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198-170
STATE OF ALASKA • AKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS h,h,..4,,, 1.Operations Abandon E Plug Perforations r Fracture Stimulate E Puy Operations Shutdown Performed: Suspend Perforate IT Other Stimulate fl Alter Casing 9 Change Approved Program Plug for Redrill Perforate New Pool "- Repair Well F Re-enter Susp Well fT Other: is- 2. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory 198-170 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-22914-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25650 KRU 1D-123 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 6055 feet Plugs(measured) None true vertical 4043 feet Junk(measured) None Effective Depth measured 6023 feet Packer(measured) 5402, 3225 true vertical 4012 feet (true vertical) 3427, 1978 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 121 121 0 0 PRODUCTION 5999 7 5/8 6039 4028 0 0 GRAVEL PACK 400 4 1/2 5802 3802 0 0 LINER 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 5513-5545', 5577-5610',5612-5643', 5668-5688', 5698-5718', 5738-5790' True Vertical Depth: 3527-3557', 3588'-3619', 3621-3650',3674-3693',3702-3721', 3740-3790' RECEIVED NOV 2 0 2015 Tubing(size,grade,MD,and TVD) 3.5, L-80, 5363=MD,3387=TVD AOGCCj CC Packers&SSSV(type,MD,and TVD) 2 PACKERS, PLEASE SEE ATTACHED SCHEMATIC FOR DETAIL DEPTH INFORMATION SSSV-NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): none �y 6 Treatment descriptions including volumes used and final pressure: SCANNED JAN 2 9 i_U Ib 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory fDevelopment 3' Service r Stratigraphic Copies of Logs and Surveys Run 16.Well Status after work: Oil F Gas IT WDSPL Printed and Electronic Fracture Stimulation Data IT GSTOR WINJ WAG r GINJ IT SUSP SPLUG r- 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 Jonathan Coberly a 265-1013 Email Jonathan.Coberly(a�conocophillips.com Printed Name Jonathan Coberly Title Sr.Wells Engineer Signature - v Phone:265-1013 Date II/Zp//s VTL /2-/ I V Form 10-404 Revised 5/2015 A /,2"j�Z'77. RBDMS' NOV 2 3 2015 Submit Original Only • KUP PROD • 1D-123 're- 01 • Conoco1 ��5 r.• F tWell Attributes Max Angle&MD TD Alaska Inc. Wellbore API/UWI Field Name Wellbore Status Inel(°) MD MKS) Act Btm(914131) t,mocm°ra9tnc , 500292291400 WEST SAK PROD 64.25 3,544.65 6,055.0 ••• ° Comment H25(ppm) Date Annotation End Date KB.Grd(ft) Rig Release Date 1D-123.11/11/20151'3919 PM SSSV:NONE 10 12/16/2013 Last WO: 6/26/2011 112.10 12/29/1998 Vowel schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag. Rev Reason:GLV C/O,RESET ESPCP, lehallf 11/11/2015 HANGER;35 G-I 1 .71; IT PACKOFF.SLIPSTOP Casing Strings Casing Deacrlption OD(In) ID(In) Top(ftKB) Set Depth(905) Set Depth(TVD)...WtILen(I...Grade Top Thread CONDUCTOR 16 15.062 40.5 121.0 121.0 62.58 H-40 WELDED !; Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 1 PRODUCTION 75/8 6.875 40.5 6,039.0 4,027.6 29.70 L-80 ABM-BTC ...-......-.-�.... -...-. ,. IA.Casing Description OD(in) ID(m) Top(ttKB) Set Depth(ttKB) Set Depth(TVD)...Wt/Len II...Grade Top Thread madmitCONbUCTOR 4d5-121.0 GRAVEL PACK LINER 4 1/2 4000 5402.3 5,802.4 3,801.8 Liner Details ( Nominal ID Top(ftKB) Top(TVD)(ttKB) Top Incl IT dem Des Com (in) 5,402.3 3,423.3 20.09 PACKER SIZE 7682-40,MODEL SC-1 GRAVEL PACK 4.000 PACKER w/5.5"SEAL-LOCK HT BOX DOWN GAS LIFT 3 097.9 5,406.5 3427.3 20.06 UPPER EXT 80-40 UPPER EXTENSION 4.880 5,410.9 3,431.4 20.03 SLEEVE 80-40 GRAVEL PACK SLIDING SLEEVE 4.380 I 5,412.4 3,432.8 20.02 SBE 80-40 SEAL BORE 4.000 5,414.4 3,434.7 20.01 LOWER EXT 80-40 LOWER EXTENSION 3.940 PACKER;3,224.3 5,430.8 3,450.1 19.91 SOS SHEAR OUT SAFETY JOINT 3.940 5,494.1 3.509.7 19.51 SCREEN 'BAKERWELD GRAVEL PACK SCREEN 4.000 5,799.1 3,798.7 17.90 SEAL ASSY BAKERS-22 SNAP LATCH ASSEMBLY 3.930 6,800.0 3,799.6 17.90 PACKER BAKER FB-1 RETAINER PRODUCTION PACKER 4.000 GAS LIFT.3,306.411 Tubing Strings Tubing Description String Ma ID(In) Top(ftKB) Set Depth(ft...Set Depth(TVD)( Wt(Ib/it) Grade Top Connection TUBING-WO 2015- 31/2 2.992 35.6 5.363.5 3,386.9 9.30 I-80 EUE 8rd AB Mod I ESP Completion Details Nominal IS GAS LIFT:5,220.7 Top(rtKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (In) 35.6 35.6 0.00 HANGER VETCO GRAY CWCT TUBING HANGER 2.950 3,224.8 1,977.8 63.49 PACKER WEATHERFORD HYDROW II DUAL STRING PACKER 2.992 5,273.7 3,303.0 21.29 ESP GAUGE WELL LIFT DISCHARGE GAUGE 2.992 ESP GAUGE;5,273,7 fir,. 5,332.2 3,357.6 20.61 ESP INTAKE CENTRILIFT TTC RECEIVER VV/PERF INTAKE 2.992 5,336.7 3,361.8 20.56 SEAL CENTRILIFT TOP SEAL SECTION 5,350.5 3,3747 20.41 GEAR CENTRILIFT GEAR REDUCTION UNIT SLIPSTOP;5,2900 '4. 5,351.8 3,375.9 20.40 ESP MOTOR CENTRILIFT ESP MOTOR PACKOFI=;5,291.0 5,359.8 3,383.5 20.35 GAUGE WELL LIFT MOTOR GAUGE PCESP.3.298.0 01 5,361.6 3,385.1 20.34 CENTRALIZE CENTRILIFT MOTOR CENTRALIZER I. R Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) ESP INTAKE:5.332.2 ,,,iii Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Dee Com Run Date ID lin) SEAL.5,336.7 5,290.0 3.318.2 21.10 SLIPSTOP 3.5"SLIPSTOP(OAL 92") 10/30/2015 GEAR,5,350.4 5,291.0 3.319.1 21.09 PAGKOFF 3.5"D&D PACKOFF(OAL=T-6") 10/30/2015 ESP MOTOR.5.351.8 5,298.0 3,325.6 21.01 PCESP 3.5"PCESP(OAL=33') 10/30/2015 GAUGE;5,359.6 i°_91.-..; - CSG PATCH Production casing patch set 16"below tubing 8/10/2011 °7 mandrel,sleeve 10"x65,.500 pipe and is 8'3"long. CENTRALIZER.5,361.5 m Perforations&Slots Shot ..-,p� Dens Top Bt(f(TVD) (rn Top(ftKB) 8tm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 5,513.0 5,545.0 3,527.5 3,557.7 WS D,1D-123 12/18/1998 12.0 IPERF 4 1/2"HSD BigHole Chrgs 5,577.0 5,610.0 3,588.0 3,619.2 WS B.1D-123 12/18/1998 12.0 IPERF 41/2"HSD BigHole Chrgs 11�� 5,612.0 5,643.0 3,621.1 3,650.5 WS A4,1D- 12/18/1998 12.0 IPERF 41/2"HSD BIgHole i 123 Chrgs 5.668.0 5,688.0 3,674.2 3,693.1 WS A3.1D- 12718/1998 12.0 IPERF 41/2"HSD BIgHole 123 Chrgs 5,698.0 5,718.0 3,702.6 3,721.6 WS A3,1D- 12/18/1998 12.0 IPERF 41/2"HSD BIgHole 123 Chrgs 5,738.0 5.790.0 3,740.6 3,790.0 WS A2,1D- 12/18/1998 12.0 )PERF 41/2"HSD BIgHole I PERF;5,513.0-5.545.0- i 123 Chrgs Mandrel Inserts IPERF;5,577.0-5.810.0--• St Il -. ati in on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(In) Sore Type Type (In) (pall Run Date Corn IPERF:5,612.0-5.643.01 3,097.9 1,920.8 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 10/29/2015 IPERF,5606.0-9898.0- it 2 3,308.4 2,015.0 CAMCO KBMG 1 GAS LIFT SOV BK 0.000 0.0 10/29/2015 20008 3 5,220.7 3,253.7 CAMCO KBMG 1 GAS LIFT DMV BK-5 0.000 0.0 10/18/2015 IPERF:5,898.0-5,718.0 Notes:General&Safety End Date Annotation IPERF;5,738.0-5,790.0- I, 8/19/2010 NOTE.View Schematic w/Alaska Schematic9.0 1 GRAVEL PACK LINER;5.402.3- 5 802.4 -5,802.4 PRODUCTION;90 5-6,039.0 • 0 a Operations Summary (with Timelog Depths) 443,g 1D-123 Co scoPhilips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/12/2015 10/12/2015 1.50 MIRU MOVE RURD P Prep for moving the sub and pits. 0.0 0.0 00:00 01:30 10/12/2015 10/12/2015 1.00 MIRU MOVE MOB P PJSM. Move the pits away from the 0.0 0.0 01:30 02:30 sub. 10/12/2015 10/12/2015 0.75 MIRU MOVE MOB P Jack up the sub,move the sub off well 0.0 0.0 02:30 03:15 1D-121,and position sub on the pad in order to move mats/herculite. 10/12/2015 10/12/2015 1.50 MIRU MOVE RURD P PU herculite,move mats from around 0.0 0.0 03:15 04:45 1D-121,setup mats around 1D-123, and lay out herculite. 10/12/2015 10/12/2015 1.25 MIRU MOVE MOB P Spot the sub over well 1 D-123. 0.0 0.0 04:45 06:00 10/12/2015 10/12/2015 0.50 MIRU MOVE RURD P Lay out herculite for the pits. 0.0 0.0 06:00 06:30 10/12/2015 10/12/2015 1.00 MIRU MOVE MOB P PJSM. Spot the pits to the sub 0.0 0.0 06:30 07:30 10/12/2015 10/12/2015 0.50 MIRU MOVE RURD P Set mats under the pits. 0.0 0.0 07:30 08:00 10/12/2015 10/12/2015 4.00 MIRU MOVE RURD P RU berming around the cellar and pits. 0.0 0.0 08:00 12:00 Spot LEPD tank and berm. Spot the cutting box and berm. RU steam to the pits. RU lines at interconnect. Pressure up air boots on the flow line. RU handrail,complete rig acceptance checklist,and accept the rig at 12:00 hours. 10/12/2015 10/12/2015 2.75 MIRU WELCTL RURD P PJSM. Load BST#2 with 9.1 ppg 0.0 0.0 12:00 14:45 filtered brine. RU squeeze manifold for well kill. 10/12/2015 10/12/2015 1.25 MIRU WELCTL 'SEQP P PJSM. PT 4"mud line to 3500 psi 0.0 0.0 14:45 16:00 (good test). PT lines to the kill tank to 1000 psi(good test) 10/12/2015 10/12/2015 1.00 MIRU WELCTL WAIT T Wait for CDR2 to finish using the 0.0 0.0 16:00 17:00 lubricator so the Vetco hand could bring it back to the rig. 10/12/2015 10/12/2015 1.00 MIRU WELCTL MPSP P RU the lubricator,pull the BPV,and 0.0 0.0 17:00 18:00 RD the lubricator. Tubing=350 psi and IA=450 psi). 10/12/2015 10/12/2015 2.50 MIRU WELCTL KLWL P PJSM. Reverse circulate 9.1 ppg 0.0 0.0 18:00 20:30 brine down the IA taking return up the tubing to the kill tank at 2 BPM. Got 9.1 ppg brine to surface shut down the pumps. Pumped 164 bbls and lost 9 bbls during the circulation. 10/12/2015 10/12/2015 0.50 MIRU WELCTL OWFF P Monitor the well pressures. Initial: 0.0 0.0 20:30 21:00 SITP=54 psi and SICP=54 psi. Final: SITP=70 psi and SICP=54 psi. SimOps: RU to bullhead and top off BST#2 with 9.1 ppg brine. 10/12/2015 10/12/2015 1.00 MIRU WELCTL KLWL P Bullhead 92 bbls down the tubing to 0.0 0.0 21:00 22:00 the formation at 2 BPM=750 psi. 10/12/2015 10/12/2015 0.50 MIRU WELCTL OWFF P Monitor the well pressures. Initial: 0.0 0.0 22:00 22:30 SITP=100 psi and SICP=80 psi. Final: SITP=150 psi and SICP=100 psi. SimOps: RU to bullhead and top off BST#2 with 9.1 ppg brine. Page 1/7 Report Printed: 11/17/2015 d • 4110 Operations Summary (with Timelog Depths) 1D-123 Conocc t'hi hps Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/12/2015 10/12/2015 0.50 MIRU WELCTL KLWL P Reverse circulate 10 bbls down the IA 0.0 0.0 22:30 23:00 taking returns out the tubing to the kill tank and confirmed 9.1 ppg brine at surface. Circulate 42 bbls down the tubing taking returns out the IA to the kill tank and confirmed 9.1 ppg brine surface. 10/12/2015 10/13/2015 1.00 MIRU WELCTL OWFF P Monitor the well pressures. Initial: 0.0 0.0 23:00 00:00 SITP=86 psi and SICP=50 psi. Final: SITP=126 psi and SICP=104 psi. SimOps: Empty the kill tank 10/13/2015 10/13/2015 1.50 MIRU WELCTL OWFF T Monitor the well pressures. Initial: 0.0 0.0 00:00 01:30 SITP=126 psi and SICP=104 psi. Final: SITP= 186 psi and SICP= 124 psi. Shut the tubing and IA. Bleed off the pressure and it was all gas. Discuss options with town engineer. 10/13/2015 10/13/2015 0.75 MIRU WELCTL RURD T Reload BST#2 with 9.1 ppg brine. 0.0 0.0 01:30 02:15 10/13/2015 10/13/2015 1.50 MIRU WELCTL KLWL T PJSM. Reverse circulate 160 bbls of 0.0 0.0 02:15 03:45 9.1 ppg brine down the IA taking returns up the tubing to the kill tank at 2 BPM. Lost 48 bbls during the circulation. 10/13/2015 10/13/2015 0.25 MIRU WELCTL RURD T Blow down circulating lines. RU 0.0 0.0 03:45 04:00 gauges to the tubing and IA. 10/13/2015 10/13/2015 1.00 MIRU WELCTL OWFF T Monitor the well pressures. Initial: 0.0 0.0 04:00 05:00 SITP=54 psi and SICP=76 psi. Final: SITP= 100 psi and SICP= 75 psi. 10/13/2015 10/13/2015 4.50 MIRU WELCTL WAIT T Calculate new KWF and Wait for 12.0 0.0 0.0 05:00 09:30 ppg spike fluid to arrive to weight up to 9.6 ppg brine.then recalculated with a 125 psi over balance and weighted up to 10.0+ 10/13/2015 10/13/2015 11.50 MIRU WELCTL KLWL T Bullhead 230 bbls of 10.0+ppg 0.0 0.0 09:30 21:00 NaCI/NaBr KWF down Tbg and IA at 2 bpm @ 620 psi. Then bleed off Tbg and IA to kill tank. Reverse circulate 8 bbls to kill tank. SITP-8 psi SICP-0 psi. Bleed off SITP and replace with 8 bbls, SITP-13 psi SICP-0 psi. Bleed off SITP and replace with 30 bbls, leave well open to atmosphere and vent off gas-slight blow on the IA after 3.5 hrs of being open w/50% LEL reading on monitor. Page 2/7 Report Printed: 11/17/2015 • Operations Summary (with Timelog Depths) °A;1-4, 1D-123 CoricicoPhiliips Atsck: Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/13/2015 10/13/2015 1.50 MIRU WELCTL KLWL T Circulate 170 bbls of 10.0+ppg 0.0 0.0 21:00 22:30 NaCI/NaBr KWF down the Tbg taking returns to the kill tank on a full open choke @ 2 bpm with max pressure of 95 psi at 32 bbls pumped,equivalent to open GLM @ 3246-ft±. FCP=84 psi.w/85 bbls recovered of the 170 bbls pumped-50%returns. Took first initial 12 bbls get returns- equivalent to 281-ft±of fluid level from surface. 10/13/2015 10/14/2015 1.50 MIRU WELCTL OWFF T Monitor well for flow -SITP=on 0.0 0.0 22:30 00:00 Vaccumn SICP=small amount of pressure-5 psi?. ©23:30 hrs TBG and IA on vaccumn. Call out DHD and contiinue to monitor well. 10/14/2015 10/14/2015 3.00 MIRU WELCTL OWFF T Monitor well for flow TBG and IA on 0.0 0.0 00:00 03:00 vac.since 23:30 hrs DHD arrived and shot 1st fluid level @ 02:30 at 240-ft depth and 2nd fluid level @ 03:00 hrs at 282-ft depth. 10/14/2015 10/14/2015 0.50 MIRU WHDBOP MPSP P Install BPV in tbg hanger 0.0 0.0 03:00 03:30 10/14/2015 10/14/2015 1.50 MIRU WHDBOP NUND P ND Tree, RU wire rope sling to 0.0 0.0 03:30 05:00 traveling blocks,break Tbg adapter pull 1k to pull adapter off seal neck, disconnect traveling blocks and tie onto bridge crane and remove Tree. 10/14/2015 10/14/2015 5.00 MIRU WHDBOP NUND P RD all circulating equipment tied 0.0 0.0 05:00 10:00 intoTbg spool. NU 13-5/8 5M BOPE. Install mouse hole and flow riser, install turn buckles. install cross over's FOSV's. 10/14/2015 10/14/2015 0.50 MIRU WHDBOP RURD P Grease test spool, HCR choke,HCR 0.0 0.0 10:00 10:30 Kill,Manual Choke and Kill Valves. 10/14/2015 10/14/2015 3.50 MIRU WHDBOP BOPE P Conduct Initial BOP test at 250/2,500 0.0 0.0 10:30 14:00 psi on all BOPE with 3-1/2 test joint w/ 10"donut. 24 hr notice was given @ 7:35 hrs on 10-12-15 and Right to witness was waived by Bob Noble @ 17:30 hrs on 10-13-15. Test 1-3 LPR's,UPR's and Annular on 3-1/2 test joint along with Choke Valves 1,2,3,4,5,6 and 16,Kill Demco and HCR Kill. Conduct Koomey Drawdown test 6 bottles of N2 Ave.2,108 psi to 200 psi=35 seconds and to system pressure=146 seconds Test Blind rams along with Choke Valves 7,8,9,10,11,12,13,14,and 15, Upper and Lower TD Valves,Manual and Hydraulic Choke,HCR Choke and Kill,Manual Choke and Kill and outer and inner test spool valves. 10/14/2015 10/14/2015 0.50 MIRU WHDBOP RURD P RD test equipment and blow down 0.0 0.0 14:00 14:30 choke manifold and kill line,drain stack. Page 3/7 Report Printed: 11/17/2015 k0 � �` Operations Summary (with Timelog Depths) 1D-123 CPhillips ALskka Rig: NABORS 9ES 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(MKB) 10/14/2015 10/14/2015 0.50 MIRU WHDBOP MPSP T Pull Blanking plug,tap into BPV and 0.0 0.0 14:30 15:00 check for pressure -check positive- remove dry rod. Shoot fluid level on IA= 342-fit. 10/14/2015 10/14/2015 0.75 COMPZN RPCOMP RURD T RU circulation lines in cellar to IA 0.0 0.0 15:00 15:45 valve 10/14/2015 10/14/2015 1.00 COMPZN RPCOMP KLWL T Pump 30 bbls down TBG ICP=30 psi 0.0 0.0 15:45 16:45 FCP=60 psi 10/14/2015 10/14/2015 0.50 COMPZN RPCOMP MPSP T Tap into BPV and check for pressure 0.0 0.0 16:45 17:15 -check negative-removeBPV. Set Isosleeve inside TBG hanger 10/14/2015 10/14/2015 2.75 COMPZN RPCOMP RURD P MU landing jt into Hanger,RU ESP 0.0 0.0 17:15 20:00 spooler and BOLDS. Had 1 lock down screw that seized up-was able to back out but will not be ran back in. 10/14/2015 10/14/2015 0.50 COMPZN RPCOMP PULL P Un-land hanger at 100K and continue 0.0 0.0 20:00 20:30 to pull up2-ft and load IA with KWF- took 12 bbls to load IA. Continue to pull up to 150K and packer sheared, string weight fell back to 67K. 10/14/2015 10/14/2015 0.50 COMPZN RPCOMP OWFF P Load IA with trip tank and monitor well 0.0 0.0 20:30 21:00 -establish loss rate of 50 bph. Re Land hanger and open TBG and IA to pit 2 and monitor well for flow. 10/14/2015 10/15/2015 3.00 COMPZN RPCOMP OWFF T Call another 580 bbls of Filtered 9.8 0.0 0.0 21:00 00:00 ppg 3%KCL/NaCl Brine for conducting a Static Fluid Column. 10/15/2015 10/15/2015 6.50 COMPZN RPCOMP OWFF T Wait for the order of 580 bbls of 0.0 0.0 00:00 06:30 Filtered 9.8 ppg 3%KCL/NaCI Brine for conducting a Static Fluid Column. Shoot FL-252-ft±, SimOps-Slip and cut drill line 10/15/2015 10/15/2015 0.25 COMPZN RPCOMP PULL P Pull hanger 4-ft above TBG spool 5,352.0 5,348.0 06:30 06:45 10/15/2015 10/15/2015 0.25 COMPZN RPCOMP OWFF P monitor for flow-good 0.0 0.0 06:45 07:00 10/15/2015 10/15/2015 1.00 COMPZN RPCOMP PULL P Pull hanger to rig floor-85K up wt; 5,348.0 5,279.0 07:00 08:00 60K do wt. Disconnect pig tail from hanger,lay down landing joint,hanger with 30-ft joint and 2-10-ft x 3-1/2 pup joints. 10/15/2015 10/15/2015 0.50 COMPZN RPCOMP OTHR P Fill hole while RU ESP cable over the 5,279.0 5,279.0 08:00 08:30 sheave 10/15/2015 10/15/2015 9.00 COMPZN RPCOMP TRIP P Continue to POOH standing back 3- 5,279.0 1,399.0 08:30 17:30 1/2,9.3#, L-80 EUE 8rd AB Mod Tubing from 74-ft to 3,380-ft. Double displ of 5 stds/5 bbls. Lay down Weatherford 3-1/2 x 7-5/8 Hydrow II Feed thru packer 10/15/2015 10/15/2015 1.25 COMPZN RPCOMP TRIP P Continue to POOH from 1399-ft to 830 1,399.0 830.0 17:30 18:45 -ft.and after re-run ESP cable over sheave. 10/15/2015 10/15/2015 0.50 COMPZN RPCOMP OWFF P Fill hole with 25 bbls and monitor well 830.0 830.0 18:45 19:15 for flow during crew change outs. 10/15/2015 10/15/2015 1.50 COMPZN RPCOMP TRIP P Continue to POOH from 830-ft to 43-ft 830.0 43.0 19:15 20:45 to TTC Receiver Page 4/7 Report Printed: 11/17/2015 • • • Operations Summary (with Timelog Depths) tea.; . 1D-123 Corillips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time. End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/15/2015 10/16/2015 3.25 COMPZN RPCOMP PULL P PJSM,POOH laying down TTC 43.0 0.0 20:45 00:00 receiver and slotted intake,Top Seal section,Bottom Seal Section,GRU, ESP Motor,Gauge and Motor Centralizer. Recovered 97 cannon clamps, 194 C/C Pins,4 Protectrolizers and MLE Flat guards. 10/16/2015 10/16/2015 1.00 COMPZN RPCOMP OWFF P Shoot FL against closed Blind rams- 0.0 0.0 00:00 01:00 222-ftt. Fill hole with 25 bbls of 9.8 ppg KWF-filled to stack Sim Ops-Clear and Clean rig floor 10/16/2015 10/16/2015 5.50 COMPZN RPCOMP ALFT P Rig up rope to ESP Cable tail to run 0.0 0.0 01:00 06:30 over sheave. Un load ESP cable pulled and swap with New. Load BHA in Pipe shed and confirm lengths. Break down 10-ft pup off of slotted intake,Prep ESP Cable head for install 10/16/2015 10/16/2015 8.00 COMPZN RPCOMP ALFT P PU 562 SP1,60 HP 1240 volt 29A 0.0 0.0 06:30 14:30 Motor and load with oil as per Centrilift rep.MU pump assy to Motor,Tie in pot head and meg-good test. MU DGU and PT to 5,000 for 3 minutes- good test. Begin Tripping in hole and cannon clamp closing tool failed. 10/16/2015 10/16/2015 1.00 COMPZN RPCOMP WAIT T Wait for Centrilift to replace cannon 0.0 0.0 14:30 15:30 clamp closing tool due to failure. 10/16/2015 10/16/2015 1.75 COMPZN RPCOMP TRIP P Continue to trip in the hole with ESP 0.0 1,088.0 15:30 17:15 Components on 3-1/2 9.3#,L-80 EUE 8rd Tubing to 1,088-ft. 46K up wt,43k do wt. 10/16/2015 10/16/2015 0.75 COMPZN RPCOMP ALFT P Meg test ESP cable-Failed,re test- 1,088.0 1,088.0 17:15 18:00 failed. Showing short in cable. 10/16/2015 10/16/2015 2.00 COMPZN RPCOMP TRIP T POOH from 1,088-ft to 96-ft and found 1,088.0 96.0 18:00 20:00 damaged ESP cable at the bottom of the Gauge unit-SS band slide up and damage the amour and cut into the cable. POOH to pot head and disconnect. Install protection cap 10/16/2015 10/17/2015 4.00 COMPZN RPCOMP EQRP T Cut MLE and remove damaged ESP 96.0 96.0 20:00 00:00 conductor line. Prep for splicing on the MLE. 10/17/2015 10/17/2015 3.00 COMPZN RPCOMP EQRP T Resplice MLE and test-test failed 96.0 96.0 00:00 03:00 10/17/2015 10/17/2015 12.25 COMPZN RPCOMP EQRP T Cut MLE and remove damaged ESP 96.0 96.0 03:00 15:15 conductor line.Test and found bad leg in the 6,000-ft of ESP Conductor line. RD line from across sheave and prep drum for removal. Remove drum and Install replacement. String line over sheave. Splice on(NEW)MLE Meg line and all tested good. 10/17/2015 10/17/2015 2.25 COMPZN RPCOMP TRIP T RIH w/ESP assembly as per run 96.0 1,088.0 15:15 17:30 order and megging ESP conductor every 500-ft from 96-ft to 1,088-ft. Meg cable @ 623-ft and1,095-ft Page 5/7 Report Printed: 11/17/2015 S • Operations Summary (with Timelog Depths) y � 1 D-123 ries., CoeloccsPhitltpr5 F€xka Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/17/2015 10/17/2015 3.25 COMPZN RPCOMP TRIP P Continue to RIH w/ESP assembly as 1,088.0 2,146.0 17:30 20:45 per run order and megging ESP conductor every 500-ft from 1,088-ft to 2,138-ft 52K up[wt,47K dn wt. Meg cable @ 1,569-ft.and 2,146-ft 10/17/2015 10/18/2015 3.25 COMPZN RPCOMP ALFT P Measure,cut and meg cable. Splice 2,146.0 2,146.0 20:45 00:00 cable thru Weatherford Hydrow II Packer sleeve. 10/18/2015 10/18/2015 0.75 COMPZN RPCOMP ALFT P Continue to splice cable thru 2,146.0 2,146.0 00:00 00:45 Weatherford Hydrow II Packer sleeve. 10/18/2015 10/18/2015 2.00 COMPZN RPCOMP EQRP T While setting hand slips after 2,146.0 2,146.0 00:45 02:45 completion of splice and re connect to packer pentrator,the amour was damaged by the setting of the hand slips. Repair and test.--good 10/18/2015 10/18/2015 7.25 COMPZN RPCOMP TRIP P PJSM with all involved,Continue to 2,146.0 5,290.0 02:45 10:00 RIH w/ESP Completion from 2,146-ft to 5,290-ft 73K up wt,53K dn wt 10/18/2015 10/18/2015 1.00 COMPZN RPCOMP THGR P MU landing joint and Tbg Hanger 5,290.0 5,290.0 10:00 11:00 10/18/2015 10/18/2015 4.50 COMPZN RPCOMP ALFT P Conduct Top Splice,Meg test--test 5,290.0 5,290.0 11:00 15:30 good 10/18/2015 10/18/2015 1.00 COMPZN RPCOMP THGR P Land TBG hanger and RILDS with 5,290.0 5,354.0 15:30 16:30 Bottom of Centralizer @ 5,354-ft and Packer @ 3,225-ft 10/18/2015 10/18/2015 5.50 COMPZN RPCOMP FRZP P RU Little Red Services to the IA and 5,354.0 5,354.0 16:30 22:00 PT pump line to 2,000 psi. Bull head 111 bbls of gelled Diesel at 1.5 bpm @ 750 psi. Close in IA and Disconnect. RU to TBG and fill TBG at.25 bpm to.5 bpm with 30 bbls of LEPD diesel. 10/18/2015 10/18/2015 0.75 COMPZN RPCOMP PACK P Pressure up to 1,000 psi for 5 5,354.0 5,354.0 22:00 22:45 mionutes,and stage up to 3,500 psi and set packer @ 3,225-ft. Hold pressure for 20 minutes -had to bump up after 1st 10 minutes.-Good Test 10/18/2015 10/19/2015 1.25 COMPZN RPCOMP PRTS P RU LRS to IA and PT lines @ 2,000 5,354.0 5,354.0 22:45 00:00 psi-Open IA and PT to 1500 psi and chart for 30 minutes. 10/19/2015 10/19/2015 1.25 COMPZN RPCOMP PRTS P Continue to PT the IA to 1500 psi and 5,354.0 5,354.0 00:00 01:15 chart for 30 minutes. Good test- Bleed off and RD Little Red Services. 10/19/2015 10/19/2015 0.75 COMPZN WHDBOP MPSP P RD Landing joint,pull Side port ISO 0.0 0.0 01:15 02:00 sleeve,install TWC and drain stack through the production wing valve using LRS to pull back fluid. 10/19/2015 10/19/2015 1.50 COMPZN WHDBOP OTHR P RD ESP Sheave,Trunk,and send all 0.0 0.0 02:00 03:30 third party tools off the rig floor. Drop turn buckles,drain LEPD tank,pull fluid from cuttings box. Sim ops-Break bolts on BOPE 10/19/2015 10/19/2015 1.50 COMPZN WHDBOP NUND P ND BOP and Rack back same. 0.0 0.0 03:30 05:00 Page 6/7 Report Printed: 11/17/2015 S rcII _ 9 Operations Summary (with Timelog Depths) .., ID-123 ConocoPhitltps Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/19/2015 10/19/2015 1.75 COMPZN WHDBOP NUND P lift and hang Production Tree. Visually 0.0 0.0 05:00 06:45 check adapter and penetrator sealing surfaces. NU Tree. Sim ops;Transport camps and shops from 1D to 1J pad. 10/19/2015 10/19/2015 0.50 COMPZN WHDBOP PRTS P Test hanger void 250/5,000 psi- 0.0 0.0 06:45 07:15 good test. Test ESP conductor line as per Centrilift. 10/19/2015 10/19/2015 1.00 COMPZN WHDBOP PRTS P PT tree with diesel to 250/5,000 psi- 0.0 0.0 07:15 08:15 good test. RD Test equipment. 10/19/2015 10/19/2015 1.00 COMPZN WHDBOP MPSP P Pull TWC and install Type H BPV. 0.0 0.0 08:15 09:15 10/19/2015 10/19/2015 0.75 DEMOB MOVE RURD P Prep cellar and tree for rig release. 