grilling and Fvrmativn Eveluativn Well Plan 1J-182 Slot 1J 182 Plan RKB @ 121 OOft (Doyon 15 (40+81)) Plan RKB @ 121.OOft (Doyon 15 (40+81)) True Minimum Curvature Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Fasting DLSEV Vert Section (ft) (') (°) (ft) (ft) (ft) (ft) (ft) (ft) (°l100fU (ft) 13,200.00 90.72 180.24 3,386,09 3,265.09 -11,528.25 -1,817.17 5,933,840.67 557,052.73 0.00 11,528.25 13,300.00 90.72 180.24 3,384.83 3,263.83 -11,628.24 -1,817.59 5,933,740.69 557,053.09 0.00 11,628.24 13,400.00 90.72 180.24 3,383.58 3,262.58 -11,728.23 -1,818.00 5,933,640.71 557,053.46 0.00 11,728.23 13,500.00 90.72 180.24 3,382.32 3,261.32 -11,828.22 -1,818.42 5,933,540.73 557,053.82 0.00 11,828.22 13,600.00 90.72 180.24 3,381.07 3,260.07 -11,928.21 -1,818.84 5,933,440.74 557,054.18 0.00 11,928.21 13,700.00 90.72 180.24 3,379.81 3,258.81 -12,028.20 -1,819.26 5,933,340.76 557,054.55 0.00 12,028.20 13,800.00 90.72 180.24 3,378.55 3,257.55 -12,128.20 -1,819.67 5,933,240.78 557,054.91 0.00 12,128.20 13,900.00 90.72 180.24 3,377.30 3,256.30 -12,228.19 -1,820.09 5,933,140.80 557,055.27 0.00 12,228.19 14,000.00 90.72 180.24 3,376.04 3,255.04 -12,328.18 -1,820.51 5,933,040.82 557,055.64 0.00 12,328.18 14,100.00 90.72 180.24 3,374.79 3,253.79 -12,428.17 -1,820.92 5,932,940.83 557,056.00 0.00 12,428.17 14,200.00 90.72 180.24 3,373.53 3,252.53 -12,528.16 -1,821.34 5,932,840.85 557,056.37 0.00 12,528.16 14,300.00 90.72 180.24 3,372.28 3,251.28 -12,628.15 -1,821.76 5,932,740.87 557,056.73 0.00 12,628.15 14,361.21 90.72 180.24 3,371.51 3,250.51 -12,689.36. -1,822.01 5,932,679.67 557,056.95 0.00 12,689.36 14,372.88 90.37 180.18 3,371.40 3,250.40 -12,701.03 -1,822.05 5,932,668.00 557,057.00 3.00 12,701.03 1J-182 T5 (wp11) 14,373.24 90.37 180.18 3,371.40 3,250.40 -12,701.39 -1,822.06 5,932,667.64 557,057.00 3.00 12,701.39 14,400.00 90.37 180.18 3,371.23 3,250.23 -12,728.14 -1,822.14 5,932,640.89 557,057.12 0.00 12,728.14 14,500.00 90.37 180.18 3,370.59 3,249.59 -12,828.14 -1,822.46 5,932,540.90 557,057.59 0.00 12,828.14 14,600.00 90.37 180.18 3,369.95 3,248.95 -12,928.14 -1,822.78 5,932,440.91 557,058.05 0.00 12,928.14 14,700.00 90.37 180.18 3,369.32 3,248.32 -13,028.14 -1,823.10 5,932,340.93 557,058.51 0.00 13,028.14 14,800.00 90.37 180.18 3,368.68 3,247.68 -13,128.13 -1,823.42 5,932,240.94 557,058.97 0.00 13,128.13 14,900.00 90.37 180.18 3,368.04 3,247.04 -13,228.13 -1,823.74 5,932,140.95 557,059.43 0.00 13,228.13 15,000.00 90.37 180.18 3,367.40 3,246.40 -13,328.13 -1,824.06 5,932,040.96 557,059.89 0.00 13,328.13 15,100.00 90.37 180.18 3,366.77 3,245.77 -13,428.13 -1,824.38 5,931,940.98 557,060.35 0.00 13,428.13 15,200.00 90.37 180.18 3,366.13 3,245.13 -13,528.12 -1,824.70 5,931;840.99 557,060.81 0.00 13,528.12 15,300.00 90.37 180.18 3,365.49 3,244.49 -13,628.12 -1,825.02 5,931,741.00 557,061.27 0.00 13,628.12 15,400.00 90.37 180.18 3,364.85 3,243.85 -13,728.12 -1,825.34 5,931,641.01 557,061.73 0.00 13,728.12 15,500.00 90.37 180.18 3,364.22 3,243.22. -13,828.12 -1,825.66 5,931,541.03 557,062.19 0.00 13,828.12 15,600.00 90.37 180.18 3,363.58 3,242.58 -13,928.11 -1,825.98 5,931,441.04 557,062.65 0.00 13,928.11 15,700.00 90.37 180.18 3,362.94 3,241.94 -14,028.11 -1,826.30 5,931,341.05 557,063.11 0.00 14,028.11 15,800.00 90.37 180.18 3,362.31 3,241.31 -14,128.11 -1,826.62 5,931,241.06 557,063.57 0.00 14,128.11 15,900.00 90.37 180.18 3,361.67 3,240.67 -14,228.11 -1,826.94 5,931,141.08 557,064.03. 0.00 14,228.11 16,000.00 90.37 180.18 3,361.03 3,240.03 -14,328.10 -1,827.26 5,931,041.09 557,064.49 0.00 14,328.10. 16,100.00 90.37 180.18 3,360.39 3,239.39 -14,428.10 -1,827.58 5,930,941.10 557,064.95 0.00 14,428.10. 16,200.00 90.37 180.18 3,359.76 3,238.76 -14,528.10 -1,827.90 5,930,841.12 557,065.41 0.00 14,528.10 16,300.00 90.37 180.18 3,359.12 3,238.12 -14,628.10 -1,828.22 5,930,741.13 557,065.88 0.00 14,628.10 16,400.00 90.37 180.18 3,358.48 3,237.48 -14,728.09 -1,828.54 5,930,641.14 557,066.34 0.00 14,728.09 16,461.09 90.37 180.18 3,358.09 3,237.09 -14,789.19 -1,828.74 5,930,580.05 557,066.62 0.00 14,789.19 16,500.00 91.37 179.59 3,357.50 3,236.50 -14,828.09 -1,828.66 5,930,541.16 557,067.00 3.00 14,828.09 16,500.17 91.37 179.59 3,357.50 3,236.50 -14,828.26 -1,828.66 5,930,540.99 557,067.00 2.70 14,828.26 1J-182 T6 (wp11) 16,600.00 91.37 179.59 3,355.11 3,234.11 -14,928.06 -1,827.94 5,930,441.21_ 557,068.50 0.00 14,928.06 16,700.00 91.37 179.59 3,352.71 3,231.71 -15,028.02 -1,827.22 5,930,341.26 557,070.00 0.00 15,028.02 16,800.00 91.37 179.59 3,350.31 3,229.31 -15,127.99 -1,826.50 5,930,241.31 557,071.50 0.00 15,127.99 16,897.54 91.37 179.59 3,347.97 3,226.97 -15,225.50 -1,825.80 5,930,143.82 557,072.96 0.00 15,225.50 16,900.00 91.45 179.61 3,347.91 3,226.91 -15,227.96 -1,825.78 5,930,141.36 557,072.99 3.00 15,227.96 9/13/2006 1:15:21PM Page 8 of 11 COMPASS 2003.11 Build 50 ORIGINAL II Halliburton Energy Services ttf°r I lpS Alaska Planning Report -Geographic Cr•illing and Formation Evaluation Database: EDM_2003.11_b48 Local Co-ordinate Reference: `:`,'ell Plan 1J-182 -Slot 1J-182 Company: ConocoPhilllps Alaska, Inc. ND Reference: Plan RKB @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-182 Survey Calculation Method: Minimum Curvature Wellhorr: 1J-182 Design: 1J-182 (wp11) Planned Survey 1._!