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181-052
STATE OF ALASKA ALADA OIL AND GAS CONSERVATION COMIIISION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing 17 \f0V Operations Shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casio 9 Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well 17 Re-enter Susp Well rOther: 1- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development rExploratory r 181-052 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-20585-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25649 KRU 1C-08 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9791 feet Plugs(measured) 8695 true vertical 7109 feet Junk(measured) none Effective Depth measured 9153 feet Packer(measured) 8639 true vertical 6582 feet (true vertical) 6213 Casing Length Size MD TVD Burst Collapse CONDUCTOR 48 16 80 80 SURFACE 2683 10.75 2714 2586 PRODUCTION 9737 7 9768 7089 RECEIVED Perforation depth: Measured depth: 8927-9012,9018-9030, 9096-9122 OCT 12 2015 True Vertical Depth: 6433-6498,6503-6512,6562-6582 woolE,C NOV 2 4 2015 AOGCC Tubing(size,grade,MD,and TVD) 4.5, L-80,8823 MD,6354 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER S-3 Hydr PACKER @ 8639 MD and 6213 TVD NO SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 607 10061 6135 -- 534 Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations g Exploratory r Development Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil p Gas r VVDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Andrew Beat Cad 265-6341 Email Andrew.T.Beat a(�conocophillips.com Printed Name Andr eat Title Sr. Wells Engineer Signature & Phone:265-6341 Date 10/7//5 vrlr-L ld/ ' J i A t 0 /i i J.JRBDMS OCT 13 2015 Form 10-404 Revised 5/2015 Submit Original Only • • ConocoPhillips Time Log & Summary Wel'view Web Reporting Report Well Name: 1C-08 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 9/6/2015 8:00:00 AM Rig Release: 9/14/2015 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/06/2015 24 hr Summary Move rig f/1Y to 1C-80-Moved rig office, shop&pit module f/1Y to 1C-08-Moved Sub baes to Oliktok Y- Tool house team moving&setting mats f/Y to 1R/1G Acccess 06:00 00:00 18.00 0 0 MIRU MOVE MOB P Lowered derrick&turned sub around @ 1Y pad-Moved rig office, shop& pit module f/1Y to 1C-08-Moved sub f/1Y to Oliktok Y Wit for mats to be set)-Tool house team moving& setting rig mats f/Y to 1R/1G access road. 09/07/2015 Continue moving Rig Sub Base towards 1R/1G intersetion-Staged sub.2 miles f/1 R/!G turn off-tool house shuffling mats 00:00 00:00 24.00 0 0 MIRU MOVE MOB P Continue moving the Rig Sub Base f/ Y to.2 miles f/1R/1G turn-off- Staged&waiting on mats to be shuffled to cont. on to 1R/!G turn off 09/08/2015 Continue moving the Rig Sub Base f/1Y,staging the Rig at the 1A pad"Y". Lay mats across the"Y" intersection and continue moving to KCC. 00:00 00:00 24.00 0 0 MIRU MOVE MOB P Continue moving the Rig Sub Base f/1Y,staging the Rig at the 1A pad "Y". Lay mats across the"Y" intersection and continue moving to KCC. 09/09/2015 Continue moving the Rig sub base staging at KCC. Lay mats on the KIC and 1C pad access road. Stage the Rig at the KIC, 1C pad"Y". Lay mats on the 1C pad access road and move the Rig to 1C pad. 00:00 00:00 24.00 0 0 MIRU MOVE MOB P Continue moving the Rig sub base, staging at KCC. Lay mats on the KIC and 1C pad access road. Stage the Rig at the KIC, 1C pad"Y". Lay mats on the 1C pad access road and move the Rig to 1C pad. 09/10/2015 Move and stage the Rig sub base on 1C pad. Hang the BOP stack and tree in the cellar box. Spot the Rig over 1C-08 and raise the derrick. Spot the pits and prepare the rig for well kill. Set BPV and kill the well. 00:00 04:00 4.00 0 0 MIRU MOVE MOB P Continue moving rig sub base from the KIC/1C pad"Y"to 1C pad. Stage rig on 1C pad. 04:00 07:30 3.50 0 0 MIRU MOVE RURD P R/U BOP stack on bridge cranes and M/U Koomey lines. Set BOP stack on cellar pedestal. Hang Tree in cellar box. 07:30 11:00 3.50 0 0 MIRU MOVE RURD P Center rig over 1C-08. Raise the derrick and spot the pits. Rig accepted at 11:00 hrs 9/10/2015 Page 1 of 5 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 19:00 8.00 0 0 COMPZ MOVE RURD P R/U fuel tank, berming, and cattle chute. Bridle down and take on 600 bbls of 9.7 ppg of Brine. prepare cellar and wellhead for well kill. 19:00 19:30 0.50 0 0 COMPZ WELCTL MPSP P Set BPV and install lubricator. 19:30 21:00 1.50 0 0 COMPZ WELCTL RURD P Prepare cellar,wellhead, choke lines and choke house to tiger tank for well kill. 21:00 00:00 3.00 0 0 COMPZ WELCTL KLWL P Kill well, IA= 190 psi, OA= 150 psi. Vent IA pressure to choke house and tiger tank, Bleed pressure to"0"psi. Monitor IA for 15 minutes. (Good,no flow). 