0.0 0.0 09:15 10:00 Release Nabors 9ES @ 10:00 hrs on 10-19-15. SITP=0,SICP=0. Page 7/7 Report Printed: 11/17/2015 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection, [ ~ ~' - / ~ File Number of Well History File PAGES TO DELETE RESCAN D [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: Other - Pages: DIGITAL DATA [] Diskettes, No. r~ Other, No/Type OVERSIZED [] Logs of various kinds Other Complete COMMENTS: Scanned by: Beverly Mildred Daretha~owell TO RE-SCAN Notes: Date: ~ ~' 2 ~ /S/ Re-Scanned by: Beverty Mildred Daretha ath~-~.~well Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 26, 2011 RECEIVED Commissioner Dan Seamount Alaska Oil and Gas Commission 140V 1 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Alaska Oil " Cons - s sjon lq j 70 Anc„, „, „,, Commissioner Dan Seamount: 1 ( a Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement 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 cement was pumped on 9/11 and, 9/12, 2011. The corrosion inhibitor /sealant was pumped 10/15, 10/16, 10/17 and, 10/18, 2011. 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 Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, fila/PRY? td t Martin Walters ConocoPhillips Well Integrity Projects Supervisor • 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 10126111 1A,1B,1C,1D, 1E & 1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 1A -22 50029221270000 1910030 SF N/A 18" N/A 2.55 10/18/2011 WSW -01 50029205370000 1801400 20" N/A 20" N/A 2.5 10/16/2011 WSW -02 50029208120000 1821370 2'10" N/A 2'10" N/A 6 10/16/2011 WSW -03 50029208170000 1821420 12" 1.00 20" 09/11/2011 4.25 10/16/2011 WSW -07 50029208610000 1821880 SF N/A 19" N/A 1 10/17/2011 1C -170 50029231540000 2030780 19'3" 1.20 10" 09/11/2011 18.74 10/15/2011 _ 1C-174 50029231400000 2030270 7' 1.00 8" 09/11/2011 14.8 10/15/2011 _ 1C -190 50029231360000 2030030 9'4" 1.50 8" 09/11/2011 15.2 10/16/2011 1 D -08 50029220266000 1770530 5'2" 1.20 6" 5/28/2011 3.8 10/15/2011 1D -12 50029229480000 1990840 18" N/A 18" N/A 3.4 10/15/2011 1D -41 50029232880000 2051880 16" N/A 16" N/A 3.55 10/15/2011 1D-123 D -123 50029229140000 1981700 11'5" 2.30 5" 09/12/2011 4 10/15/2011 1E-11 50029207870000 1820510 22" N/A 15" N/A 1.2 10/17/2011 1Y -09 50029209350000 1830520 7' 2.00 5" 09/12/2011 1.7 10/18/2011 • • , ,-.-- S iri WELL LOG TRANSMITTAL I ,. PROAcrivE DiAgnostic SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 2' (907) 659 -5102 �� b RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : RECEIVED ProActive Diagnostic Services, Inc. Attn: Robert A. Richey JUL 8 2011 130 West International Airport Road Suite C Anchorage, AK 99518 Akaka ON & Gas Cons. Commission Fax: (907) 245 -8952 Mchorage 1 1) Caliper Report 25- Jun -11 1D-123 1 Report/ CD 50 -029- 22914 -00 2) ` c.(7 03 Signed : + , , 1 Date : 02 `{ l Print Name: C- a .- Z (.k1..o-V4.4.... PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 • PHONE: (907)245 -8951 Fax: (907)245 - 8952 E : PDSANCHORAGE(CD.MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Dishibution\ TransmittalSheets \ConocoPhillips_Transsmit.docx L 1 g47 • • Multi- Finger Caliper Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 1D -123 Log Date: June 25, 2011 Field: Kuparuk (West Sak) ' Log No.: 6852 State: Alaska Run No.: 1 API No.: 50- 029 - 22914 -00 Pipet Desc.: 7.625" 29.7 Ib. L-80 ABM -BTC Top Log Intvll.: Surface Pipet Use: Surface Casing Bot. Log Intvll.: 5,325 Ft. (MD) 1 Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS : All depths in this report refer to uncorrected slick line measured depth. This log was run to assess the condition of the 7.625" surface casing with respect to corrosive and mechanical damage, as well as to identify areas of buckling or ID restriction due to subsidence. The caliper recordings indicate the 7.625" surface casing appears to be in good condition with respect to corrosive and mechanical damage. No significant wall penetrations or areas of cross - sectional wall loss are recorded throughout the 7.625" surface casing logged. A 3 -D log plot of the caliper recordings across the interval where the ESP will be placed is included in this report. ' Although no significant I.D. restrictions are recorded, the caliper recordings indicate mild buckling with slight areas of ovality from —180' to —1,300'. An overlay of the centered and off - center caliper recordings highlighting the areas of mildly buckled 7.625" surface casing is included in this report. 1 MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 15 %) are recorded throughout the surface casing logged. MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: 1 No significant areas of cross - sectional wall Toss (> 8 %) are recorded throughout the surface casing logged. I MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the surface casing logged. 1 RECEIVED JUL 8 2011 Alaska t $ Gast Corm C�1t1#10 1 1 Anolwrago I Field Engineer: N. Kesseru Analyst: M. Lawrence Witness: Adams / Freeborn 1 ProActive Diagnostic Services, Inc. / P.Q. box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS©memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 a8 - (7 6 I • • PDS Multifinger Caliper 3D Log Plot I Company : ConocoPhillips Alaska, Inc. Field : Kuparuk (West Sak) Well : 1D -123 Date : June 25, 2011 I Description : Detail of Caliper Recordings Across ESP and Packer Setting Interval Comments Depth Maximum Penetration Maximum I.D. 3-0 Log Image Map 1 1ft:240ft 0 % 100 3.5 inches 4.5 0° 0° 90° 180° 270° 0° I I Minimum I.D. 3.5 inches 4.5 Nominal I.D. 3.5 inches 4.5 I .. ! I 5180 1. Joint 163 ( •W" -- - I 5190 IiII _ t �� FM 5200 11111 — 5210 I i1 — III/, I -- _- 5220 I Joint 164 , 5230 i � I 5240 • — 1 I _ 5250 t TA ‘ ' t i 1 5260 - -- -- — i Ili Joint 165 5270 - - - - i - ' -- - 11 - 5280 ` - ' �� ' 5290 _ — —" — _ F -- 5300 H ! � --- 1 -1. - -- — F — I _— ;�ifi Joint 166 5310 I — i I ,_a 5320 - - -- — ■I I I • • ii; PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk (West Sak) ■ Well : 1D -123 Date : June 25, 2011 I Description : Overlay of Centered and Off - Center Caliper Recordings Across Buckled 7.625" Casing Maximum I.D. Depth 3 -D Log (Off -Center) Image Map (Off - Center) 3-0 Log (Centered) Image Map (Centered) -- lft:600ft .37 amt I Itime I — 6 inches 8 329° 0° 90° 180° 270° 0° 329° 0° 90° 180° 270° 0° Minimum I.D. —1 6 inches 8 Nominal I.D. I 6 inches 8 =i�— _ . _ . 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Correlation of Recorded Damage to Borehole Profile I • Pipe 1 7.625 in (30.7 - 5291.3') Well: 1D-123 Field: Kuparuk (West Sak) I Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: June 25, 2011 I I Approx. Tool Deviation . Approx. Borehole Profile III 34 I i 10 413 j i I 20 4 829 1 30 1 1254 40 1669 50 il l 2093 0 I 60 2516 Z ' 0 70 2943 Q 80 i \ 3373 — I 1 ) 90 e l 3802 1 100 1 4229 I 110 - 4657 120 7 5078 I ' 125 5291 0 50 100 1 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 125 I' I I • • I PDS Report Overview �� s . Body Region Analysis I Well: 1D-123 Survey Date: June 25, 2011 Field: Kuparuk (West Sak) Tool Type: UW XR MFC 40 No. 217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 7.625 ins 29.7 ppf L -80 ABM -BTC Analyst: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 7.625 ins 29.7 ppf L -80 ABM -BTC 6.875 ins 7.625 ins 6.0 ins 6.0 ins I Penetration(% wall) Damage Profile (% wall) 150 Penetratio body Metal loss body 0 50 100 0-. 100 50 III 0 I 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 126) 126 0 0 0 50 I Damage Configuration ( body ) 20 I 15 Asairmar 10 1 5 100 0 I Isolated General Line Other Hole/ Pacing Corrosion Corrosion Damage Pos. Hole I Number of joints damaged (total = 12) 12 0 0 0 0 Bottom of Survey = 125 I I I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7.625 in 29.7 ppf L -80 ABM -BTC Well: 1 D-123 Body Wall: 0.375 in Field: Kuparuk (West Sak) I Upset Wall: 0.375 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 6.875 in USA Survey Date: June 25, 2011 I Joint Jt. Depth Pen. Pen. Pen. Me 1,11 Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 31 0 0.02 5 1 6.92 Pup 1 34 0 0.03 8 2 6.89 2 76 0 0.03 8 2 6.89 3 119 0 0.03 7 2 6.91 4 162 0 0.03 7 2 6.88 I 5 205 0 0.04 10 4 6.89 6 245 0 0.03 8 2 6.88 7 288 0 0.03 8 2 6.89 8 329 0 0.03 7 2 6.86 Slight Ova due to Mild Buckling. I 9 372 0 0.03 7 4 6.88 Slight Ova due to Mild Buckling. 10 413 0 0.03 8 6 6.90 Slight Ova due to Mild Buckling. 11 456 0 0.03 9 6 6.89 Slight Ova due to Mild Buckling. 12 492 0.05 0.04 9 8 6.88 Slight Ova due to Mild Buckling. I 13 533 0 0.03 7 3 6.87 Slight Ova due to Mild Buckling. 14 576 0 0.02 6 3 6.88 Slight Ova due to Mild Buckling. 15 618 0 0.03 8 3 6.91 16 661 0 0.04 12 7 6.87 I 17 18 703 0 0.03 8 2 6.91 746 0 0.03 9 3 6.87 19 786 0 0.03 7 3 6.88 20 829 0 0.03 9 3 6.89 21 873 0 0.04 10 3 6.89 I 22 916 0 0.03 72 6.83 23 959 0 0.03 8 2 6.88 23.1 1001 0 0 0 0 6.83 Tam Port Collar 24 1004 0 0.03 8 1 6.88 I 25 1047 0 0.03 8 2 6.87 26 1090 0 0.04 11 2 6.86 27 1129 0 0.03 9 2 6.87 28 1170 0 0.03 7 2 6.86 I 29 1213 0 0.04 10 2 6.84 30 1254 0 0.03 9 2 6.87 31 1294 0 0.03 7 2 6.88 32 1337 0 0.04 9 2 6.86 33 1378 0 0.03 8 2 6.86 I 34 1420 0 0.03 7 3 6.84 35 1459 0 0.04 10 2 6.88 36 1502 0 0.03 9 2 6.86 37 1543 0 0.04 9 3 6.86 I 38 1586 0 0.03 8 1 6.85 39 1626 0 0.03 8 2 6.87 40 1669 0 0.03 7 2 6.86 41 1711 0 0.04 10 2 6.86 I 42 1752 0 0.04 9 2 6.86 43 1795 0 0.03 9 2 6.87 44 1838 0 0.04 10 2 6.86 45 1881 0 0.03 8 1 6.87 I 46 1924 0 0.03 9 2 6.87 47 1968 0 0.03 7 2 6.84 48 2011 0 0.03 9 2 6.86 IPenetration Body I Metal Loss Body Page 1 I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7.625 in 29.7 ppf L-80 ABM -BTC Well: 1 D-123 Body Wall: 0.375 in Field: Kuparuk (West Sak) I Upset Wall: 0.375 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 6.875 in Country: USA Survey Date: June 25, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 49 2050 0 0.03 8 2 6.86 O 50 2093 0.03 9 2 6.84 51 2136 O 0.04 10 4 6.85 Slight Oval due to Mild Buckling. 52 2179 0 0.04 10 2 6.87 53 2222 O 0.03 8 3 6.84 Slight Oval due to Mild Buckling. I 54 2264 55 2307 0 0.04 10 2 6.83 Slight Oval due to Mild Buckling. 0 0.04 10 3 6.87 Slight Oval due to Mild Buckling. 56 2348 0 0.04 10 2 6.84 Slight Oval due to Mild Buckling. 57 2389 0 0.02 6 2 6.82 I 58 2432 0 0.03 7 2 6.86 59 2476 O 0.03 8 2 6.86 60 2516 0 0.04 10 2 6.88 61 2559 0 0.03 9 2 6.86 1 62 2602 0 0.03 9 2 6.86 63 2645 0 0.03 9 2 6.87 64 2686 0 0.03 7 2 6.88 65 2728 0 0.03 7 2 6.88 I 66 2771 0 0.03 9 2 6.86 67 2813 0 0.03 9 2 6.85 68 2857 0 0.03 8 2 6.87 69 2900 0 0.03 7 2 6.88 70 2943 0 0.03 8 2 6.88 I 71 2985 0 0.02 6 2 6.89 72 3028 0 0.03 9 2 6.84 73 3071 0 0.04 11 2 6.86 74 3113 0 0.04 10 2 6.84 I 75 3156 0 0.03 8 2 6.88 76 3200 0 0.03 8 I 6.86 77 3243 0 0.03 9 2 6.86 78 3286 0 0.03 7 1 6.87 I 79 3330 0 0.03 8 2 6.88 80 3373 0 0.03 8 2 6.86 81 3414 0 0.02 6 1 6.86 82 3457 0 0.03 9 2 6.84 83 3500 0 0.04 11 2 6.82 I 84 3544 0 0.03 8 2 6.87 85 3587 0 0.03 7 2 6.87 86 3630 0 0.03 9 2 6.84 87 3673 0 0.03 7 2 6.88 I 88 3716 0 0.03 9 2 6.87 89 3759 0 0.03 7 1 6.86 90 3802 0 0.04 11 2 6.85 91 3845 0 0.03 9 1 6.86 I 92 3888 0 0.03 9 2 6.86 93 3931 0 0.03 7 1 6.84 94 3974 0 0.03 8 1 6.85 95 4015 () 0.03 7 2 6.86 96 4058 0 0.03 7 2 6.84 I 97 4102 0 0.03 7 1 6.84 98 4145 0 0.03 8 2 6.88 Penetration Body I Metal Loss Body Page 2 I 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7.625 in 29.7 ppf L-80 ABM -BTC Well: 1D-123 Body Wall: 0.375 in Field: Kuparuk (West Sak) Upset Wall: 0.375 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 6.875 in Country: USA Survey Date: June 25, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) °r%> (Ins.) 0 50 100 99 4187 0 0.03 8 2 6.86 100 4229 () 0.03 7 1 6.86 101 4273 0 0.04 11 2 6.86 102 4316 0 0.03 7 1 6.85 I 103 4359 0 0.03 8 2 6.88 104 4401 0 0.03 7 2 6.84 105 4445 0 0.03 7 1 6.87 106 4488 0 0.04 10 2 6.84 107 4531 0 0.03 8 2 6.85 I 108 4573 0 0.04 11 2 6.88 • 109 4616 0 0.05 13 2 6.87 Shallow Pitting. • ■ 110 4657 0 0.05 12 1 6.86 Shallow Pitting. 7 111 4699 0 0.03 8 1 6.86 112 4739 0 0.06 15 2 6.88 Shallow Pitting. on 4777 O 0.04 11 2 6.86 • ■ 114 4820 0 0.04 12 1 6.83 ■ 115 4863 0 0.04 11 1 6.86 ■ 16 4906 0.05 0.04 12 1 6.82 ■ I i 117 4949 0 0.05 14 2 6.84 Shallow Pitting. • 118 4992 0 0.04 12 2 6.84 Shallow Pitting. ■ 119 5035 0 0.06 15 2 6.84 Shallow Pitting. • 120 5078 0 0.05 13 2 6.86 Shallow Pitting. ■ I 121 5121 122 5163 0 0.05 13 2 6.88 Shallow Pitting. ■ 0 0.05 13 2 6.86 Shallow Pitting. ■ 123 5206 0 0.05 13 1 6.87 Shallow Pitting. • 124 5248 0 0.04 12 2 6.85 Shallow Pitting. • I 125 5291 0 0.05 14 2 6.87 Shallow Pitting. I Penetration Body Metal Loss Body I I I I I I Page 3 I I • • I PDS Report Cross Sections I Well: 1D -123 Survey Date: June 25, 2011 Field: Kuparuk (West Sak) Tool Type: UW XR MFC 40 No. 217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 I Tubing: 7.625 ins 29.7 ppf L -80 ABM -BTC Analyst: M. Lawrence I I Cross Section for Joint 12 at depth 494.017 ft Tool speed = 50 Nominal ID = 6.875 I Nominal OD = 7.625 I Remaining wall area = N/A , 1 - _\ Tool deviation = 14° I / ; ■ I / 1 / \ I I I I I \ / I I I Minimum I.D. = 6.900 ins Slight Oval due to Mild Buckling I I I I ConocoPhillips (a ilikttribut ogle & IVY T OD-123 W ellbore AGI/UW I Field Name Well Status Inc! C) ND OMB) Act Btm (MB) rAlpa KUP 500292291400 WEST SAK PROD 64.25 3.544.65 6,055.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (It) Rig Release Date i ... Well Coats - 1D - 123 1/25rz0io n 12 .'3 ,SSSV: NONE 0 8/7/2009 Last WO: 9/29/2005 112.10 12/29/1998 SmamMic - Arius1 Annotation Depth (ftKB) End Date Am otatlon Last By End Dale Last Tag: Rev Reason: Reset Pump Assy. GLV C/O Imosbor 1/25/2010 Casing Strings Strin OD Stang ID Set Depth Set Depth (TVD) String at Sbring O � Casing Description PN 15, Top PIKeI PBB (RIB) Pb Grade Suing Top Thad CONDUCTOR 16 15.062 0 121.0 121.0 62.58 H�0 WELDED i 121 SURFACE 75/8 6.750 0.0 6,039.0 4,027.6 29.70 L-80 BTCMOD • Tubing Strings Smog OD Stang ID Set Depth Set Depth (TVD) String Wt Grade" Tubing Description (in) tin) Top)WRB) (1KB) (11KB) (ibsm) Sting Top Tied TUBING 3 112 2.992 0.0 5,356.0 3,379.9 9.30 L -80 EUE 8rd Li Hea[Trace._ ' 3.ozs Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) ESP MANDREL, 1 Top Depth 4,146 y (ND) Top Ind / Top (RIB) ( ) C) Description Comment dm Date ID (In) /ii 3,025 1,887.7 62.94 Heat Trace HEAT TRACE 9/25/2005 ' 4,146 2,420.9 55.80 ESP CAMCO/KBGM/1 /DMV /BK-S// / Comment: STA 1 9/25/2005 2.920 ESP C MANDREL • MANDREL, B...=4 5,248 3,279.1 21.05 ESP CAMCO /KBGM/1 /SOV /BK- 5//20001 Comment STA 2 1/5/2010 2.920 MANDREL 5,298 3,325.6 20.74 SLIPSTOP TUBING STOP (OAL= 21.75) 1/23/2010 1.500 i i �= 5,300 3,327.5 20.73 PACKOFF 3.5" D &D PACKER/STINGER ASSEMBLY (OAL= 96.5 ") 1/23/2010 1.610 alPSroP, s.z9e 5,308 3,335.0 20.68 PUMP 3.5" TTC PCP ESP (OAL4'5") 8/10/2008 t 5,309 3,335.9 20.67 NIPPLE CENTRILIFT SLOTTED NIPPLE 9/25/2005 PACKOFF, ' � 5,329 3,354.6 20.55 GAUGE BAKER GUARDIAN GAUGE 9/25/2005 3.500 5.300 .i 5,338 3,363.0 20.49 INTAKE TTC CROSSOVER 9/25/2005 i I .: 5,343 3,367.7 20.46 SEAL CENTRILIFT GSB3 DB LT FERILH6H SEAL ASSEMBLY 9/25/2005 • 5,357 3,380.8 20.37 GEARBOX CENTRILIFT GEAR REDUCER 11:4:1 525 SERIES 9/25/2005 NIPPLE, 5,309 - 1 i �' 5,359 3,382.7 20.36 MOTOR 57 HP 1315/26 KMH w/motor centralizer 9/25/2005 5,367 3,390.2 20.31 Centralizer CENTRILIFT MOTOR CENTRALIZER 9/25/2005 i PUMP. 5,308 yy Perforations & Slots Top (ND) Bun (TVD) Dens GAUGE. 5.329 I Top (ItKB) Ben MKS) ) MD) ) PIX Shot B) Zone Dale ND- type Comment I 5,513 5,545 3,527.8 3,557.9 WS D, 1D-123 12/18/1998 12.0 IPERF 4 1/2" HSD BigHole Chrgs '' f 5,577 5,610 3,588.0 3,619.2 WS B, 1D-123 12/18/1998 12.0 IPERF 4 1/2" HSD BigHole Chrgs Irviwo 5 930 - E 5,612 5,643 3,621.1 3,649.0 WS A4, 1D -123 12/18/1998 12.0 IPERF 4 1/2" HSD BigHole Chrgs 5,668 5,688 3,672.9 3,692.1 WS A3, 1D-123 12/18/1998 12.0 )PERF 4 1/2" HSD BigHole Chrgs •• 5,698 5,718 3,701.6 3,720.7 WS A3, 10-123 12/18/1998 12.0 IPERF 4 1/2" HSD BigHole Chrgs allY 5,738 5,790 3,739.9 3,789.6 WS A2, 1D -123 12/18/1998 12.0 IPERF 4 1/2" HSD BigHole Chrgs SEAL. 5.343 GEARBOX. - • 5.357 MOTOR, 5,359 Centralizer. 5,367 1 I IPERF, ' 5.513-5.545 1 PE6 I 5,577-5,610 RE, 1 PERF. I 6125,643 PERF, I 508-5,688 i IPERF. 5,698 -5,718 I IPERF. 5,7385.790 I '.. • II SURFACE. 8,039 N TD, 8,055 Brett Packer Page 12 of 26 6/17/2011 1 • • 1 I CASING / TUBING / LINER DETAIL Tubing or Csq Description WELL: 1D-123 ARCO Alaska, Inc. DATE: 9/5/1998 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES I # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS I RKB to landing Ring 40.50 Vetco Gray Fluted Mandrel Casing Hanger & Pup 2.55 40.50 23 Jts. 7 -5/8" 29.7# L -80 ABM -BTC Casing (jts #118 - #140) 973.08 43.05 Tam Port Collar 2.43 1016.13 I 104 Jts. 7 -5/8" 29.7# L -80 ABM -BTC Casing (Jt #14 -117) 4421.05 1018.56 Marker Pup Jt. 7 -5/8" 29.7# L -80 ABM -BTC Casing 21.05 5439.61 Marker Pup Jt. 7 -5/8" 29.7# L -80 ABM -BTC Casing 21.90 5460.66 11 Jts. 7 -5/8" 29.7# L -80 ABM -BTC Casing (Jts #3 -#13) 470.31 5482.56 I GEMOCO Float Collar PBTD 1.32 5952.87 2 Jts. 7-5/8" 29.7# L -80 ABM-BTC Casing (Jts. #1 ) 83.29 5954.19 GEMOCO Float Shoe 1.49 6037.48 1 6038.97 Marker Jt. Between Jt. #13 & 14 1 TAM Port Collar Between Jt#117 & 118 Centralizers I Jt. #1 Bow spring on stop collar in middle of Jt. Jt.#2 2 Spiroglide centralizers w/ stop collar in middle of Jt. Jt. #3 Bow spring on stop collar in middle of Jt. I Jt.#4 -13 2 Spiroglide centralizers w /stop collar in middle of each Jt.(20 total) Bow spring on cplg. Of 16, 19, 22, 25, 28, 31, 34, 37, 40, 43, 46, 49, 52,55, 58, 61, 64, 67, 70, 73, 76, 79, 82, 85, 88, 91, 94, 97, 100, I 103, 106, 107, 110, 113, 116, 119, 122, 125, 128, 131, 134, 137 41 Total ' 10 jts to stay in shed #141 - #150 1 1 Remarks: String Weights with Blocks: ? ?K# Up, ? ?K# Dn, 8K# Blocks. Ran ? ?? joints of tubing. Drifted tubing, GLMs, & hanger with 2.867" plastic rabbit. Used Arctic Grade API Modified No Lead 1 thread compound on all connections. Tubing is non - coated. 1 Parker Rig #245 Drilling Supervisor: Cunningham /Lutrick 1 Brett Packer Page 15 of 26 6/17/2011 1 1 0 • 1 1 ARCO ALASKA INCA TUBING TALLY 1 PAGE: 1 of 2 WELL NUMBER: 1D-123 RIG: Parker Rig #245 TUBING DESCRIPTION: 7 5/8 "29.7# L -80BTC -Mod 1 DATE: 4 Sept. "98" 1 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 '<= 42.48 26 42.97 51 43.17 76! 43.22 101 41.38 126 42.98 151 176 2 : 40.81 27 43.35 52: 43.12 77 41.89 102 43.42 127; 42.99 152 177 I 3 " 4288 28; 4253 53 4222 78 4164 ;103; 4016 128 4350 153 178 4 43.36 29 38.65 54 43.38 79 42.53 104 42.79 129 41.22 154 179 1 42.91 30 39.80 56. 43.27 80 43.27 105 41.06 130 36.28 155 180 6 43.60 31" 42.54 56 43.21 81 42.99 108:'' 43.42 131 43.24 156 181 I 41.73 32 41.02 r 57 43.28 82 ! 40.43 107 39.14 132 41.04 157 182 , 43.16 33 42.88 58 r 43.38 83 43.50 108 41.59 133 ! 43.38 158 183 9 43.37 34 42.16 59 43.19 84 43.11 .1E013_ 41.14 134 41.13 159 184 I 1*.f; 40.39 35 43.32 60 43.33 8.5' 110 42.99 135 43.07 160 185 % 41.98 36 43.11 61. 41.39 86 40.76 111 40.31 136: 40.40 161 186 43.44 37 ! 43.35 62 43.22 87 43.09 112 41.05 137 43.13 162 187 43.49 38 42.24 63 43.45 88. 41.47 113 43.49 138 43.24 163 188 I 14 43.47 39 43.44 64 43.23 89 43.23 114 40.69 139 43.00 164 189 15 41.25 40i 43.20 65 43.44 90 43.25 115: 3 9.01 140 42.25 165 190 41.66 41 43.46 66 43.50 91 43.16 116 43.00 141 43-44 166 191 I 17 43.50 42 42.37 67, 43.60 92 43.19 117 43.01 142 40,98 167 192 18 41.41 43 42.22 68 41.99 93 38.98 418` 42.99 143 40 168 193 43.49 44 43.33 69 43.50 94 , 43.35 119 43.13 144 42790 169 194 20 42.10 45 43.25 70 43.00 95 43.41 120 43.46 145 X13.37 170 195 I 21 42.59 48 43.28 71 41.74 96 43.24 121, 43.42 146 4 10.70 171 196 43.35 47 40.96 72 42.99 97 - 43.23 122 43.49 147 43.27 172 197 23 43.14 48 43.47 73:' 43.44 98 43.25 123 40.38 148 43.37 173 198 I 24 43.16 "49 43.23 74 43.50 99 42.99 1241 42.98 149 X13.23 174 199 i 43.13 50 43.16 75 42.06 400 41.59 125 42.38 150 44-60 175 200 Tot 1065.85 Tot 1063.29 Tot 1075.60 Tot 1062.26 Tot 1049.88 Tot 1055.40 Tot Tot I TOTAL LENGTH THIS PAGE = 6372.28 DIRECTIONS: TOTAL JOINTS THIS PAGE = 150 1 1 1 1 1 1 Brett Packer Page 16 of 26 6/17/2011 1 • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RECEIVED AUG 16 2QVV August 12, 2011 paiks 01 & caw &ommission Anttlst r Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 i' )AUI 2U'6 Commissioner Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., well 1D -123, PTD 198 -170, Sundry 311 -211 surface casing repair. Please call MJ Loveland or Martin Walters at 659 -7043 if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor . STATE OF ALASKA • ALASKA AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations J Stimulate r Other p Welded SC Patch Alter Casing r Pull Tubing f Perforate New Pool fl Waiver f Time Extension Change Approved Rogram r Operat. Shutdown fl Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 198 -170 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r 50- 029 - 22914 -00 "($) 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650 • ' 1D-123 9. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 6055 feet Plugs (measured) None true vertical 4043 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 0 true vertical 0 feet (true vertucal) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 121 121 PRODUCTION 5998 10 6039 4028 6890 4790 SLEEVE 97" patch fabbed from 10" .500 wall X65 pipe RECENED Perforation depth: Measured depth: 5513 -5545, 5577 -5643, 5668 -5688, 5698 -5718, 5738 -5790 AUG z�11 True Vertical Depth: 3528 -3558, 3588 -3649, 3673 -3692, 3702 -3720, 3740 -3790 Mika 011 & Gas Caw Gcmmission Tubing (size, grade, MD, and TVD) 3.5, L -80, 5329 MD, 3354 ND Anchorage Packers & SSSV (type, MD, and ND): Weatherford Hydroflow II @ 3370' MD, 2049' TVD 11. Stimulation or cement squeeze summary: NA Intervals treated (measured): 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 NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development ''- Service r Stratigraphic E 15. Well Status after work: Oil p • Gas r VVDSPL r Daily Report of Well Operations X GSTOR r WINJ r WAG r" GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -211 Contact MJ Loveland /Martin Walters Printed Name Martin Walters Title Well Integrity Project Supervisor Signature 4... Phone: 7043 Date: 08/13/11 RBDMS AUG 16 201* u 1 Form 10 -404 Revised 10/2010 Submit Original Only • • 1D-123 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07123/111 Remove 10' of conductor. Chip cement & clean production casing for UT inspection. 08/03/111 Made final cut on conductor (11' 5 3/4 ") 08/08/11 Installed wedding bands on SC. Collars made from 8" x 65 .500 pipe and are 6" long, Welders installed sleeve made from 10" x 65.500 pipe and is 8' 3" long, total length is 8' 8 1/2" long. 08/09/11 Post SC repair MITIA. (Passed) Pressured up IA to 2500 psi for 1 hour test.Starting pressure= SI/2500, 15 min= Sl/2450, 30 min= SI/2450, 45 min= SI/2450, Ending= S1/2450, Bleed down IA, Final T/I =SILO 08/10/11 Insulators denso wrapped production casing. Welders installed 11' 5" 16" x 62.58# .375" conductor casing .), 4 . - • - - . ! ' • -,-,. ''.... t • . ■ . • 0 ,,, • ' -- . • - * . . • • _ .. -• " .. . - — 0 - - _ ' - — - t • - - - . • - ..' ' -.-- — - * _ — , — — - .. • — - - — - • - - — — . . , , . • • . . y - - • 4 . • ,..,-. -. ' , , , . • . , . . -.• - • 't . - . . . , • ' . o. 41 , . . . . I ' 11 . 4 .... '.... .1. . Afitt . . . ir ... ',.. 4 - : ' — `'.,, t `N k -' , ::+.*'.. C.,":■'',,l."''', . -, - , • • ' '' .‘''' " '' ' ' ■-- •.- '` - -"" \ '''' • ©ConocoPhillips Alaska, Inc , , I , , • ' ' ■ This photo is copyright by •0 ` . , •.. ConocoPhillips Alaska, Inc. .. -•-•' ..i.."--. .-- - ..- - ,,C:-. •,, ' 04 and cannot be released or .4. 7- lit ri , . . .... _ .., published without express 4i . , . written consent of .,.. , . .. . ConocoPhillips Alaska . - •, •,,,,,, . • , -•-• . -,-•",1 ' , • . : ,..;,,,1 4 1,4 ' •4` . ..,..ell 'I' '. 1 :4 ' 4' lf'!''" t i: i : " . ' : : , ' / . ..‘ ' ' /01 :4°'' .; . '' ' 1,,,,...7 '■■:' ' 4 : 4 ,14 i .1: ■• , • ' ' 0' ' .46" ; ,,,‘ ',' I. ' " • . ' . ' ' ' '. , . ' 0 1111111'S.' - .....1■16......... . ....itri-:,:e--,Iff..i.:. '/,,,*.'f.t .;-,,,,,:`,,,..,,, Alti, , ii-: .7..1v164 ,i, 1.; 3. I' , : : • : ., - . 