-1~:'~~ ~::I:~1'~1 Map Map MD Inclination Azimuth TVD SSTVD +N/-5 +EI-W Northing Fasting DLSEV Vert Section (ft) f) C) (ft) (ft) (ft) (ft) eft) (ff) (°/100ft) (ft) 16,900.36 .91.46 179.61 3,347.90 3,226.90 -15,228.32 -1,825.78 5,930,141.00 557,073.00 3.00 15,228.32 1J-182 T7 (wp11) 17,000.00 91.46 179.61 3,345.37 3,224.37 -15,327.93 -1,825.10 5,930,041.41 557,074.46. 0.00 15,327.93 17,100.00 91.46 179.61 3,342.83 3,221.83 -15,427.89 -1,824.42 5,929,941.46 557,075.92 0.00 15,427.89 17,200.00 91.46 179.61 3,340.29 3,219.29 -15,527.86 -1,823.74 5,929,841.52 557,077.38 0.00 15,527.86 17,300.00 91.46 179.61 3,337.75 3,216.75 -15,627.82 -1,823.06 5,929,741.57 557,078.84 0.00 15,627.82 17,400.00 91.46 179.61 3,335.20 3,214.20 -15,727.79 -1,822.38 5,929,641.62 557,080.30 0.00 15,727.79 17,500.00 91.46 179.61 3,332.66 3,211.66 -15,827.75 -1,821.69 5,929,541.67 557,081.76 0.00 15,827.75 17,600.00 91.46 179.61 3,330.12 3,209,12 -15,927.72 -1,821.01 5,929,441.73 557,083.23 0.00 15,927.72 17,700.00 91.46 179.61 3,327.58 3,206.58 -16,027.68 -1,820.33 5,929,341.78 557,084.69 0.00 16,027.68 17,789.83 91.46 179.61 3,325.30 3,204,30 -16,117.48 -1,819.72 5,929,252.00 557,086.00. 0.00 16,117.48 BHL @ 1779 0ft MD, 3325ft TVD :1292 ' FSL & 1010' FWL -Sec 14 - T10N - R10E - 41/2" -1J-182 T8 (Toe) (wp11) , 9/13/2006 1:15:21PM Pa e 9 of 11 COMPASS 2003.11 Build 50 ~~~~ • • Philli Halliburton Energy Services ~staJ°r noco ps Planning Report -Geographic Orilltng and Formation Alaska Evaiseaticn Database: _EDM_2003.11_b48 Local Co-ordinate Reference: `i':'ell Plan 1J-182 -Slot 1J-182 Company: ConocoPhillips Alaska. Inc. ND Reference: F' an RKB @ 121. OOft (Doyon 15 (40+81 )) Project Kuparuk River Unit MD Reference: r-ian RKB @ 121. OOft (Doyon 15 (40+81 )) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-182 Survey Calculation Method: Minimum Curvatu re Wellhore: 1J-182 ^esign: 1J-182 (wp11) '~ Geologic Targets 1J-1~~~2 ~ j TVD i Fdt~rnc +N!-S +E-W Northing Easting (ft) (=trip-~ ft it (h) (ft) 3,371.40- 1J-182 T5 (wp11) -12,701.03 -1,822.05 5,932,668.00 557,057.00 - Point 3,325.30 1J-182 T8 {Toe} (wp11} -16,117.48 -1,819.72 5,929,252.00 557,086.00 - Point 3,347.90 1J-182 T7 (wp11) -15,228.32 -1,825.78 5,930,141.00. 557,073.00 -Point 3,388.60 1J-182 T4 (wp11) -11,327.90 -1,816.34 5,934,041.00 557,052.00 - Point 3,359.30 1J-182 T1 (D-Sand Top} (wp11} -7,491.51 -1,804.39 5,937,877.00 557,034.00 - Point 3,427.90 1J-182 T3 (wp11) -9,228.69 -1,808.95 5,936,140.00 557,043.00 - Point 3,357.50 1J-182 T6 (wp11} -14,828.25 -1,828.66 5,930,541.00 557,067.00 - Point 3,431.11 1J-182 T2 (wp11) -8,228.91 -1,806.96 5,937,139.67 557,037.19 - Point 3,431.00 1J-182 DD Poly @ 95% {wp1i} -8,228.91 -1,806.96 5,937,139:67 557,037.19 - Polygon Point 1 0.00 0.00 5,937,441.04 557,036.41 Point 2 0.39 -50.00 5,937,441.04 556,986.41 Point 3 -19.53 -50.05 5,937,421.12 556,986.52 Point 4 -216.40 -50.55 5,937,224.27 556,987.56 Points -1,300.71 -53.57 5,936,140.08 556,993.00 Point6 -1,300.79 -53.57 5,936,140.00 556,993.00 Point 7 -1,303.33 -53.58 5,936,137.46 556,993.01 Point 8 -3,399.99 -60.96 5,934,041.00 557,002.00 Point 9 -3,410.23 -61.00 5,934,030.77 557,002.04 Point 10 -4,773.12 -66.67 5,932,668.00 557,007.00 Point 11 -4,782.43 -66.71 5,932,658.69 557,007.04 Point 12 -6,900.34 -73.28 5,930,541.00 557,017.00 Point 13 -6,946.46 -73.17 5,930,494.89 557,017.47 Point 14 -7,300.41 -70.40 5,930,141.00 557,023.00 Point 15 -7,303.85 -70.38 5,930,137.56 557,023.05 Point 16 -8,189.57 -64.34 5,929,252.00 557,036.00 Point 17 -8,190.35 35.67 5,929,252.00 557,136.00 Point 18 -7,304.64 29.63 5,930,137.56 557,123.05 Point 19 -7,301.19 29.61 5,930,141.00 557,123.00 Point 20 -6,947.24 26.84 5,930,494.89 557,117.47 Point 2l -6,901.12 26.73 5,930,541.00 557,117.00 Point 22 -4,783.22 33.30 5,932,658.69 557,107.04 Point 23 -4,773.90 33.33 5,932,668.00 557,107.00 Point 24 -3,411.01 39.01 5,934,030.77 557,102.04 Point 25 -3,400.78 39.05 5,934,041.00 557,102.00 Point 26 -1,304.11 46.43 5,936,137.46 557,093.01 Point 27 -1,301.57 46.44 5,936,140.00 557,093.00 Point 28 -1,301.49 46.44 5,936,140.08 557,093.00 Point 29 -217.18 49.46 5,937,224.27 557,087.56 Point 30 -20.31 49.96 5,937,421.12 557,086.52 Point 31 -0.39 50.00 5.937.441.04 557.086.41 9/13/2006 1:15:21 PM Page 10 of 11 ~GINAL COMPASS 2003.11 Build 50 • ~ Con coPiiiips Alaska Azimuth 205.00 202.03 192.81 192.81 192.81 192.81 192.81 192.81 180.20 180.20 180.20 Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-182 -Slot 1J-182 Company: ConocoPhillips Alaska, Inc. TVD Reference: P'an RKB @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: F"an RKB @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: true Well: Plan 1J-182 Survey Calculation Method: Minimum Curvature Wellbore: 1J-182 Design: 1J-182 (wp11) L- - - Prognosed Casing Points Measured Depth (ft) 3,670.22 9,766.78 17,789.82 Prognosed Formation Intersection Points Measured Depth Inclination (ft) (°) 1,702.82 47.14 1,850.54 52.76 2,771.29 77.14 3,670.22 77.14 6,672.64 77.14 7,472.68 77.14 7,764.83 77.14 8,443.52 77.14 9,105.36 80.00 9,508.61 85.00 9,766.78 85.00 Plan Annotations Measured Depth (ft) 40.00 300.00 702.06 1,629.31 1,729.31 2,365.33 3,670.22 8,636.12 9,058.91 9,325.58 9,766.78 9,899.98 17,789.82 Vertical Depth (ft) 2,153.00 3,419.50 3,325.30 Verfical Depth (ft) 1,550.00 1,646.00 1,953.00 2,153.00 2,821.00 2,999.00 3,064.00 3,215.00 3,350.00 3,397.00 3,419.50 Halliburton Energy Services Planning Report -Geographic Casing Hole Diameter (") Diameter (~~) 13-3/8 16 9-5/8 12-1/4 4-1/2 6-3/4 +N!