09/11/2015 Completion kill, N/D Tree and N/U BOPE. Test BOPE. 00:00 01:00 1.00 MIRU WELCTL MPSP P Set BPV and Install lubricator. 01:00 04:30 3.50 0 0 MIRU WELCTL KLWL P Completion kill, pump 409 bbls of 9.7 ppg brine. Take returns out the IA to the tiger tank. Pump 3 bpm, ICP 110 psi, FCP 320 psi. 04:30 05:00 0.50 0 0 MIRU WELCTL OWFF P Observe well for flow,well static. 05:00 05:30 0.50 0 0 MIRU WELCTL RURD P Prepare cellar and wellhead to install BPV. 05:30 06:00 0.50 0 0 MIRU WELCTL MPSP P Install IS-A BPV and test to 1000 psi for 10 minutes. 06:00 08:30 2.50 0 0 MIRU WHDBO NUND P N/D tree and adaptor flange. Tree pulled free at 8600 lbs,tree weight 5000 lbs. 08:30 12:00 3.50 0 0 MIRU WHDBO NUND P N/U BOPE, and intall choke lines and kill line hoses. 12:00 15:00 3.00 0 0 MIRU WHDBO RURD P R/U test equipment for BOP test. 15:00 18:00 3.00 0 0 MIRU WHDBO BOPE T Body test BOP stack, choke manifold and top drive to 5000 psi. Choke manifold had multiple leaks. TQ flanges and retest, no test. 18:00 19:00 1.00 0 0 MIRU WHDBO RURD T Blanking plug appeared to be leaking. Pull and redress blanking plug and install. Placed call to CPAI Drilling Superintendent for test pressure dispensation on the BOP's. Plan test pressure of 5000 psi can be reduced to 3000 psi due to possible damage to the blanking plug. 19:00 21:00 2.00 0 0 MIRU WHDBO BOPE T Install 4.5"test joint and test BOPE. Test Choke manifold to 5000 psi, no test. Test lower pipe rams to 3000 psi, no test. Page 2 of 6 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 00:00 3.00 0 0 MIRU WHDBO BOPE T Continue testing BOPE.Test#1: LPR, TIW,250/3000 psi,test good. Test#2: UPR, HCR, Kill/Choke, 250/3000 psi,test good. Test#3: Bag, Manual Kill/Choke, 250/3000 psi,test good.Test#4: Blinds, CMV, Rig floor Kill, 250/5000 psi, test good. Test Koomey:AOGCC test,good. CPAI Draw Down test, good. 09/12/2015 Repair CMV and Manual choke and finish testing BOPE. Pull tubing hanger to the floor and lay it down, R/U, pull and L/D 4 1/2"tubing completion. 00:00 04:00 4.00 0 0 MIRU WHDBO BOPE P Test BOPE-Test#5: Blinds, CMV 15, 1,2, 3, 16, and rig floor Kill. Test #6: Blinds, CMV 7, 5, 6, Upper IBOP and Outer Test Spool. Test#7 : Blinds, 7, 8, 9 Inner Test Spool Valves, Lower IBOP.Test#8 : Super choke and Manual choke.Test#9: CMV 10, 11, and TIW Valve. Test #10: CMV 12, 13, and Dart Valve. CMV 4 and the Manual Choke failed.Test witnessed by Chuck Sheeve,AOGCC Rep. 04:00 06:00 2.00 0 0 MIRU WHDBO RGRP T Repair CMV#4 and manual choke. 06:00 06:30 0.50 0 0 MIRU WHDBO SVRG P Service rig. 06:30 07:00 0.50 0 0 MIRU WHDBO RURD P R/U spooling unit slips and elevators. 07:00 07:30 0.50 0 0 MIRU WHDBO MPSP P Pull BPV. 07:30 08:30 1.00 0 0 COMPZ RPCOM PULL P Pull tubing hanger while circulating. Pulled free at 175K. Pull hanger to floor and lay it down. 08:30 11:00 2.50 0 0 COMPZ RPCOM CIRC P Circulate 598 bbls of 9.7 ppg brine at 6 bpm, 700 psi, 11:00 11:30 0.50 0 0 COMPZ RPCOM PULL P Lay dwon landing joint and tubing hanger. 11:30 18:00 6.50 0 3,812 COMPZ RPCOM PULL P Pull 4 1/2"completion,spooling the SSV control line, SSV 3,812'.Recoverd 27 bands,total bands ran in the hole 38. 18:00 18:30 0.50 3,812 3,812 COMPZ RPCOM SFTY P Conducted HSE Stand Down/Finish Strong in 2015 with both crews. 18:30 00:00 5.50 3,812 1 6,510 COMPZ RPCOM PULL P Continue to pull 4 1/2"completion f/3812't/6510'. 39/13/2015 Pull 4 1/2"Tubing Completion. Run 4 1/2"Tubing Completion per running detail. Pump corrosion inhibitor and land hanger.Test tubing and casing/hanger, N/D BOP's. 00:00 02:00 2.00 6,510 0 COMPZ RPCOM PULL P Continue pulling 4 1/2"tubing completion f/6510't/0'. Observed corrosion on joints#224 t/#271. 271 total joints L/D. 02:00 02:15 0.25 0 0 COMPZ RPCOM OWFF P Monitor well for 10 minutes,well static. 02:15 02:30 0.25 0 0 COMPZ RPCOM PULL P L/D 6 GLM's, SEALS, SSSV, clean floor. Page3of5 •Time Logs 111 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:00 0.50 0 0 COMPZ RPCOM SVRG P Service Top Drive. 03:00 04:00 1.00 0 0 COMPZ RPCOM RURD P R/U to run 4 1/2"Tubing Completion. Jet stack and inspect for steel bands. Ready stack for TIH. 04:00 04:30 0.50 0 0 COMPZ RPCOM SFTY P PJSM ;TIH with 4 1/2"Completion. 04:30 07:15 2.75 0 1,690 COMPZ RPCOM PUTB P RIH with 4 1/2"Tubing Completion as per running detail t/1690'.47K PUW and SOW. 07:15 07:30 0.25 1,690 1,690 COMPZ RPCOM SFTY P Well Control Drill ;Well secured 38 secs, CRT 108 secs.After Action Review was conducted following drill. 