11 11 lk i , ( , I Is, t , . if . '",,,,, ■ ':', I' .4. . :Vo , -/,. , r,,i,,,,,,,,,,,,-,.,-1 4" ' 0 4 , 1 jfkr ' ,, ,-;', •, ' '‘( '.; ix f ,4.. " i i i A 7 . , 7, f011A,' . 1(4 .1 . ,, ,,,:-. ''''.::: ' "' ' i , ' // 5.4'; : ' '," • :if, :` "" :, ' : , " , ' ' ' ., . ,,,,,,...., •-• .•",,, .. . , . :411111 • 1 . A • Nk.,* •":`:" ; , . , • . . , . , ti h, : ..i ,, 41111111%. pnocoPhiilips Alaska, Inc photo is copyright by , ‘i ) ocoPhillips Alaska, Inc. cannot be released or •Ilshed without express n conqPnt of ocoPhillips Alaska ''''' . ,s i .‘t, • :iik A. t I . . i.; , v. .... ..,...„. . 1 , ,.. _ t , • •• • e . ,' , r . , . ! : I I p i .fr.. I . L 't• , L„.„, ......, ■ ,.:',..' , . . " . ' : ,,,, Ple , .,,...,.' : ''''Allit . 4 1 4 . ,.. . , \ *' I . •.. 1 . ... .......— ` STATE OF ALASKA ALASKA •AND GAS CONSERVATION COMMISS• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Perforations r Stimulate r Other ES 1' C/o Alter Casing r Pull Tubing izi Perforate New Pool r Waiver r Time Extension r Change Approved Program j"- Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: - ConocoPhillips Alaska, Inc. Development Fi Exploratory r `+ 198 -170 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r * 50- 029 - 22914 -00— 00) 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650 • . 1D-123 9. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 6055 feet Plugs (measured) None true vertical 4043 feet Junk (measured) None Effective Depth measured 6023 feet Packer (measured) 3370, 5402, 5800 true vertical 4012 feet (true vertucal) 2047, 3423, 3799 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 121 121 PRODUCTION 5998 7.625" 6039 4028' �° :, 'I, t ""- GRAVEL PACK 400 4.5" 5802 �1 3801' -�" 4, LINER ;' ti 41UL �} 5 Ln fi Perforation depth: Measured depth: 5513'- 5545', 5577'- 5610', 5612'- 5643', 5668'- 5688', 5698'- 5718', 5738' -5790' ' " '' True Vertical Depth: 3528'- 3558', 3588'- 3619', 3621'- 3649', 3673'- 3692', 3702'- 3721', 3740' -3790' Tubing (size, grade, MD, and TVD) 3.5, L -80, 5353 MD, 3354 TVD Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD HYDROFLOW II DUAL STRING PACKER @ 3370 MD and 2042 TVD PACKER - GRAVEL PACK PACKER @ 5402' MD and 3423' TVD PACKER - BAKER FB -1 RETAINER PRODUCTION PACKER @ 5800' MD and 3799' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable 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 223 62 84 -- 169 Subsequent to operation shut -in 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development RI * Service r Stratigraphic I 15. Well Status after work: Oil Re Gas r WDSPL r Daily Report of Well Operations XXX GSTOR E WINJ r WAG r GINJ 1 — SUSP r SPLUG r" 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact J. Brett Packer @ 265 -6845 Printed Name J. Brett Packer Title Wells Engineer Signature . 73_ 7 Phone: 265 -6845 Date 7/2 j l f( Form 10 -404 Revised 10/2010 RBDMS JUL 2 7 2011 7%7g Submit Original Only : • KU P 1D-123 ConacoPild lips , we 1 Attrib tes Max Angle & MD TD ` ' Wellbore APVUWI F m ld N e Well Status Inc! () MD (ftKB) Act Btm (BOB) c.c.xx+c -�N uw• 500292291400 I WEST SAK PROD 64 25 l 3,544.65 6,055.0 Cy st NONE H2S ( !Annotation End Date KB - Ca1d . Rig 2 Date nt - arT SSS NONE 0 I 9/15/2011 0 (Last I W WO: 6,'26/2011 112.10 12/2/2 9/1998 '91T•' I>iC•J' 11 1. 5 3 P � "-` _ _ , 0 " """" .+... ".a g � , A otation Depth (ftKB) End Date Annotation Last Mod ... End Date Rev Reason WORKOVER 1 ninam 7/14/2011 Casing Strings . - 4g • Casing Description String 0... String ID ... Top (kKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd HANGER,41 '' CONDUCTOR 15.062 40.5 121.0 121.0 62.58 H WELDED :.... Casing Description String 0... String ID ... Top (PoB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 5/8 6 875 40.5 6,039.0 4,027.6 29.70 L-80 ABM -BTC . Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String WL.. String ... String Top Thrd Gravel Pack Liner 4 1/2 4.000 5,402.3 5,802.4 3,801.4 It .finer Details - � -,17a7411911 Top Depth ''• (ND) Top Inc! Nomi... ` r r 41 -12 Top (MB) MKB) C) Item Description Comment ID (in) 5,402.3 3,423.4 20.09 PACKER SIZE 76B2-40, MODEL SC -1 GRAVEL PACK PACKER w/ 5.5" 4.000 SEAL -LOCK HT BOX DOWN 5,406.5 3,427.4 20.06 UPPER EXT 80-40 UPPER EXTENSION 4.880 5,410.9 3,431.5 20.03 SLEEVE 80-40 GRAVEL PACK SUDING SLEEVE 4.380 GAS LIFT, - - 5,412.4 3,432.9 20.02 SBE 80-40 SEAL BORE 4.000 3,246 5,414.4 3,434.8 20.01 LOWER EXT 80-40 LOWER EXTENSION 3.940 5,430.8 3,450.2 19.91 SOS SHEAR OUT SAFETY JOINT 3.940 5,494.1 3,510.0 19.51 SCREEN BAKERWELD GRAVEL PACK SCREEN 4.000 di ll°111.- 5,799.1 3,798.2 17.05 SEAL ASSY BAKER S -22 SNAP LATCH ASSEMBLY - 3.930 -- 5,800.0 3,799.1 17 -05 PACKER BAKER FB -1 RETAINER PRODUCTION PACKER 4 - 000 Tubing Strings Tubing Des pt on String O Sating ID ... Top (HKB) Set Depth (f -.. Set Depth (ND) ...ring g Wt_. String String Top Thrd II-- TUBING WO 3 1/2 1 2 992 40.5 5,352 8 I 3,376 9 L 930 L-80 EUEBrdABMOD t r _ 3g �Q w) W GAS LIFT. Com tion Details Top Depth ,483 (TVD) Top Intl Nomi... ToP (BOB) (ftKB) (C) Item Description Comment ID (in) - :. 40.5 40.5 -1.55 HANGER Vetco 10 3/4" CWCT TBG Hanger w/ 4.909" MCA lift threads. 2.990 Bore= 2.950 "; H221212 -1; HN C7313 3,370.4 2,046.8 65.65 PACKER WEATHERFORD HYDROFLOW II DUAL STRING PACKER S/N 2.992 GUAGE, 5,263 - 31359147 - 5,263.0 3,293.1 20.96 GUAGE WELLLIFT DISCHARGE GUAGE UNIT 2.992 5,319.4 3,345.6 20.61 INTAKE TTC RECIEVER/CROSSOVER W/ PERFORATED INTAKE 2.992 Ir 5,324.8 3,350.7 20.57 SEAL CENTRIUFT TOP SEAL SECTION - 5,331.7 3,357.2 20.53 SEAL CENTRIUFT BOTTOM SEAL SECTION INTAKE, 5,319 :; 5,338.6 3,363.6 20.49 GEARBOX CENTRILIFT GEAR REDUCTION UNIT SEAL, 5,325 5,340.4 3,365.3 20.47 MOTOR CENTRIUFT ESP MOTOR, 76 HP, 1360/34 KMHG 1360 V/34 A T -1 SEAL, 5,332 - z r 5,348.7 3,373.1 20.42 GUAGE BHI WELLLIFT MOTOR GUAGE - -- GEARBOX, __. 5,350.8 3,375.0 2041 Centralizer CENTRILIFT MOTOR CENTRALIZER 5.339 I MOTOR, 5,340 - -- Perforations & Slots GUAGE, 5,349 . 0 Shot Top (TVD) Btm (TVD) Dens Centralizer, Top (ftKB) Btrn (BOB) (BOB) (ftKB) Zone Date ls•••• Type Comment 5,351 1 1 5,513 5,545 3,527.8 3,557.9 WS D, 1D-123 12/18/1998 12.0 IPERF 4 1/2" HSD BigHole Chrgs 5,577 5,610 3,588.0 3,619.2 WS B, 1D -123 12/18/1998 12.0 IPERF 4 1/2" HSD BigHole Chrgs 5,612 5,643 3,621.1 3,649.0 WS A4, 10 -123 12/18/1998 12.0 IPERF 4 1/2" HSD BigHole Chrgs 5,668 5,688 3,672.9 3,692.1 WS A3, ID -123 12/18/1998 12.0 IPERF 41/2" HSD BigHole Chrgs - -` 5,698 5,718 3,701.6 3,720.7 WS A3, 1D -123 12/18/1998 12.0 IPERF 41/2" HSD BigHole Chrgs ,r 5,738 5,790 3,739.9 3,789.6 WS A2, 1D -123 12/18/1998 12.0 IPERF 4 1/2 HSD BigHole Chrgs Notes: General & Safety End Date Annotation 8/19/2010 NOTE: View Schematic w/ Alaska Schematic9.0 IPERF, i T 5,513 -5,545 IPERF, 5,577 -5,610 IPERF, 5,612 - 5,643 ,,, IPERF, •P - 5.668 -5,688 f ° . Mandrel Details IPERF, Top Depth Top Port 5,698 -5,718 (TVD) Incl OD Valve Latch Size TRO Run Stn Top (fKB) (ftKB) (°) Make Model (in) Sem Type Tyne (in) (Pal) Run Date Can... 1 3,246.1 1,987.3 63.55 CAMCO KBMG 1 GAS LIFT DMY BK - 5 0.000 0.0 7/10/2011 IPERF, 2 3,483.3 2,092.4 64.74 CAMCO KBMG 1 GAS LIFT DMY BK - 5 0.000 0.0 6/2612011 5,738 -5,790 ,pii Gravel Pads Liner, _ -- 5,402 -5,802 PRODUCTION, 41- 6,039 A TD, 6,055 • • Time Log & Summary ConocoPhillips W'enview Web Reporting Report Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 6/19/2011 10:00:00 PM Rig Release: 6/28/2011 3:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/18/2011 24 hr Summary Conduct Non - standard rig move from 3H -12 to 3H Pad entrance, repair broken Tugs on tires. Conduct Non - standard rig move from 3H -12 to 1Q Pad 07:00 07:30 0.50 MIRU MOVE DMOB P Move to 3H -Pad entrance 07:30 08:30 1.00 MIRU MOVE DMOB P Shuffle mats ahead of rig 08:30 15:00 6.50 MIRU RIGMNT RGRP T Found broken lugs and replace same 15:00 18:00 3.00 MIRU MOVE DMOB P Road Nordic Rig 3 from 3 H Pad to 31 Pad Access 18:00 19:00 1.00 MIRU MOVE DMOB P Shuffle mats ahead of rig 19:00 00:00 5.00 MIRU MOVE DMOB P Road Nordic Rig 3 from 3 I Pad Access to 1Q Pad Access 06/19/2011 Conduct Non - standard rig move from 1Q -Pad to 1D Pad. MIRU. 00:00 05:00 5.00 MIRU MOVE DMOB P Road Nordic Rig 3 from 1Q Pad to 1R Pad Access 05:00 08:00 3.00 MIRU MOVE DMOB P Standby for CPAI Kuparuk Field crew change & stage mats ahead of the rig. 08:00 11:00 3.00 MIRU MOVE DMOB P Start moving rig again from 1R turn- off to .4 miles past KIC three way stop. 11:00 11:30 0.50 MIRU RIGMNT SFTY T Held PJSM on removing and replacing inside tire. 11:30 18:00 6.50 MIRU RIGMNT RGRP T remove and replace inside tire. 18:00 20:30 2.50 MIRU MOVE DMOB P Continue to Move rig from .4 miles past KIC three way stop to 1D Pad 20:30 22:00 1.50 MIRU MOVE RURD P Build mat ramp to climb up on double mats. Spot rig and berm up. Spot rig equipment and load pipe shed with Test jt, landing jt, and Lubricator. Accepted Nordic rig at 22:00 hrs on 6 -19 -11 22:00 00:00 2.00 MIRU 06/20/2011 Continue to RU auxilary equipment. Filter and heat 3% KCL. Kill Well 00:00 06:00 6.00 MIRU MOVE RURD P Lay spill containment for filter equipment, lay down area and kill tank area. Spot auxilary equipment and berm up same. Lay kill line to kill tank from rig. Load, rack and Tally 200 jts of 3 1/2, 9.3#, L -80 8rd AB Mod. and drift same to 2.867 ". Page 1 of 10 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 14:00 8.00 COMPZ MOVE RURD P Mi filtering water. LRS to heat water to 170 degs prior to killing the well. Hoist up ESP sheave up in the derrick. 14:00 14:30 0.50 COMPZ WHDBO MPSP P PJSM, Pull BPV. TBG on a slight vac. IA @ 550 psi. 14:30 17:00 2.50 COMPZ WELCTL COND P LRS has first tanker of 290 bbls of 3% KCL Brine almost to 180 °F temp. The second tanker of 290 bbls of 3% KCL Brine is still getting filtered. 17:00 19:00 2.00 COMPZ WELCTL PRTS P Pressure test kill lines to 250 / 3,000 psi and open IA to choke manifold. Prepare to bleed off gas to Kill tank. 19:00 00:00 5.00 COMPZ WELCTL CIRC P Bleed IA from 550 psi to 0 psi. Begin reverse circulating with 3% KCL at 170 °F at 3 bpm at 60 psi ICP. Took 53 bbls to get circulation. Pump 290 bbls with 115 bbls recovered. Pump 2nd load of 290 bbls 3% KCL at 170 °F at 3 bpm at 3 bpm at 60 psi. ICP. 06/21/2011 Kill Well and ND Tree. NU BOPE. Test BOPE 00:00 01:00 1.00 COMPZ WELCTL CIRC P Continue to reverse circulating with 3% KCL at 170 °F at 3 bpm at 130 psi ICP. Took 23 bbls to get circulation. Pump 290 bbls with 165 bbls recovered. 01:00 05:00 4.00 COMPZ WELCTL COND P Continue to filter 3rd load of 290 bbls of 122 °F 3% KCL. 05:00 05:30 0.50 COMPZ WELCTL CIRC P Circulate 3rd load of 3% KCL Brine at 5 bpm at 140 psi taking returns to rig pits. 05:30 06:00 0.50 COMPZ WELCTL OWFF P Monitor well for flow - No flow present 06:00 06:15 0.25 COMPZ WHDBO SFTY P Held PJSM with rig crew and Vetco Gray rep on dry rod setting of 'CIW Type "H" BPV 06:15 06:45 0.50 COMPZ WHDBO MPSP P Dry rod and set the 'CIW Type "H" BPV, Lay down and store dry rod 06:45 07:15 0.50 COMPZ WHDBO SFTY P Held PJSM on ND of Vetco Gray 3 1/8" 5M x 11" 5M Tree and Adapter, Inspecting 4.909" TBG hanger lift threads and Installing Blanking plug. Held Sim ops meeting with Crane operator and assigned rig crew for lifting and setting ESP spooler and empty spool. along with lifting and installing of guard rails. 07:15 08:30 1.25 COMPZ WHDBO NUND P ND the Vetco Gray 3 1/8" 5M x 11" 5M Tree and Adapter, Inspecting 4.909" MCA TBG hanger lift threads and Installing Blanking plug. Sim ops lifting and setting ESP spooler and empty spool. along with lifting and installing of guard rails. Page 2 of 10 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 08:45 0.25 COMPZ WHDBO SFTY P Held PJSM with rig crew assigned to NU of 11" BOPE 08:45 13:00 4.25 COMPZ WHDBO NUND P NU of 11" BOPE. Install 6 -ft Riser Continue with Sim ops lifting and setting ESP spooler and empty spool. along with lifting and installing of guard rails. 13:00 13:30 0.50 COMPZ WHDBO SFTY P Held PJSM with crew on RU and Testing of BOPE at 250 / 3,000 psi on 3 1/2 8rd FOSV, LPR's, Blinds and UPR's with 3 1/2 Test jt, along with testing of Annular at 250 / 2,500 psi with 3 1/2 Test jt. 13:30 17:00 3.50 COMPZ WHDBO BOPE P RU and Test BOPE at 250 / 3,000 psi on 3 1/2 8rd FOSV, LPR's, Blinds and UPR's with 3 1/2 Test jt, along with Annular at 250 / 2,500 psi with 3 1/2 Test jt. Annular failed. 17:00 17:30 0.50 COMPZ WHDBO SFTY T Held PJSM with rig crew on removing and replacing 11" 5M Annular element. 17:30 22:00 4.50 COMPZ WHDBO RGRP T Drain BOP Stack, remove riser, pull and replace annular element. Install riser and fill BOP stack in preparation for test. 22:00 23:30 1.50 COMPZ WHDBO BOPE P Continue to Test BOPE at 250 / 3,000 psi on LPR's with 2 7/8 Test joint, along with Annular at 250 / 2,500 psi with 2 7/8 jt and 3 1/2 Test jt. Draw Down - 2,950 System Pressure 18 second for 200 psi to full pressure 96 seconds for 0 psi to full system pressure 4 N2 Bottles at 2,050 psi 24 Hr notice was given to AOGCC at 07:30 hrs on 6 -19 -11 and Waived by Bob Noble at 10:00 hrs on 6 -20 -11 23:30 00:00 0.50 COMPZ WHDBO MPSP P Pull Blanking plug and BPV. Install side isolation sleeve. 06/22/2011 MU LJ, BOLDS, Unland hanger, circulate surface to surface, POOH, laying down TBG and completion / components. Gather samples from ESP conponents. 00:00 02:00 2.00 COMPZ WELLPF OTHR P MU landing joint while continuing to filter KW fluid 02:00 03:00 1.00 5,367 5,348 COMPZ WELLPFTHGR P BOLDS, Unland hanger at 145k and pull from 28 -ft to 9 -ft with TBG hanger at 95k up wt. Page 3of10 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 07:00 4.00 5,348 5,367 COMPZ WELLPF CIRC P Attempt to circulate with 34 bbls to fill hole - had oil cap, reland TBG hanger. Pump 216 bbls down TBG taking returns to kill tank with oil cap., cleaned up after 200 bbls - ran out of filtered KWF - monitor well while waiting for next 290 bbls of filtered KWF. Pump additional 100 bbls to remove oil cap on IA. 07:00 09:30 2.50 5,367 5,367 COMPZ WELLPF PULD P Pull hanger to rig floor, disconnect esp cable and trace line from hanger. Hang heat trace sheave. UD hanger assembly and two joints. 09:30 13:30 4.00 5,367 4,256 COMPZ WELLPF PULL P Run heat trace and ESP cable through sheaves. Start OOH with 3.5" ESP completion, triple displace pipe displacement. 13:30 14:30 1.00 4,256 4,256 COMPZ WELLPF OPNW P Monitor for flow. Filter additional SW and load trip tank. Offload 30 joints of decompletion from pipe shed. 14:30 22:30 8.00 4,256 38 COMPZ WELLPF PULL P Continue to POOH w/ 3.5" decompletion, continue to triple displace pipe displacement. 22:30 00:00 1.50 38 0 COMPZ WELLPF OTHR P Pulled to Hi - pot and clipped motor 3 -ft above and band same to the motor, RIH to top of seal and gather samples of oil from the Seal unit and motor. 06/23/2011 Inspect shafts and bearings on ESP comnponents, and lay down same in shipping boxes. Clean clear rig floor. PU and RIH w/ C/0 BHA #1 on 3 1/2 TBG - Picking up all. 0/0 to 5,790 -ft ±, Circ clean. POOH ✓ standing back 3 1/2 and laying down BHA #1. PU a • :. _••-•1 - _ , - • • I -. 00:00 02:00 2.00 0 0 COMPZ WELLPF PULD P Break down, inspect ESP equipment, load in shipping boxes Recovered 465- 5 ft mid joint dual channel 2- 4 ft mid joint dual channel 7- 3 ft mid joint dual channel 6- 2 ft mid joint dual channel 54- DC cross couplings 44- SC cross couplings 18- SS flat bands 2- flat guards 3- protectolizers According to 05 workover paperwork we are 14 short of 5 ft mid joint dual channels, 3 short of 4 ft mid joint dual channels & 6 short of SS flat bands. All ESP equipment turns smoothly and appears in good shape. 02:00 03:30 1.50 0 0 COMPZ WELLPF OTHR P Unload pipe shed, clean & clear rig floor. 03:30 04:00 0.50 0 0 COMPZ WELLPFOTHR P Install wear ring. 04:00 07:30 3.50 0 1,081 COMPZ WELLPF PULD P PU Baker clean out assembly (BHA #1) Page 4of10 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 08:00 0.50 1,081 1,081 COMPZ WELLPF OTHR P Prep ESP spool for shipment. 08:00 14:00 6.00 1,081 5,790 COMPZ WELLPFTRIP P TIH w/ BHA #1 on 3 1/2" TBG to 5,765'MD. MU head pin & pump down tubing to fill pipe, add additional joint and dry tag @ 5,789'MD. MU head pin, attempt to pump down tubing several different rate to loosen debris, unable to work pipe below 5,790'MD, right at bottom perfs. Decision made not try reverse circulating with minimal pump pressure on backside. Town Enginneer good with depth. 14:00 16:00 2.00 5,790 5,790 COMPZ WELLPF OTHR P AES crane arrived on location. Offload old ESP & Heat trace spools from rig floor. Load new ESP spool. 16:00 19:00 3.00 5,790 1,080 COMPZ WELLPFTRIP P POOH w/ BHA #1 and stand back 50 stands of 3 1/2" EUE 8rd tubing in derrick. 19:00 20:00 1.00 1,080 767 COMPZ WELLPFTRIP P POOH standing back 4 3/4" DC's and laying down Baker tools from 1,080 -ft to 767 -ft. 20:00 21:00 1.00 767 0 COMPZ WELLPF PULD P POOH from 767 -ft laying 2 7/8 PAC DP and mule shoe 21:00 22:00 1.00 0 0 COMPZ WELLPF OTHR P Kick out Baker tools and 25 jts of 2 7/8 PAC DP. Bring in Test packer components. 22:00 00:00 2.00 0 2,670 COMPZ WELLPF TRIP P PU and RIH w/ Tandem Test Packer assy to 2,670 -ft 55k up wt, 52k dn wt. X6/24/2011 Continue to RIH w/ Tandem Test Packer to 5,350 -ft. Set RBP - POOH to 3,275 -ft. Set Test PKR and Test below to 2,500 psi and IA to 500 psi. POOH w/ Test PKR and RIH w/ TBG to 5,320 -ft. Dump 250# of sand on RBP. 00:00 01:30 1.50 2,670 5,350 COMPZ WELLPF TRIP P Continue to RIH w/ Tandem Test Packer assy from 2,670 -ft to 5,350 -ft. 01:30 02:00 0.50 5,350 5,350 COMPZ WELLPF PACK P Attempt to set Baker Model "G" Lockset Bridge plug at 5350 -ft, unable to set RBP, up slips would grab, down slips would only take 2 to 4k max weight, release RBP. 02:00 02:30 0.50 5,350 5,350 COMPZ WELLPF SFTY P Held PJSM on POOH with Tandem Test Packer - having the possiblity of hanging up - awareness 02:30 04:00 1.50 5,350 3,275 COMPZ WELLPF TRIP T POOH f/ 5350 -ft to 3275 -ft, attempt to test IA w/ retrievamatic test packer 54k up wt. 51k dn wt. 04:00 04:30 0.50 3,275 3,275 COMPZ WELLPF PACK P Set Retrievamatic Packer at 3,275 -ft and slack off 16k on packer. 04:30 05:00 0.50 3,275 3,275 COMPZ WELLPF PRTS P PT IA to 500 psi for 10 minutes on chart - Not able to get test - possible leak by packer - unable to transfer 20k down wt. - On next run will add 13k of DC wt to BHA. Page 5 of 10 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 06:30 1.50 3,275 0 COMPZ WELLPF TRIP T Bleed down & release packer and POOH from 3,275 -ft to surface, stand back 3 1/2 TBG, LD RBP & Retrievamatic test packer off load RBP f/ pipe shed. after inspection of test packer it appears test packer has debris in unloader valve, work debris out as per Baker rep. 06:30 07:00 0.50 0 0 COMPZ WELLPFSFTY P PJSM , Hang blocks, cutting slip drill line & serviceing rig 07:00 08:30 1.50 0 0 COMPZ WELLPF SLPC P Hang blocks and cut & slip drill line (84 -ft) 08:30 09:30 1.00 0 0 COMPZ WELLPF SVRG P Grease crown 09:30 10:00 0.50 0 0 COMPZ WELLPF SFTY P PJSM w/ Baker hand, running RBP & Retrievamatic test packer. 10:00 12:30 2.50 0 5,348 COMPZ WELLPFTRIP P PU MU & RIH w/ Baker RBP & Retrievamatic test packer to 5348 -ft, 75k up, 60k do 12:30 13:30 1.00 5,348 5,328 COMPZ WELLPF PACK P Set RBP as per Baker rep. PUH 20 -ft set test packer. 13:30 14:30 1.00 5,328 5,328 COMPZ WELLPF PRTS P Test RBP- passed 14:30 15:00 0.50 5,328 3,230 COMPZ WELLPFTRIP P PUH f/ 5328 -ft to 3230 -ft w/ test packer. 15:00 15:30 0.50 3,230 3,230 COMPZ WELLPF PACK P Set test packer @ 3230 -ft 15:30 16:00 0.50 3,230 3,230 COMPZ WELLPF PRTS P Test between RBP & test packer 2500 psi on chart & hold 10 min. bleed down pressure between RBP & test packer. 16:00 19:30 3.50 3,230 3,230 COMPZ WELLPF PRTS P Attempt test annulus above test packer- failed, after multiple attempts continued to fail. RD test hoses to TBG for monitoring. Test annulus 500 psi on chart & hold 10 min- passed. 19:30 20:00 0.50 3,230 3,230 COMPZ WELLPFSFTY P PJSM Tripping OOH & standing back pipe. 20:00 21:00 1.00 3,230 0 COMPZ WELLPFTRIP P POOH f/ 3230 -ft (54k) w/ test packer standing back 3 1/2 TBG, LD test packer & off load f/ pipe shed. 21:00 21:30 0.50 0 0 COMPZ WELLPF SFTY P PJSM tripping in hole 21:30 23:00 1.50 0 5,313 COMPZ WELLPFTRIP P RIH open ended w/ 3 1/2 TBG to 5313 -ft (65k up) 23:00 00:00 1.00 5,313 5,313 COMPZ WELLPF OTHR P Dump 250# 20/40 mesh sand and let settle 1 hr. 06/25/2011 Tag sand, POOH, RU e-line & run GYRO log, PDS caliper log & Baker Atlas Vertilog, RIH & wash down to 5,343 -ft and CBU (184 bbls) retrieve RBP. Circulate 198 bbls, Monitor well. POOH from 5,351 -ft to 3,494 -ft. 00:00 00:30 0.50 5,313 5,343 COMPZ WELLPF OTHR P Continue let sand settle on RBP & soft tag sand @ 5343 -ft. 00:30 01:00 0.50 5,343 5,343 COMPZ WELLPFSFTY P PJSM on POOH and standing 3 1/2 tbg back. 01:00 02:30 1.50 5,343 0 COMPZ WELLPFTRIP P POOH standing back 3 1/2 TBG f/ 5343 -ft to surface. 02:30 03:00 0.50 0 0 COMPZ EVALWEOTHR P Spot E -line equipment Page 6 of 10 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 03:15 0.25 0 0 COMPZ EVALWE SFTY P PJSM on E -line RU, Discuss open hole job 03:15 04:15 1.00 0 0 COMPZ EVALWE RURD P RU E -line sheaves, connect GYRO logging tools. 04:15 09:00 4.75 0 5,343 COMPZ EVALWE ELOG P RIH w/ GR / CCL & GYRO tool to above TOS @ 5,343 -ft. Log up to surface @ 80 fpm and stops as per Gyro rep. Good data. RDMO Gyrodata equipment. 09:00 10:00 1.00 0 0 COMPZ EVALWE ELOG T Wait on PDS caliper equipment from Prudhoe. 10:00 15:30 5.50 0 5,343 COMPZ EVALWE ELOG P MU PDS extended reach caliper assembly and string. RIH w/ caliper to TOS @ 5,343 -ft, start logging up to surface @ 12:30 at 50 fpm. On surface, check tool for data, good data. Sent data for processing @ 15:30. RDMO PDS equipment. 15:30 18:00 2.50 0 3,154 COMPZ EVALWE ELOG P MU Baker Vertilog assembly. Start in hole with logging tools, set down @ 3,154 -ft, made several attempts to pass restrictions, called town Engineer, decision made to log out of hole from restriction to surface. Log out from 3,154 -ft to surface - no problems. 18:00 18:30 0.50 0 0 COMPZ EVALWE RURD P RD Eline equipment 18:30 19:30 1.00 0 0 COMPZ WELLPF OTHR P Bring retieving head to rig floor. Bring in Cannon Clamps to rig floor. 19:30 20:00 0.50 0 0 COMPZ WELCTI SFTY P Held PJSM on MU and RIH w/ Retrieving tool for RBP 20:00 21:00 1.00 0 5,320 COMPZ WELCTI TRIP P MU and RIH w/ retieving tool to 5,320 -ft 74k up wt, 57k do wt 21:00 21:30 0.50 5,320 5,343 COMPZ WELCTL MPSP P Wash down at 10 bpm at 900 psi and wash sand down to 5,343 -ft to top of Baker Model "G" Lockset Bridge plug. CBU at (184 bbls) 3,900 stks pumped, slowed PR to 3 bpm at 110 psi, wash down 4 -ft to 5,347 -ft (seen pressure increase to 250 psi and Engage & Release RBP (pressure fell back to 110 psi)- allow elements to relax. Seen some loss in returns, then regained previous return rate. 21:30 22:30 1.00 5,343 5,343 COMPZ WELCTL CIRC P Circulate another 198 bbls of Filtered 3% KCL at 5 bpm at 290 psi 22:30 23:00 0.50 5,343 5,351 COMPZ WELCTL OWFF P Lower down to 5,351 -ft and Monitor well for flow and fluid loss 23:00 23:30 0.50 5,351 5,351 COMPZ WELCTL SFTY P Held PJSM on POOH with RBP - discuss while pulling RBP, last movement has to be in upward motion, if you over run and lower back down, there is a possiblity of releasing off RBP. Page 7 of 10 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 5,351 3,494 COMPZ WELCTL TRIP P POOH with Baker Model "G" Lockset Bridge plug from 5,351 -ft, laying down 5 jts of 3 1/2, 9.3 #, L -80 EUE 8rd AB Mod TBG and standback 54 stands in derrick. Lay down 3 jts and Baker Model "G" Lockset Bridge plug. 06/26/2011 Continue to POOH w/ RBP. PU and RIH 3 1/2 ESP recompletion. Land Hanger and PT Void . - failed. 00:00 01:30 1.50 3,494 0 COMPZ WELCTL TRIP P Continue to POOH with Baker Model "G" Lockset Bridge plug from 3,494 -ft, standing back stands in derrick. Lay down 3 jts and Baker Model "G" Lockset Bridge plug. Offload RBP and Test Packer. 01:30 02:00 0.50 0 0 COMPZ WELLPF OTHR P Pull wear ring 02:00 02:30 0.50 0 0 COMPZ RPCOM OTHR P Prep ESP equipment 02:30 03:00 0.50 0 0 COMPZ RPCOM SFTY P Held PJSM with rig crew, Centrilift and Weatherford on PU and MU of ESP completion. 