-E (ft) -475.97 -578.65 -1,406.70 -2,261.28 -5,115.58 -5,876.16 -6,153.89 -6,799.10 -7,438.77 -7,839.03 -8,096.22 +El-W (ft) -221.95 -267.07 -489.61 -683.93 -1,332.98 -1,505.93 -1,569.08 -1,715.80 -1,804.21 -1,805.60 -1,806.50 R~iL.i~EtJ7` Grilling and Formation Evaluation Base Perm T3 K15 T3+550 Ugnu C Ugnu B Ugnu A K13 WSAK D WSAK C WSAK B Vertical Local Coordinates Depth +N;-S +E/-W Comment (ft) (ft) ift) 40.00 0,00 0.00 SHL @ 1570' FSL & 2434' FEL -Sec 35 - T11 N - R10E 300.00 0,00 0.00 KOP @ 300ft MD, 300ft TVD -Build @ 2.5°/100ft 700.00 -31.88 -14.87 Continue Build @ 4°/100ft , 702ft MD, 700ft TVD 1,500.00 -427.13 -199.17 Sail @ 47° Inc : 1629ft MD, 1500ft TVD 1,568.02 -493.57 -230.15 Continue Build @ 5°/100ft , 1729ft MD, 1568ft TVD 1,862.68 -1,020.76 -401.85 Sail @ 77.14°Inc & 192.81 °Azi : 2365ft MD, 1863ft TVD 2,153.00 -2,261.28 -683.93 13 3/8" Casing @ 3670ft MD, 2153ft TVD - 692' FNL & 2160' FWL -Sec 2 - T10N - R10 3,257.85 -6,982.20 -1,757.43 Continue Build /Turn @ 3/100ft , 8636ft MD, 3258ft TVD 3,341.93 -7,393.02 -1,804.05 Sail @ 80°Inc & 180.20°Azi : 9059ft MD, 3342ft TVD 3,381.05 -7,656.70 -1,804.97 Continue Build @ 3°/100ft , 9326ft MD, 3381ft TVD 3,419.50 -8,096.21 -1,806.50 9 5/8" Casing @ 9767ft MD, 3420ft TVD -1247' FNL & 1032' FWL -Sec 11-T10N-R10E 3,431.11 -8,228.91 -1,806.96 Continue Build @ 3°/100ft , 9900ft MD, 3431ft TVD - Geosteer in B-Sand 3,325.30 -16,117.47 -1,819.72 BHL @ 17790ft MD, 3325ft TVD :1292' FSL & 1010' FWL -Sec 14 - T10N - R10E 9/13/2006 1:15:21PM Page 11 of 11 COMPASS 2003.118ui1d 50 RII~:~ • • 11 Alaska Plan: 1 J-182 (wp11) ri i i Anticollision Summary 14 September, 2006 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-182 1 J-182 Local Coordinate Origin: Centered on Well Plan 1J-182 -Slot 1J-182 Viewing Datum: Plan RKB @ 121.OOft (Doyon 15 (40+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet I v. .~. I ~ .~ ~w€. ~. ~.~ Sp®rry Grilling Services ORIGINAL Halliburton Company Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 9!14/2006 'time: 14:10:53 Page: ] Field: Kuparuk River Unit Reference Site: Kuparuk iJ Pad Co-ordinat e(NE) Refc rcncc: Well: Pla n 1J-182, Tr ue North Reference Nell: Plan 1J-182 Vertical (I' VD) Kcferc nce: Doyon 15 (40+81) 12 1.0 Refcrcncc Wellpath: 1J-182 Db: Oracle -__ _ ___ NO GLOBAL SCAN: Using user defined selection & scan criteria -- Reference: _ Plan: 1 J-182 (wp11) & NOT PLANNED P Interpolation Method: MD I nterval: 100.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 40.00 to 17789.83 ft Scan Method: Trav Cylinder North Maximum Radius: 1974.98 ft Erro r Surface: Ellipse + Casing Casing Points h1D fV D Diameter HoleSiae Name ft ft in in 3678.40 2154.97 13.375 9598.60 3405.42 9.625 16.000 13 3/8" 12.250 9 5/8" _- - __ _ - ~ 17789.76 3325.74 4.500 6.750 4 1 /2" Plan: 1 J-182 (wp11) Date Composed: 8/28/2006 j Version: 2 Principal: Yes Tied-to: From Well Ref. Point Summary <---------------------- Offset N'cllpath ------ ---------------> Refcrcncc Offset Ctr-Ctr Nn-Go Allowable ', Site Wcll Wellpath MD b1ll Distance Area Deriafion Warning ft ft ft ft ft Kuparuk 1J Pad 1J-127 1J-127 V4 298.70 300.00 202.81 5.68 197.13 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127L1 V1 298.70 300.00 202.81 5.55 197.26 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127L1PB1 V2 298.70 300.00 202.81 5.79 197.02 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127L2 V1 298.70 300.00 202.81 5.55 197.26 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127PB1 V1 298.70 300.00 202.81 5.79 197.02 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127PB2 V1 298.70 300.00 202.81 5.79 197.02 Pass: Major Risk Kuparuk 1J Pad 1J-133 1J-133 L1 V2 Plan: 1J- 300.00 300.00 147.44 6.63 140.81 Pass: Major Risk Kuparuk 1J Pad 1J-133 1J-133 V2 311.45 300.00 148.63 5.92 142.71 Pass: Major Risk Kuparuk 1J Pad 1J-14 1J-14 V10 719.45 700.00 108.03 9.75 98.28 Pass: Major Risk Kuparuk 1J Pad 1J-152 1J-152L1 V2 8884.71 13408.00 135.44 32.51 102.92 Pass: Minor 1/200 Kuparuk 1J Pad 1J-152 1J-152L2 V1 8606.95 13112.00 175.18 33.35 141.83 Pass: Minor 1/200 Kuparuk 1J Pad 1J-154 1J-154 V5 309.99 300.00 582.11 6.05 576.06 Pass: Major Risk Kuparuk 1J Pad 1J-154 1J-154L1 V5 309.99 300.00 582.11 5.93 576.18 Pass: Major Risk Kuparuk 1J Pad 1J-154 1J-154L2 V3 