07:30 11:30 4.00 1,690 5,050 COMPZ RPCOM PUTB P Continue running 4 1/2"Tubing Completion f/1690't15050'. 11:30 12:00 0.50 5,050 5,050 COMPZ RPCOM SVRG P Service valve on coolant brake valve. 12:00 15:30 3.50 5,050 8,580 COMPZ RPCOM PUTB P Continue running 4 1/2"Tubing Completion f/5050't/8580'. PUW= 112KK, SOW=80K. 15:30 16:30 1.00 8,580 8,580 COMPZ RPCOM HOSO P L/D 3 joint of tubing, P/U 35.36'of pup joints and 1 joint tubing 40.43 for space out. 16:30 18:00 1.50 8,580 8,619 COMPZ RPCOM THGR P M/U landing joint and tubing hanger and space out 3'from being fully located, 8618.77'. 18:00 20:00 2.00 8,619 8,618 COMPZ RPCOM THGR P Circulate 9.7 ppg corrosion inhibited brine. Pump at 3 bpm, 245 psi. FCP 3 bpm, 230 psi. Total bbls pumped 290. 20:00 20:30 0.50 8,618 8,618 COMPZ RPCOM HOSO P Land hager, SOW=82K, RILDS. 20:30 21:00 0.50 8,618 8,618 COMPZ RPCOM PRTS P Pressure test tubing to 3000 psi for 30 minutes. (Test good). 21:00 21:30 0.50 8,618 8,618 COMPZ RPCOM PRTS P Pressure test casing to 2500 psi for 30 minutes. (Test good). 21:30 21:45 0.25 8,618 8,618 COMPZ RPCOM CIRC P Bleed IA to 0 pressure, bleed tubing to 0 pressure. Pressure up IA to 2850 psi to shear SOV. Pump bothe ways to ensure SOV sheared. 21:45 22:15 0.50 0 0 COMPZ WHDBO MPSP P Install IS-A BPV. 22:15 22:30 0.25 0 0 COMPZ WHDBO MPSP P Pressure test BPV to 1000 psi for 10 minutes. (Test good). 22:30 00:00 1.50 0 0 COMPZ WHDBO NUND P N/D BOPE. 09/14/2015 N/D BOPE, N/U Tree and test. Freeze protect well and move Rig to 1C-18. 00:00 03:00 3.00 COMPZ WHDBO NUND P N/D BOPE. 03:00 05:00 2.00 COMPZ WHDBO NUND P N/U Tree. 05:00 06:00 1.00 COMPZ WHDBO PRTS P Pressure test Packoffs, 250/5000 psi for 5 minutes, (Test Good). 06:00 06:30 0.50 COMPZ WHDBO MPSP P Pull BPV and set TWC. 06:30 07:30 1.00 COMPZ WHDBO NUND P Fisish N/U of Tree. 07:30 09:00 1.50 COMPZ WHDBO PRTS P Pressure test Tree 250/5000 psi, (Test Good). Page 4 of 6 • Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 12:00 3.00 COMPZ WHDBO FRZP P Pump 70 bbls of diesel down IA at 2 bpm, 1500- 1900 psi. U-tube for 1 hour. Job completed-Pulled existing 4 1/2"Tubing from the PBR. Swapped out Tubing with new 4 1/2" 12.6# L-80 IBTM. Rig released 12:00 hrs 9/14/2015. Page 5 of 6 b P PROD 0 1C-08 ,C©nocoPhillip$ ; Attributes Max Angle&MD TD Alaska,Inc. [ii# Wellbore API/DWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) crx.04 tIiIpS 500292058500 KUPARUK RIVER UNIT PROD 57.25 4,400.00 9,791.0 na.. ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-08,10/12/201510:25:29 AM SSSV: TRDP 80 11/10/2014 Last WO: 9/6/2015 39.01 5/16/1981 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 9,022.0 6/13/2015 Rev Reason: WORKOVER smsmith 10/7/2015 HANGER;16.7 '' a Casing Strings iii �t Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread II. CONDUCTOR 16 15.060 32.0 80.0 80.0 65.00 H-40 WELDED ■ ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread AA SURFACE 10 3/4 9.950 31.2 2,714.0 2,587.2 45.50 K-55 BUTT Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 31.2 9,767.9 7,090.3 26.00 K-55 Buttress CONDUCTOR;32.0-80.0 ;I 1` Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread WINDOW L1-01 6.161 5.500 8,924.0 8,934.0 6,438.4 Tubing Strings Tubing Description (String Ma...'ID(in) Top(ftKB) I Set Depth(ft...Set Depth(TVD)(...I Wt(lb/ft) (Grade Top Connection GAS LIFT;2,599.6 TUBING-WO 2015 4 1/2 3.958 16.7 8,615.41 6,195.0 12.60 L-80 IBTM Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) i 16.7 16.7 0.13 HANGER FMC TUBING HANGER 3.911 8,589.9 6,175.8 41.10 NIPPLE CAMCO DB NIPPLE 3.813 SURFACE;31.2-2,714.0 !t, 8,611.4 6,192.0 40.89 SEAL ASSY BAKER 190-47 SEAL ASSMEBMLY W/LOCATOR 3.833 Tubing Description !String Ma...11D(in) I Top(ftKB) 'Set Depth(ft..JSetDepth(TVD)(...IWt(Ib/ft) Grade I Top Connection TUBING-ORIGINAL 41/2 3.958 8,615.4 8,822.81 6,353.3 12.60 L-80 IBTM Completion Details Nominal ID GAS LIFT,4,353.6 c=, Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 8,615.4 6,195.1 40.85 PBR BAKER 190-47 PBR 3.875 8,639.4 6,213.2 40.61 PACKER BAKER S-3 PACKER 3.875 8,781.4 6,321.7 40.20 NIPPLE X NIPPLE 3.813 8,821.4 6,352.3 40.20 WLEG WIRELINE ENTRY GUIDE 3.958 Other In Hole(Wireline retrievable plugs,valves, pumps,fish,etc.) GAS LIFT;5,914.1 Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 8,692.3 6,253.5 40.08 CATCHER SET ON WRP(OAL 33") 7/13/2015 8,695.0 6,255.6 40.05 PLUG 4.5"WFT WRP 6/17/2015 GAS LIFT;7,147.2 8,933.0 6,437.7 40.00 Whipstock BAKER THRU-TUBING 19'WHIPSTOCK,w/RA 7/23/2004 PELLETS TAGGED @ 8940"TOP OF WHIPSTOCK @ 8930';TESTED SWAB&MASTER TO 3500 psi. GAS LIFT;6,017.1 