03:00 06:00 3.00 0 0 COMPZ RPCOM OTHR P PU Motor, motor gauge unit, and centralizer. Open oil ports and drain shipping oil. PU and MU Gear reduction unit, Tandem seal section and TTC receiver, cross over with pert intake and 10 -ft pup jt. Open all oil ports and drain shipping oil and allow to drain. String ESP cable over ESP Sheave. Fill ESP Components with fresh oil, connect Pothead. Install 4 protectolizers and 2 1/2 flat guards. Meg Test ESP cable - 2.9 ohms phase to phase, infinity kick phase to ground, 2.09 "G" ohms phase to ground. 06:00 07:00 1.00 0 85 COMPZ RPCOM TRIP P Continue hole with ESP completion as per procedure. 07:00 09:00 2.00 85 85 COMPZ RPCOM PULD P PU gauge assembly & wire -in same. 09:00 12:00 3.00 43 2,067 COMPZ RPCOM TRIP P Changed upper 10' pup with 8' pup. Continue in hole with ESP completion as per procedure to packer depth. 12:00 15:45 3.75 2,067 2,079 COMPZ RPCOM PULD P PU & MU Weatherford WFT Hydrow packer, MU cable assembly through packer, check integrity. 15:45 19:00 3.25 2,079 5,306 COMPZ RPCOM TRIP P Continue in hole with completion from 2,079 -ft to 5,306 -ft upwt =89k and do wt = 68k as per procedure. 19:00 20:00 1.00 5,306 5,330 COMPZ RPCOM HOSO P MU TBG Hanger and Space out for final splice from 5,306 -ft to 5,330 -ft. 20:00 22:00 2.00 5,330 5,330 COMPZ RPCOM OTHR P Meg ESP wire before cutting ESP cable for splice. Make cable and make final splice and Meg same - test good. Page 8 of 10 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 5,330 5,353 COMPZ WHDBO DHEQ P Land Vetco Gray TBG Hanger - verify orientation. RILDS. PT pack off upper seal at 250 / 5,000 psi. - Good test. Lower seal failed. BOLDS 06/27/2011 Change out seals and re -land Hanger, PT at 250 /5,000 psi. Spot CI Brine. RU slick line and set wrp at 3,390 -ft Set ESP Packer. Pull Dummy valve from Stage 1 at 3,246 -ft. FP w/ CI 9.6 Brine. Set BPV and dress tree 00:00 02:00 2.00 5,353 5,353 COMPZ WHDBO DHEQ T Pull hanger to floor and change out seals. Land TBG Hanger and RILDS. PT Upper and Lower hanger voids at 250 / 5,000 - good test. 02:00 03:30 1.50 5,353 5,353 COMPZ WELLPF CRIH P RU Circulate 180 bbls of CI 8.5 ppg 3% KCL at 2 bpm at 60 psi down IA. 03:30 04:00 0.50 5,353 5,353 COMPZ WELLPF OTHR P Pull landing jt and remove ISO sleeve. MU landing jt. 04:00 10:30 6.50 0 3,395 COMPZ WELLPF SLKL P RU Slick line and RIH to 3,483 -ft and Locate GLM #2. Found mandrel one stand deeper than tall indicated.POOH to 3,380 -ft and mark line, Continue to POOH. Verify depth of GLM #1 @ 3,246 -ft. Also locate mandrel one stand deeper than tally. POOH w/ KOT. PU and MU WRP and setting tool, RIH and set at 3,390 -ft. POOH and hang back. Note: Located both GLM's one stand lower in hole than tally. Depth shown are corrected accordingly. 10:30 11:00 0.50 0 0 COMPZ WELLPF PACK P Pressure up and set WFT Hydrow II packer at 3,370 -ft. Initial pressure bobble @ 2,850 psi, take pressure up to 4,000 psi, set packer. 11:00 11:30 0.50 0 0 COMPZ WELLPF PRTS P RU and Pressure test IA at 500 psi for 10 minutes on Chart. Void pressure bled off to 485 psi, then held solid 10 minutes. 11:30 14:30 3.00 0 3,151 COMPZ WELLPF SLKL P MU Slick line and RIH w/ 3" GS & 10 -ft. Catcher Sub to above WRP @ 3,390 -ft and set catcher, POOH.RIH w/ KOT and Pull 1" DV from station #1 GLM at 3,246 -ft. and POOH with same. RD Slickline. 14:30 15:30 1.00 0 0 COMPZ WHDBO OTHR P Pull Landing jt. Set BPV and Drain Stack. 15:30 16:00 0.50 0 0 COMPZ WHDBO SFTY P Held PJSM on ND BOPE 16:00 17:30 1.50 0 0 COMPZ WHDBO NUND P ND BOPE and set back. 17:30 18:00 0.50 0 0 COMPZ WHDBO DHEQ P Meg ESP cable 18:00 20:00 2.00 0 0 COMPZ WHDBO NUND P NU Tree and Test hanger and pack off at 250/5,000 psi for 10 minutes on chart Page 9 of 10 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 20:30 0.50 0 0 COMPZ WHDBO DHEQ P Meg ESP cable 20:30 20:45 0.25 0 0 COMPZ WHDBO SFTY P Held PJSM with Vetco Gray and rig crew on pulling TWC 20:45 21:15 0.50 0 0 COMPZ WHDBO MPSP P pulling TWC with dry rod 21:15 21:45 0.50 0 0 COMPZ WELLPF SFTY P Held PJSM on pumping CI 9.6 ppg Brine and taking returns to kill tank 21:45 23:30 1.75 0 0 COMPZ WELLPF CIRC P PT kill line to tank at 250 / 3,000 psi. Open IA to kill tank and pump 140 bbls of CI 9.6 ppg Brine down TBG string circulating thru open pocket GLM at 3,246 -ft at 2 bpm with 80 psi ICP and 110 psi FCP 23:30 23:45 0.25 0 0 COMPZ WHDBO SFTY P Held PJSM with crew and Vetco Gray on set BPV and Dressing Tree. 23:45 00:00 0.25 0 0 COMPZ WHDBO MPSP P Dry rod in with Type "H" BPV. Secure well and Dress same. 06/28/2011 Finish Dressing Tree, Pull off and Release Nordic Rig 3 at 03:00 hrs, 00:00 02:00 2.00 0 0 COMPZ WHDBO OTHR P Continue to Dress tree, Stage rig mats in preparation to pull off double mats and Prep for rig move 02:00 02:30 0.50 0 0 COMPZ MOVE SFTY P Held PJSM with Rig crew on moving rig. 02:30 03:00 0.50 0 COMPZ MOVE DMOB P Jack up and Move rig off Double mats. Move mats and Clean cellar Release Nordic Rig 3 as of 03:00 hrs on 6 -28 -11 Page 10 of 10 . • • u a ' SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMPIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 MJ Loveland Well Integrity Project Supervisor 1 0 ConocoPhillips Alaska, Inc. (� P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1D-123 Sundry Number: 311 -211 Dear Ms. Loveland: 4 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, Daniel T. Seamount, Jr. Chair DATED this V day of July, 2011. Encl. • . • • ConocoPh l l i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 27, 2011 >- F 5 ' Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 ` Anchorage, AK 99501 Dear Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 1D -123, PTD 198 -170 surface casing inspection and repair. Please call Martin Walters or me at 659 -7043 if you have any questions. Sincerely, y � r � MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures STATE OF ALASKA+, + ALASKA" AND GAS CONSERVATION COMMISSI APPLICATION FOR SUNDRY APPROVALS r,„.0 �` '� 710i 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r R epair well r '�'' `1 i ge p 7o v a t g miicciiS3i�jh Suspend r Rug Perforations r Perforate r Pull Tubing r .t'•f1in°ial"stfsion r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other:Welded SC Patch r • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r • Exploratory r 198 -170 ' 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 22914 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No F7 1D-123 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25650 • 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 ND (ft): Plugs (measured): Junk (measured): 6055 • 4043 • Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 121' 121' PRODUCTION 5998 10 6039' 4028' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5513 - 5545, 5577- 5643, 5668- 5688, 5698 -5718, 5738 -5790 3528 -3558, 3588- 3649, 3673 -3692, 3702 -3720, 3740 - 3790 3.5 L -80 5329 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) Packer = ESP FeedThru Packer Packer = 3275' Estimated depth before RWO completed - will be corrected on 10 -404 SSSV = no SSSV 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r ' Service r 14. Estimated Date for Commencing Well after proposed work: Operations: 15. a Status a P P P 7/20/2011 Oil r • Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and corr to the best of nrediiviedge. Contact: MJ Loveland /Martin Walters I Printed Name MJ Lo■ela Title: Well Integrity Project Supervisor Signature + / /At /eri ' Phone: 7043 Date ,t i l ,i ? /_,, `/ Commission Use Only Sundry Number:31 i ,... 000"' 1 k ( Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r O t h e r : - P Ol t .Z i s (C dr as ; # 1 , 0 1 ; a 4 . . . 4 4..6 Subsequent Form Required: / D `>! 64 1 / , l APPROVED BY / / 1 Approved by: / COMMISSION THE COMMISSION Date: / / = 1 JUL 7 20 T , .„ � .In <�.,�,; Form 10 -403 Revi- IGI 74 �. z/. 4 Subm in Duplicate C • • ConocoPhillips Alaska, Inc. Kuparuk Well 1D -123 (PTD 198 -170) SUNDRY NOTICE 10 -403 APPROVAL REQUEST . June 27, 2011 This application for Sundry approval for Kuparuk (WestSak) well 1D -123 is for the proactive inspection and repair of the surface casing near surface. This well was a single casing packerless ESP well that was . drilled and completed in 1998. During proactive casing inspection work the production casing was discovered to have several areas with localized near surface corrosion and significant wall loss. A prior planned workover to install a packer style ESP pump was accelerated to June 2011 to enable the well to be secured. The rig workover to install a packer was completed June 27, 2011. While the well is still secured, before being prepared for production, ConocoPhillips intends to excavate around the well head approximately 20' deep, remove the conductor, and patch the suspected areas on the surface casing. With approval, inspection and possible repair of the production casing will require the following general steps: 1. Ensure the well is Secure with a tubing tail plug. 2. Remove the floor grate, well house, flow lines, and other equipment from around the wellhead. 3. Remove gravel from around well head to an approximate depth of 20' 4. Install nitrogen purge equipment for the conductor (and OA if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and femove cement from the outside of the surface casing for inspection. Remove all of theft exposed $ conductor if needed. Notify AOGCC Inspector for opportunity to inspect. CPAI Mechanical Engineers will determine if patch or repair is needed to return the casing to operational integrity. 7. If a patch is required, QA/QC will verify the repair for a final integrity check. 8. Install anti - corrosion coating as specified by CPAI Corrosion Engineer. 9. Replace the conductor and fill the void with cement and top off with sealant. 10. Backfill as needed with gravel around the wellhead. 11. Remove plugs and return the well to production. 12. File 10 -404 with the AOGCC post repair. Well Integrity Project Supervisor 6/27/2011 • ~~~ L ~~~~~~ ~~. PROAcrive DiacNOSTic SeltvicES, INC. To: AOGCC Christine ~r-ffefl 'Sbto~~ac/ 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 • RE : Cased Hale/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 A.~~'~~.% ~lrs~, `~ ~~j~) Fax: (907) 245-8952 1) MTT Report 22-Jun-10 1 D-113 2) MTT Report 23,Jarr-10 1 D-123 J `~~ l~~' ~~~ 1 Report 50-029-22917-00 1 Report 50-029-2291400 Signed Date : ,)~~. ~ ~ ~~~)~ Print Name: An PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907-245-8951 Fax: (907)245-88952 E-MAIL : ~pdsanchorageCa~memorvloa.com WEBSITE : wwtnr.memorvloa.com C:~Documant~ and Satting,~Dlana W illiamslD~kWp\Transmit_Conoco.~cx • • Memory M~Ignetic Thickness T©ot Log Results ~ummsry __ Company: ConocoPhillips Alaska, Inc. Well: 1 D-123 Lag Date: June 23, 2010 Field: West Sak Lag No.: 6796 State: Alaska Run No.: 1 AP1 Na: 50-029-22914-00 Pipet Desc.: 3.5" 9.3 Ib L-80 EUE 8RD Top Log Intvl.: Surface Pipet Use: Tubing Bat. Log fntvl.: 175 Ft. {MD) Pipet Desc.: 7.625" 29.7 fb L-80 BTCMOD Top Log Intvl.: Surtace Pipet Use: Surface Casing Bot. Log Intvl.: 175 Ft. {MD) Pips3 Desc.: 16" 62.58 {b. H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log fntvl.: 121 Ft. {MD} Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS ?his MTT data is tied into the Mandrel Hanger ~ 0' pepth. This is the first time this well has been logged with the 12 Arm Magnetic Thickness Tool {MTT). The MTT responds to the total metal thickness of the 3.5" tubing, 7.625" surface casing, with some influence from the 16" conductor pipe. Passes at 5Hz, 8Hz and 10Hz were made at 20 fpm. iNT~RPRETATION,`OF M,TT LOG RESU4TS The MTT log results cover the interval from surface to 175'. Changes in metal volume are relative to the calibration points at 48' and 10T, where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 3.5" tubing, 7.625" casing and 16" conductor pipe. A log plot overlay of the average overall metal thickness recorded by the 5Hz, 8Hz and 10Hz passes is included in this report. This plot indicates an area of up to 14°h relative metal loss over the interval {2' - 4') in the 10Hz pass. Over the same interval, the 8Hz pass indicates up to 9% relative metal ions and the 5Hz pass indicates up to 8°~ relative metal loss. All three passes indicate relative metal loss of up to ~8% over the interval 56' - 76'. A tog plot of the entire 5Hz pass is included in this report. Indications of general isolated metal toss are recorded throughout the majority of the interval logged in the 5Hz pass. The indications appear to be more prevalent from 50' to the bottom of the logged interval. An expanded log plot of the top 30' of the 5Hz pass is included in this report as weN. A maximum -8°~b circumferential metal loss is indicated in the interval between 2' and 4' in the 5Hz pass, and a maximum ~14% circumferential metal loss is indicated in the same interval in the 10Hz pass. A maximum ~8% circumferential metal loss IS indicated in the interval between 56' and 76' in the 5Hz pass. A maximum ^~4% circumferential metal loss is indicated in the interval between 156' and 171' in the 5Hz pass, which appears to be associated with a tubing joint manufactured with a slightly thinner wall or a slightly different material The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the ' tool is responding to, which may include influences from the 3.5", 7.625" and 16" pipe. If ail of the metal loss is specific to the 7.625" surface casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. Field Engineer: IV. Kesseru Analyst: HY. Yang & J. Burton Witness: B. i3oehme ProActive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX 77497 Phone: (Z$1) or ($$$) 565-90$5 Fax: (2$i) 565-1369 E-mail: PDSramemary•iog.cam Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ' lgit-I~f "'"~E"s SHz, z and 1DHz Delta Fetal Thi ess Passes overlay Q~p ~n~i1 ~ ~ 1 D-123 June 23, 2Q10 Pn°ACriv[ DinyrrosTic Scevi[cs Database File: d:lwarrior\data\1d-123\overlay.db Dataset Pathname: overlay Presentation Format: overlay Dataset Creation: Thu Jun 2418:13:33 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2010 (10Hz) (%) 50 -50 Delta Metaf Thickness 2010 (8Hz) (%) 50 -50 Delta Metal Thickness 2010 (5Hz) (%) 50 0 20 Metal 4a 10Hz Delta Metal Thickness --~- ~"_~5Hz Delta Metal Thickness 60 Bottom of 16" 80 o"~" ~E"s~°~ R~rded Magnetic Thickness L~ Data - 5Hz Pass 4~' 1~ M 1 D-123 June 23, 2Q10 P°°Arrivc ~in~n9sTic SEnvitcs Database File: d:lwarriorldatal1d-12315hzpass.db Dataset Pathname: SHzPass Presentation Format: 18 Dataset Creation: Fri Jun 25 11:15:05 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness {%) 50 1.8 MTTP01 (rad) 11.8 0 Line Speed (fitlmin) -?ClOi -7 MTTP12 (rad) 3 Tree Metal Loss elta Metal Thickness Tubing Jt. 1 20 3.5" Collar 40 Tubing Jt. 5" Metal Tubing Jt. of 16" Conductor 80 .625„ Collar ~~"~~"s R rded Magnetic Thickness L Data - 5Hz Pass Q4u A~r's,G ~ ~ 1 D-123 June 23, 2Q10 Po°ACTIYF DIA(~I'NSTIC SF11Y{EES Database File: d:lwarriorldatal1d-123\expanded 5hzpass.db Dataset Pathname: SHzPass Presentation Format: 18 Dataset Creation: Fri Jun 25 11:1x:05 2010 Charted by: Depth in Feet scaled 1:60 -50 Delta Metal Thickness {%) 50 1.8 MTTP01 (rad) 11.8 0 Line Speed (ft/min) -200 -7 MTTP12 (rad) 3 ~ - -_ - __ _ f = ._._..u ~ -- Tree .~ --- ~- Line S peed ' _.. . -- - ,~ i ~ ~ .~, I _ __ ~ --, Hanger r " ~~ ._4... .. :~ - - F.s~ 7.62 5 C olla 8 % M etal Los s De lta Meta i Th ickness - -- --- - 10 3" Tubing Jt. 1 r s 20 } 3.5 " Co llar •~~ '~ -- - -- -50 Delta Metal Thickness {%} 50 1.6 MTTP01 {rad) 11.8 0 ~ Line Speed (ftlmin) -200 -7 MTTP12 (rad) 3 ~; ~ KUP 1D-123 ConocoPhillips ~ I At tri An to iR MD W epDOre A PI 1 PNW Name Well Sgl us pltl / ') 1 ~ (R ai'""'' '" 500292291400 WESTSAK PROD 64.25 3,544.65 6,055.0 ----__.___..__ __ ~ i : - CannM•rn SSSV: NONE N2t IpPm 0 a 8!712009 Arrwtallan LastWO: a 9129!2005 -DrA IN 112.10 Rfg elease Dale 12129/1998 Ama[atlon Last Tag ) e ATatatlon Rev Reason. Reset Pump Assy, GLV GO Last eY Irrwshor t9tG e 1/262010 Casin Strin s C D esc M Siring IIN 9tring D fml Top gnto) t Doper (lam) Depth !tote) 8tnrq Wl gbsnq n t.ra g ee 8b1ngT Tlatl C DUC TO 1 6 75.0 2 0.0 127.0 121. 0 62.58 H•40 WEL ED sat SURFAC E 75/ 8 6.750 0.0 6, 39.0 4,027. 6 29.70 L-80 BTCMOD t i Stri ub nn D n escription fl PN ~ MI Top Pe'~1 Patel ImsAq Ora ee Strt T 11atl Heal Tram, TUBING 3 1/ 2 2.992 0. 5,366.0 3,37 . 9 9.30 L•80 EUE 8rtl 3~ Otl i H l All J T bl R Re 8 tri v Fish etc MANt7REt, Ter o e n op wv . u un r e . a iafi ITVDI Top intA 1~) M Desoripllon C emrisrM Rrn Date n PN 3,025 1,887.7 62.94 H eat Trace HEAT (RAC E 9/25/2006 4,146 2.420.9 66.80 E P AMCd G M/1/DMY/ dill orrment TA 92 05 2.920 Esv M ANDREL MPNDREL. s,aa3 ,2 3,279.1 21.05 C O/KBG M/1/SO / - / one irent A 1!5201 2. 0 M ANDREL 5,298 3,325.6 20.74 S LIPS TUBING ST P (OAL= 1.7 1 32010 1.500 5,300 3,327.5 20.73 P AC OFF 3.5" D&D PA CKER/STINGE R ASSEM Y (OAL= .5") tl2 010 1.610 stiPStGP. 5 308 3 335.0 20. P UMP 3. PC P P(OAL~ 4'5'~ 7 s2e3 , , - 5,309 3,335.9 20.67 N IPPLE CENTRILIFT SLOTTEDNI PPLE 9252006 PACKOFF, 329 3 3 6 20 55 G AUGE AKE DIAN U 92 0 5,300 , , . . 338 3 383 8 .49 IN T TTC CROSS OV 252 , , . 5,343 3,367.7 20.46 EAL C (LIFT GSB3 DB LT FERILH SE AL ASSEMBLY 9 II, ~ 5,3 3.380.6 20.37 EA OX C RILI GEAR RE U CER 1 :4:1 5 5 S I 92 D05 NIPPiE. s,3u9 ~ j ~,~ 5,359 3,382.7 20.36 M OTOR 57 HP 13152 6 KMH w/mot or centralizer 9252005 r _ 5,36 3.390.2 20.37 C errva8zer C NTRILI M R EN TRALI R 51 t` ~ ~ Parfota tions 8~ 81ota PUMP, 1.308 'I Top ITVD) etrn 17VD) Dens GAUGE,5329 ~~ E~'~ T N® ebn (RKy (~) 1~ tone Dat! lel~•• Co rMrnrt - ~4 I I' 5,513 5,545 3,527.8 3,55 .9 D, 10.123 1211 1988 12.0 fPER 12" HSD BigF bfe Chrgs "~ k~ 5,5 5,610 3,588.0 3,619.2 WS B, 1D-123 1 18/ 998 12.0 IP 4112"HSD ole Chrgs INTNSE. 5,338 6, 12 5.64. 3,621.1 9.0 WS A4. 1D-723 1211811 12.0 1 RF 4 1 H - H ok Chrgs 5.688 3,672. 3.692.1 WS A3, 1 D-123 72/18!1998 120 1P RF 4 112" SD BigH ok Chrgs ~~ e • e 5, 5,718 3,701.6 3,7 .7 WS A3. 10.123 1y1811 2.0 R 4 1 HSD Brg ole gs 5,738 5,790 3,739.9 3,789.6 WS A2, 1D-123 12/1811998 12.0 IPERF 4 2"HSD Big ole Chrgs SEAL, 5,343- - GFJ3?BJX, 5 35] MOTOR,5359 Gentrah.er, 5 361 IPERF. 5,5135 545 IPERF, 5 5175 610 IPERF, 5 6125 643 IPERF, S 66&5 838 IPERF, 5,6985 716 IPERF, 5, F335,790 SURFACE. 8,039 TD. 6.055 4~ ~~~~~ Tiit~E~~ ~~r~~r+~v~~-i 1~" 1~ ~il~ ICt~`C ~r~ h+i~ }t.~ jt.:;:~•~ . t~~C__~_~ ~~~~~ !'~t ~.~ 5 `~`». ~`~'`~-- - ` . , ~~~ ~ PUt'S ~3-~r'~• EUE 3rd Ate it~OD St~a~~ut pins - 1t~' ~ .33' i t~.SS ` ~ ,~„ ~~~5 -~---- S~ ~ 52 '~~" rd Af3 AtOC3 tdbiit .lts ~ -1615 3-1 ~~. EUt= 5 9 " r .3~a 5 i ~ $1 S . , ~,.-,, 18 5«J 101 3-i 12"~ 1 " CAIt4CC} 'KBA~M' OLIN 5.39"QD - 2.367 . • Jts IS~2 3-112" EUE Srd Ad MOD (fell jts} 61.9Q 5225.99 3-112" EUE 8 rd Ad MOD Spaceout Pup 3.5"C)D - 2.99"ID '10.12 52$5.$9 3-112" EUE 8 rd AB MOD Handling Pup 3.5"OD - 2.99"ID 10.12 5299.41 Slotted Nipple 3.50" OD - 2.992 ID 3.00 5349-13 3-112" Tubing TTC Crossover 3.50" OD - 2.992" 10 1.51 5312.1.3 ESP Tandem Seal GSB3 DB 1L H6PFS '13.80 5313.64 ESP Gear Reduction Unit 9:1 525 Series 1.31 5327.44 ESP Motor 57 HP 1315126 KMH 6.86 5328.75 ESP Motor Centralizer .54 5335.61 53;6.11 Note: Raychem Heat Trace attached @ 15' do from box end on jt 71 Note: 80T Outside Sentry Gauge attached to middle of 2nd 10' pup Rernarks: String VV~:ights with 61oc1',s: $5 K# Up, 351;# Dn, 6K# $IocW,s. Elan 166 joints of tubing. Uriti,r~ tubin8, GLhfi: , ~, hanger with 2.857" plastic rabbit.. Used ,Arctic Grade AP! Modified Na ~,~~~ tt~r~ad 4vrriPvund~-Gt+nncrctiUn;:. Tub'trlg i~ non-GUaf.+~d. ~ , ~. 7`~b~rr~r~ c~~ ~ ~e'or~~~~^~ h ;CEO ,~.tas~Ca~s ~!"~c. ~idianf of f~trantiC Richf~ld C©mnanv ~A~~Mp 'I OF' - "TENS - - CQNIPLETE QESCF~1PTIalw CAF EQtJIP1VIE1`~T P.l.hl'~ LE!'~GTN ~. f~~PT~ TOPS ~_r~>{B to landin Rin 41.50 Vetca Gra Fluted Mandrel Casin !-Ian er ~ pu 2=55 4+0=5C 3 Jts. 7-5/8" 29.7# L-80 ABM-BTC Casin 'ts#118 - #140 978.08 43.Oa Tam Port Collar 2.43 10'15.' 4 Jts. 7-5/8" 29.7# L-80 ABM-BTC Casin Jt #14-117 442'3.05 1018., Marker Pu Jt. 7-518" 29.7# L-80 ABM-BTC Casin 21.05 5439.E Marker Pu Jt. 7-518" 29.7# L-80 ABM-BTC Casin 21.90 54Ei0.~ 1 Jts. 7-518" 29.7# L-Sa ABM-BTC Casin Jts #3-#13 470.3'1 5482.' GEMOCfJ Float Collar PBTD 1.32 5952.a Jts. 7-5/8" 29.7# L-80 ABM-BTC Casin Jts.#1  83.29 5. GEMOCO Float Shoe 1.49 6 ~',~ E3038.' Marker Jt. Between Jt.#13 & 14 TAM Port Collar Between Jt#1'17 & 118 .~ -.. a fu~ ~iw... ~. .~A..r.A.W dew !.F ~ R "'.'^°' +rt~~rn~v~.:tP~wif~.+.R+^~w<.+7'~MWIM 4 ~+..n. . ~.~+!~ w.rr~aannteww''4c~YYres~l~'n,PM-~h •:' r ; .vfl.. ~ -. r .. >... x x. ~ L~ f 4~ ~ ~ cyygA f y -~ ~~. . -~- x ~~ ... ~ ~. ~ r~ ~~ ; ~' a i ~~~~ Jt.~~ ~~~v ~ ring ~n ~o~ ~~~~~ ~n <<~~~~ .~Y .~ -. f ~ +~~ `f~r ~ ~ ~1 E _~ Ll i 6 1 ~,q . ~..r ~ ..~,o _ :..: , i..,~. +w.. ,ww'~~Y4.r ,~ `: P;yiwd ,~+M~ • ~` w ' ~,,,1 +~~ +t ~ ..,`.~ ~++,. ~.w~a ~.~.~.. qtr. .i.. ,r. arr:.~,.aw. -+1+»,~;. .~R .t+I~M"~` ~*+e ~.~ ~i r.jj~ • ~- . \.. L- +r v- -+. +.~; .. arN~lr. .rru"~w+:- w:~ +~r. !r ~+1~~~: ~ ~.~. ~ i~~ . ~i ~! *` • °`~ i^ +s K M .+ w #, is °~` ~. 'wW"'. JW '^~"~ ~ "! ,rb ~,.>..~~: ~ , ~ti< ~,(. ~r, t+r~w~ w `. .sx +qe ~WWR`i.: . . Conoc~illips Alaska RECEIVED .JUL 1 0 Z007 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Alaska Oil & Gas Cons. Commission Anchorage July 6,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK. 99501 SC¡'~~NED JUL 11 2007 ll.",\1° .C\~ \ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter 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. Please M.J. Loveland at 907-659-7043, if you have any questions. .;;;/~ M.~l~ ConocoPhillips Well Integrity Project Supervisor ..-'" ~- . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbrs ft aar 1 0-09 198-065 23" na 5 6/9/2007 10-101 200-183 2" na 3.2 6/9/2007 10-102 200-075 2" na 3.2 6/9/2007 10-103 202-096 5" na 8 61912007 1O-105a 201-202 25" na 38 6/912007 10-106 197-240 2" na 3.2 6/9/2007 10-107 200-177 2" na 3.2 6/912007 10-108 198-187 8" na 12.8 6/9/2007 10-113 198-178 2" na 1 6/9/2007 10-114 198-159 2" na 1 6/912007 10-115 197-232 2" na 1 6/912007 10-116 198-172 2" na 1 6/9/2007 10-117 197-237 2" na 1 6/912007 10-118 197-229 2" na 1 6/912007 10-119 197-222 2" na 1 6/9/2007 10-122 198-149 2" na 1 6/9/2007 10-123 198-170 2" na 1 6/912007 1O-125a 200-044 2" na 1 6/912007 10-126 198-108 2" na 1 6/9/2007 10-127 198-109 8" na 2.5 6/912007 10-128 198-133 2" na 1 6/912007 10-129 197-213 2" na 1 6/9/2007 10-130 197-183 23" na 5 6/9/2007 Kuparuk Field June 9,2007 ) ') Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 ConocóPhillips October 20, 2005 ~~ 0. Cf'::'/ 449.~,_ ('1 '''~ ,Í løf~ I.JIf ~ 9 !,4' ""a, '<:/1 ,() W~'\ ~6 · 6s,$" , 00.) 1>1,/)1 . ¿;~,'^ J~I.Í' v,,~~. '¡'. 70/,' . It . ðUe '~?ìJI:h. QI$3, . 1(1) Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Reports of Sundry Well Operations for 1 D-123 (APD 198-170) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Reports of Sundry Well Operations for the recent workover on the West Sak well 1 D-123. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, JI{. ¡¡(? M. Mooney Wells Group Team Leader CPA I Drilling and Wells SCANNED NO\! G 1 2.005 MM/skad Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 41', Pad 71' 8. Property Designation: AOL 25650, ALK 468 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR PRODUCTION Perforation depth: Abandon D Alter Casing D measured true vertical measured true vertical Length 80' 5998' RECEIVED STATE OF ALASKA OCT 2 4 Z005 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIONSAlaska Oil & Gas Cons. Commissio A~orage Time Extension D D ) ) Repair Well 0 Pull Tubing D Operat. ShutdownD Stimulate D Waiver D Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development 0 Stratigraphic D Other Re-enter Suspended Well 5. Permit to Drill Number: 198-1701 6. API Number: 50-029-22914-00 Exploratory D Service D 9. Well Name and Number: 1 D-123 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool 6055' 4043' feet feet feet feet Plugs (measured) Junk (measured) Size MD TVD Burst Collapse 16" 7-5/8" 121' 6039' 121' 4028' Measured depth: 5513'-5545',5577'-5610',5612'·5643', 5668'-5688', 5698'-5718', 5738'·5790' Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run_ true vertical depth: 3528'-3558',3588'-3619',3621'-3651', 3674'-3693', 3703'-3722', 3741'·3790' Daily Report of Well Operations _X Tubing (size, grade, and measured depth) 3-1/2" , L-80, 5356' MD. Packers & SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) 13. Treatment descriptions including volumes used and final pressure: none RBDMS 8Ft 0 CT 2 5 2005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl 26 18 18 83 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ D 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: Contact Printed Name Signature Oil-Bbl 151 157 Casinq Pressure Tubinq Pressure 544 173 WDSPL D Mike Mooney @ 263-4574 #onï1~~ Form 10-404 Revised 04/2004 Title Phone Wells Group Team Lead Date /òÄôÄ'>5 Prepared bv Sharon AI/$up-Drake 263-4612 ,. ORIGINAL Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10-123 10-123 WORKOVER/RECOMP Nabors 3S Start: 9/15/2005 Rig Release: 9/24/2005 Rig Number: Spud Date: 9/2/1998 End: Group: 9/18/2005 00:00 - 02:00 2.00 MOVE RURD MOVE Lay down derrick. Prep rig for move to 1 D-123. 