309.99 300.00 582.11 5.89 576.21 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170 V2 311.07 300.00 241.70 6.06 235.64 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170L1 V1 311.07 300.00 241.70 5.93 235.77 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170L2 V1 311.07 300.00 241.70 5.93 235.77 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170PB1 V1 311.07 300.00 241.70 6.17 235.53 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170PB2 V1 311.07 300.00 241.70 6.17 235.53 Pass: Major Risk Kuparuk 1J Pad 1J-184 1J-184 V5 1641.91 1600.00 58.07 30.71 27.36 Pass: Major Risk Kuparuk 1J Pad 1J-184 1J-184L1 V5 1641.91 1600.00 58.07 30.56 27.51 Pass: Major Risk Kuparuk 1J Pad Plan 1J-129 Plan 1J-129 V2 Plan: 1 300.00 300.00 176.64 6.63 170.01 Pass: Major Risk Kuparuk 1J Pad Plan 1J-130 Plan 1J-130 V2 Plan: 1 300.00 300.00 166.17 6.63 159:54 Pass: Major Risk Kuparuk 1J Pad Plan 1J-132 1J-132 V2 Plan: 1J-132 300.00 300.00 151.18 6.47 144.71 Pass: Major Risk Kuparuk 1J Pad Plan 1J-135 Plan 1J-135 VO 312.59 300.00 147.35 5.61 141.73 Pass: Major Risk Kuparuk 1J Pad Plan 1J-136 1J-136 L1 V1 Plan: 1J- 397.42 400.00 152.32 8.06 144.26 ~ Pass: Major Risk i Kuparuk 1J Pad Plan 1J-136 1J-136 V2 Plan: 1J-136 397.42 400.00 152.32 8.11. 144.21 Pass: Major Risk ~ Kuparuk 1J Pad Plan 1J-173 1J-73 Kuparuk Producer 300.00 300.00 179.91 5.84 174.07 Pass: Major Risk Kuparuk 1J Pad Plan 1J-174 Plan 1J-01 B Lat V0 596.22 600.00 154.56 8:80 145.75 Pass: Major Risk Kuparuk 1 J Pad Plan 1 J-176 Plan 1J-02 B Lat V0 791.38 800.00 110.90 12.32 98.58 Pass: Major Risk Kuparuk 1 J Pad Plan 1 J-178 Plan 1J-03 B Lat V0 702.31 700.00 67.28 .10.46 56.83 Pass: Major Risk Kuparuk 1J Pad Plan 1J-180 Plan 1J-180 L1 V1 Plan 890.60 900.00 43.56 13.23 30.33 Pass: Major Risk Kuparuk 1J Pad Plan 1J-180 Plan 1J-180 V2 Plan: 1 890.60 900.00 43.56 13.38 30.17 Pass: Major Risk Kuparuk 1J Pad Plan 1J-182 1J-182 L1 V5 Plan: 1J- 9100.00 9100.00 0.00 0.00 0.00 FAIL: No Errors Kuparuk 1J Pad Plan 1J-L14(BO) Plan 1J-L14(BO) VO Pla 313.20 300.00 216.91 6.69 210.22 Pass: Major Risk Kuparuk 1J Pad Plan 1J-L15(BP) Plan 1J-L15 D Lateral 313.09 300.00 203.33 . 5.93 197.40 Pass: Major Risk Kuparuk 1J Pad Plan 1J-014 (BM) 1J-014 B Lateral VO PI 312.84 300.00 167.39 5.90 .161.49 Pass: Major Risk Kuparuk 1J Pad Plan 1J-015(60) 1J-015 D Lateral VO PI 313.01 300.00 190.09 5.92 184.17 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-137 Plan: 1J-137 L1 V6 Pla 311.77 300.00 157.89 6.63 .151.26 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-137 Plan: 1J-137 V3 Plan: 311.77 300.00 157.89 6.78 151.11 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-137 Rig: 1J-137 L1 PB1 VO 409.93 400.00 160.14 10.21 149.92 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-137 Rig: 1J-137 L1 VO 409.93 400.00 160.14 10.21 149.92 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-137 Rig: 1J-137 VO 409.93 400.00 160.14 10.21 149.92 Pass: Major Risk Kuparuk 1J Pad WSP-08 WSP-O8 V2 404.53 400.00 218.68 12.09 206.59 Pass: Major Risk Kuparuk 1J Pad WSP-09 WSP-09 V1 392.52 400.00 191.84 9.03 182.82 Pass: Major Risk Kuparuk 1J Pad WSP-10 WSP-10 V1 315.24 300.00 180.60 6.93 173.66 Pass: Major Risk )GRAM OR!G!N91_ Halliburton Company Anticollision Report Company: ConocoPhiNipsAiaska Inc. Date: 9/14/2006 fimc: 14:10:53 Page: 2 Field: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Co-ordinate(NE) Refer ence: Well: Plan 1J-182, Tr ue North Reference Nell: Plan 1J-182 vertical (TVD) Refere nce: Doyon 15 (40+81) 121.0 Reference «'eJlpath: 1J-182 Db: Orade Summar~~ <------------- -------- Offset N'ellpath -------------------> Reference Offset Ctr-Ctr No-Go Allowable Site Wcll Wellpath MD MD Distance Area Der~a6on Warning ft ft ft ft ft Kuparuk 1J Pad WSP-11 WSP-11 V1 396.23 400.00 190.31 8.31 182.00 Pass: Major Risk Kuparuk 1 J Pad WSP-12 WSP-12 VO 594.92 600.00 222.11 13.07 209.04 Pass: Major Risk Kuparuk 1 J Pad WSP-13 WSP-13 V1 716.91. 700.00 251.63 13.96 237.66 Pass: Major Risk Kuparuk 1 J Pad WSP-14 WSP-14 V1 903.29 900.00 293.11 17.74 275.32. Pass: Major Risk Kuparuk River Unit N West Sak 5 West Sak 5 V5 10443.53 3500.00 983.45 334.59 648.86 Pass: Major Risk j ORIGINAL Closest to Pool 1J-182 (wp11) B-Sand ',•,/ a~ , Closes t A roach: Reference Wel l: 1J-182 w 11 Plan Offset Well: 1J -12 ~.1 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. ND E + /W - 180° Comments De th Incl. An le TRUE Azi. ND E + /W - 180° Comments POOL Min Distance POOL Min Distance (903.76 ft) in POOL (903.76 ft) in POOL (9766.7 - 17789.83 MD) (9766.7 - 17789.83 MD) to 1J-152 L1 (5747 - to 1J-182 (wp11) Plan 9Q3.76 9766.78 85 180.2 3299.025 5937272 557036.9 8096.141 13408 MD) 13408 90.87 172.05 3315.123 5938174 556998.9 7193.034 (5747 - 13408 MD) Closest A roach: Reference Well : 1J-182 w 11 Plan Offset ell: 1J -154 L1 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. An le TRUE Azi. ND E + /w _ 180° Comments Depth Incl. An le TRUE Azi. ND E + /w - 180° Comments POOL Min Distance POOL Min Distance (1472.56 ft) in POOL (1472.56 ft) in POOL (9766.7 - 17789.83 MD) (9766.7 - 17789.83 MD) to 1J-154 L1 (4347 - to 1J-182 (wp11) Plan 9472.56 i=bi""'!