Perforations&Slots Shot I Dens Top(TVD) Btm(TVD) (shotslf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,927.0 9,012.0 6,433.1 6,498.2 UNIT D,C-4, 5/16/1981 4.0 IPERF GAS LIFT;8,525.0 G-3,1C-08 1 9,018.0 9,030.0 6,502.8 6,512.0 C-2,1C-08 5/16/1981 4.0 IPERF 9,096.0 9,122.0 6,562.4 6,582.3 C-1,UNIT B, 5/16/1981 4.0 IPERF 1C-08 NIPPLE,8,589.9 Mandrel Inserts St SEAL ASSY;8,611.4 ati on Top(TVD) Valve Latch Port Size TRO Run PBR;8,615.4- N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 2,599.6 2,495.8 CAMCO KBG2- 1 GAS LIFT DMY BK-5 0.000 0.0 9/13/2015 PACKER;8,639.4 1 R 2 4,353.6 3,619.3 CAMCO KBG2- 1 GAS LIFT SOV BK-5 0.000 0.0 9/13/2015 DCK-2 1R 3 5,914.1 4,505.3 CAMCO KBG2- 1 GAS LIFT DMY BK-5 0.000 0.0 9/13/2015 CATCHER;8,692.2 \111/5 1 R1R PLUG;8,695.0 `/// 4 7,147.2 5,207.1 CAMCO KBG2- 1 GAS LIFT DMY BK-5 0.000 0.0 9/13/2015 1R 5 8,017.1 5,758.8 CAMCO KBG2- 1 GAS LIFT DMY BK-5 0.000 0.0 9/13/2015 1R !^^ 6 8,525.0 6,127.1 CAMCO KBG2- 1 GAS LIFT DMY BK-5 0.000 0.0 9/13/2015 1R 1 Notes: General&Safety End Date Annotation NIPPLE;8,781.3 7/23/2004 NOTE:1C-08L1 ISA'PLOP N DROP'LINER SIDETRACKED OFF 1C-08L1-01 7/23/2004 NOTE:TRI-LATERAL WELL: 1C-08(B/C-SANDS), 1C-08L1 (C-SAND),1C-08L1-01 (C/D-SANDS) 2/5/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 1 I WLEG,8,821.4 I l I J SLOTS;8,795.0-9,407.0 L i LINER L1-01-3 1/2"x 3 3/16"x t 2 7/8";8,713.0-11,270.0 ' Whipstock;8,933.0 I WINDOW L1-01;8,924.0-\ 8,934.0 IPERF;8,927.0-9,012.0 IPERF;9,018.0-9,030.0 IPERF;9,096.0-9,122.0 PRODUCTION;31.2-9,767.9 a, Ima.(~roject Well History File Cover )ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~- ~' L-0~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: Grayscale items: [] Poor Quality Originals: Other: NOTES: [] Other, No/Type BY; BEVERLY ROBIN VINCENT~ARIA WINDY [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing BY: OBIN VINCENTt SHERYL ¥1ARIA WINDY. Scanning Preparation. ~.~ x 30 = ? 0 BY: BEVERLY ROBIN VINCENT SHERY M~WINDY -F TOTAL PAGES Production Scanning Stage '1 PAGE COUNT FROM SCANNED FILE: ' 7'~. PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: BY; BEVERL~ VINCENT SHERYL MARIA WINDY NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES ,, NO ReScanned (individual page [special RESCANNED BY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: General Notes or Comments about this file: Isl Quality Checked 12110102Rev3NOTScanned.wpd CJ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 9, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 ~ ~ ; .. ~ ~ ~r ~s Anchorage, AK 99501 ri~~~~~~~` ' ` ~ ~~ Dear Mr. Maunder: • JUN ~ 1 2009 Alaska Oil & Gas Cons. Cammis~~cr, Anchors®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 if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. , The cement was pumped May 27~', 2009. The corrosion inhibitor/sealant was pumped May 31St and June 1St, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ,,~,~%~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor _ • _ .. . • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 6/9/2009 Well Name PTD # Initial top of cement Vol, of cement um ed Final top of cement Cement top off -date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 A-06 181-116 n/a 0.25 22" 5/27/2009 1.70 5/31/2009 1 C-08 181-052 9'6" 3.50 20" 5/27/2009 1.30 5/31/2009 1C-15 198-229 4'10" 1.00 25" 5/27/2009 3.40 5/31/2009 1 D-125A 200-044 4'9" 1.00 10" 5/27/2009 4.50 6/1/2009 1H-03 182-115 15'10" 2.00 24" 5/27/2009 2.60 5/31/2009 1 C-08 (PTD 1810520) Report of failed TIFL Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Thursday, January 15, 2009 9:38 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 1 C-08 (PTD 1810520) Report of failed TIFL Attachments: 1 C-08 schematic.pdf; 1 C-08 90 day TIO plot.jpg Tom and Jim U Page 1 of 1 .~ Kuparuk gas lifted producer 1C-08 (PTD 1810520) failed a dia nostic TIFL on 01/14/09 and has been added to the weekly SCP report. The TIO prior to SI for the test was 260/1075/96 A leaking GLV is suspected. Slickline will troubleshoot the GLV's and repair if possible. Attached is a schematic and 90 day TIO plot. «1 C-08 schematic.pdf» «1 C-08 90 day TIO plot.jpg» .~ Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 z.:~ `~'`'' ~~ ~ k J~l~ ~` `t ~OC~. £r: bfi 1 / 15/2009 KRU 1 C-08 PTD 181-052 1 / 15/2009 TIO Pressures • • ~(771i000~11I~1~35 " ~ KUP _ 1C-08 Well Attributes - - ~ _ __ WeNbore APIIUWI Field iJama Well status Vrodrlm Well Type Inel (°) M(J (fU[81 II) tmaz/ (11... / 500292058561 IKUPARUK RIVER UNIT (PROD I 104.11 10,093.98 11,351.0 Comment H25 (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date - SSSV: TRDP 0 7/1/2008 Last WO: 7!23/2004 39 01 5/16/1981 wen c ry 1 -~i§§: 1 1 j oos z zz oa am -- . Scfie~neic ~ Acwal - Annotation Depth (kKB) End Dale Annotation End Date ,Last Tag: 9,153.0 7/26/2004 Rev Reason: MULTI-LATERAL FIX 11/13/2008 Casing Stlings - g ~ String OD String ID _ Set Depth Set Depth (ND) String Wt String IDUGTOR ~ Casing Description (in) (in) Top (ftK6) (HKB) (kKB) (Ibs/k) Grade String Top Thrtl , so - CONDUCTOR 1 6 15.06 0 0.0 80.0 80.0 65.00 H-40 ~raty vaNa, - - SURFACE 103/ 4 9.79 4 0.0 2,714.0 2,585.9 45.50 K-55 1,aos~ =VE, 1,806 - !=.r --( PRODUCTION 7 6.15 1 0.0 9,767.0 7,089.6 26.00 K-55 - WINDOW L1 O1 6 161 5.500 8,924.0 8 934.0 6,438.3 -- - - - Tubing Strings. -- iURFACE, 2 714 - String OD String ID Set Depth Sat Depth (TVD) String W[ a[nng ' Tubing De+erlption (in) (in) Top (ftKB) (kK8) (kKB) (Iba/k) Gratle String TOp Thrd f„ TUBING 41/2 3.958 0.0 8,823.0 6,353.4 12.60 L-80 IBT-MOD cns uFT, z 72 '--'~ _____ Other In Hole All Jewel Tubin Run & Retrievable Fish. etc. rY~ g ) 6 . , - Top Depth (ND) Top Top (kKB) (kKB) Inc! (°) Description Comment Run Date ID (in) GAS LIFT, _ ` 1,806.0 1,800.4 18.21 Safety Valve TRM-4FE-CF SSSV w/DB PROFILE set 7/23/2004 7/23/2004 3.812 4s]s - 1,806.0 1,800.4 18.21 SLEEVE FRAC SLEEVE 6/24/2005 2.250 2,728.0 2,597.4 36.56 GAS LIFT CAMCOlKBG-2/1/GLV/BK/.188/1290/ Comment: STA 1 2/10/2005 2.938 4,679.0 3,796.3 56.80 GAS LIFT CAMCO/KBG2/1/OV/BK/.25// Comment: STA 2 11/26/2004 2.938 GAS LIFT, ~ 6,166.0 4 653.2 54.50 GAS LIFT CAMCO/KBG-2/1/DMY/BK/// Comment: STA 3 11/26/2004 2.938 6,166 , -- 7,304.0 5,297.2 53.70 GAS LIFT CAMCO/KBG-2/1lDMY/BK///Comment: STA4 11/26/2004 2.938 8,072.0 5,797.2 45.14 GAS LIFT CAMCO/KBG2/1/DMY/BK-5!//Comment: STAS 11/23/2004 2.935 cns LI~ ~ -~ 8,560.0 6,153.4 41.40 GAS LIFT CAMCO/KBG-2/1/DMY/BK-5/// Comment: STA 6 11/23/2004 2.938 __ ._ - 8,615.0 6,194.1 39.79 PBR BAKER 190-47 PBR 7/23/2004 3.875 5,639.0 6,212.6 39.85 PACKER BAKER S-3 PACKER 7/23/2004 3.875 - _ ( 8,781.0 6,321.4 40.20 NIPPLE HES'X' (9CR 10124023) NIPPLE 7123/2004 3.813 GAS LIFT, s,o]2 "NIPPLE NOT USABLE w/3.5" LINER RUNNING THRU IT" t t ) ; 8,821.0 6,351.9 40.00 WLEG WIRELINE GUIDE 7123/2004 3.958 ~-~' 8,933.0 6,437.5 39.83 Whipstock BAKER THRU-TUBING 19' WHIPSTOCK, wlRA PELLETS 7/23/2004 cns LIFT, e sso TAGGED @ 8940" TOP OF WHIPSTOCK @ 5930'; TESTED . SWAB & MASTER TO 3500 psi. _ Perfora -.._.... tions _. -__ - ..-... _ --- 'BR.8.61a Top (ND) Btm (ND) oha[ Dana - Top (kKB) Blm (kKB) (kKB) (kKB) Zone Date (+h^• Type Comment - - 8,927.0 9,012.0 6,432.9 6,498.9 UNIT D, C-0, 5!16/1981 4.0 IPERF t i C-3, 1 C-08 :ER, 8,fi39 9,018.0 9,030.0 6,503.4 6,512.4 C-2, 1C-08 5!1611981 4.0 IPERF 5 9,096.0 9,122.0 6,562.4 6,552.3 C-1, UNIT B, 5/1611981 4.0 IPERF ~ iC-08 s [ s Notes: General & Safety - --- ~ _ - -----~ End Date Annotator e ~ 7!23/2004 NOTE: TRI-LATERAL WELL: 1C-08 (B/CSANDS), 1C-08L1 (C-SAND), 1C-OSLt-01 (C/0. SANDS) 'LE, a,]e1 € -~~ 111 NOTE: 1C-O8L1 IS A'PLOP N DROP' LINER SIDETRACKED OFF 1C-0SL1-01 f A ~ . C .EG, 8,821 _ Lp { Nhipslock, 8,933- T WINDOW -Ot, 8,934 - IPERF, 927.9,012 IPERF, - 016-9 a30 Slots, 7959,407 ~ -. IPERF, 096-9,122 - JER L1-01 OP, 9 414 Slots, 42]-9,903 uoow u, 9,725 JUCTION, 9,]6] D(1C-O8), 9,]91 JER Lt-01 M, 11 2]0 _ ~ ~ (g'(-os <. WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street -Suite ~ I ð'O Anchorage, Alaska 99501 RE: Distribution - Final Print[s) 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 : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford,1>< 77497 WELL DATE loG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR BLUE LINE Open Hole 1 Res. Eva!. CH 1 1 1 Mech. CH 1 c-OS 7-25-04 Caliper Survey 1 Rpt or 2 Color Print Name: Date : Pf-lf /0 <f Signed: PROACTivE DiAGNOSTic SERVicES, INC., PO Box I ~69 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@rnernorylog.corn Website: www.rnernorylog.corn .f't,~tJ - cR- <6þ Cf ! 01 ~ ~ Mike Mooney Wells Group Team Leader Drilling & Wells Conoc~iIIi ps P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 August 23, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1 C-08 (APD # 181-052) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 1 C-08. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ll¡j~ M. M~oney Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED AUG 2 4 2004 Alaska Ojl & Gas Cons C '. . omm;SSlon Anchorage OR'G'NAL Aft_I.. Ion 1. Operations Perfonned: Abandon 0 RepairWeli 0 Plug Perforations 0 Stimulate 0 Other Y'LJ Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development - 0 Exploratory 0 181-0521 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchoraç¡e, Alaska 50-029-20585-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 1 C-08 8. Property Designation: 10. Field/Pool{s): ADL 25649 Kuparuk River Oil Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9791' feet true vertical 7109' feet Plugs (measured) Effective Depth measured 9153' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SURFACE 2683' 10-3/4" 2714' 2586' PRODUCTION 9736' 7" 9767' 7089' Perforation depth: Measured depth: 8927'-9012',9018'-9030',9096'-9122' true vertical depth: 6433'-6498',6503'-6512',6562'-6582' Tubing (size, grade, and measured depth) 4-1/2' , L-80, 8823' MD. Packers & SSSV (type & measured depth) Baker S-3 packer @ 8639' SSSV= 1806' 12. Stimulation or cement squeeze summary: AUG ~ 4 'f'! 'it RIJIIII 8F L f','i Intervals treated (measured) n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oll-Bbl Gas-Me! Water-Bbl Casino Pressure Tublno Pressure Prior to well operation -- Subsequent to operation SI -- 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 Gas 0 WAGD GINJD WINJD WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A II C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team leader ~ ~. Signature ¡j ¡j~ Phone Date í$; 2 ~ (I '. PrAoarAd bv Sharon ~ rakA 263-4612 I v .~ t(ECE/VED STATE OF ALASKA AUG 2 4 2004 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska OJ' & G REPORT OF SUNDRY WELL OPERATIONS as Cons. COmmisso ~ ~ Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only ~ ~ ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 C-08 Common Well Name: 1 C-08 Event Name: WORKOVER/RECOMP Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 3S From - To Hours I Code I Sub Phase I Code 7/7/2004 20:00 - 23:00 3.00 MOVE DMOB MOVE 23:00 - 00:00 1.00 MOVE RGRP MOVE 7/8/2004 00:00 - 01 :00 1.00 MOVE RGRP MOVE 01 :00 - 04:00 3.00 MOVE MOVE MOVE 04:00 - 06:00 2.00 MOVE MOVE MOVE 06:00 - 14:00 8.00 MOVE RURD RIGUP 14:00 - 17:00 3.00 WELCT WRKOVR WRKOVR WRKOVR 17:00 - 18:00 18:00 - 19:40 1.00 WELCT 1.67 WELCT 19:40 - 21 :00 1.33 WELCT OBSV WRKOVR 21 :00 - 22:00 1.00 WELCT WRKOVR 22:00 - 22:15 0.25 WELCT WRKOVR 22:15 - 00:00 1.75 WELCT WRKOVR 7/9/2004 00:00 - 01 :30 1.50 WELCT CIRC WRKOVR 01:30 - 02:10 02:10 - 03:30 0.67 WELCT OBSV WRKOVR 1.33 WELCT CIRC WRKOVR 03:30 - 04:30 1.00 WELCT CIRC WRKOVR 04:30 - 05:15 0.75 WELCT OBSV WRKOVR WRKOVR WRKOVR WRKOVR 05:15 - 05:30 05:30 - 06:00 06:00 - 07:00 0.25 WELCT 0.50 WELCT 1.00 WELCT Page 1 of 9 Spud Date: 4/21/1981 End: Group: Start: 7/7/2004 Rig Release: Rig Number: 35 Description of Operations Demob Rig for upcoming rig move to 1 C-08 Rig Generators shutdown called mechanic for repair. Repaired Generator problem and called out Peak for the move. Shut down Rig Camp. Trucks on location and preparing for move. Move rig from 1 G pad to 1 C-08. Spot rig over well. Pull forward and layout Herculite for containment. Back rig up and center over well. Spot pit module and pipe shed. Raise derrick and scope up. Connect all hoses and electric lines. Accepted rig @ 1400 hrs. Bleed off OA to bleed trailer. 500 psi Tubing press = 650 psi, IA = 650 psi. R/U lubricator and pull BPV. R/U hardline to kill tanks. Load pits with seawater. Displaced well bore with seawater taking returns to kill tanks.Pumping down the tubing taking returns from the Csg. Initial Tbg Pressure = 850 psi. Initial Csg Pressure = 430 psi. Pump Rate 4.5 BPM, Held 500 psi to 700 psi back pressure on choke. Returns 1 for 1 during the circulation. Pumped a total of 260 bbls of seawater. Returns clean seawater at end of circulation. SID and monitor pressures. Loaded Pits with 10.5# brine. Initial Tbg Pressure = 590 psi & Initial Csg Pressure = 740 psi. After app: 1 hour Tbg Pressure = 1140 psi & Csg Pressure = 1450 psi. Bled back 20 bbls of seawater Tbg Pressure = 350 psi & Csg Pressure = 700 psi. Monitored 1 hour. Tbg Pressure = 500 psi & Csg Pressure = 900 psi. Ordered out another load of seawater. Held Job scope change Pre-job meeting. Unloaded 10.5# brine form pits. Vaced out Kill tanks. Wait on load of seawater. Load pits with seawater. Tbg Pressure = 600 psi & Csg Pressure = 1000 psi. Begin pumping 8.5# seawater down the tubing taking returns from Csg to Kill tanks. Holding 1100 psi on the Csg and pump rate @ 4 BPM. Bled Gas off intially after 20 bbls pumped, had fluid to surface. Got crude oil back for another 20 bbls then started getting seawater. Continued pumping @ 4 BPM, maintained 1 for 1 returns and holding 100 psi on the Csg. Pumped a total of 290 bbls. SID and bled Tbg & Csg down to 500 psi. Monitored Pressures and loaded pits