02:00 - 06:00 4.00 MOVE MOB MOVE Move rig from 1 D-1 02 to 1 D-123 06:00 - 09:00 3.00 MOVE RURD MOVE Prep to spot derrick sub over well. Hold pre-job safety meeting. Move BOP stack in behind well, have difficulties do to soft pad. Back rig into place numerous times to ensure placement. Attempt to level pad better; pad is soft and uneven due to fill brought in to level, in some areas 2' deep. 09:00 - 12:00 3.00 MOVE RURD MOVE Place rig mats; shore up underside with cribbing and hand shovel gravel. Need to pull bullplug on front annulus valve to make room for mat, valve leaking badly by. Call out grease crew to service all the wellhead valves. 12:00 - 14:00 2.00 MOVE POSN MOVE Call DTH for additional hands to lay down herculite. Conduct pre-job safety meetin; focus on high-wind hazards with laying dawn herculite (winds gusting to 35 mph causing difficulties). Lay down liner and begin to spot up rig...difficult getting centered due to tight spacing. 14:00 - 14:30 0.50 MOVE POSN MOVE Rig placed on standby (dayrate) due to high winds impeding progress at 14:00. Note: Time adjusted approx 4 hrs due to standby incurred waiting for additional help to hold pit liner due to winds, valve service crew to service annulus valve, etc. 14:30 - 16:00 1.50 MOVE POSN MOVE Derrick sub spotted up. Move in pipe shed and pits. 16:00 - 18:00 2.00 MOVE RURD MOVE Begin installing handy-berm walls, make up pit lines, etc. Ready to raise derrick. Cont. to rig up. Work on pre-spud checklist. 18:00 - 00:00 6.00 MOVE RGRP MOVE Rig up in cellar area. Burm around rig. Rig Maintenance. Too windy to raise derrick. (30-50 mph) 9/19/2005 00:00 - 06:00 6.00 WAlTON WOW RIGUP Continue standing by for weather. Unable to raise derrick do to high winds (30-50mph) 06:00 - 11 :00 5.00 WAlTON WOW RIGUP Check winds hourly for change. Winds averaging 23 mph, gusting 36 mph. Rig crews performing maintenance. Ready to proceed with raising derrick once winds die. 11 :00 - 14:00 3.00 WAlTON WOW RIGUP Winds 27 mph average, gusting to 38. Still unable to raise derrick. 14:00 - 16:00 2.00 WAlTON WOW RIGUP Winds 29 mph average, 38 gusts. Still unable to raise derrick. 16:00 - 17:00 1.00 WAlTON WOW RIGUP Winds 22 mph average, 38 gusts. Toolpusher reviewing policy with Nabors Superintendent. 17:00 . 19:00 2.00 WAlTON WOW RIGUP Winds 22 mph average, toolpusher evaluating weather. Decide to wait do to strong gusts. 19:00 - 21 :00 2.00 WAlTON WOW RIGUP Winds 28 mph average, 38 gusts. Still unable to raise derrick. 21 :00 - 23:30 2.50 WELLSR RURD RIGUP Raise derrick, Rig-up lines to derrc. Rig off standby rate at 21 :00 and back on rig move. 23:30 - 00:00 0.50 WELLS~ PLGM DECOMP Accept rig at 23:30 9/19/05. Rig-up lubricator to pull BPV 9/20/2005 00:00 - 02:00 2.00 WELLS PLGM CMPL TN Pull BPV. Lay down lubricator. Rig -up LRS on wellhead. Hold pre-job safety meeting. Check and test flow back lines and tanks. Casing pressure 1300 psi. Begin bleeding off casing pressure. 02:00 - 05:00 3.00 WELCTl KILL CMPL TN Bleed casing pressure to 300 psi. LRS preheated 8.6# seawater with 13% KCL to 150 degree. Start pumping seawater @ 2 BPM. Monitoring lines and tanks while pumping. Pumped total of 260 bbls. Still have I I small amount of gas on casing. Seawater truck empty. Rig down tanker I i I I and LRS. Rig-up lines to finish kill with rig. 105:00 - 06:00 : 1.00 I WELCTL.! KILL CMPL TN I Decide to circulate another 50 bbls seawater 3% KCLfrom pits to tanks. 106:00 - 10:30 ! 4.50 I WELCT~ CIRC CMPL TN ' Check well; still small amount of gas breaking out. Rig up to circulate I i back to pits. Come online at 4 bpm down tubing, taking rtns back to I . I I i pits. I I . I Install BOP. BOP 110:30 -13:54 3.40' CMPL TN NUND DECOMP I Set BPV. Pull wellhead and prep for BOP install. I I test waived by Jeff Jones @ 13:53 9/20/05. i I 1 I i I Printed: 10/19/2005 3:31:53 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10-123 10-123 WORKOVER/RECOMP Nabors 38 Start: 9/15/2005 Rig Release: 9/24/2005 Rig Number: Spud Date: 9/2/1998 End: Group: 9/20/2005 13:54 -16:30 2.60 WELCTL NUND DECOMP Continue NUND proceedures. 16:30 - 17:00 0.50 WELCTL NUND DECOMP Make up test joint with TIW - Dart 17:00 - 23:00 6.00 WELCTL BOPE DECOMP Function and Pressure test BOP to 250 psi 3000 psi. Annular test 250 psi 2500 psi. Rig down test equipment. 23:00 - 00:00 1.00 WELCTL NUND DECOMP Pull test dart and BPV. Install isolation sleeve. 9/21/2005 00:00 - 02:30 2.50 WELLSR RURD DECOMP Continue install of isolation sleeve. Make up landing joint to hanger. Check fluid level. BOLD's. Free hanger. Up weight 55K, hanger pulled free at 70K. 02:30 - 05:00 2.50 WELLSR RURD DECOMP Rig up eqipment to spool ESP and heat trace cable. 05:00 - 08:30 3.50 FISH PULL DECOMP Begin pulling 3.5" ESP completion, standing back tubing in derrick. 08:30 - 16:12 7.70 FISH PULL DECOMP Continue to pull origional completion. Order 200 BBLS of 100 DEG. 3% KCL 8.7 PPG water for circ fluid. Losing aprox 1.5 - 3 BBLS per stand to keep pipe semi clean. 16:12 -18:00 1.80 FISH PULL DECOMP Recovered 100% of the RayCHem heat trace. 1 heat trace end shoe 6',479 heat trace flat guards 6', 19 heat trace flat guards 4',27 heat trace flat guards 3',--- 1,562 ea bands, Appears that origional tally is wrong. 18:00 - 19:30 1.50 FISH RURD DECOMP Clean up rig area and prepare for continuation of POOH. 19:30 - 00:00 4.50 FISH PULL DECOMP Continue OOH wI 3.5" ESP completion 9/22/2005 00:00 - 01 :00 1.00 FISH PULL DECOMP Continue OOH wI completion. 01 :00 - 02:30 1.50 WELLSR PULD DECOMP On surface with motor assembly. One flat bands missing motor assembly. Finger missing on LaSalle protectolizer guard at middle of seal section. Missing finger is approximately (3 3/4" x 2 1/2" x 1/2"). ESP cable tested good. Motor grounded out. Lay down motor assembly. Prep rig floor for test packer BHA. 02:30 - 03:15 0.75 WELLSR PULD DECOMP Make up Test packerlRBP BHA. Install wear ring. 03: 15 - 04:45 1.50 WELLSR TRIP DECOMP RIH wI 3.5" tubing as work string and test packerlRBP BHA. Unable to work packer through top of BOP stack. Lay down packer in mouse hole. Fish 4' flat band from stack. Call workover engineer. Decide to rerun packer assembly. 04:45 - 10:30 5.75 WELLSR TRIP DECOMP RIH wI 3.5" tubing as work string and test packerlRBP BHA. Several issues with wt loss during RIH. Around 1,200' WT slacked off enough to cause concern. Four more areas WT slacked off and continued to RIH. 10:30 - 11 :37 1.12 WELLSR PLGM DECOMP Pre-job safety meet. Set Baker RBP while rotating. UP WT = 39K DWN WT = 27K. Set RBP on single number six. Six in shed. 11:37 -12:15 0.63 WELLSR SFTY DECOMP Safety stand down with Mike Mooney and Rich Nelson. 12:15 - 12:45 0.50 WELLSR PLGM DECOMP Pulled single number six OOH and set RBP @ 5,320'. Pressure test while holding onto RBP failed. 2 BPM @ 250 PSI. Suspect equalizing valve not shutting. 12:45 - 14:00 1.25 WELLSR PLGM DECOMP Set Baker retrievamatic packer ant test tubing to 2,500 PSI. Test IA to I 2,500 PSI charted and signed. 14:00 - 16:22 2.37 WELLSR PULD DECOMP Have issues with power tongs gripping pipe to rotate required amount of I i I torque to unset Baker retrievamatic. Switch to rotary table and witness I 0.63 WELLSJTRIP ! wt decress while in slips. Rotated with 9K over string wt. 1 16:22 -17:00 1 DECOMP ! Begin pulling OOH. Lay dwn six singles and stand back the rest. 17:00 - 23:00 j I 6.00 I WELLS~ TRIP DECOMP i On surface with test packer assembly ·23:00 - 00:00 1.001 WELLSR PULD DECOMP i Lay down packer assembly. Prep rig floor to run completion. 9/23/2005 100:00-12:15 : 12.25: CMPL TN' RUNT CMPL TN ~ Prep rig floor and ESP equipment to run completion. Begin running I : ESP completion. Some issues with Centrilift and prep work. Discussed I i I with Lead Centrilift field REP. Ran Baker i 12:15 -14:30 i 2.25 CMPL TN: RUNT ; CMPL TN Rig up Ray Chem heat trace. Change out crews. Move sheaves for Centrilift and Ray Chem to spool side by side. Average loss of fluid to Printed: 10/19/2005 3:31:53 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10-123 10-123 WORKOVER/RECOMP Nabors 3S Start: 9/15/2005 Rig Release: 9/24/2005 Rig Number: Spud Date: 9/2/1998 End: Group: 12:00 - 18:00 ,$êlÞ··' ~Ôgê"· 2.25 CMPL TN RUNT CMPL TN formation = 5 BBL per hour. 9.50 CMPL TN CMPL TN Continue to RIH 4.58 CMPL TN RUNT CMPL TN Continue to run completion. Installing dual channel (F/STD#34) clamps every 6' @ 8" apart & single channel. Drift out of derrick. 4.42 CMPL TN RURD CMPL TN Terminate ESP, I wire and Heat Trace cables. MEG CABLE 3.00 CMPL TN RURD CMPL TN Land tubing hanger. Watch guide pin turn pipe 5 DEG. Test upper and lower seals to 5,000 PSI. Set BPV. Prepare to NU BOPE. 6.00 WELCTL NUND CMPL TN Nipple DWN BOPE & remove chokes/HCR. Install Tree. PT to 5,000 PSI for 30 min. Passed. Rig released @ 18:00 on 9-24-2005 9/23/2005 12:15 -14:30 14:30 - 00:00 00:00 - 04:35 9/24/2005 04:35 - 09:00 09:00 - 12:00 Printed: 10/19/2005 3:31:53 PM ConocoPhlllips Alas)a. Inc::. 1 D-123 ) KRU 1)-123 Angle (â) TS: deg (â) Angle @ TD: 17 deg @ 6055 API: 500292291400 SSSV Type: NONE Well Type: PROD Orig 12/29/1998 Completion: Last W/O: 9/2912005 Ref Log Date: TD: 6055 ftKB Max Hole Angle: 64 deg (â) 3545 TUBING (0-5356, 00:3.500, 10:2.992) Rev Reason: WORKOVER Last Update: 10/8/2005 Annular Fluid: Reference Log: 40.5' RKB Last Tag: Last Tag Date: Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 PRODUCTION 7.625 Tubing String - TUBING Size I Top 3.500 0 Perforations Sum mary Interval TVD 5513 - 5545 3528 - 3558 5577 - 5610 3588·3619 5612 - 5643 3621 - 3651 5668 - 5688 3674 - 3693 5698 - 5718 3703 - 3722 5738 - 5790 3741 - 3790 Gas Lift Mandrels/Valves St MD TVD Man Man Type V Mfr Mfr 4146 2419 CAMCO KBGM 2 5248 3279 CAMCO KBGM Other :plugs¡ equip., etc.) - JEWELRY Depth TVD Type 3025 1888 Heat Trace 5309 3336 NIP 5328 3354 PUMP Heat Trace (3025-5248, 00:1.000) :>ROOUCTION (0-6039, 00:7.625, Wt:29.70) Top Bottom TVD Wt Grade Thread 0 121 121 62.58 H-40 WELDED 0 6039 4028 29.70 L-80 BTCMOD TVD Wt I Grade Thread 3380 9.30 L-80 EUE 8rd Bottom 5356 Gas Lift MandrelNalve 2 (5248-5249, Ft SPF Date Type 32 12 12/18/1998 IPERF 33 12 12/18/1998 IPERF 31 12 12/18/1998 IPERF 20 12 12/18/1998 IPERF 20 12 12/18/1998 IPERF 52 12 12/18/1998 IPERF Comment 41/2" HSD BigHole Chrgs 41/2" HSD Big Hole Chrgs 41/2" HSD BigHole Chrgs 4 1/2" HSD BigHole Chrgs 4 1/2" HSD BigHole Chrgs 41/2" HSD Big Hole Chrgs Zone WSD WSB WSA4 WSA3 WSA3 WSA2 Status NIP (5309-5310, 00:4.500) Vlv Cmnt V Type VOD Latch Port TRO DMY 1.0 BK-5 0.000 0 SOV 1.0 BK-5 0.000 0 Description Date Run 9/25/2005 9/30/2005 PUMP (5328-5329, 00:3.500) ID 0.000 0.000 0.000 GAUGE (5329-5338, 00:4.000) HEAT TRACE CENTRILlFT SLOTTED NIPPLE 3.5" TTC-ES-PCP PUMP (33'1" OAL) @ 5328' RKB, PART #65600, STATOR #ST-0010016, ROTOR #RT-R50470-9, MODEL #250-T-1800, set 9/29/2005 PUMP ASSEMBLY 3.5" D&D PACKOFF set @ 5305'; TEST TOOL RUN ON TOP OF PACKOFF; SET 3.5" SLlPSTOP (â) 5298' 9/30/2005 GAUGE BAKER GUARDIAN GAUGE XO TTC CROSSOVER SEAL CENTRILlFT GSB3 DB L T FERILH6H SEAL ASSEMBLY GEARBOX CENTRILlFT GEAR REDUCER 11:4:1525 SERIES MOTOR 57 HP 1315/26 KMH wlmotor centralizer Centralizer CENTRILlFT MOTOR CENTRALIZER XO (5338-5343, 00:4.500) 3.500 0.000 0.000 0.000 0.000 0.000 5329 5338 5343 5357 5359 5367 3355 3363 3368 3381 3383 3390 SEAL (5343-5357, 00:5.130) GEARBOX (5357-5359, 00:5.250) MOTOR (5359-5367, 00:5.620) Centralizer (5367 -5368, 00:6.000) Perf (5513-5545) Perf (5577-5610) Perf (5612-5643) Perf (5668-5688) Perf (5698-5718) Perf (5738-5790) ) Conoc~hillips Alaska ) P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 4,2005 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., we1l1D-123 (PTD 1981700). The report regards temporary use of gaslift to produce the ESP-completed well. Note that attempts to use gaslift were not successful due to freezing problems and the well will remain shut-in until a workover is performed. Please call MJ Loveland/Marie McConnell at 659-7224 if you have any questions. Sincerely, ~""~C ~ Jerry Dethlefs Problem Well Supervisor SCANNED JUt û? 2005 Attachments r) r-' ,,:J'""t ¡r-' i~ t: ~ 1 5'=< ~ .....~". JUL C 2005 OJ I (;~ ,...." "" I."...,:.; L ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION tLw fr.: REPORT OF SUNDRY WELL OPERATIONS Repair Well 0 Pull Tubing 0 Ope rat. ShutdownD Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 1. Operations Performed: P. O. Box 100360 7. KB Elevation (ft): RKB 112' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth measured true vertical Effective Depth measured true vertical Casing Structural CONDUCTOR PRODUCTION Length 121' 5927' Perforation depth: 6055' 4043' Size 16" 7-5/8" Stimulate 0 °JljL 0 iJìR005 Waiver 0 Time Extension 0 :1'> ~. '" ,, 0;1 1: f:'::, ,.... f' .;".,.. Re·enter SLlc;penae-d W'èll '."IJ~_ ,~) . 5. Perni'it'iÓ:Ö'tilVNHmber: Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development _ 0 Stratigraphic 0 Exploratory 0 o 198-170 6. API Number: 50-029-22914-00 Service 9. Well Name and Number: 1 0-123 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool feet feet feet feet Plugs (measured) Junk (measured) MD TVD Burst Collapse 121' 6039' 121' 4028' Measured depth: 5513-5545,5577-5610,5612-5643 true vertical depth: 3528-3558,3588-3619,3621-3651 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 5312' MD. Packers & SSSV (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: N/A RBDMS BFL JUl 0 6 2005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl 56 59 26 18 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: Oil0 GasD WAG 0 GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 305-112 13. Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil-Bbl ESP 306 GL 151 Casinq Pressure Tubinq Pressure 263 544 260 1000 WDSPL 0 Contact Marie McConnell/MJ Loveland @ 659-7224 Printed Name J.erry, Dethlefs ~ ~ Title Signature fZ. . _ ~ L ~ Phone Form 10-404 Revised 04/2004 Problem Well Supervisor 907-659-7224 Date 7/~/as;.- Submit Original Only ) ) 1 D-123 DESCRIPTION OF WORK COMPLETED SUMMARY 2005 f:'¡, Date Event Summary 6/29/20~Report from the West Sak Production Engineer: ~pdÞ-o( 1AIP 10-123 is a failed ESP that we have been trying to produce on gas lift, The initial gas lift attempt was made on 5/22 but the well hydrated off after 4 days. We tried thawing out the tubing by pumping over 800 bbl of hot diesel down the IA with no results, A CT thaw job was required to bring the well back on. The second attempt to flow the well made 7/22, This time the well hydrated off after 5 days even though it was receiving daily methanol sweeps, We are not planning on trying any further attempts to produce this well on gaslift. Prior to the ESP failing this well was producing -310 bopd. ) TUBI NG (0-5312, 00:3.500, 10:2.992) ProdLlctio n (0-6039, 00:7.625, V\II::29.70) GAUG E (5294-5295, 00:4.000) NIP (5309-5314, 00:3.500) SEAL (5314-5327, 00:5.130) GEARBOX (5327 -5328, 00:5.250) MOTOR (5328-5329, 00:5.620) Perf (5513-5545) Perf (5577 -5610) Perf (5612-5643) Perf (5668-5688) Perf (5698-5718) Perf (5738-5790) ,'. ].:.:.:...:.:... ... \~i~~;~!!::.. . ·:i:::i:::.I:::i:::.:.:::.i:::.i:::i:::.i:::i:::·.:::.:.·:::.i:::::::.I:::::::.' ...¡:. ~.:.;;........".~.;;::::::~:~ li'¡.:i ;::;:;:~:~:. . . ., :!·~ffffffff:·g::i:~~;:~[[~[[i Interval TVD 5513 - 5545 3528 - 3558 5577 - 5610 3588 - 3619 5612 - 5643 3621 - 3651 5668 - 5688 3674 - 3693 5698 - 5718 3703 - 3722 5738 - 5790 3741 - 3790 Gås:UftMändrelsAlêilves '.' St MD TVD Man Man Type Mfr 1 5220 3253 CAMCO KBMM öthEÚ'(þl Ügs ,equíþ.,etc.) ~JEWELRY Depth TVD Type 5294 3322 GAUGE 5309 3336 NIP 5314 3341 SEAL 5327 3353 GEARBOX 5328 3354 MOTOR API: 500292291400 SSSV Type: NONE Annular Fluid: Reference Log: Last Tag: Last Tag Date: çåsing string> ALL'" Description Conductor Production Size 3.500 --- ......- ~ ......- ~ ~ --- ..-- ~ ~ ~ ) KRU 1 D-123 Well Type: Orig Completion: Last W/O: Ref Log Date: TD: Max Hole Angle: PROD 12/29/1998 Angle @! TS: deg @! Angle @! TD: 17 deg @! 6055 Rev Reason: Set OV Last Update: 5/29/2005 Size Top 16.000 0 7.625 0 Bottom TVD Wt Grade Thread 121 121 62.58 H-40 WELDED 6039 4028 29.70 L-80 BTCMOD Wt Grade Thread 9.30 L-80 EUE 8rd Date Type Comment 12 12/18/1998 IPERF 4 1/2" HSD BigHole Chrgs 12 12/18/1998 IPERF 4 1/2" HSD BigHole Chrgs 12 12/18/1998 IPERF 4 1/2" HSD BigHole Chrgs 12 12/18/1998 IPERF 4 1/2" HSD BigHole Chrgs 12 12/18/1998 IPERF 4 1/2" HSD Big Hole Chrgs 12 12/18/1998 IPERF 4 1/2" HSD BigHole Chrgs Top o Bottom 5312 Zone WS D WS B WSA4 WSA3 WSA3 WSA2 V Mfr V Type VOD Latch Port TRO CAMCO o Date Run 5/16/2005 Vlv Cmnt OV 1.0 BK 0.188 Description BAKER SENTRY GAUGE - PUMP INTAKE Slotted Nipple Tandem Seal GSB3 DB IL H6PFS Gear reduction unit 9: 1 525 series 57 HP 1315/26 KMH w'motor centralizer ID 3.500 2.992 0.000 0.000 0.000 Z005 (0 ,ðt /ru, ',' f.ï-::¡ !(ii' l' \\ :r.:-=:J~ 'f,- ' ',:r:::þ" ",' (~."" ' !J ~ /1~ '~ ;; i: '\"~ :1' -ÍdJl'\ ! :\ i" , 0\; ~ I.' \ ':¡ L '). (Q) : j Jru\ L L6 rñ' .,'111'\\, ~~ ',r:!! , 'I ' I . i i :J ' ' ¡ 11 " ;i, :j I,~ :"I? q J i iJ" ~~ ;~,.l ) ~ 11 IA\ i i ,.I J,~ : " in,. \ i i if.., 'w ~ ) ,....--., ~ fU '\>',., :rù ) \..;....1 FRANK H. MURKOWSKI, GOVERNOR AItASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7ft! AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brad Gathman Problem Well Supervisor ConocoPhillips (Alaska), Inc. P.O. Box 100360 Anchorage, Alaska 99510 1D \Gýð/\ Re: Kuparuk 1D-123 Sundry Number: 305-112 "Iì ? (),' 0 ~.', SCJ..\NNEJ) M¡~Y 1. J. f_. Dear Mr. Gathman: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd ollowing the date of this letter, or the next working day if the 23rd day falls on a olida or weekend. A person may not appeal a Commission decision to Superior 000 less rehearing has been requested. Œ S' cer ~ t. J J _J K ormar h~ '--- DATED this3 day May, 2005 Encl. ) Conoc;Phillips Alaska ) P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEI\/1=O APR 2 9 2005 Alaska Oil & Gas Cons. ~Llmmission Anchorage ) ,1° ~~~ April 27, 2005 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well1D-123 (PTD 1981700). The variance request is for approval to temporarily use gaslift to produce the ESP-completed well. Also attached is a discussion and well schematic. Please call MJ Loveland at 659-7224 or myself if you have any questions. Sincerely, í?yµ Brad Gathman Problem Well Supervisor Attachments ¡ ('\ ,I \\ ~ ,i\ ~ 1 <J \ 1.1 I, t...". Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 112' 8. Property Designation: Kuparuk River Unit 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 6055' 4043' Casing Length Size 1. Type of Request: Abandon Alter casing CONDUCTOR PRODUCTION Commencing Operations: 16. Verbal Approval: Commission Representative: 121' 5927' D Alaakit Qjlai~rGas ~nS'A~mgPH~!tt!!J . AnclWage D Time Extension . 0 Other D Re-enter Suspended Well D 5. Permit to Drill Number: 198-170 '-./" 6. API Number: ./' 50-029-22914-00 V ) ) STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL D D o 20 AAC 25.280 Suspend D Operation Shutdown D Repair well D Plug Perforations D Pull Tubing D Perforate New Pool D 4. Current Well Class: Development _ 0 Stratigraphic D Service Perforate Stimulate Exploratory D D o r:5-Z!.o~/.s k ~C =IVED 'ý~ APR 2 9 Z005 9. Well Name and Number: 1 0-123 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): MD TVD Perforation Depth MD (ft): 5513-5545,5577-5610,5612-5643 5668-5688, 5698-5718, 5738-5790 Packers and SSSV Type: no packer no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch n 14. Estimated Date for 16" 121' 6039' 7-5/8" Perforation Depth TVD (ft): 3528-3558,3588-3619,3621-3651 3674-3693, 3703-3722, 3741-3790 Packers and SSSV MD (ft) Tubing Size: 3-1/2" Date: no SSSV 13. Well Class after ProposE;1d work: Exploratory n Development ~ 15. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Brad Gathman Signature ~--?-v Contact: Title: Phone 659-7224 Commission Use Onlv Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test D Location Clearance D Mechanical Integrity Test D t:5" I ~ -0\ RBDMS BFL MAYO 9 2005 COMMISSIONER INSTRUCTIONS ON REVERSE BY ORDER OF .,T.':~,GOM~J~~ION) :!,",) ;;: ¡ [I ~ Burst Collapse Tubing Grade: L-80 Tubing MD (ft): 5312' Service D Plugged D WINJ D Abandoned D WDSPL D MJ Loveland/Brad Gathman Problem Well Supervisor Date tf /2-7-/0.5 Sundry Numbe~ _I {2.. LD:t:~mØJ~ ) ) ConocoPhillips Alaska, Inc. RECEIVED West Sak WelllD-123 (PTD 1981700) APR 2 9 2005 SUNDRY NOTICE 10-403 VARIANCE REQUEST . Alaska Oil & Gas Cons. Commission AprIl 27, 2005 A h ge nc ora The purpose of this Sundry Notice is for approval to produce ConocoPhillips' West Sak we1l1D- 123 on gaslift. The well is completed as an ESP (electric submersible pump) producer and does not have a production packer. 1D-123 produced via ESP until 04/17/05, at which time it was shut-in due to an electrical short downhole. At this time no more re-starts will be attempted, the problem will need to be fixed by a rig workover. The tubing is configured with one gaslift mandrel at 5220' RKB (3253' TVD). Gaslift wjll be applied in the "standard" configuration; i.e., gas will be injected down the annulus and enter the tubing through the gasÚft valve. All production from the well will be through the tubing to surface facilities. Since there will not be annular flow with this configuration, supplemental corrosion/erosion inspections will not be undertaken. The last production test on 04/15/05 (ESP production) recorded 306 BOPD, 59 BWPD (16%WC), and 56 MSCF of gas. Attached is a wellbore diagram of the well. ConocoPhillips proposes that: 1. The AOGCC approve this request for a time period not to exceed 24 months from the approval date; 2. Should a workover not be completed within the approved time period the AOGCC will be contacted for a review and discussion of the plan forward. NSK Problem Well Supervisor TUBING (0-5312, 00:3,500, 10:2,992) Production (0-6039, 00:7,625, Wt:29,70) PACKOFF SLlPSTOP (5240-5241, 00:3,500) GAUGE (5294-5295, 00:4.000) NIP (5309-5314, 00:3,500) SEAL (5314-5327, 00:5,130) GEARBOX (5327-5328, 00:5,250) MOTOR (5328-5329, 00:5,620) Perf (5513-5545) Perf (5577-5610) Perf (5612-5643) Perf (5668-5688) Perf (5698-5718) Perf (5738-5790) ) Co·nocoPhiiUips Alaska, Inc. f¡ ii Ii ~ i .~~,-~ r~' l' I I' !. . ' ~ , ~. i 1\' - jt~ il~ E~ ~ i~ ~ R~ ~ Ii, Ir¡ ~!' 1'1 . 1',; ~ ~ ~,~. - I I .,.. t. J/ ¡ \ 1·, J ' :f II i '1 "~I ~! \ =I~ =t -"'- Reference Log: Last Tag: Last Tag Date: Cås¡tig$trihg·-ÄLL Description Conductor Production TÛbing..String-TUBING Size I Top 3.500 0 PenôrationsSÙmrriåry Interval TVD 5513 - 5545 3528 - 3558 5577 - 5610 3588 - 3619 5612 - 5643 3621 - 3651 5668 - 5688 3674 - 3693 5698 - 5718 3703 - 3722 5738 - 5790 3741 - 3790 Gås\;'iftllllå"drelslVålves St MD TVD Man Man Type V Mfr V Type V OD Latch Mfr 5220 3253 CAMCO KBMM CAMCO 1. 