°' 9766.78 85 180.2 3299.025 5937272 557036.9 8096.141 11285 MD) 11285 90.53 172.41 3346.842 5938175 558199.1 7202.348 (4347-11285 MD) Closest A roach: Reference Well : 1J-182 w 11 Plan Offset ell: 1J -159 L1 Coords. - Coords. - ASP ASP 3-D ctr-ctr ' ' Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. An le TRUE Azi. ND E + NV - 180° Comments Depth Incl. An le TRUE Azi. ND E + /W _ 180° Comments POOL Min Distance POOL Min Distance (2586.82 ft) in POOL (2586.82 ft) in POOL (9766.7 - 17789.83 MD) (9766.7 - 17789.83 MD) to 1J-159 L1 (4565 - to 1J-182 (wp11) Plan 2586.82 9766.78 85 180.2 3299.025 5937272 557036.9 8096.141 11187 MD) 11187 90.12 182.99 3397.883 5938276 559418.7 7110.355 (4565-11187 MD) Closest A roach: Reference Well : 1J-182 w 11 Plan Uset Well: 1J -184 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. An le TRUE Azi. ND E + /W _ 180° Comments De th Incl. An le TRUE Azi. ND E + /W _ 180° Comments POOL Min Distance POOL Min Distance (1297.66 ft) in POOL (1297.66 ft) in POOL (9766.7 - 17789.83 MD) (9766.7 - 17789.83 MD) to 1J-184 (9275 - 17870 to 1J-182 (wp11) Plan 9297.66 9766.78 85 180.2 3299.025 5937272 557036.9 8096.141 MD) 9500 88.11 178.06 3336.502 5937324 558333 8053.542 (9275-17870 MD) Closest A roach: Reference Well : 1J-182 w 11 Plan Offset Well: 1J -188 w 02 Coords. - Coords. - ASP ASP 3-D ctrctr ' -- ~ Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) . View VS Min. Dist. Depth Incl. An le TRUE Azi. ND E + /W _ 180° Comments Depth Incl. An le TRUE Azi. ND E + /W _ 180° Comments POOL Min Distance POOL Min Distance (1113.03 ft) in POOL (1113.03 ft) in POOL j9766.7 - 17789.83 MD) (9766.7 - 17789.83 MD) to 1J-180 (wp02) (10473 to 1J-182 (wp11) Plan 9993.p3 15575 90.37 180.18 3243.232 5931465 557063.3 13903.04 - 15897.22 MD) 15897.22 89.6 178.99 3239.37 5931468 555950.3 13891.42 (10473 - 15897.22 MD) • iJ-182 [~illina Hazards ~imma (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Surface Hole Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate - Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out Intermediate Hole Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material,. stabilized BHA, decreased mud wei ht Abnormal Reservoir Low BOP training and drills, increased mud Pressure wei ht. Lost circulation Low Reduced um rates, mud rheolo ,LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo ,LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin ! ~ @ l.1 1J-182 Drilling Hazards Summary iii~~~ € _ i 9/12/2006 1:18 PM CemCADE~ Preliminary Job Design 13 3/8" Surface (V1 - wp10) Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 8/16/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263-4207 Mobile: (907) 748-6900 email: martinl3@slb.com < TOC at Surface i Previous Csg. < 20", 91.5# casing at 80' MD < Base of Permafrost at 1,703' MD (1,550' N D) < Top of Tail at 2,878' MD < 13 3/8", 68.0# casing in 16" OH '' 1 TD at 3,678' MD (2,153' ND) Mark of Schlumberger Preliminary Job Design based on limited input data. For estimate purposes only Schlumbenger Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 2,878' MD. Lead Slurrv Minimum pump time: 300 min. (pump time plus 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x (80') x 1.00 (no excess) = 81.5 ft3 0.4206 ft3/ft x (1703' - 80') x 3.50 (250% excess) = 2389.2 ft3 0.4206 ft3/ft x (2878' - 1703') x 1.35 (35% excess) = 667.2 ft3 81.5 ft3 + 2389.2 ft3+ 667.2 ft3 = 3137.9 ft3 3137.9 ft3 / 4.45 ft3/sk = 705.1 sks Round up to 710 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv Minimum pump time: 200 min. (pump time plus 120 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.4206 ft3/ft x (3678' - 2878') x 1.35 (35% excess) = 454.2 ft3 0.8407 ft3/ft x 80' (Shoe Joint) = 67.3 ft3 454.2 ft3 + 67.3 ft3 = 521.5 ft3 521.5 ft3/ 2.47 ft3/sk = 211.1 sks Round up to 220 sks BHST = 46~, Estimated BHCT = 63~. (BHST calculated using a gradient of 2.6`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbll (min) /mini CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 ASL 7.0 558.8 79.8 113.1 DeepCRETE 6.0 .92.9 15.5 128.6 Drop top plug 0.0 0.0 5.0 133.6 Water 5.0 20.0 4.0 137.6 Switch to rig 0.0 0.0 5.0 142.6 Mud 7.0 509.7 72.8 215.4 Slow & bump plug 3.0 9.0 3.0 215.8 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, TY < 15 Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 17-21, TY = 20-25 Centralizers: Recommend 2 per joint throughout tail slurry column ORIGINAL :. - i n CemCADE Preliminary Job Design 9-5/8"" intermediate Casing (V1 - wp10) Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 8/16/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263-4207 Mobile: (907) 748-6900 email: martin13C~3slb.com Previous Csg. < 13 3/8", 68.0# casing at 3,678' MD < Top of Tail at 6,226' MD < 9 5/8", 40.0# casing in 12 1 /4" OH TD at 9,599' MD (3,420' TV D) Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 