with 10.5# brine. Tbg Pressure = 500 psi & Csg Pressure = 500 psi. Begin Pumping 10.5# brine down the Tbg taking returns from the Csg to the Kill tank. Pump rate @ 4.5 BPM, Holding 1100 psi on Csg. Had some problems with the pump after 240 BBls pumped and had to slow rate down to 3 BPM. Continued holding 1100 psi on the CSG and maintained 1 for 1 returns. Checking weight on returns after 305 BBls pumped got good 10.5# brine coming back. SID and bled both the Tbg and the Csg to 0 psi. Well is dead. Lined up to take returns to the pits thru the super choke. Begin pumping down the Tbg taking returns from the Csg to the pits. Circulated Btms Up 229 bbls with zero loss/gain. SID Monitor Well for flow and prepare to set BPV. Tbg Pressure = 0 psi & Csg Pressure = 0 psi. No gainsllosses to pits. Appears to be out of balance, as having a hard time bleeding off at tree cap. Installed a U-tube hose, equalized and bled off. Tbg Pressure 0 psi & Csg Pressure 0 psi. Installed BPV Held Pre-Workover Mtg with the Day Crew Blow down circ. lines, ND tree. Printed: 8/17/2004 12:56:53 PM ~ ~ ConocoPhillips Alaska Page 2 of 9 Operations Summary Report Legal Well Name: 1 c-oa Common Well Name: 1 C-08 Spud Date: 4/21/1981 Event Name: WORKOVER/RECOMP Start: 7/7/2004 End: Contractor Name: Nabors Alaska Drilling Rig Release: Group: Rig Name: Nabors 3S Rig Number: 3S Date From - To Hours Code I ¿;ou~e Phase Description of Operations - 719/2004 07:00 - 13:30 6.50 WELCTL NUND WRKOVR NU BOPE. 13:30 - 15:00 1.50 WELCTL NUND WRKOVR Change top set of pipe rams to 3-1/2'. 15:00 - 16:00 1.00 WELCTL NUND WRKOVR Attempt to set FMC Blanking Plug. Could not get started in threads. 16:00 - 18:00 2.00 WELCTL NUND WRKOVR ND stack just above tubing hanger, pick up on stack, remove SBMS bushing and screw test plug in by hand. NU stack on top of tubing WELCTL head again. 18:00 - 20:00 2.00 BOPE WRKOVR Pressure Test BOPE. FMC Plug Off tool appears to be leaking by. Test Ok'd by state inspector Chuck Sheve on location. Begin testing the bag WELCTL and had a leak at the flange. 20:00 - 22:30 2.50 NUND WRKOVR ND the Bag and replaced the API ring. 22:30 - 23:15 0.75 WELCTL BOPE WRKOVR Pressure Test Bag and completed BOP Test. 23:15 - 00:00 0.75 WELCTL BOPE WRKOVR Remove FMC plug off tool. Drain Stack to assist in pulling BPV. 7/10/2004 00:00 - 00:45 0.75 WELCTL BOPE WRKOVR Finished draining stack and removed BPV. Well is still dead. 00:45 - 02:15 1.50 FISH PULL WRKOVR Prepped floor for pulling tubing. Picked up Halliburton spooling unit to floor. Installed 3-1/2' BTC landing Jt wI TIW and pump in equipment. 02:15 - 02:45 0.50 FISH PULL WRKOVR BOLDS. Pulled up on Tbg. Worked slowly up to 121 k (blk wt = 12k). Worked pipe back and forth with no luck. Pulled up to max 125k (blk wt = 12k) and locked brake to let set. Notified SWS E-line unit to start this away. 02:45 - 05:00 2.25 FISH CIRC WRKOVR Worked pipe some more and decided to circulate and work pipe. Started circulating down tbg @ 3 BPM. Returns were a little gas cut with some traces of crude. Continued circulating and working pipe up to 121 k (blk wt = 12k). While waiting on E-line crew to arrive. Circulated 300 bbls around returns cleaned up. 05:00 - 06:00 1.00 FISH CIRC WRKOVR SID circulating and pulled a suction valve out of pump to make it hammer and rattle the pipe. It appears that pipe may be moving slightly made about 1'. Still waiting for SWS E-line to show. 06:00 - 06:30 0.50 FISH CIRC WRKOVR Continue circulating and rattling pipe. Max pull 121k (blk wt = 12k). Rig lost all power. SID pump and shut in well as it appeared well took a kick. SWS E-line on location. 06:30 - 09:00 2.50 FISH CIRC WRKOVR Power back on. Continue to circulate @ 3BPM @ 260 psi. Took 2 bbl gain. Shut in 180 psi. Circulated out gas bubble. Lost 6 bbls. 09:00 - 16:30 7.50 FISH OTHR WRKOVR Well finalily cleaned up. Continued pumping and working pipe (rattling). Pipe coming up hole but in small increments. Could not go back down. Pipe was moving but we had to pull hanger to floor, would not go back down. Pulled up hole until hanger 7' above rig floor. Max pull 148k + block wt 12k 16:30 - 17:00 0.50 FISH CIRC WRKOVR Mixed and pumped 20 bbls LubTex pill, spotted at bottom of open GLM. 17:00 - 19:45 2.75 FISH RURD WRKOVR Broke out tubing hanger and pup. Rig up Schlumberger E-line unit. Installed 6' pup and attached control line to spooler. Lowered tubing back in hole 6'. Set slips and left hanging wt of 85k. 19:45 - 21 :30 1.75 FISH RURD WRKOVR Continued RU E-line. 21 :30 - 00:00 2.50 FISH CPBO WRKOVR RIH wI 12' of single strand 1-11/16' string shot. Found that fish in the tubing has moved down and tagged top of fish @ 8654' rkb. Set string shot off across tubing @ 8607.5' - 8619.5' RKB. POOH. 7/11/2004 00:00 - 02:30 2.50 FISH RURD WRKOVR On surface with fired string shot. Make up Chemical Cutter. Held a safety meeting with SWS and Rig crew on the hazards of chemical cutter. 