2000# TBG Shear Other(ph.lgs,eqOiP',etc:) -JEWELRY Depth TVD Type Description 5240 3272 PACKOFF D&D PACKOFF & SLlPSTOP set @ 5240' SLM SLlPSTOP 3272 PUMP 3322 GAUGE 3336 NIP 3341 SEAL 3353 GEARBOX 3354 MOTOR 1D423 API: 500292291400 SSSV Type: NONE Annular Fluid: 5240 5294 5309 5314 5327 5328 ) KRU 1 D-123 Well Type: PROD Orig Completion: 12/29/1998 Last W/O: Angle @ TS: Angle @ TD: Rev Reason: deg @ 17 deg @ 6055 Reset Packoff, Slipstop, PUMP, Set SOV 9/18/2004 Ref Log Date: TD: Last Update: Size 16,000 7.625 Top Bottom TVD Wt Grade Thread 0 121 121 62.58 H-40 WELDED 0 6039 4028 29.70 L-80 BTCMOD TVD Wt I Grade Thread 3339 9.30 L-80 EUE 8rd Status Ft SPF Date Type Comment 32 12 12/18/1998 IPERF 4 1/2" HSD Big Hole Chrgs 33 12 12/18/1998 IPERF 4 1/2" HSD Big Hole Chrgs 31 12 12/18/1998 IPERF 41/2" HSD Big Hole Chrgs 20 12 12/18/1998 IPERF 41n"HSDB~H~eCh~s 20 12 12/18/1998 IPERF 41/2" HSD Big Hole Chrgs 52 12 12/18/1998 IPERF 41/2" HSD Big Hole Chrgs Bottom 5312 Zone WSD WSB WSA4 WSA3 WSA3 WSA2 Port TRO Date Vlv Run Cmnt 9/15/2004 (1) SOV 1.0 BK 0.000 o ID 0.000 LlFTEG 250 T1800 PCP PUMP 34.'5" LONG set 9/14/2004 BAKER SENTRY GAUGE - PUMP INTAKE Slotted Nipple Tandem Seal GSB3 DB IL H6PFS Gear reduction unit 9:1 525 series 57 HP 1315/26 KMH w/motor centralizer 0,000 3,500 2.992 0.000 0.000 0.000 RECEIVED APR 2 9 2005 Alaska Oil & Gas Cons. Commission Anchorage 198-170-0 KUPARUKRIVUWSAK 1D'123 50- 029-22914-00' i/iiILLIPS"~XSKAINC Roll #1: Start: Stop Roll #2: Start Stop MD 06055 TVD 04043 -Cbmpletion Date: '~/29/98 Completed Status: 1-OIL Current: Name Interval 8764 1,2 SPERRY MPT/GR/EWR4 ,]~-4]'-709-'"~ f"l ~ ]..).- J'3~,.2,3 SPERRY MPT/GR/EWR4 /,~DGRJEWR4-MD FINAL 121-6055 ~"~DGR/EWR4-TVD ~'I~SRVY RPT FINAL 121-4043 SPERRY 0~6055. Sent Received T/C/D OH 10/21/98 10/28/98 OH 10/7/98 t 0/7/98 OH 10/21/98 10/22/98 OH 10/21/98 10/22/98 OH 10/13/98 10/14/98 Thursday, January 25, 2001 Page 1 of 1 ARCO Alaska, Inc. ~', Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 11, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-123 (Permit No. 98-179) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1D-123. If there are any questions, please call 265-6120. Sincerely, T. W. Mc Kay Drilling Team Leader AAI Drilling TWM/skad STATE OF ALASKA r'/-,-U~,SKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL E~] GAS [~] SUSPENDED E~ ABANDONED] SERVICE E~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-170 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22914 4 Location of well at surface 9 Unit or Lease Name 211' FNL, 598' FEL, Sec. 23, T11N, R10E, UM ~ .. Kuparuk River Unit At Top Producing lnterval!~'-/"Z~'/~ ~ ~~ ]!, 10 WellNumber 808' FNL, 922' FWL,'Sec. 23, T11N, R10E, UM i' . - I,,~ . ~i 1D-123 At Total Depth ! ~'.~_":i' ..~'~ ~~! 11 Field and Pool 833' FNL, 755' FWL, Sec. 23, TllN, R10E, UM - KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. West Sak Oil Pool RKB 41', Pad 71'I ADL 25650 ALK 468 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 02-Sep-98 05-Sep-98 29-Dec-98I NA feet MSL 1 17 Total Depth (MD+'I'VD) 18 Plug Back Depth (MD+'['VD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 6055' MD & 4043' 'I-VD 6023' MD & 4012' 'I-VD YES X~ NO U N/A feet MD 1522 APPROX 22 Type Electric or Other Logs Run GR/Res, GR/CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF. 121' 24" 9 cu yds High Eady ' :'~ . ~.. . 7.625" 29.7# L-80 SURF. 6039' 9.875" 680 sx AS III L & 340 sx Class G -- SURF. ~-. 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD ' "::'~ ~ /i~_'~~ , interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 5336' N/A 5513'-5545' MD 3528'-3558' ']'VD 12 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 5577'-5610' MD 3588'-3619' 'I-VD 12 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5612'-5643' MD 3621'-3650' TVD 12 spf 5513'-5545', 5577'-5610', see attachments 5668'-5688' MD 3674'-3693' TVD 12 spf 5612'-5643', 5668'-5688', 5698'-5718' MD 3703'-3722' TVD 12 spf 5698'-5718', 5738'-5790' 5738'-5790' MD 3741'-3790' TVD 12 spf 27Date First Production of Operation (Flowing, gas lift, etc.)PRODUCTION TEST "~f"~-~'~M F%''~'~i~'I/~~ ~'~ i Method ~ i ~? ' 2/6/99 Flowing Date of Test Hours Tested PRODUCTION FOI OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL RATIO 2/6/99 3 TEST PERIOQ 19 4 0 100I 23 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) 3ress. 0 0 24-HOUR RATE: 141 3 28 0 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 9. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak Sand 5510' 3525' Bottom West Sak Sand 5961' 3953' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title DATE Prepare~-~ ~ Sharon Allsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 1/19/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-123 WELL ID: AK9613 TYPE: AFC: AK9613 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:09/02/98 START COMP:12/13/98 RIG:NORDIC % 2 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22914-00 09/02/98 (D1) MW: 9.1 VISC: 350 PV/YP: 48/70 APIWL: 5.6 TD: 300'( 300) DRILLING 9 7/8" HOLE @ 1100' SUPV:CUNNINGHAM/LUTRICK Move rig from iD-iii to 1D-123. NU diverter and test. Drill from 121' to 208'. Mud flow line plugged w/gravel, take off & clean out. Drill from 208' to 300' 09/03/98 (D2) MW: 9.7 VISC: 268 PV/YP: 37/49 TD: 3607'(3307) DRILL 9 7/8" HOLE SUPV:CUNNINGHAM/LUTRICK Drill from 300' to 3607' APIWL: 6.1 09/04/98 (D3) MW: 9.6 VISC: 250 PV/YP: 47/57 TD: 5881' (2274) TOOH SUPV:CUNNINGHAM/LUTRICK Drill from 3607' to 4553' APIWL: 4.1 09/05/98 (D4) MW: 9.8 VISC: 260 PV/YP: 53/71 APIWL: 3.5 TD: 6055'(174) CEMENT 7 5/8" CSG. & SET TREE SUPV:CUNNINGHAM/LUTRICK Drill from 5881' to 6055'. Ream from 4820' to 4850'. Run 7-5/8" casing. 09/06/98 (D5) MW: 9.5 VISC: 75 PV/YP: 28/27 APIWL: 3.5 TD: 6055' ( 0) FREEZE PROTECT WELL/ SET TREE & BPV SUPV:CUNNINGHAM/LUTRICK Run casing 7-5/8" to casing shoe @ 6040' Pump cement. Drill out cement from 5573' to 5743' 09/07/98 (D6) MW: 9.5 VISC: 75 PV/YP: 28/27 APIWL: 3.5 TD: 6055' ( 0) RELEASE RIG @ 1430 HRS. SUPV:CUNNINGHAM/LUTRICK Drill out cement from 5743' to 5954'. Freeze protect well. N/D diverter, N/U tree and test to 5000 psi, OK. Release rig from 1D-123 @ 1430 hrs. Date: 1/19/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 REMEDIAL AND COMPLETION OPERATIONS WELL:iD-123 WELL ID: AK9613 TYPE: -- AFC: AK9613 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:09/02/98 START COMP:12/13/98 RIG:NORDIC % 2 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22914-00 12/13/98 (C7) TD: 6040' PB: 0' 12/14/98 (C8) TD: 6040' PB: 5952' 12/15/98 (C9) TD: 6040' PB: 5952' 12/16/98 (Ci0) TD: 6040' PB: 5952' 12/17/98 (Cll} TD: 6040' PB: 5952' 12/18/98 (C12) TD: 6040' PB: 5952' CLEANING OUT ICE F/ 2180' MW: 8.3 FW SUPV:M.C. HEIM Move rig from 1D-112 to 1D-123. Accept rig @ 1100 hrs. 12/13/98. N/D tree. NU BOPE and test to 250/3500%. REVERSE OUT ACID WASH MW: 8.7 BRINE SUPV:M.C. HEIM RIH w/mill and scraper, drill ice plug from 2180' to 2360' Clean out ice plug @ 3433' Pump caustic wash. RD SWS AFTER SETTING FB-1 MW: 8.7 BRINE SUPV:DON E. BREEDEN/LEWIS LEDLOW Pump acid wash. RIH with FB-1 sump packer. Tight spots at 1100' to 1150', & 1258' REVERSING OUT PERF DEBRIS MW: 8.7 BRINE SUPV:DON E. BREEDEN/LEWIS LEDLOW RIH w/FB-1 sump packer and set @ 5798' ELM. Run GR/CCL log fro 5795' to 5200' REVERSE CIRCULATING OUT F MW: 0.0 SUPV:DON E. BREEDEN/LEWIS LEDLOW Perforate A2 sands fro 5790' to 5738' ELM. Pump HEC breakdown. Pump frac. BLEEDING DOWN & MONITORIN MW: 8.7 BRINE SUPV:DON E. BREEDEN/LEWIS LEDLOW Continue to clean out fiber from frac job. Reverse out carboprop and fiber, reverse circulate hole clean for re-frac of A2. Pump data frac and re-frac A2. Reverse out fiber and frac sand. Date: 1/19/99 12/19/98 (C13 TD: 6040' PB: 5952' 12/20/98 (C14 TD: 6040' PB: 5952' 12/21/98 (C15 TD: 6040' PB: 5952' 12/22/98 (C16 TD: 6040' PB: 5952' 12/23/98 (C17 TD: 6040' PB: 5952' 12/24/98 (C18 TD: 6040' PB: 5952' 12/25/98 (C19 TD: 6040' PB: 5952' 12/26/98 (C20 TD: 6040' PB: 5952' ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 DOWELL PUMPED PRE-FRAC WE MW: 0.0 BRINE SUPV:DON E. BREEDEN/LEWIS LEDLOW Reverse circulate hole clean and displace to clean filtered brine. Hold back pressure & slowly bleed off ballooning pressure. Reverse out tubing volume, got oil stained & gas cut brine. Weight up brine and displace well to 9.3 ppg brine. No flow. Perforate A3 at 5668'-5688', & 5698-5718', 12 spf. CHANGING OUT KELLY (PERF MW: 9.8 BRINE SUPV:DON E. BREEDEN/LEWIS LEDLOW Pump high reate breakdown and data frac. Pump frac. Reverse circulate, got gas & oil breaking out. Shut in and monitor pressure. Displace well to brine. Well dead. SPOTTING SAND WITH WORKST MW: 9.8 BRINE SUPV:DON E. BREEDEN/LEWIS LEDLOW Perforate A4 @ 5612'-5643', Perforate B @ 5579'-5610', 12 spf. Pump high rate breakdown. Pump data frac. LANDED HANGER ON 3-1/2" D MW: 9.8 BRINE SUPV:M.C. HEIM /LEWIS LEDLOW Well flowing. Reverse circ. Dump sand down DP. Chase with brine. Reverse sand from 5513' to 5555' WORK STUCK PIPE. MW: 9.8 BRINE SUPV:M.C. HEIM /LEWIS LEDLOW Perf from 5515 to 5546', 12 spf. Start frac. Wash from 5488' to 5585' PICKING UP FISHING BHA MW: 9.2 BRINE SUPV:M.C. HEIM Cleaning hold by reverse circ from 5585' to 5711', packed off, attempt to regain circ, attempt to reverse circ, packed off both ways, pipe stuck. Attempt to free stuck pipe. RIH w/free point. Tight @ 1300' & 2760'. RIH w/slick sinker bars. RIH, torque pipe, misfire, guardian safe system shorted out. RIH w/ run %2, misfire, GSS failed. POH. RIH w/run %3, misfire, cap fired, no detonation to primer cord. POH FOR OVERSHOT TO RETRI MW: 8.7 BRINE SUPV:M.C. HEIM Continue to work pipe. RIH w/fishing tools. Jar on fish. Reverse circ, cleaning out sand from 5593' to 5786' SETTING PACKER FOR GRAVEL MW: 8.7 BRINE SUPV:M.C. HEIM RIH w/overshot to retrieve packer plug. RIH to run gravel pack assembly. Date: 1/19/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 12/27/98 {C21) TD: 6040' PB: 5952' 12/28/98 (C22) TD: 6040' PB: 5952' PICKING UP 3-1/2" TBG. SUPV:M.C. HEIM Gravel pack. MW: 8.7 RUNNING COMPLETION. MW: 8.7 SUPV:M.C. HEIM RIH w/3.5" tubing and run completion w/ esp motor. BRINE BRINE 12/29/98 (C23) TD: 6040' PB: 5952' N/U AND TESTING BOPE ON N MW: 0.0 SUPV:RICK OVERSTREET Finish running completion. ND BOPE. NU tree and test to 500/5000 psi. Prepare for rig move. Date 12/17/98 Well Name 1D-123 Service Type PUMPING Desc of Work "A2" FRAC Supervisor CHANEY Complete Accident E~] Injury Spill Summary Up~bming Job Num Unit 1215981836.3 AFC AK9613 0 Prop 18WST7 Uploaded to S Contractor Key Person Successful Initial Tbg Press 0 Initial lnt Csg Press 0 Initial Out Csg Press 0 DS-GALLEGOS Final Tbg Press 300 Final Int Csg Press 300 Final Out Csg Press 0 "A2" FRAC SCREENED OUT EARLY. TOTAL PROP PUMPED 34295 LBS, PLACED 26569 LBS OF IN THE FORM W/4# PPA OF #16/20 & 1 OF PROPNET @ THE PERF'S. REVERSED OUT TBG & LEFT APP: 2200 LBS OF PROP IN THE WELLBORE AND EST FILL LEVEL @ 5650 MAX TREATING PRESSURE 7000 PSI. [Frac-Refrac] Date printed: 01119199 at: 15:23:38 Date 12/18/98 UpComing ~ '"" ~' Well Name 1D-123 Job Num 1215981836.3 AFC AK9613 Prop 18WST7 Service Type PUMPING Unit 0 Uploaded to S Desc of Work "A2" REFRAC Supervisor CHANEY Contractor Key Person DS-GALLEGOS Complete [~ Successful ~ Accident ~] Initial Tbg Press 300 Final Tbg Press 650 Injury [~ Initial Int Csg Press 300 Final Int Csg Press 650 Spill [~ Initial Out Csg Press 0 Final Out Csg Press 0 Summary "A2" REFRAC COMPLETED. PUMPED 106605 LBS OF PROP, PLACED 105523 LBS IN THE FORM WI 9# PPA OF #16/20 & 1% BW PROPN THE PERF'S. LEFT 1082 LBS OF PROP IN THE WELLBORE. EST FILL LEVEL ¢_. 5700' RKB. MAXIMUM TREATING PRESSURE 5700 PSI. OBTAINED. [Frac-Refrac] Date printed: 01/19/99 at: 15:23:56 Date 12/20/98 uP~dming Well Name 1D-123 Job Num 1215981836.3 AFC AK9613 Prop 18WST7 Service Type PUMPING Unit 0 Uploaded to S Desc of Work "A3" SANDS FRAC Supervisor CHANEY Contractor Key Person DS-GALLEGOS Complete [~ Successful Accident [~] Initial Tbg Press 30 Final Tbg Press 0 Injury E~ Initial Int Csg Press 30 Final Int Csg Press 0 Spill E~] Initial out csg Press 0 Final Out Csg Press 0 Summary "A3" SAND FRAC COMPLETED. PUMPED 112587 LBS OF PROP AND PLACED 106995 LBS OF PROP IN THE FORM W/9# PPA OF #16/2 @ THE PERF'S. FAILED TO TREAT JOB W/PROPNET DUE TO EQUIPMENT PROBLEMS. REVERSED OUT TBG AND LEFT 1300 LBS OF THE WELLBORE. EST FILL TO BE AT 5660' RKB. MAXIMUM PRESSURE 7000 PSI. NO TSO. [Frac-Refrac] Date printed: 01/19/99 at: 15:24:17 Date 12/21/98 up-~bming ['--I Well Name 1D-123 Job Num 1215981836.3 Service Type PUMPING Unit Desc of Work "A4/B" SANDS FRAC Supervisor CHANEY Contractor Key Person Complete [~ Successful [~ Accident [-'--I Initial Tbg Press 120 Injury r--I Initial Int Csg Press 120 Spill ['--] Initial Out Csg Press 0 Summary AFC AK9613 0 Prop 18WST7 Uploaded to S DS-GALLEGOS FinaITbg Press 30 Final Int Csg Press 30 Final Out Csg Press 0 "A4/B" SANDS FRAC COMPLETED. PUMPED 110066 LBS OF PROP IN THE WELLBORE, PLACED 108377 LBS IN THE FORM W/9# PPA #16/20 PROP W/1% BW OF PROPNET @ THE PERF'S. LEFT 1689 LBS OF PROP IN THE WELLBORE AND EST FILL LEVEL TO BE AT 5 RKB. MAXIMUM PRESSURE 7000 PSI. TSO OBTAINED. [Frac-Refrac] Date printed: 01/19/99 at: 15:24:54 Date 12/23/98 uP'~ming E~ Well Name 1D-123 Job Num 1215981836.3 AFC AK9613 Prop 18WST7 Service Type PUMPING Unit 0 Uploaded to S Desc of Work FRAC THE D SAND Supervisor RIGGS Contractor Key Person DS-YOKUM Complete [~ Successful [~ Accident r~ Initial Tbg Press 0 Final Tbg Press 620 Injury [~ Initial Int Csg Press 0 Final Int Csg Press 589 Spill ~ Initial Out Csg Press 0 Final Out Csg Press 0 Summary PUMPED D SAND FRAC FRAC PER PROCEDURE WI70# HEC GEL AND 3 % KCL WATER @ 20 BPM AND AVG PRESSURE OF 3400 PS MAX PRESSURE OF 7000 PSI. PUMPED 70,642 LBS OF 16/20 PROP W/63,965 LBS OF 9 PPG TO PERFS. LEFT 6677 LBS PROP IN PIP EXPECT TAG @ TOP PERF. 5513' DID NOT GET A TIP SCREEN OUT. [Frac-Refrac] Date printed: 01119/99 at: 15:25:08 Kuparuk Unit Kuparuk 1D 1D. 123 SURVEY REPORT October, ~998 Your Ref: API-500292291400 Last Survey Date 05-September-98 Job# AKMMS0362 KBE- 112.10' DRILLING SERVICE5 RECEIVED OCT 1 4 1998 ~omge Survey Ref: svySO Sperry-Sun Drilling Services Survey Report for 1D- ~23 Your Ref: AP1-500292291400 Kuparuk Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) 0.00 0.000 0.000 -112.10 121.00 0.000 0.000 8.90 173.00 1.000 100.000 60.90 287.00 1.440 231.130 174.89 379.51 7.210 261.110 267.10 469.56 14.260 271.850 355.53 561.12 20.260 265.750 442.93 651.43 26.190 259.590 525.90 743.65 32.140 258.830 606.39 834.59 37.860 260.100 680.85 925.72 44.510 260.550 749.40 1017.55 51.700 261.800 810.68 1109.13 58.540 260.430 863.02 1288.74 60.510 260.040 954.11 1560.74 61.000 258.840 1087.00 1841.31 61.170 264.150 1222.73 2128.20 60.660 264.430 1362.19 2411.85 62.420 263.080 1497.36 2692.11 63.430 259.610 1624.95 2979.35 62.810 258.210 1754.82 3265.04 63.600 259.070 1883.61 3544.66 64.250 260.370 2006.52 3828.90 61.970 261.000 2135.07 3924.24 58.540 262.110 2182.37 4020.97 55.340 261.550 2235.13 4113.93 54.570 261.410 2288.51 4209.47 53.660 260.650 2344.51 4303.64 50.490 261.670 2402.38 4399.47 47.680 262.040 2465.14 4494.09 44.150 262.170 2530.96 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.00 N 0.00 E 121.00 0.00 N 0.00 E 173.00 0.08 S 0.45 E 286,99 1.15 S 0.31E 379.20 2.78 S 6.34W 467.63 3.29 S 23.03W 555.03 4.11S 50.13W 638.00 8.87 S 85.36W 718.49 17.31S 129.48W 792.95 26.80 S 180.75W 861.50 36.86 S 239.87W 922.78 47.30 S 307.38W 975.12 58.93 S 381.55W 1066.21 85.19 S 534.10W 1199.10 128.69 S 767,40W 1334.83 164.99 S 1010.17W 1474.29 189.93 S 1259.64W 1609.46 217.08 S 1507.51W 1737.05 254.66 S 1754.15W 1866.92 303,93 S 2005.56W 1995.71 354.15 S 2255.58W 2118.62 398.97 S 2502,70W 2247.17 440.01S 2752.84W 2294,47 452.18 S 2834.71W 2347.23 463.69 S 2914.94W 2400.61 474.96 S 2990.21W 2456.61 487.03 S 3066.67W 2514.48 498.46 S 3140.05W 2577.24 508.72 S 3211.73W 2643.06 518.06 S 3279.04W Dogleg Rate (o/looft) Vertical Section (ft) 5959453.81 N 560490.69 E 0.00 5959453.81 N 560490.69 E 0.000 0.00 5959453.73 N 560491.14 E 1.923 -0.20 5959452.66 N 560491.01 E 1.955 0.75 5959450.98 N 560484.38 E 6.492 5.98 5959450.33 N 560467.69 E 8.105 16.25 5959449.30 N 560440,59 E 6.836 32.90 5959444.25 N 560405.40 E 7.088 57.54 5959435.46 N 560361.35 E 6.464 90.39 5959425.56 N 560310.16 E 6,340 128.31 5959415.02 N 560251.12 E 7.304 171.33 5959404,04 N 560183.70 E 7.895 219,60 5959391,81 N 560109.62 E 7.569 272.76 5959364,32 N 559957.29 E 1,113 383.99 5959318.94 N 559724.35 E 0,425 556.80 5959280.70 N 559481.88 E 1.658 729.37 5959253.74 N 559232.62 E 0.197 896.74 5959224.60 N 558984.98 E 0,748 1064.95 5959185.04 N 558738.65 E 1.160 1240.85 5959133.75 N 558487.64 E 0.485 1429.00 5959081.51 N 558238.04 E 0.386 1617.10 5959034.71 N 557991.29 E 0.478 1799.12 5958991.65 N 557741.48 E 0.826 1979,89 5958978.83 N 557659.72 E 3.737 2038.02 5958966.67 N 557579.58 E 3.344 2094.67 5958954.79 N 557504.40 E 0.837 2148.19 5958942.11 N 557428.04 E 1.150 2203.06 5958930.09 N 557354.75 E 3.473 2255.60 5958919.25 N 557283.16 E 2.947 2306.19 5958909.37 N 557215.92 E 3.732 2353.45 Kuparuk 1D Comment Continued... 12 October, 1998 - 15:06 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-123 Your Ref: API-500292291400 Kuparuk Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 4587.56 39.920 261.650 2600.37 2712.47 526.85 S 3340.99 W 4681.98 36.970 260.340 2674.31 2786.41 536.02 S 3398.97 W 4778.48 36.070 260.330 2751.86 2863.96 545.66 S 3455.58 W 4872.73 32.160 260.670 2829.88 2941.98 554.39 S 3507.71 W 4970.06 28.430 260.000 2913.90 3026.00 562.62 S 3556.10 W 5064.03 25.330 260.240 2997.71 3109.81 569.91 S 3597,95 W 5158.64 22.610 261.740 3084.15 3196.25 575.95 S 3635.90 W 5348.97 20.420 261,350 3261.21 3373.31 586.21 S 3704.94 W 5633.05 18.640 261.830 3528.93 3641.03 600.11 S 3798.88 W 5991.88 17.050 261.460 3870.49 3982.59 616.07 S 3907.68 W 6055.00 17.050 261.460 ' 3930.84 4042.94 618.82 S 3925.98 W 5958900.08 N 557154.05 E 5958890.45 N 557096.14 E 5958880.35 N 557039.61E 5958871.20 N 556987.56 E 5958862.59 N 556939.23 E 5958854.96 N 556897.44 E 5958848.61N 556859.54 E 5958837.80 N 556790.59 E 5958823.14 N 556696.76 E 5958806.30 N 556588.10 E 5958803.40 N 556569.82 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 216.170° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6055.00ft., The Bottom Hole Displacement is 3974.45ft., in the Direction of 261.043° (True). Dogleg Rate (°/100ft) 4.541 3.241 0.933 4.153 3.848 3.301 2.946 1.153 0.629 0.444 0.000 Vertical Section (ft) 2397.11 2438.73 2479.92 2517.73 2552.93 2583.52 2610.80 2659.82 2726.49 2803.58 2816.60 Kuparuk 1D Comment Projected Survey Continued... 12 October, 1998 - 15:06 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for ID-123 Your Ref: API-500292291400 Kuparuk Unit Kuparuk 1D Comments Measured Depth (ft) 0.00 6055.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 0.00 N 0.00 E 4042.94 618.82 S 3925.98 W Comment Tie-on Survey Projected Survey 12 October, 1998 - 15:06 - 4 - DrillQuest 0 F! I Cl--I I~ CS SEFI~JICE S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.- Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1D-123, October 21, 1998 f, AK-MM-80362 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22914-00 O ,T ?8 i998 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A I'"', ..... i ,.I ! ~ D I::! I I--I-- I IM G WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs October 21, 1998 1D-123, AK-MM-80362 The technical data limed bdow is being submitted herewith. Please address any problems or concerns to the attention off Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 1D-123: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22914-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22914-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia "' &. O,,,T £ ° 1998 Anchor~e 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 · (907) 273-3500. Fax (907) 273-3535 DF:IlL-lING S I:: I:i~/I C E S 13-0ct-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re' Distribution of Survey Data for Well 1 D-123 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 6,055.00' MD (if applicable) Please call me'at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 00T 1 4 1998 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION September 1, 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Thomas W. McKav Shallow Sands Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1 D- 123 ARCO Alaska, Inc. Permit No: 98-170 Sur Loc: 211'FNL, 598'FEL, Sec. 23, T11N, R10E, UM Btmhole Loc. 827'FNL, 715'FWL. Sec. 23. TllN, R10E. UM Dear Mr. McKay: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not bccn requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 1 D-123. Please note that an,,' disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a permitted existing well on Drill Site 1D must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or for a period longer than one year. Bloxvout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · Robert N. Christenson. P.E. Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures Department of Fish & Game, Habitat Section w/o cncl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA ALAS,-,~ OIL AND GAS CONSERVATION COMM-,~51ON PERMIT TO DRILL 2O AAC 25.005 la. Type of Work Ddll X Redrill I lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41' Pad 7]' feet Kuparuk River Field ;~. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchora~le, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 211' FNL, 598' FEL, Sec. 23, T1 IN, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 801' FNL, 884' FWL, Sec. 23, TllN, R10E, UM 1D-123 #U-630610 At total depth 9. Approximate spud date Amount 827' FNL, 715' FWL, Sec. 23, T1 iN, R10E, UM 9]3/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1D-122 6175' MD 715' @ TD feet 15' @ 300' feet 2560 4130' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 63.63° Maximum surface 1380 psig At total depth (TVD) 1813 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' +_.200 CF 9.875" 7.625" 29.7# L-80 BTC MOD 6134' 41' 41' 6175' 4130' 652 Sx Arcticset III L & 331 Sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: true measured vertical feet feet Plugs(measured)ORIGINAL Effective depth: measured feet Junk (measured) true vertical feet Casing ~tornUc~tuUcr~r Length Size CementedR E C E IV LCd[~ured depth True Vertical depth Surface Intermediate Production AUG 19 1998 Liner Perforation depth: measured ~ 0ii & Gas Cons.C0mmis,filt true vertical/tachorago 20. Attachments Filing fee X Property plat BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify. J_h__at the foregoing is true and correct to the best of my knowledge ~ .¢ ~ Signe 1 ~/~::~A- Title Shallow Sands Team Leader Date Commission Use Only I APl number I Approval date I See cover letter for Perm4"~rnber j ~ b 50- f-~ ~ C~ -- ~, ~. C,~ ~, ~ ~...._ / ..- ~ ~1~ other re..~uirements Conditions of approval Samples required Yes ~ Mud Icg required Yes .(-J:~ Hydrogen sulfide measures Yes (N~ Directional survey required v No Required working pressure for DOPE 2M 3~ 5M 10M 15M Other: ORIGINAL SIGNED-BY Robert N. (:::;hri,tenso¢l by order of ¢..... Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor August 17, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1 D-123 West Sak Phase lB Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1 D pad. The well is designated as a monobore production well using a single 7 5/8" casing string, with 3-1/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak Pool Rules. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU and West Sak wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-123, such as shallow gas. There have been ten (10) Kuparuk wells and (20) West Sak wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) 8) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. Please note that the anticipated spud date for this well is September 3, 1998. If you have any questions or require further information, please contact Scott Goldberg at (907) 263-4622 or Tom McKay at (907) 265-6890. Sincerely, Scott Goldberg ~ Operations Drilling Engineer CC: West Sak 1D-123 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Cliff Crabtree NSK6 Drill, Case and Completion Plan for West Sak 1D-123 (Gl) Frac Pack Producer General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. 