3373' MD annular length. Tail Slurrv Minimum thickening time: 300 min. (Pump time plus 120 min.) DeepCRETE C«~ 12.5 ppg - 2.25 ft3/ft 0.3132 ft3/ft x 3373' x 1.25 (25% excess) = 1320.5 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 1320.5 ft3 + 34.1 ft3 = 1354.6 ft3 1354.6 ft3/ 2.25 ft3/sk = 602.0 sks Round up to 610 sks BHST = 799=, Estimated BHCT = 69~. (BHST calculated using a gradient of 2.69=/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) tminl CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW 100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 5.0 75.0 15.0 40.0 DeepCRETE 5.0 241.3 48.3 88.3 Drop top plug 0.0 0.0 5.0 93.3 Water 5.0 20.0 4.0 97.3. Switch to rig 0.0 0.0 5.0 102.3 Mud 6.0 692.8 115.5 217.8 Slow & bump plug 3.0 9.0 3.0 220.8 MUD REMOVAL Recommended Mud Properties: 8.9 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH" II, Pv ~ 19-22, TY = 22-29 Centralizers: Recommend • 2 per joint on shoe track • 1-~/z per joint until 350' and above West Sak • 1-~/z per joint across all Ugnu i',GINAL Insulated Conductor, 20" 94# K-55 x 34'+0.372 Wi +/- g0' Wellhead /Tubing/ Tree: 13-3/8" x 4.1/2", 5,000 psi t i 13.3/8" Casing Sltoe, 68#, L-80, BTC se4~d 3678' MD, 2153' TVD` Tubing String 4-1 /2" 12.8#, L-80, IBTM 3.958" ID, 3.833" Drift -..~* ~/j-a~,.f sri ~ 7" x 9~/e Model B F~'6 Hanger GLM, Camco, 4-1/2" x 1" KBMG e, G LM, Camco, 4-112" x 1"KBMG Bottom of Motor Centralizer -',~ Centralift 418 HP KMHFER with FC6000 Pump B-sand Window '89~MD,342a'TVD 'D' Sand Lateral ~4f 4.117" 17.611, BTC, .\ ~` L-80 Slottetl Linm 4-112" PayZone ECP -`„ 4.1/2" Guitle Shoe ' ~ F..-:. T'a ~~ W `-° \ 4-112" Casing Shoe, 11.8#, L-80 BTCM 4112" bent joint shoe Set @ 17789' MD, 3259' ND 5-112" Tieback Sleeve ~~'~ ; 7" X 9.58" Liner Top Packer 7" X 9-5/a" Flex La Liner Hanger) Pecker ASSembty at Liner Hanger +l-YBe9 M0 9 zsq r Casing Sealbore Recap 4.75" ID ®8aker Huehaa 2005, Thla tlocumam may not be reproduced or dintribuled, In wMla ar In part, In any form m by any means electronic or mechanical, including photoeopying, rmoNinp, or by any Information abrega erM retrbval systmn now known ar hereafter Invented, wkhoul wddan penniaslon hom eakm Hughm Inc vr~~~o Mips West Sak Hybrid Producer 1 J -182 Dual Lateral Completion S 'Ill"19d XYlilg6 Baker Oil Tools Equipment Specifications 7"" X 9-5/8" HOOK Hanger Malnbore Drill: 7.00" ~~ Malnbore Drill, with diverter: 6.25" 'B' Sand Lateral Lateral Drift, no diveRer or LEM: 8.15" Lateral Drift, wl diverter, no LEM: 5,13" LateragMainbora Diverter OD: 8.50" 41 L-80 Slotted Llner~ ~~ l/}` 4112 E ntnc / `\ , ' J( / ~ uld Shoe ~ . --.~ '.y ~""~ -~ ~~' 4-1/2" Casing Shoe, 11 , L-80 BTCM 9.5 ' Casing. Shoe,40.0#, L-80 BTC Set @ 17790' M 3325' ND MD,3420'ND ~~a`~.~ +~~'~ eg inc) \ owe rnu: o„wl„p xe.: 2006 West Sak Dual Lataml Completion • Pretluov w. September 7, 20D6 Drawn eY: Rwbbn N".: D Pape No.: fMre D. Kuck 1 ~ 1 • • ~ • SHARON K gLLSUP-DRAKE CONOCOPHILLIPS ATO f530 ANCHORgG~gK 99501 Pav ro rHE ORDER Op ST~T~ '1 / ~ / ~y r 1157 DarE ~! ~1 ~ ~~~~','~ ~" ~~1551/441 M~rganChase ~ j low ~PMorgan Chase -~ Columbus, pl..l Bank, N,q Valid Up To 50 DOLLARS 8 e;°~;n9acke= 00 Dollars MEMO 8 7 4 7 ~!- ___-- ~' ~ i907q 1 15 7 -------_--- ~' • • TRANSMITTAI. LETTEIa C'gIECKLIST WELL NAME PTD# Development Service Exploratory Stratigraphic Vest Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-ONS WHAT ~ (OPTIONS) APPLIES ~ TEXT FOR APPROVAL LETTER MULTI LATERAL i The permit is for a new wellbore segment of existing ~ well ((If last two digits in ~ j API number are ;Permit No. ,API No. 50- - - . ~ j' between 60-69) 'Production should continue to be reported as a function of the ;original API number stated above. ;' PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs j ~ ~ ac uired for the ilot hole must ~ q p be clearly differentiated in both , ~ i well name ( PH) and API number (~0- - -_} from records, data and logs I ~ j ~ acquired for well SPACING !EXCEPTION I ,' ~ ~ The permit is approved subject to full compliance with 20 AAC ~ 25.0». Approval to perforate and roduce / in'ect is contingent !upon issuance of a conservation order approving a spacing exception. assumes the ~ liability of any protest to the spacing exception that may occur. DRY DITCH j All dry ditch sample sets submitted to the Commission must be in i i SAMPLE I no greater than 30' sample intervals from below the permafrost or ~ ~ from where samples are first caught and 10' sample intervals through target zones. i ~ Non-Conventional Please note the following special condition of this permit: i ~ production or production testing of coal bed methane is not allowed Well for (name of well) until after (Companv Name) has designed and j implemented a water well testing program to provide baseline data ~ ; on water quality and quantity. (Company Name) must contact the ~ i I Commission to obtain advance approval of such water well testing Rev: 1 12506 C:~jody\transmittal checklist ~ • ^^ ~ N ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ rn o m o- ~ ~ ~ N N , ~ ~ ~ N O ~ ~ ~ ~ ~ ~ o 3 Q . . _ ~ ~ o, M' c. , a. 3' w, c ~ , a o, ~ ~ p O p' _, ~ ~, g ~, ~ ~ ~ ~' ~ ~, ~ a; ai, ~ m a m, 3 ~ O ~ ~ ~ s ~ >' ;~ ~ c c d, N, o i o ~ ~~ ~ o. ~, n m' r ca. .o m m O cNO, ~ ~ ~ i i ~ n o ~ ~ 'o~ ~ ~ o N, O a. ~ ~ ~ ~ ~ ° N r n o d o, °~, c ~, o, ~ N (~, ~, ~ ~ ~ . ~ o. c. m p. ~, ~ a ~ a 3 ai, ~, N ~, m m ° ¢, . a, °~ ~ c o c. ~ ~ y t , .a c. X `, ~ ~ Q. ~, c. m; a, , ~, w 3, o o, a 4 ~ a ~ m. _, m ~~ T ~ 'a ~ a a m, ~ ~ a m rn , ~ , a i ~ ~ 3 Y ~ ~ ~ a~ 3. ~ a v; Z ~ ~ ~ , a Y' 3 ~ n ~ ~ > > O '. . V'~ ~~ y, ~ ~ ~ ~ ~ ~ ~ ~ d, ~ ~~ ~ N, ~ ~, > ~ N pr ~ N ~ ~~ L L6 ~ ~ p O ~ ~ , ~ C' O, y, m. a °~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~, ¢, ~ ~ ~ O ~ ~, ~ ~ 4 . Y. ~ p~ ~ ~ , O~ , , c, n °~ a~ te- ~ ~ o, c, d, a ° , a ~ ~, ~, ~ M a ~ co ° v i a , Y N. - O' ~ i; m. ~ U ', ~, ~, .a ~, m. 4 ~, ao' _ • ~ O. . ~ Y. ~~ y, `~ ~ ~ ~ ~ ~ ~ O, O, n ~ ~, ~, ~ ~ O~ ~ a, N j. y, N F- 00 N~ ~~ C, ~ ~ ~ yN y. ~ t. n ~ ~ y. N, -~~ m c, ~ >~~ ~~~ EM. p ~ ~ ~ ~ ~ ~ ~ ~, ~, ~ ~ 3, '~~ ~ ~ ~, N, N. N' a~ ~p, a0 ' v ' ~ ~, i c ai o o ~ ~ ? a~ ~ d w Qy ' ' ~, m. , y. n n ~, m' ~, m. ~ ~' ~ v ~ ar _ ~, c~ ~ c E o f9 ~ , O, ; Y ~, ~~ O. ~ ~ ~ ~ ~ ~ w, ~ Q C ~ ~ >' ~ ~ U. N, ~ N. ~, a O N O N Z ~ 3, O, ~~ O, ~ ~ ~ ~ N. ~ L. O. LA O, X' (q, ~, ~~ N T N. Y i w ~. Y, ~, U. ~, Q Q ~ ~ a, ~ ~, _ _ w ~, ~ n , a~ ~ o ~ ~ ~ O n N N~ N, N, >- } N~ N~ N N~ N~ N~ N~ N, N, N, N, N, N, N, }, } } } } } } N N~ N, N, }, } N~ N, } N N ~- ¢, ¢, ¢, ¢~ Z 2 Z Z N~ N, ¢ } Z' N, ~ N O, ~' Z O, Z N N~ N, N, >-, ~-, ~ N~ ¢, N, Z ~-, N~ N N, N, } } N N~ N N, N, N, } } } N~ ~ ~ N, O, ¢, } Z Z N N~ N, N, ¢, ¢~ }, }, Z Z ¢, Z O (` T \_~ ~' ` m >` p U i/A ~, , _ , O. a o'N ' ~' ' _ V C c ~ ~ O' , ~ f/~ O, N, , ~ V' ~ ~ ~ uj, a f6. fQ O U, O LLi ' ~' ' .N. ' ~ ~ N' n . i C ~ a, Q Q, ~ N• m ~ O, p ~ _ ~ `* a ~ N, ~ o N' o f0 p ~~ ~ ~ -a. 4 .o. o, ~, ~ ~, c ~ a~ a, •y a o n + , i ~ a . ~ ~ ~ 7. N. ~ 3 C~ ~~ N, C, a. 0 ~ ~ y, O, 7. N ~, ~ ~~ c C• Ub ~ C. ~ >, ~, N. , w o, , •_ o •~ 3 o v ° Mo, ?~, . ~, N. a o. _ a ~ o' ~, a, m. N Y Z -6, o c, .a O. °, .c, a ° m. n p, ~ c, y. m a o, rn a~' ' N 4 t c, o c. ~, a .. ~ ~ E~ E, a, `' c, c ' E' ' ~ % ~, o. N' ' c. w+, ~ f' .,, c o , o2S' . c. c. m. ~ rn N r , n ~ c o o a ~ « ~ o a, o, a °, ~ o ¢ 3 o ~ o U' .4 ~ o, 4 a~ ~ o, n . ~ ~ ~3 o N >~ ~, x g y 'N N d ~ ~ ~ m; . O• ~ c• ~ O > > O ~ o ~ ' ~ C, ~ ° '°~ ~ ` , N, c N (6. ~ . Q. `6 N, O N. ~ 'O O, OD o N N p g o. ~ $, ~ •_, ~~ ~ o w. a m m, ~ , Y m; - ° o, ~ o, °~ m ~, ~ 3, ~ R ~, a ~ s ~, 3 °, a i .E ~ Y ¢ ~? (O. . m m a m, ~' c, ~~ ~ ~ f6. pr, pi, o, .c, • __o a a m ~ o, N. f0' 'O. E~ -° ~ ~ ' ~ ~ •~~ c o, d ` ~~ ~.., , M. ~p ~-, N N, V, N, ~ N. ° N, n Q'. 3' O, ,~' o' O N' f ' N 3' O' c E W O ~ 0 4 a ~ ~ a' c' a v ~`~' o' a' ~ 3, . 3 ~ ~ m_, .., o. ' N .~ ~ ~~ ._. o, f0 ~, ~ ~, ~ o, uN n 'a N ~, m o. 0 3; o .c Z' •~- U . 0 a -~ 0, a. c ~ > m. m a~ m a°, ~, ' ~ a. o, o a. o ° m~ ~~ o~ o; ~ °~ ~~ o, o~ Y, ~ o~ . o N, a, ~, , ~~ °, ~, , ~ rn •o~ ~~ n ~ °, , ~ N. ~, , ~ °~ _ ° a ~ o, a ~ 4 0 a~, of a~' ~ ~ o. w~ ~~ a ~ '„ ~ °, • ~ ~ a m n °, °~ m m - T ° o O of ~ y; m' a, m OS ~ ~ o ~, ~ ~: 3 ~°' c ~ a °' ' ' o o a- a °, ` ;° 0, o. E. ~, .S. n °. m, N T 4 N, N, •v_~, , m a~ ~ ~, N, .3 c, v' rn ~ c a' or o ` ~ _ o m n, ~ •= a >, ~, o 2, j w c, ,~ ? . . ~, T «. ~ fl. a i 0 y ' a f0• ~~ _, a, a, a. U. ~ C• o O, 1]~ o a, .O a. ~, N• N~ •N, N, N, a ', >, .~? y, t. N, ~ w uh ~= U• O ~, o Q~ p (6• ~~ , ~, LL U O m ~, ~, ~, m, m. m, -d o. t, c. c. m. v. c. $' ~ a~ m o a a m m' ° ~' N. m _, 3, v o N ~ m' a o. ~ m. j c, m. c. $ c' ~"" Z N O ° ~ w- c 3, m, m, m, Y, ~ v v v ~, o o, o, o, a o, o, ~ m o °' ~ m o' E ~ ca v vi a' >' a o. c , °, 3, ~, ~, ~, -' 3 ~, a' rn ~, _ ~, v. ~ ~ ~' ~= a o , ~ d E' vi. ~ _ c, v ~ ° '~ 3 N' o, m, N co v ~' ~ n ~ ~, m, , o 3. Y a~, aoi ~ °~ ° °~ ~' ~ 4 ~ a~, a~, ~ ~, ~ o, o ~; ~ ~, ~ ~ a ° a `a ~ O r' O ° °' a°i' m; ~' ~; ~' o' 0 t- >, U ~ a, ~, w p, ~', ~', ~; U, _, O; O, a, o.; U ~; Q; a, z' , U, tn, U, U, U, U, ¢, ~; ¢, "_; o; , , m, m, U, ~; ~'', ~', a, p, cn, tn, U, t`/ W n O N M 'd' to (O I~ M m _ 0 N M C to CO f~ a0 O O N M eY « 7 CO f~ N m (,~`~~ O ~ N M V' O tD f~ 00 O ~ r ~ N N N N N N N N N N M M M M M M M M M M U ~_ U o o o C "'' N a0+ N y N U O M 'i+ ~ N 01 ~ N ~ N 4 N O d O N ~~+ fA _ rn i d ~ O O T N E (~ ~ ~~ J~ W p E a~ o '~ ~ a a Q, a LL ~ w a a w ~ n w ~ a~ ~~ J Well I-listory File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well Nistory file and to simplify finding information, infom~alion 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 inforrnaiion. • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Feb 08 12:34:42 2007 Reel Header Service name .............LISTPE Date .....................07/02/08 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................07/02/08 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Kuparuk River Unit West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER OPERATOR WITNESS • Scientific Technical Services Scientific Technical Services 