3. Spud and directionally drill 9 7/8" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 7 5/8" 29.7# L80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with non freezing completion brine, bump the plug and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results of pressure test NOTE: TAM Port Collar will be placed in the 7 5/8" casing +1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar,La ~op job may be performed in lieu of utilizing the port collar. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. 6. Nipple down diverter, nipple up tubing head and BOP's. Test BOP's. Notify AOGCC 24 hours before test 7. Rig up and run workstring to TD. Circulate the well with seawater and freeze protect the upper_+2000' with diesel 8. Nipple down BOP's. Install production tree and pressure test same. 9. Secure well, release rig RECEIVED AUG 19 1998 Alas~ Oil & Gas Cons. C0mmiss~0r, ~ch0rage 1D-123 (Gl) Page 1 SG, 08/17/98, v.1 Completion Plan for West Sak 1D-123 (Gl) Four-Stage, Single-Trip Frac-Pack Job, Frac-Packed Producer General Procedure: Well Preparation 1. Move in / rig up completion rig. , Pull back pressure valve, nipple down tree and install 11" 5M WP BOP stack and pressure test same. . Trip in with 6-3/4" bit and scraper on 3-1/2" workstring, and RIH to PBTD. Pressure test 7-5/8" 29.7# L80 BTC-MOD casing. Perform casing wash and displace well to filtered brine. Pickle workstring as required. Filter brine to desired level. Trip out. . Rig up E-line unit, and make correlation run as required with GR/CCL to correlate logs for perforating. . Make up Baker sump packer on E-line. RIH and set same below A2 sands (bottom pay sands). Space out and set sump packer to position TCP guns accurately on next trip in. POOH with E-line. . Pick up TCP perforating gun string to perforate all West Sak intervals in one trip. Trip in with 3-1/2" workstring, and sting into sump packer seal bore. Locate TCP guns on depth. Set TCP packer above West Sak. . Use diesel cap and/or void tubing to achieve desired underbalance. Drop bar and fire guns. . Release packer and reverse out to clean brine. Kill well as required. TOH with TCP gun string. . Pick up gravel pack assembly, including wire-wrapped screens, gravel pack and isolation packers, blank pipe, frac-pack crossover tool, and other jewelry and trip in hole on 3-1/2" workstring. Screens and packers should be spaced out to allow for isolated frac-packs on the following four West Sak intervals in one trip: Stage 1: A2 Stage 2: A3 Stage 3: A4 + B Stage 4: D 1 D-123 (Gl) Page 2 SG, 08/17/98, v.1 Stage 1 10. 11. 12. 13. 14. Stage 2 15. 16. 17. 18. 19. Stage 3 20. 21. 22. 23. 24. Locate gravel pack string into seal bore of sump packer. Sting lower screen seal assembly and snap-latch into sump packer. Set all isolation packers. Rig up and pressure test frac equipment at surface. Position frac-pack crossover tool as required. Perform data frac for Stage 1. Using 16-20 mesh carbolite proppant, proceed to frac Stage I with the specified volume of proppant. Shift crossover tool, and gravel pack Stage 1. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Re-position frac-pack tools to frac-pack Stage 2 interval. Rig up and pressure test frac equipment at surface. Position frac-pack crossover tool as required. Perform data frac for Stage 2. Using 16-20 mesh carbolite proppant, proceed to frac Stage 2 with the specified volume of proppant. Shift crossover tool, and gravel pack Stage 2. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Re-position frac-pack tools to frac-pack Stage 3 interval. Rig up and pressure test frac equipment at surface. Position frac-pack crossover tool as required. Perform data frac for Stage 3. Using 16-20 mesh carbolite proppant, proceed to frac Stage 3 with the specified volume of proppant. Shift crossover tool, and gravel pack Stage 3. Shift gravel pack tools, and reverse out excess proppant and frac fluids. 1 D-123 (Gl) Page 3 SG, 08/17/98, v.1 Stage 4 25. 26. 27. 28. 29. 30. 31. 32. 33. 34. 35. 36. 37. 38. Re-position frac-pack tools to frac-pack Stage 4 interval. Rig up and pressure test frac equipment at surface. Position frac-pack crossover tool as required. Perform data frac for Stage 4. Using 16-20 mesh carbolite proppant, proceed to frac Stage 4 with the specified volume of proppant. Shift crossover tool, and gravel pack Stage 4. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Release frac-pack running tools and trip out of well. At this point, the flow conduit inside the screens from the sump packer to the upper packer should be free of sand and any plugs. Rathole should be available below sump packer. Circulate well to clean brine. TOH with workstring. Change rams to 3 1/2" and pressure test same unless VBR's are available. Pick up Centrilift ESP on 3 1/2" production tubing. Run in well with ESP pump with power cable and data gathering information wire attached to tubing. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. Position ESP at desired depth, set tubing hanger and run electrical penetrators through same. Make surface electrical connections as required, and set back pressure valve in tubing hanger. Nipple down BOP stack, and nipple up production tree. Pressure test production tree. Secure well. Release rig and turn well over to production. 1D-123 (Gl) Page 4 SG, 08/18/98, v.1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1D-123 (Gl) Drilling Fluid Type Extended Bentonite Slurry Drilling Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 40 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.7-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12 % Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A 7 5/8" surface / production casing string will be run to total depth (TD). This combination surface / production casing will be cemented to surface. A TAM Port Collar will be placed at approximately 1000' TVD. This will be used as a contingency if cement is not brought to surface as planned. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-123 (Gl) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. 1 D-123 (G 1 ) Page I SG,08/17/98,v.1 Based on actual well test data from the nearby WS1-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.7 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,514' MD/TVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base to surface, the following MASP can be computed: MASP = (3942 ft)(0.46- 0.11 psi/ft) = 1380 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 7' 5/8" combination surface / production casing in this well, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi. The 7' 5/8" 29.7'# 1.80 ElTO casing to be used has a burst rating of 6,890 psi; 70 % of this burst rating is 4,823 psi. Drilling Area Risks: Drilling risks in the West Sak 1D-123 (Gl) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. Well Proximity Risks: The nearest existing well to West Sak 1D-123 (Gl) is WS 1D-122. As designed, the minimum distance between the two wells would be 15.0' at 300' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existing well on DS-ID. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-123 (Gl) surface casing will be filled with diesel and/or non-freezing brine after cleaning out the 7 5/8" casing and prior to the drilling rig moving off of the well. 1 D-123 (Gl) Page 2 RECEIVED AUG i 9 1998 Alaslfa 0il & Gas Cons, CoBmJssJoB Anchorage SG, 08/17/98,v. 1 3-1/2" Production Tubing 9,3# L-80 EUE 8RD-Mod Power Cable for ESP Centrilift West Sak Well 1 D-123 (Gl) Four (4) Stage Frac-Pack 16" Conductor Casing @ 80' Raychem Heat Trace (through permafrost) 2438' MD/1634' TVD TAM International 7 5/8" Port Collar Set at approximately 1000' TVD Camco 3-1/2" x 1" 'KBMM' Gas Lift Mandrel Arctic Lift 3500 psi Shear circulating valve pre-loaded in GLM (circulate well for freeze protection purposes) ESP Pump Section Centrilift ESP Gearbox Centrilift ESP Motor Section Centrilift D Sand Frac-Pack Assembly with Screen Baker Oil Tools B + A4 Sands Frac-Pack Assembly with Screen Baker Oil Tools A3 Sand Frac-Pack Assembly with Screen Baker Oil Tools 7-5/8" Combination Surface/Production Casing, 29.7# L-80 BTC-MOD Set at 6175' MD/4130' TVD A2 Sand Frac-Pack Assembly with Screen Baker Oil Tools ARCO Alaska, Inc. SG, 08/17/98 O~0ted ~ f;~ For: BROCKWAY Dote plotted : 24-Jun-g8 Plot Reference ;s WS 1D-125/GI Vers. ~4. Ceord~notes ore in feet reference spot ~123. T~e Vettica~ Oepths ore reference ~B (Porker .......... Slrucfure : Pod 10 Well: 125 Field : Kuparuk River Unit Location : North Slope, <- West (feet) 4200 3900 3600 3300 3000 2700 2400 2100 1800 1500 1200 900 600 500 0 I I I I I f TD LOCATION: 827' FNL, 715' mL SU~FAC~ 300 600 900 1200 i500 1800 2100 2400 2700 3000 3300 3600 3900 4200 RKB ELEVATION: 112' K0P TVD=300 TMD=300 DEP=0 6.00 12.00 18.00 24.00 DLS: 6.00 deg per 100 ft 30.00 i6.00 42.00 48.OO 54.00 EOC TVD=1156 TMD=1361 DEP=551 TARGET LOCATION: 801' FNL, 884' FWL SEC. 23, T11N, RIOE TARGET TVD=3661 TMD=5676 OEP=3844 SOUTH 59O WEST 3798 211' FNL, 598' FEL SEC. 25, T11N, RIOE 261.17 AZIMUTH 3844' (Z0 TARGET) MAXIMUM ANGLE 63.63 DEG PERMAFROST TVD=1654 TMD=2458 DEP=1496 BEGIN ANGLE DROP TVD=2268 TMD=3865 DEP=2775 63.00 57.00 51.00 48.00 4-5.00 42.00 39.00 DLS: ,3.00 deg per 100 ft ,36.00 T/ UGNU SNDS -PFD=2941 TMD=4889 ,35.00 30.00 27.00 24.00 END ANGLE DROP TVD=,3326 TMD=5320 DEP=3722 21.00 T/ W SAK SNDS 71/0=,3514 TMD=5520 DEP=3790 TARGET - A3 TVD=3661 TMD=5676 DEP=3844 TARGET ANGLE 20 DEG B/ W SAK SNDS TVD=3942 TMD=5975 DEP=5946 TD - CSG PT TVD=4130 TMD=6175 OEP=4014 I i i 0 300 i i i i I i i ii i I i i I i I I i I I 600 900 1200 1500 1800 21 O0 2400 2700 5000 5300 3600 VerficQI Section (feet) -> Azimuth 261.17 wHh reference 0.00 N, 0.00 E from slot #123 i I I I 3900 4200 300 300 300 600 900 Creeled by finch For: EROCKI~AY Dote plotted : 24-dun-g8 Plot Reference is WS 1D-123/G1 Vets. ~4. Coordinotes are in feet reference slot ~t12.3. / 4O iD 0 + 40 0 80 I ¥ ARCO Alaska, Inc. S~ructure : Pad 1D Well : 123 Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 800 760 720 680 640 600 560 520 480 440 400 360 320 280 240 200 160 120 80 40 0 40 150 240 ~ i i i i i i I i i I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ~ [ I %~800 ...... _ 1100 70~(4~¢0~ 2600 ............ 6 -~900 300 20O ~2o ~ 17oo ~~oo ~1ooo ~ ........................... 1400 ~ 1500 ~ ..................................................... 1200 1100 ~ ~ ~ - ................... ~ooo 9o0 soo ~ ~ ~ .................... soo ~oo ~ ~ ~ 160O ~ ~ 50( 800 ~ ~ ~ 700 ~ ~) aaa ................ ~9oo ~ ~ gO0 .................. 2000 500 1~00 1000 ~ ~ ............ 2100 500 ~ c~ ~ ~ ~ oo ....................... ~ 20o ~' ~ ~ 3oo ._~ soo ~ 1200 1400 ~~ .........~,'--- . _,~ ...~' 800.,/ ..... /,/ 11 0~/" 200 2oo~ ' .~.~ .... ~'~oo ~ aaa ,,'" .,," ~ ,,"/ , ,,,'" ............... " . ....... .,,, ,// // ,0 ,,,," 100( 800 760 720 680 640 600 560 520 480 440 400 360 520 280 2~0 200 160 120 ~0 <- West (feet) 240 200 )c]6o 120 8O 4O 0 0 4o -'~ ._+. 8O I v 120 160 200 ~_40 28O 32O Ierected by finch For: BROCKWAY Dote plotted : 24-Jun-98 Plot Reference is WS 1D-123/C1 Vets, ;~4. Coordinates ore in feet reference slot ~/12.3. True Verticol Depths~RKB (Porker //24§). ARCO Alaska, Inc. Structure: Pad 1D Well : 123 Field : Kuporuk River Unit Location : North Slope, Alaska <- West (feet) 2700 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 500 4O0 ~ 3200 3100 .... 330~-'""'"'--~3700 '"~--.¢'-~-- 300 ~ .............. 3000 2900 ..................... ?oo ........................... ~700 2600 2500 ...................................... ?00 2`300 2900 280~ 2700~ 200 ................... 2000 ......................... ~900 1800 1700 lOO .............. 0 Q~ 100 -+- 200 0 300 I v 4OO 5OO 600 500 400 3OO 2OO 700 8OO 9OO lO0 12_0.C].~ O 1300 ............... 100 1400 ...................... 1500 1600 .................... 200 1700 ..................... 2107./-~~ 3oo I 2 310 1800 .-" / ,3500 ~ 1.~.0..0.......-1470// L/~ 500 390 ~ 6oo --" 1500 ~-" / /' ...... ~ ,..27..1"~oo ........ ~ 6oo_...~ ,,,;;,,,,,, · 700 ....... 17oo .,294oo /54oo ] soo i I I I i I I i I I [ .... ']- .... 'T-- I I I i I I I I I I I i I I I I I I I I I I I I I I I I I I / 900 2700 2600 2500 2400 2.300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 11 O0 1000 900 800 700 600 500 <- West (feet) aska, In ........... Slructure : Pod 1D Well: 125 Field : Kuporuk River Unif Locetion : North Slope, AleskoI WELL PROFILE DATA ..... Po;hr ..... ~0 thc C{r ~ North E<~st V. s~c~ D~g/I(X 'l~e ~ 0.~ 0.~ 261,17 0.00 0.~ 0.~ 0.~ 0,~ KCP 3~.00 0.~ 261,17 300.000.~ 0.00 0.~ 0.~ E~d ~f ~td 1360.5~63.~ 261,17 11~5.5~ -Bl.~7 --524.5~ ~30.BI ~.~ End ~t Ha~ 3~t.~8 ~.~ 2~1,~7 2266.11 -425.93 -27~2.27 2775.15 0.~ End o~ Drop 5319.8820.~ 26t,17 3326.06 -571.1g -3677.~3721.59 3.~ Tcrget ~ I0-G1 ~d 2 5676.32 20.~ 261,17 3661.00 -58g.go -37gT.g6 38~5,~ 0.~ ~E~4 c~ H~d 5975.5520.~ 261.17 3~2.00-605.60 -~S99.02 3g~5.77 0.~ T.O. ~ Etd of Ho~d 6175.3520.~ 261,17 ~l~g.g~ -616.10 -3966.62 530 55O ,320 TRUE NORTH 0 10 700 · · 310 I Creoted bl' finch For: BROCIC~AY Oote plated : 24-Jun-98 Plot Reference fs WS 1D-123/GI Ve.m. ~4. CuordinOtes ere ;n feet r~ference slot ~125. [rue Vsdicol Depths ore reference RKB (Parker 700 3O0 290 70 280 9OO 8© 27O 9O 26O 100 250 110 240 250 220 210 20O Normal Plane Travelling Cylinder- Feet ; 7oo 1 50 ' gO0 190 180 All aa s shown are Measured depths on Reference Well ARCO Alaska, Inc. Pad 1D 123 slot #123 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : WS 1D-123/G1 Vets. #4 Our ref : prop2203 License : Date printed : 24-Jun-98 Date created : 16-Apr-97 Last revised : 12-Jun-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 17 59.241,w149 30 36.341 Slot Grid coordinates are N 5959453.696, E 560490.676 Slot local coordinates are 211.00 S 598.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 1D,123 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 0.00 0.00 261.17 0.00 0.00 N 0.00 300.00 0.00 261.17 300.00 0.00 N 0.00 400.00 6.00 261.17 399.82 0.80 S 5.17 500.00 12.00 261.17 498.54 3.20 S 20.62 600.00 18.00 261.17 595.09 7.17 S 46.18 700.00 24.00 261.17 688.40 12.67 S 81.58 800.00 30.00 261.17 777.46 19.64 S 126.42 900.00 36.00 261.17 861.29 27.99 S 180.21 1000.00 42.00 261.17 938.97 37.65 S 242.37 1100.00 48.00 261.17 1009.65 48.49 S 312.21 1200.00 54.00 261.17 1072.55 60.42 S 388.97 1300.00 60.00 261.17 1126.99 73.28 S 471.81 1360.53 63.63 261.17 1155.58 81.47 S 524.52 1500.00 63.63 261.17 1217.52 100.65 S 648.00 2000.00 63.63 261.17 1439.59 169.40 S 1090.67 2437.73 63.63 261.17 1634.00 229.60 S 1478.21 2500.00 63.63 261.17 1661.66 238.16 S 1533.34 3000.00 63.63 261.17 1883.72 306.91 S 1976.02 3500.00 63.63 261.17 2105.79 375.67 S 2418.69 3865.48 63.63 261.17 2268.11 425.93 S 2742.27 3886.55 63.00 261.17 2277.57 428.82 S 2760.86 3986.55 60.00 261.17 2325.29 442.30 S 2847.70 4086.55 57.00 261.17 2377.53 455.39 S 2931.94 4186.55 54.00 261.17 2434.16 468.04 S 3013.37 4286.55 51.00 261.17 2495.03 480.21 S 3091.75 4386.55 48.00 261.17 2559.97 491.88 S 3166.88 4486.55 45.00 261.17 2628.80 503.01 S 3238.55 4586.55 42.00 261.17 2701.33 513.58 S 3306.57 4686.55 39.00 261.17 2777.36 523.54 S 3370.73 4786.55 36.00 261.17 2856.68 532.88 S 3430.88 4886.55 33.00 261.17 2939.09 541.58 S 3486.84 4888.83 32.93 261.17 2941.00 541.77 S 3488.07 4986.55 30.00 261.17 3024.34 549.60 S 3538.47 5086.55 27.00 261.17 3112.21 556.92 S 3585.61 5186.55 24.00 261.17 3202.46 563.52 S 3628.15 5286.55 21.00 261.17 3294.84 569.40 S 3665.96 5319.88 20.00 261.17 3326.06 571.19 S 3677.50 5500.00 20.00 261.17 3495.32 580.64 S 3738.37 5519.88 20.00 261.17 3514.00 581.69 S 3745.09 5676.31 20.00 261.17 3660.99 589.90 S 3797.96 PROPOSAL LISTINO Dage 1 Your ref : WS 1D-123/G1 Vets. #4 Last revised : 12-Jun-98 Dogleg Vert Deg/100ft Sect E 0.00 0.00 E 0.00 0.00 W 6.00 5.23 W 6.00 20.87 W 6.00 46.74 W 6.00 82.56 W 6.00 127.94 W 6.00 182.38 W 6.00 245.28 W 6.00 315.96 W 6.00 393.64 W 6.00 477.46 W 6.00 530.81 W 0.00 655.77 W 0.00 1103.75 W 0.00 1495.94 W 0.00 1551.73 W 0.00 1999.71 W 0.00 2447.69 W 0.00 2775.15 KOP W 3.00 2793.97 W 3.00 2881.84 W 3.00 2967.09 W 3.00 3049.50 W 3.00 3128.82 EOC Base Permafrost Begin Angle Drop W 3.00 3204.86 W 3.00 3277.38 W 3.00 3346.21 W 3.00 3411.15 W 3.00 3472.02 W 3.00 3528.65 W 3.00 3529.89 W 3.00 3580.90 W 3.00 3628.61 W 3.00 3671.65 Top Ugnu Sands W 3.00 3709.92 W 3.00 3721.59 End Angle Drop W 0.00 3783.19 W 0.00 3789.99 Top West Sak Sands W 0.00 3843.49 TARGET - West Sak A3 5676.32 20.00 261.17 3661.00 589.90 S 3797.96 W 0.00 3843.50 5975.35 20.00 261.17 3942.00 605.60 S 3899.02 W 0.00 3945.77 6000.00 20.00 261.17 3965.16 606.89 S 3907.35 W 0.00 3954.21 6175.35 20.00 261.17 4129.94 616.10 S 3966.62 W 0.00 4014.18 WS 1D-G1 Rvsd 26-Jan-98 Base West Sak Sands TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #123 a~d TVD from RKB (Parker #245) (112.00 Ft~e mea~ sea level). Bottom hole distance is 4014.18 on azimuth 261.17 degrees '~-~ wellhead. Total Dogleg for wellpath is 107.26 degrees. Vertical section is from wellhead on azimuth 261.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,123 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-123/G1 Vets. #4 Last revised : 12-Jun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 300.00 300.00 0.00 N 0 00 E KOP 1360.53 1155.58 81.47 S 524 2437.73 1634.00 229.60 S 1478 3865.48 2268.11 425.93 S 2742 4888.83 2941.00 541.77 S 3488 5319.88 3326.06 571.19 S 3677 5519.88 3514.00 581.69 S 3745 5676.31 3660.99 589.90 S 3797 5676.32 3661.00 589.90 S 3797 5975.35 3942.00 605.60 S 3899 6175.35 4129.94 616.10 S 3966 52 W EOC 21 W Base Permafrost 27 W Begin Angle Drop 07 W Top Ugnu Sands 50 W End Angle Drop 09 W Top West Sak Sands 96 W TARGET - West Sak A3 96 W WS 1D-G1 Rvsd 26-Jan-98 02 W Base West Sak Sands 62 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6175.35 4129.94 616.10S 3966.62W 7 5/8" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-G1 Rvsd 26-Jan 556698.000,5958833.000,0.0000 3661.00 589.90S 3797.96W 14-Oct-96 . . . ARCO Alaska, Inc. Pad 1D,123 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 0.00 0.00 261.17 0.00 211.00 S 598.00 300.00 0.00 261.17 300.00 211.00 S 598.00 400.00 6.00 261.17 399.82 211.80 S 603.17 500.00 12.00 261.17 498.54 214.20 S 618.62 600.00 18.00 261.17 595.09 218.17 S 644.18 700.00 24.00 261.17 688.40 223.67 S 679.58 800.00 30.00 261.17 777.46 230.64 S 724.42 900.00 36.00 261.17 861.29 238.99 S 778.21 1000.00 42.00 261.17 938.97 248.65 S 840.37 1100.00 48.00 261.17 1009.65 259.49 S 910.21 1200.00 54.00 261.17 1072.55 271.42 S 986.97 1300.00 60.00 261.17 1126.99 284.28 S 1069.81 1360.53 63.63 261.17 1155.58 292.47 S 1122.52 1500.00 63.63 261.17 1217.52 311.65 S 1246.00 2000.00 63.63 261.17 1439.59 380.40 S 1688.67 2437.73 63.63 261.17 1634.00 440.60 S 2076.21 2500.00 63.63 261.17 1661.66 449.16 S 2131.34 3000.00 63.63 261.17 1883.72 517.91 S 2574.02 3500.00 63.63 261.17 2105.79 586.67 S 3016.69 3865.48 63.63 261.17 2268.11 636.93 S 3340.27 3886.55 63.00 261.17 2277.57 639.82 S 3358.86 3986.55 60.00 261.17 2325.29 653.30 S 3445.70 4086.55 57.00 261.17 2377.53 666.39 S 3529.94 4186.55 54.00 261.17 2434.16 679.04 S 3611.37 4286.55 51.00 261.17 2495.03 691.21 S 3689.75 4386.55 48.00 261.17 2559.97 702.88 S 3764.88 4486.55 45.00 261.17 2628.80 714.01 S 3836.55 4586.55 42.00 261.17 2701.33 724.58 S 3904.57 4686.55 39.00 261.17 2777.36 734.54 S 3968.73 4786.55 36.00 261.17 2856.68 743.88 S 4028.88 PROPOSAL LISTING Page 1 Your ref : WS 1D-123/G1 Vets. #4 Last revised : 12-Jun-98 Dogleg Vert Deg/100ft Sect W 0.00 0.00 W 0.00 0.00 KOP W 6.00 5.23 W 6.00 20.87 W 6.00 46.74 W 6.00 82.56 W 6.00 127.94 W 6.00 182.38 W 6.00 245.28 W 6.00 315.96 W 6.00 393.64 W 6.00 477.46 W 6.00 530.81 EOC W 0.00 655.77 W 0.00 1103.75 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 1495.94 Base Pera~afrost 1551.73 1999.71 2447.69 2775.15 Begin Angle Drop W 3.00 2793.97 W 3.00 2881.84 W 3~00 2967.09 W 3.00 3049.50 W 3.00 3128.82 W 3.00 3204.86 W 3.00 3277.38 W 3.00 3346.21 W 3.00 3411.15 W 3.00 3472.02 4886.55 33.00 261.17 2939.09 752.58 S 4084.84 W 3.00 4888.83 32.93 261.17 2941.00 752.77 S 4086.07 W 3.00 4986.55 30.00 261.17 3024.34 760.60 S 4136.47 W 3.00 5086.55 27.00 261.17 3112.21 767.92 S 4183.61 W 3.00 5186.55 24.00 261.17 3202.46 774.52 S 4226.15 W 3.00 5286.55 21.00 261.17 3294.84 780.40 S 4263.96 W 3.00 5319.88 20.00 261.17 3326.06 782.19 S 4275.50 W 3.00 5500.00 20.00 261.17 3495.32 791.64 S 4336.37 W 0.00 5519.88 20.00 261.17 3514.00 792.69 S 4343.09 W 0.00 5676.31 20.00 261.17 3660.99 800.90 S 4395.96 W 0.00 5676.32 20.00 261.17 3661.00 800.90 S 4395.96 W 0.00 5975.35 20.00 261.17 3942.00 816.60 S 4497.02 W 0.00 6000.00 20.00 261.17 3965.16 817.89 S 4505.35 W 0.00 6175.35 20.00 261.17 4129.94 827.10 S 4564.62 W 0.00 3528.65 3529.89 Top Ugnu Sands 3580.90 3628.61 3671.65 3709.92 3721.59 End Angle Drop 3783.19 3789.99 Top West Sak Sands 3843.49 TARGET - West Sak A3 3843.50 WS 1D-G1 Rvsd 26-Jan-98 3945.77 Base West Sak Sands 3954.21 4014.18 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 14, T11N, R10E and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 4014.18 on azimuth 261.17 degrees from wellhead. Total Dogleg for wellpath is 107.26 degrees. Vertical section is from wellhead on azimuth 261.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,123 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-123/G1 Vets. #4 Last revised : 12-Jun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 300.00 300.00 211.00 S 598 1360.53 1155.58 292.4? S 1122 2437.73 1634.00 440.60 S 2076 3865.48 2268.11 636.93 S 3340 4888.83 2941.00 752.77 S 4086 5319.88 3326.06 782.19 S 4275 5519.88 3514.00 792.69 S 4343 5676.31 3660.99 800.90 S 4395 5676.32 3661.00 800.90 S 4395 5975.35 3942.00 816.60 S 4497 6175.35 4129.94 827.10 S 4564 .00 W KOP .52 W EOC .21 W Base Permafrost 27 W Begin Angle Drop 07 W Top Ugnu Sands 50 W End Angle Drop 09 W Top West Sak Sands 96 W TARGET - West Sak A3 96 W WS 1D-G1 Rvsd 26-Jan-98 02 W Base West Sak Sands 62 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 211.00S 598.00W 6175.35 4129.94 827.10S 4564.62W 7 5/8" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-G1 Rvsd 26-Jan 556698.000,5958833.000,0.0000 3661.00 800.90S 4395.96W 14-Oct-96 ARCO Alaska, Inc. Pad 1D,123 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T Depth Degrees Degrees Depth C 0 0 R 0.00 0.00 261.17 0.00 0.00 300.00 0.00 261.17 300.00 0.00 400.00 6.00 261.17 399.82 0.80 500.00 12.00 261.17 498.54 3.20 600.00 18.00 261.17 595.09 7.17 700.00 24.00 261.17 688.40 12.67 800.00 30.00 261.17 777.46 19.64 900.00 36.00 261.17 861.29 27.99 1000.00 42.00 261.17 938.97 37.65 1100.00 48.00 261.17 1009.65 48.49 1200.00 54.00 261.17 1072.55 60.42 1300.00 60.00 261.17 1126.99 73.28 1360.53 63.63 261.17 1155.58 81.47 1500.00 63.63 261.17 1217.52 100.65 2000.00 63.63 261.17 1439.59 169.40 2437.73 63.63 261.17 1634.00 229.60 2500.00 63.63 261.17 1661.66 238.16 3000.00 63.63 261.17 1883.72 306.91 3500.00 63.63 261.17 2105.79 375.67 3865.48 63.63 261.17 2268.11 425.93 A N G U L A R Vert D I N A T E S Sect PROPOSAL LISTING Page 1 Your ref : WS 1D-123/G1 Vers. #4 Last revised : 12-Jun-98 Ellipse Semi Axes Minor Major Minor Vert. Azi. N 0.00 E 0.00 0.00 0.00 0.00 N/A N 0.00 E 0.00 0.78 0.78 0.45 N/A S 5.17 W 5.23 1.11 1.05 0.60 81.17 S 20.62 W 20.87 1.76 1.34 0.75 81.17 S 46.18 W 46.74 2.97 1.69 0.92 81.17 S 81.58 W 82.56 4.86 2.09 1.13 81.17 S 126.42 W 127.94 7.52 2.54 1.39 81.17 S 180.21 W 182.38 11.03 3.05 1.73 81.17 S 242.37 W 245.28 15.44 3.58 2.18 81.17 S 312.21 W 315.96 20.77 4.11 2.74 81.17 S 388.97 W 393.64 26.99 4.64 3.42 81.17 S 471.81 W 477.46 34.04 5.13 4.20 81.17 S 524.52 W 530.81 38.59 5.40 4.71 81.17 S 648.00 W 655.77 49.11 6.04 5.91 81.17 S 1090.67 W 1103.75 86.99 8.32 10.25 81.17 S 1478.21 W 1495.94 120.21 10.31 14.07 81.17 S 1533.34 W 1551.73 124.94 10.59 14.61 81.17 S 1976.02 W 1999.71 162.91 12.86 18.98 81.17 S 2418.69 W 2447.69 200.90 15.13 23.35 81.17 S 2742.27 W 2775.15 228.67 16.79 26.55 81.17 3886.55 63.00 261.17 2277.57 428.82 S 2760.86 W 2793.97 230.25 16.89 26.73 81.17 3986.55 60.00 261.17 2325.29 442.30 S 2847.70 W 2881.84 237.39 17.37 27.55 81.17 4086.55 57.00 261.17 2377.53 455.39 S 2931.94 W 2967.09 244.13 17.88 28.32 81.17 4186.55 54.00 261.17 2434.16 468.04 S 3013.37 W 3049.50 250.45 18.41 29.05 81.17 4286.55 51.00 261.17 2495.03 480.21 S 3091.75 W 3128.82 256.32 18.96 29.72 81.17 4386.55 48.00 261.17 2559.97 491.88 S 3166.88 W 3204.86 261.75 19.51 30.34 81.17 4486.55 45.00 261.17 2628.80 503.01 S 3238.55 W 3277.38 266.71 20.07 30.90 81.17 4586.55 42.00 261.17 2701.33 513.58 S 3306.57 W 3346.21 271.21 20.63 31.42 81.17 4686.55 39.00 261.17 2777.36 523.54 S 3370.73 W 3411.15 275.24 21.19 31.88 81.17 4786.55 36.00 261.17 2856.68 532.88 S 3430.88 W 3472.02 278.83 21.73 32.29 81.17 4886.55 33.00 261.17 2939.09 541.58 S 3486.84 W 3528.65 281.97 22.27 32.65 81.17 4888.83 32.93 261.17 2941.00 541.77 S 3488.07 W 3529.89 282.03 22.28 32.66 81.17 4986.55 30.00 261.17 3024.34 549.60 S 3538.47 W 3580.90 284.68 22.78 32.96 81.17 5086.55 27.00 261.17 3112.21 556.92 S 3585.61 W 3628.61 286.99 23.27 33.23 81.17 5186.55 24.00 261.17 3202.46 563.52 S 3628.15 W 3671.65 288.91 23.73 33.46 81.17 5286.55 21.00 261.17 3294.84 569.40 S 3665.96 W 3709.92 290.47 24.16 33.65 81.17 5319.88 20.00 261.17 3326.06 571.19 S 3677.50 W 3721.59 290.95 24.30 33.71 81.17 5500.00 20.00 261.17 3495.32 580.64 S 3738.37 W 3783.19 293.56 25.06 34.04 81.17 5519.88 20.00 261.17 3514.00 581.69 S 3745.09 W 3789.99 293.85 25.15 34.07 81.17 5676.31 20.00 261.17 3660.99 589.90 S 3797.96 W 3843.49 296.12 25.81 34.35 81.17 5676.32 20.00 261.17 3661.00 589.90 S 3797.96 W 3843.50 296.12 25.81 34.35 81.17 5975.35 20.00 261.17 3942.00 605.60 S 3899.02 W 3945.77 300.47 27.07 34.90 81.17 6000.00 20.00 261.17 3965.16 606.89 S 3907.35 W 3954.21 300.83 27.17 34.94 81.17 6175.35 20.00 261.17 4129.94 616.10 S 3966.62 W 4014.18 303.39 27.91 35.26 81.17 All data is in feet uz~less otherwise stated. Coordinates from slot #123 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 4014.18 on azimuth 261.17 degrees from wellhead. Vertical section is from wellhead on azimuth 261.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,123 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTIN~ Page 2 Your ref : WS 1D-123/G1 Vets. #4 Last revised : 12-Jun-98 POSITION UNCERTAINTY SUMMARY ============================== Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 6175 ARCO (H.A. Mag) User specified 303.39 27.91 35.26 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. Comments in wellpath MD TVD Rectangular Coords. Comment 300.00 300.00 0.00 N 0.00 E KOP 1360 2437 3865 4888 5319 5519 5676 5676 5975 6175 53 1155 73 1634 48 2268 83 2941 88 3326 88 3514 31 3660 32 3661 35 3942 35 4129 58 81.47 S 524.52 W EOC 00 229.60 S 1478.21 W Base Permafrost 11 425.93 S 2742.27 W Begin Angle Drop 00 541.77 S 3488.07 W Top Ugnu Sands 06 571.19 S 3677.50 W End Angle Drop 00 581.69 S 3745.09 W Top West Sak Sands 99 589.90 S 3797.96 W TARGET - West Sak A3 00 589.90 S 3797.96 W WS 1D-G1 Rvsd 26-Jan-98 00 605.60 S 3899.02 W Base West Sak Sands 94 616.10 S 3966.62 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6175.35 4129.94 616.10S 3966.62W 7 5/8" Casing Targets associated with this wellpath .... Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-G1 Rvsd 26-Jan 556698.000,5958833.000,0.0000 3661.00 589.90S 3797.96W 14-Oct-96 ARCO Alaska, Inc. Pad 1D,123 Kuparuk River Unit,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S PROPOSAL LISTING Page 1 Your ref : WS 1D-123/G1 Vets. Last revised : 12-Jun-98 Dogleg Vert G R I D C O O R D S Deg/100ft Sect Easting Northing 0.00 0.00 261.17 0.00 0.00N 0.00E 0.00 0.00 560490.68 5959453.70 300.00 0.00 261.17 300.00 0.00N 0.00E 0.00 0.00 560490.68 5959453.70 400.00 6.00 261.17 399.82 0.80S 5.17W 6.00 5.23 560485.51 5959452.85 500.00 12.00 261.17 498.54 3.20S 20.62W 6.00 20.87 560470.08 5959450.33 600.00 18.00 261.17 595.09 7.17S 46.18W 6.00 46.74 560444.56 5959446.15 700.00 24.00 261.17 688.40 12.67S 81.58W 6.00 82.56 560409.21 5959440.36 800.00 30.00 261.17 777.46 19.64S 126.42W 6.00 127.94 560364.43 5959433.04 900.00 36.00 261.17 861.29 27.99S 180.21W 6.00 182.38 560310.71 5959424.24 1000.00 42.00 261.17 938.97 37.65S 242.37W 6.00 245.28 560248.64 5959414.09 1100.00 48.00 261.17 1009.65 48.49S 312.21W 6.00 315.96 560178.90 5959402.67 1200.00 54.00 261.17 1072.55 60.42S 388.97W 6.00 393.64 560102.24 5959390.13 1300.00 60.00 261.17 1126.99 73.28S 471.81W 6.00 477.46 560019.52 5959376.59 1360.53 63.63 261.17 1155.58 81.47S 524.52W 6.00 530.81 559966.88 5959367.97 1500.00 63.63 261.17 1217.52 100.65S 648.00W 0.00 655.77 559843.58 5959347.79 2000.00 63.63 261.17 1439.59 169.40S 1090.67W 0.00 1103.75 559401.52 5959275.45 2437.73 63.63 261.17 1634.00 229.60S 1478.21W 0.00 1495.94 559014.52 5959212.11 2500.00 63.63 261.17 1661.66 238.16S 1533.34W 0.00 1551.73 558959.47 5959203.10 3000.00 63.63 261.17 1883.72 306.91S 1976.02W 0.00 1999.71 558517.41 5959130.76 3500.00 63.63 261.17 2105.79 375.67S 2418.69W 0.00 2447.69 558075.35 5959058.41 3865.48 63.63 261.17 2268.11 425.93S 2742.27W 0.00 2775.15 557752.23 5959005.53 3886.55 63.00 261.17 2277.57 428.82S 2760.86W 3.00 2793.97 557733.65 5959002.49 3986.55 60.00 261.17 2325.29 442.30S 2847.70W 3.00 2881.84 557646.94 5958988.30 4086.55 57.00 261.17 2377.53 455.39S 2931.94W 3.00 2967.09 557562.82 5958974.53 4186.55 54.00 261.17 2434.16 468.04S 3013.37W 3.00 3049.50 557481.50 5958961.23 4286.55 51.00 261.17 2495.03 480.21S 3091.75W 3.00 3128.82 557403.22 5958948.41 4386.55 48.00 261.17 2559.97 491.88S 3166.88W 3.00 3204.86 557328.20 5958936.14 4486.55 45.00 261.17 2628.80 503.01S 3238.55W 3.00 3277.38 557256.63 5958924.42 4586.55 42.00 261.17 2701.33 513.58S 3306.57W 3.00 3346.21 557188.71 5958913.31 4686.55 39.00 261.17 2777.36 523.54S 3370.73W 3.00 3411.15 557124.63 5958902.82 4786.55 36.00 261.17 2856.68 532.88S 3430.88W 3.00 3472.02 557064.57 5958892.99 4886.55 33.00 261.17 2939.09 541.58S 3486.84W 3.00 3528.65 557008.68 5958883.85 4888.83 32.93 261.17 2941.00 541.77S 3488.07W 3.00 3529.89 557007.46 5958883.64 4986.55 30.00 261.17 3024.34 549.60S 3538.47W 3.00 3580.90 556957.13 5958875.41 5086.55 27.00 261.17 3112.21 556.92S 3585.61W 3.00 3628.61 556910.05 5958867.70 5186.55 24.00 261.17 3202.46 563.52S 3628.15W 3.00 3671.65 556867.57 5958860.75 5286.55 21.00 261.17 3294.84 569.40S 3665.96W 3.00 3709.92 556829.81 5958854.57 5319.88 20.00 261.17 3326.06 571.19S 3677.50W 3.00 3721.59 556818.30 5958852.69 5500.00 20.00 261.17 3495.32 580.64S 3738.37W 0.00 3783.19 556757.51 5958842.74 5519.88 20.00 261.17 3514.00 581.69S 3745.09W 0.00 3789.99 556750.80 5958841.64 5676.31 20.00 261.17 3660.99 589.90S 3797.96W 0.00 3843.49 556698.00 5958833.00 5676.32 20.00 261.17 3661.00 589.90S 3797.96W 0.00 3843.50 556698.00 5958833.00 5975.35 20.00 261.17 3942.00 605.60S 3899.02W 0.00 3945.77 556597.08 5958816.48 6000.00 20.00 261.17 3965.16 606.89S 3907.35W 0.00 3954.21 556588.76 5958815.12 6175.35 20.00 261.17 4129.94 616.10S 3966.62W 0.00 4014.18 556529.58 5958805.44 #4 RECEIVED i9 199 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #123 and TVD from RKB (Parker #245) (~b~ ~ ~~ ~1~.i distance is 4014.18 on azimuth 261.17~P~e~"~e~T_h~ta~T ..... "~ ~ Bottom hole Total Dogleg for wellpath is 107.26 degrees. ~0~0[ag~ Vertical section is from wellhead on azimuth 261.17 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and comDuted using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,123 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref = WS 1D-123/G1 Vets. #4 Last revised : 12-Jun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 300.00 300.00 0.00N 0.00E KOP 1360.53 1155.58 81.47S 524.52W EOC 2437.73 1634.00 229.60S 1478.21W Base Permafrost 3865.48 2268.11 425.93S 2742.27W Begin Angle Drop 4888.83 2941.00 541.77S 3488.07W Top U~nu Sands 5319.88 3326.06 571.19S 3677.50W End Angle Drop 5519.88 3514.00 581.69S 3745.09W Top West Sak Sands 5676.31 3660.99 589.90S 3797.96W TARGET - West Sak A3 5676.32 3661.00 589.90S 3797.96W WS 1D-G1 Rvsd 26-Jan-98 5975.35 3942.00 605.60S 3899.02W Base West Sak Sands 6175.35 4129.94 616.10S 3966.62W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6175.35 4129.94 616.10S 3966.62W 7 5/8" Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-G1 Rvsd 26-Jan 556698.000,5958833.000,0.0000 3661.00 589.90S 3797.96W 14-Oct-96 2tRCO Alaska, Inc. Pad 1D 123 slot #123 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : WS 1D-123/G1 Vets. #4 Our ref : prop2203 License : Date printed : 24-Jun-98 Date created : 16-Apr-97 Last revised : 12-Jun-98 Field is centred on n?0 16 18'.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 17 59.241,w149 30 36.341 Slot Grid coordinates are N 5959453.696, E 560490.676 Slot local coordinates are 211.00 S 598.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PMSS <0-5142'>,,liS,Pad 1D WS 1D-125/H2 Vers. #5,,125,Pad 1D WS 1D-134/L5 Vets. #3,,134,Pad 1D WS 1D-132/K4 Vets. #3,,132,Pad 1D WS 1D-128/K2 Vets. #3,,128,Pad 1D PMSS <0 - 7340'>,,lO,Pad 1D PMSS <0-5462 PMSS <0-4414 PMSS <0-4530 PMSS <0-4515 PMSS <0-4590 PMSS <0-5205 PMSS <0-4850 PMSS <0-5126 >,,129,Pad 1D >,,121,Pad 1D >,,120,Pad 1D >,,119,Pad 1D >,,liS,Pad 1D >,,liT,Pad iD >,,109,Pad 1D >,,106,Pad 1D PMSS <381-6092'>,,105,Pad 1D PMSS <1957-5265'>,,133,Pad 1D PMSS <O-5015'>,,135,Pad 1D PMSS <0-4778'>,,130,Pad 1D PMSS <0-5047'>,,124,Pad 1D WS 1D-101/C5 Vets. #3,,101,Pad 1D WS 1D-104/A7 Vets. #3,,104,Pad 1D WS 1D-103/B6 Vets. #3,,103,Pad 1D WS 1D-102/A5 Vets. #3,,102,Pad 1D WS 1D-107/B4 Vers. #1,,107,Pad 1D WS 1D-151/G11 Vets. #1,,151,Pad 1D Closest approach with 3-D Last revised Distance Minimum Distance method M.D. Diverging from M.D. 2-Jun-98 150.0 180.0 180.0 5-Jun-98 74.0 460.0 460.0 27-May-98 299.0 440.0 440.0 27-May-98 225.0 240.0 240.0 1-Jun-98 118.4 500.0 500.0 28-Apr-98 345.0 120.0 120.0 2-Jun-98 179.2 400.0 400.0 2-Jun-98 30.0 100.0 100.0 2-Jun-98 45.0 100.0 100.0 2-Jun-98 60.0 100.0 100.0 2-Jun~98 104.7 300.0 300.0 2-Jun-98 120.0 120.0 120.0 2-Jun-98 270.0 100.0 100.0 2-Jun-98 315.0 100.0 100.0 2-Jun-98 344.5 300.0 300.0 2-Jun-98 236.3 460.0 460.0 2-Jun-98 310.9 605.2 605.2 2-Jun-98 192.6 540.0 540.0 2-Jun-98 56.0 460.0 460.0 27-May-98 403.0 300.0 300.0 27-May-98 358.0 280.0 280.0 27-May-98 373.0 280.0 280.0 27-May-98 388.0 300.0 300.0 27-May-98 298.0 300.0 300.0 15-Apr-97 307.9 300.0 300.0 WS 1D- 138 WS 1D-161 WS 1D-160 WS 1D-159 WS 1D- 157 WS 1D-156 WS 1D-155 WS 1D- 154 WS 1D-153 WS 1D- 150 WS 1D-152 WS 1D- 149 WS 1D- 148 WS 1D- 147 WS 1D-146 WS 1D-145 WS 1D- 144 WS 1D- 143 WS 1D- 139 WS 1D-140 /K6 Vets. #1,,138';.~d 1D /L7 Vets. #l,,161,Pad 1D /K8 Vers. #1,,160,Pad 1D /L9 Vets. #1,,159,Pad 1D /KIO Vets. #1,,157,Pad 1D /J9 Vets. #1,,156,Pad 1D /H8 Vets. #1,,155,Pad 1D /Jll Vets. #1,,154,Pad 1D ~H10 Vets. #1,,153,Pad 1D /Fl0 Vets. #1,,150,Pad 1D /G9 Vets. #1,,152,Pad 1D ~F8 Vets. #1,,149,Pad 1D 'Ell Vets. #1,,148,Pad 1D 'E9 Vets. #1,,147,Pad 1D 'D10 Vets. #1,,146,Pad 1D 'Cll Vets. #1,,145,Pad 1D 'DS Vets. #1,,144,Pad 1D 'C9 Vets. #1,,143,Pad 1D 'B8 Vets. #l,,139,Pad 1D 'A9 Vets. #1,,140,Pad 1D WS 1D-142/B10 Vers. #1,,142,Pad 1D WS 1D-141/A11 Vets. #1,,141,Pad 1D WS 1D-158/Lll Vets. #1,,158,Pad 1D WS 1D-136/J7 Vets. #1,,136,Pad 1D TOTCO Survey,,WS-8,Pad 1D 1D-B Version #3,,1D-B,Pad 1D 1D-F Version #2,,1D-F,Pad 1D 1D-D Version #2,,1D-D,Pad 1D PGMS <0-8365 >,,1,Pad 1D PGMS <0-9783 >,,2,Pad 1D PGMS <0-8070 >,,3,Pad 1D PGMS <0-7502 >,,4,Pad 1D PGMS <0-8930 >,,5,Pad 1D PGMS <0-8610 >,,6,Pad 1D MSS <3311-8200'>,,7,Pad 1D PMSS <556-7024'>,,9,Pad 1D WS 1D-122/F2 Vets. #4,,122,Pad 1D WS 1D-112/A1 Vets. #4,,112,Pad 1D WS 1D-113/Cl Version #5,,113,Pad 1D WS 1D-114/D2 Vets. #5,,114,Pad 1D WS 1D-116/E1 Vets. #4,,116,Pad 1D WS 1D-iii/B2 Vets. #5,,111,Pad 1D WS 1D-127/L1 Vets. #3,,127,Pad 1D WS 1D-110/C3 Vets. #5,,1lO,Pad 1D WS 1D-108/A3 Vets. #5,,108,Pad 1D WS 1D-131/L3 Vets. #3,,131,Pad 1D WS 1D-126/J1 Vets. #5,,126,Pad 1D PMSS <0 - ???>,,126,Pad 1D 27-May-98 27-May-98 27-May-98 27-May-98 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 27-May-98 27-May-98 27-May-98 27-May-98 27-May-98 21-May-98 24-Nov-97 24-Nov-97 24-Nov-97 10-Dec-97 4-Aug-92 4-Aug-92 4-Aug-92 13-Nov-97 13-Nov-97 6-Nov-97 29-Apr-98 9-Jun-98 12-Jun-98 12-Jun-98 11-Jun-98 11-Jun-98 11-Jun-98 27-May-98 16-Jun-98 19-Jun-98 27-May-98 27-May-98 24-Jun-98 361.6 439.2 425.6 412.0 385.1 371.8 358.7 345.7 332.9 295.8 320.3 283.9 272.4 261.1 250.3 239.9 230.1 220.8 191.1 197.2 212.2 204.3 398.5 328.1 386.5 164.6 253.6 134.9 448.0 327.9 208.0 87 8 31 9 150 6 269 5 75 0 15 0 195 0 180 0 165.0 135.0 240.0 104.9 255.0 285.0 210.0 89.1 87.8 380.0 300.0 300.0 260.0 300.0 300.0 30O.0 300.0 300 0 300 0 300 0 300 0 300 0 300 0 300.0 300.0 300.0 300.0 260.0 300.0 300.0 260.0 260.0 580.0 660.0 540.0 560.0 520.0 300.0 300.0 20.0 300 0 400 2 520 0 520 0 120 0 300 0 300 0 300 0 300 0 300 0 300.0 360.0 240.0 240.0 340.0 420.0 480.0 380.0 300.0 300.0 6040.0 4586.5 300.0 300.0 300.0 300.0 300.0 4888.8 300.0 300.0 300.0 300.0 300.0 300.0 300.0 260.0 300 0 300 0 260 0 260 0 580 0 660 0 540 0 560 0 520.0 300.0 300.0 6175.4 300.0 400.2 520.0 520.0 120.0 300.0 300.0 300.0 300.0 300.0 300.0 360.0 240.0 240.0 340.0 420.0 480.0 5000 psi BOP S ........ Kuparuk River Unit. West Sak Operations - Producer Wells 4 3 2 1 I 1. 16" Starting Head 2. 11" 5000 psi Horizontal Tubing Head 3. 11" x 13-5/8" 5000 psi Double Studded Adapter/Spacer Spool 4. 13-5/8" 5000 psi x 13-5/8" 5000 psi Spacer Spool 5. 13-5/8" 5000 psi Pipe Rams 6. 13-5/8" 5000 psi Drilling Spool with Choke and Kill Lines 7. 13-5/8" 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 8. 13-5/8" 5000 psi Annular Preventer Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 3000 psi for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with Koomey pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. ** VBRS will accornodate 3-1/2" to 6" or 4-1/2" to 7" pipe OD's as appropriate ** TAB, 06/15/98, v. 1 DIVERTER SCHEM, flC Kuparuk River Unit West Sak Operations L DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES Maintenance & Operation 1. Upon initial installation: - Close valve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion ARCO ALASKA, INC. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" Conductor 2. Slip-on Weld Starting Head 3. Diverter Assembly With One 2-1/16" 2000 psi Ball Valve 4. 20"- 2000 psi Drilling Spool With One 16" Outlet 5. One 16" HCR Knife Valve With 16" Diverter Line. The Valve Opens Automatically Upon Closure Of Annular Preventer. DiverterLineWilIBe Placed For Optimum Dispersion in Prevailing Wind Conditions 6. 20" - 2000 psi Annular Preventer TAB, 06/12/98, v.2 O£SCRIPTION OE SCi~P TION Rood C D.S. 1-D O I 100~ log 11 111 125t 124 127~ 126 128 j t29 131;3o 1~2 &7 L~GEND .0 EXISTING CONDUCTOR5 · 'AS-STAKED' CONDUCTOR LOCATION 'PROPOSED' CONDUCTOR L OCA TION ARCO Alaska, Inc. 14 15 23 24 9~ST SAK-1 THIS SURVEY VIC~N~ TY MA P SCALE: I' = I MII.~ N NO RECEIVED AU~ ~ Oil & Ga~ con~. ~om~ SEE SHE~ t 2 FOR ~S LOUNSBURY & ASSOC~TES, INC. N~ P~N~ SU~O~ AREA: 1D M~ XX UNIT: Ol DRI~ SI~ 1-D ~ST SAK PHASE lB - ~ C~DUCTORS AS-STAKED LOCA~ONS DESCRIPTION I~.SCRIP TION NO TE$ COOROINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 27. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ALL DISTANCES SHOWN ARE TRUE. 2. BASIS OF LOCAITON$ AND ELEVATIONS ARE D.S. I-D MONUM£NTS PER LHD AND ASSOCIATES. ,.~.CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS 14 ~c 23, TOWNSHIP. I1 NORTH, RANGE I0 EAST, U.M. · 4. DATE OF SURVEY.' 5/16/98, FIELD BK. L98-42 Pgs. 8-14. .5. DRILL SITE I-D GRID NORTH I$ ROTATED 00' 0I' F~'ST FROM A.S.P. ZONE 4 GRID NORTH. ~. SEE DRAIffNG NSK-`[5-1 FOR AS-BUILT LOCA170NS OF' CONDUCTORS ?-8; CEA-DIDX-6IO4DIO FOR CONDUCTORS 105, I06,109, !15, I17-121,124,129, I30,133 & 135; AND CEA-DIOX-6104013 FOR CONOUCTORS 9 & I0. LS. 1B WEST SAK-1 THIS SURVEY V1CINI TY -MAP SCALE: I' = I MILE A.$.P.s 'Y' 'X' * o 5, 959, 738. 9 *~ 5, 959, 708. 9 "5,959, 69[ 9 5,959,64~ 9 5. 959, 6,[.[ 9 5,959,61&9 5, 959, 58~[ 9 5, 959, 469. 0 5, 959, 45.[ 9 5,959,$79.2 5,959,$6`[9 5,959,$4~ 9 5, 959, J J4. I 5,959,244.0 5,959,229.2 5, 959, I53. 8 LA TI TUDE L ONGi TUDE 560, 490. 6 560, 490. 6 560, 490. 6 Sec. 14, T. 11 N., 70' I8' 02. 05' 70' 18" 01. 75' 70' 18' 01.60' R. IO E. 149' JO' J6.28' 14g' JO' J6.2B' 149' 30' J6.29" 560, 490. 6 560, 490. 6 560, 490. 6 560, 490. 6 560, 490. 7 560. 490. 7 560, 490. ? 560, 490. 7 560, 490. 7 560, 490. 7 560, 490. 7 560, 490. 7 560, 490. 8 Sec. 23, 70' 18' 70' I8" 70' 18' 70' 18" 70' 17' 70' 17' 70" 17' 70" 17' 70" 17' 70' 17' 70" 17' 70' I7' 70' I2' T. 11 N., Ol. 16' 01.01 ' 00.87" 0~57' 59.39' 59.24" 5&21' 5~06' 57.18' 57.03' 56.29' 10 E 149' JO' $6. J0' 14g' JO' 36. J0' 149' JO' J6. JO' I49' JO' J6. Jl' 149' JO' J6. J4' I49' JO' J6.34' 149' 30' $6.36' 149' $0' 36.36' 149' $0' $6.$6' I49' $0' $6.$7' I49' 30' $6.$9' I49' $0' 36.$9' I49' $0' J6.41' Proposed location, work in progress 'ARCO Alaska, Inc. LOUNSBURY & ASSOCIATES, INC. E%INEERS PLANNERS S~ORS AREA: 1D MODULE: XX DRILL SITE 1-D WEST SAK PHASE lB - WELL CONDUCTORS AS-STAKED LOCATIONS UNIT: DI 1D-114 Cement Volumes Surface Hole Surface Casing Casing Depth Casing OD Casing Weight Hole Size Upper Casing Volume/Foot Upper Annulus Volume/Foot Lower Casing Volume/Foot Lower Annulus Volume/Foot Shoe Joint Length 500' TVD Above WS HiStrgth Depth Base Permafrost Top of 3 1/2" Permafrost Excess Below Permafrost Excess feet feet Class Additive 1 Additive 2 Additive 3 Additive 4 Additive 5 Additive 6 Density Yield Water Requirement Thickening Time ift3/sx gal/sx ihours % % % % % % Class Additive 1 Additive 2 Additive 3 Additive 4 Density Yield Water Requirement Thickening Time PPg ft3/sx gal/sx hours 513 652 bbls sacks 70 bbls 331 sacks · WELL PERMIT CHECKLIST COMPANY ~ J~ I~ ~ WELL NAME ]'~ ~ / [') - ] ,,~ 3 PROGRAM: exp [] dev,,l~redrll [] serv [] wellbore seg II ann. disposal para req II FIELD & POOL ~ O/ O].~b INITCLASS [")PV /- O;l GEOLAREA ~ ~(",] UNIT# ////'(-¢ 0 ON/OFFSHORE ADMINISTRATION At~ DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to j~¢')¢-.:)¢O psig. 27. Choke manifold complies w/APl RP-53 (May 84)'. ....... 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. N N N N N N --.¥ U-' NA N {Y_.)N GEOLOGY AER DATE 30. Permit can be issued w/o hydrogen sulfide measure~..._~___ 31. Data presented on potential overpresst~ ..... 32. Seismic analysis of shallow a~..~ ............ 33. Seabed condition~.sus~e~"(Woff-shore) ............. 34~pr gress repods ....... exptora~ory onlyj ANNULAR DISPOSAL APPR DATE 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. ._------- Y N Y N Y N Y N Y N GEOLOGY_: ENGINEERING: UIC/Annular COMMISSION: JDH RNC . CO ~ ~i~ M:chel~list rev 05129198 dlf:C:\rnsoffice\wordian\diana\cho(:klist Y N Y N Y N Y N ,Annular disposal has not been requested as part of thc Permit to Drill application for Kupamk River Unit Well No. 1 D- 1 ~. Please note that any disposal of fluids generated from this drilling operation which arc pumped down thc surface/production casing annulus of a permitted existing wctl on Drill Site I D must comply with thc requirements and limitations of 20 AAC 23.080. Approval of this pcrmit to drill docs not authorize disposal of drilling xx'astc in a volume~ ..grcate-'r than 35.000 barrels through thc annular space of a single wcll or for a period longer than,.o,~ year. Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drillir Services LIS Scan Uti-~ty Fri Oct 16 10:32:46 1998 Reel Header Service name ............. LISTPE Date ..................... 98/10/16 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/10/16 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT (WEST SAK) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-80362 P. SMITH D. LUTRICK 1ST STRING 1D-123 500292291400 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 16-0CT-98 MWD RUN 2 AK-MM- 80362 P. SMITH D. LUTRICK 23 lin 10E 211 598 .O0 112.10 70.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) Or,,'r 8, 998 3i D~ STRING PRODUCTION STRING REMARKS: 9.880 6055.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION WITH MIKE WERNER OF ARCO ALASKA, INC. ON 10/13/98. 3. MWD RUNS 1 AND 2 ARE DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PPIASE-4 (EWR4). 4. WELL 1D-123 REACHED A TOTAL DEPTH (TD) OF 6055'MD, 4043'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA R_AY 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. SLIDE = MUD MOTOR DRILLING (NO ROTATION). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/16 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 RPD 78 5 6013.0 RPM 78 5 6013.0 RPS 78 5 6013.0 RPX 78 5 6013.0 GR 86 0 6020.0 FET 121 0 6013.0 ROP 122.0 6055.5 $ BASELINE CURVE FOR SHIFTS: ChivE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ EQUIVALENT UNSHIFTED DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 121.0 3607.0 2 3607.0 6055.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD ON_MM 4 1 68 RPM MWD OHMM 4 t 68 RPD MWD OHMM 4 1 68 ROP MWD FT/H 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max DEPT 78.5 6055.5 GR 12.3951 142.597 RPX 0.912 2000 RPS 1.1078 2000 RPM 1.7355 2000 RPD 1.9849 2000 ROP 9.7443 951.591 FET 0.0868 9.5621 Mean Nsam 3067 11955 66.3253 11869 67.6287 11870 137.382 11870 145.918 11870 312.955 11870 276.887 11868 0.383749 11785 First Reading 78.5 86 78.5 78.5 78.5 78.5 122 121 Last Reading 6055.5 6020 6013 6013 6013 6013 6055.5 6013 First Reading For Entire File .......... 78.5 Last Reading For Entire File ........... 6055.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File H~ader ~ Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NI/MBER: 2 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 78.5 3564.5 RPM 78.5 3564.5 RPS 78.5 3564.5 RPX 78.5 3564.5 GR 86.0 3571.5 FET 121.0 3564.5 ROP 122.0 3607.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 03-SEP-98 ISC 5.06 CIM 5.46/EWP4 1.38 MEMORY 3607.0 121.0 3607.0 1.0 64.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NIIMBER P1038CRG6 P1038CRG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 8.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): SPUD 9.10 350.0 8.0 350 5.6 6.000 MUD AT MAX CIRCULATING MUD FILTRATE AT MT: MUD CAKE AT MT: ~RMPERATURE: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 4.195 6.000 5.400 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MWD 1 API 4 1 68 RPX MWD 1 OHMM 4 1 68 RPS MWD 1 OHMM 4 1 68 RPM MWD 1 OHMM 4 1 68 RPD MWD 1 OHMM 4 1 68 ROP MWD 1 FT/H 4 1 68 FET MWD 1 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 28.6 Name Min Max Mean Nsam DEPT 78.5 3607.5 1843 7059 GR 14.5532 131.668 64.4325 6972 RPX 0.912 2000 107.556 6973 RPS 1.1078 2000 225.598 6973 RPM 1.7355 2000 240.524 6973 RPD 1.9849 2000 523.976 6973 ROP 30.6511 951.591 283.394 6972 FET 0.0868 1.7789 0.299629 6888 First Reading 78.5 86 78.5 78.5 78.5 78.5 122 121 Last Reading 3607.5 3571.5 3564.5 3564.5 3564.5 3564.5 3607.5 3564.5 First Reading For Entire File .......... 78.5 Last Reading For Entire File ........... 3607.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSI-n.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 3565 0 6013.0 RPD 3565 0 6013.0 RPM 3565 0 6013.0 RPS 3565 0 6013.0 RPX 3565 0 6013.0 GR 3572 0 6020.0 ROP 3608.0 6055.5 $ LOG HEADER DATA DATE LOGGED: 05-SEP-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM A/~GLE: 17.0 MAXIMUM ANGLE: 62.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : ISC 5.06 CIM 5.46/EWP4 1.38 MEMORY 6055.0 3607.0 6055.0 TOOL NUMBER P1038CRG6 P1038CRG6 8.500 8.5 SPUD 9.60 250.0 MUD PH: · MUD CHLORIDES (PPM) : · FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.4 350 4.1 4.900 3.186 7.000 4.500 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHMM 4 1 68 12 4 RPM MWD 2 OHMM 4 1 68 16 5 RPD MWD 2 OHMM 4 1 68 20 6 ROP MWD 2 FT/H 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 38.4 Name DEPT GR RPX RPS RPM RPD ROP FET Min 3565 12 3951 1 9877 2 0427 1 9333 2 2442 9 7443 0.099 First Max Mean Nsam Reading 6055.5 4810.25 4982 3565 142.597 69.0201 4897 3572 105.181 10.7747 4897 3565 123.089 11.7693 4897 3565 123.108 11.205 4897 3565 165.415 12.4745 4897 3565 656.25 267.621 4896 3608 9.562 0.502069 4897 3565 Last Reading 6055.5 6020 6013 6013 6013 6013 6055.5 6013 First Reading For Entire File .......... 3565 Last Reading For Entire File ........... 6055.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.6~ ~ Date of Generation ....... 98/10/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/10/16 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/10/16 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File