1J-182 500292332100 ConocoPhillips Alaska Inc. Sperry Drilling Services 08-FEB-07 MWD RUN 3 MWD RUN 4 MW0004665704 MW0004665704 R. FRENCH B. HENNINGSE F. HERBERT M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 12.250 6.750 ~v~ - /3 35 11N l0E 1569 2433 121.30 81.00 CASING DRILLERS SIZE (IN) DEPTH (FT) 13.375 3680.0 9.625 9831.0 • REMARKS: • 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 3,4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 4 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). EWR MEMORY FILLED TOWARD THE END OF MWD RUN 3. REAL-TIME DATA (SEDP,SESP,SFXE ONLY) WERE USED TO FILL IN THIS GAP, FROM 8697.5'MD-9784'MD (SENSOR DEPTHS). GAPS REMAIN IN THE SEMP & SEXP DATASETS BECAUSE DATA FROM THESE SENSORS ARE NOT PULSED UP REAL-TIME. 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-4 REPRESENT WELL 1J-182 WITH API#: 50-029-23321-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17844'MD/3361'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3638.0 17786.5 RPD 3650.0 17793.5 • • FET 3650.0 17793.5 RPS 3650.0 17793.5 RPM 3650.0 17793.5 RPX 3650.0 17793.5 ROP 3692.5 17844.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD BIT RUN NO MERGE TOP MERGE BASE 3 3638.0 9836.0 4 9836.0 17844.5 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3638 17844.5 10741.3 28414 3638 17844.5 RPD MWD OHMM 1.34 2000 40.0308 28288 3650 17793.5 RPM MWD OHMM 0.67 2000 39.9167 26114 3650 17793.5 RPS MWD OHMM 1.75 2000 37.9338 28263 3650 17793.5 RPX MWD OHMM 2.85 2000 41.7898 26114 3650 17793.5 FET MWD HOUR 0.17 119.7 1.57974 28288 3650 17793.5 GR MWD API 21.27 139.56 67.1845 28298 3638 17786.5 ROP MWD FT/H 0.23 3818.42 213.441 28305 3692.5 17844.5 First Reading For Entire File..........3638 Last Reading For Entire File...........17844.5 File Trailer Service name .............STSLI$.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/08 Maximum Physical Record..65535 ! ! File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3638.0 9782.5 FET 3650.0 9775.5 RPX 3650.0 8697.0 RPS 3650.0 9775.5 RPM 3650.0 8697.0 RPD 3650.0 9775.5 ROP 3692.5 9836.0 LOG HEADER DATA DATE LOGGED: 20-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9836.0 TOP LOG INTERVAL (FT) 3691.0 BOTTOM LOG INTERVAL (FT): 9836.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 73.6 MAXIMUM ANGLE: 84.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG. RESIS. 4 81797 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 3680.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 61.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 650 FLUID LOSS (C3) 5.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.500 72.0 • MUD AT MAX CIRCULATING TERMPERATURE: 2. 570 100.4 MUD FILTRATE AT MT: 4. 000 73.0 MUD CAKE AT MT: 3. 200 73.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size N sam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3638 9836 6737 12397 3638 9836 RPD MWD030 OHMM 1.34 2000 16.8784 12252 3650 9775.5 RPM MWD030 OHMM 0.67 44.92 12.7507 10095 3650 8697 RPS MWD030 OHMM 1.75 76.69 13.1238 12227 3650 9775.5 RPX MWD030 OHMM 2.85 30.29 10.366 10095 3650 8697 FET MWD030 HOUR 0.23 119.7 1.72205 12252 3650 9775.5 GR MWD030 API 21.27 139.56 71.9571 12290 3638 9782.5 ROP MWD030 FT/H 0.23 3818.42 188.735 12288 3692.5 9836 First Reading For Entire File..........3638 Last Reading For Entire File...........9836 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF • • File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 9776.0 17793.5 FET 9776.0 17793.5 RPS 9776.0 17793.5 GR 9783.0 17786.5 RPX 9784.5 17793.5 RPM 9784.5 17793.5 ROP 9836.5 17844.5 LOG HEADER DATA DATE LOGGED: 28-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 17844.0 TOP LOG INTERVAL (FT) 9836.0 BOTTOM LOG INTERVAL (FT) 17844.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.7 MAXIMUM ANGLE: 95.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 9831.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.70 MUD VISCOSITY (S) 63.0 MUD PH: .0 MUD CHLORIDES (PPM): 20000 FLUID LOSS (C3) 4.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000. 116.6 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: • • HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9776 17844.5 13810.3 16138 9776 17844.5 RPD MWD040 OHMM 9.68 2000 57.7199 16036 9776 17793.5 RPM MWD040 OHMM 5.61 2000 57.0363 16019 9784.5 17793.5 RPS MWD040 OHMM 7.52 2000 56.8507 16036 9776 17793.5 RPX MWD040 OHMM 5.52 2000 61.5927 16019 9784.5 17793.5 FET MWD040 HOUR 0.17 118.63 1.47102 16036 9776 17793.5 GR MWD040 API 26.88 105.16 63.5204 16008 9783 17786.5 ROP MWD040 FT/H 1.22 3404.8 232.396 16017 9836.5 17844.5 First Reading For Entire File..........9776 Last Reading For Entire File...........17844.5 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/02/08 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN • Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................07/02/08 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF Writing Library. Scientific Technical Services End Of LIS File