02:30 - 05:45 3.25 FISH CPBO WRKOVR RiH wI 2-5/8' chemical cutter. Tied in and made chemical cut 5' down on 2nd full joint above GLM#7. Cut Tbg @ 8618'. Good indication in E-line unit and on the rig floor that pipe cut. Start out of the hole with the chemical cutter. Printed: 8/17/2004 12:56:53 PM ~ ~ 'ConocoPhillips Alaska Page 3 of 9 Operations Summary Report Legal Well Name: 1 C-08 Common Well Name: 1 C-08 Spud Date: 4/21/1981 Event Name: WORKOVER/RECOMP Start: 7/7/2004 End: Contractor Name: Nabors Alaska Drilling Rig Release: Group: Rig Name: Nabors 3S Rig Number: 3S Date From - To Hours Code Sub Phase Description of Operations Code ,-... 7111/2004 05:45 - 06:30 0.75 FISH RURD WRKOVR On surface with the chemical cutter. Rig E-line equipment to the side. Break out TIW valve and install 4' pup. Pull on tbg to ensure cut had been made, pipe free, Up wt = 70k. Install 3-1/2' TIW and NU head pin to circulate. 06:30 - 07:30 1.00 FISH CIRC WRKOVR Circulate bottoms up, 230 bbls and RID E-line equipment. Shut down WELLSF monitor well (static). 07:30 - 11 :30 4.00 PULD WRKOVR RlU Halliburton Spooling unit for control line. POOH laying down 3-1/2' completion and spooling up control line. Pulled up to SSSV @ 1816'. Retrieved 33 SS bands. 11:30 - 12:30 1.00 WELLSF PLGM WRKOVR M/U Storm Packer and RIH wltubing an set below surface 50'. Press WELLSF test packer to 1000 psi. 12:30 - 18:45 6.25 NUND WRKOVR ND BOPS NID the 7-1/16' x 11' tubing head. Replace packoffs. Installed new 11' x 11' tubing head. Energized the packoffs and press test the void to 3000 psi. 18:45 - 20:15 1.50 WELCTL NUND WRKOVR NU BOPE 20:15 - 22:30 2.25 WELCTL BOPE WRKOVR Test BOPE post wellhead swap. State Inspector (Chuck Sheve) waived witness of test but requested that we test everything. Choke Hose started to leak had to replace. Completed the BOP test 22:30 - 23:30 1.00 WELLSF PULD WRKOVR Installed Wear Bushing. Cleaned up around the rig floor and straightened up the cellar. Picked up Baker Storm Packer retrieval toOl WELLSR and made up to joint of 3-1/2'. 23:30 - 00:00 0.50 PULD WRKOVR Latched into storm packer and equalized. No change in well bore conditions, it is still static. Pulled Storm packer to the floor and layed down. 7/12/2004 00:00 - 09:30 9.50 WELLSR PULD WRKOVR Started tripping out with the old completion. pulling and laying down singles. Filling hole after every 10 joints. 3.5 bblloss.. Came out wI 10' stub. Chemical cut looks good, no burrs, smooth cut, no corrosion or scale. 09:30 - 11 :00 1.50 FISH TRIP WRKOVR Clear rig floor of all GLM's etc. Set up tools for running fishing tools and work string. 11 :00 - 13:00 2.00 FISH TRIP WRKOVR Make up BHA, Overshot wI 3-1/2' grapple, Bumper sub, Oil Jars, and six 4-3/4' Drill Collars. 13:00 - 22:00 9.00 FISH TRIP WRKOVR Picking up 3-1/2" P-110 workstring and tripping in the hole with same. Postioned bottom of BHA @ 8597'. 22:00 - 23:00 1.00 FISH CIRC WRKOVR RU pump in sub and circulated bottoms up wI 10.3# brine @ 4.5 BPM for 230 bbls. 23:00 - 00:00 1.00 FISH FISH WRKOVR Got good weight check. Up wt = 87k & Dwn wt = 70k. Set down on the fish @ 8618'. Slid over and swallowed 3' - 4' of fish. Pulled up to 95k and soft stroked Hydraulic jars and pulled on up to 200k. No movement. Worked Bumper jars up to 1O0k, still no movement. 7/13/2004 00:00 - 00:30 0.50 FISH JAR WRKOVR Free Up Wt = 87k. Worked Bumper Jars on fish to 1O0k. Hit about 20 times. Fish is solid no movement. 00:30 - 00:45 0.25 FISH JAR WRKOVR Starting using Hydraulic Jars. Worked @ 125k {38k over pipe wt)for app: 10 hits. No movement. 00:45 - 01 :05 0.33 FISH JAR WRKOVR Worked Hydraulic Jars @ 135k (48k over pipe wt) for app: 20 hits. No movement 01:15 - 01:35 0.33 FISH JAR WRKOVR Worked Hydraulic Jars @ 150k (48k over pipe wt) for app: 20 hits. No movement 01:35 - 01:55 0.33 FISH JAR WRKOVR Worked Hydraulic Jars @ 170k (83k over pipe wt) for app: 20 hits. No movement 01:55 - 02:15 0.33 FISH CIRC WRKOVR Free dwn Wt = 70k. Set down 20k on top of fish and rigged up to circulate. Begin pumping and after 1 bbl away tubing pressured up to 2500 psi. Unable to circulate. Bleed back pressure. Set up to Jar again. Printed: 8/17/2004 12:56:53 PM ~ ~ ConocoPhillips Alaska Page 4 of 9 Operations Summary Report Legal Well Name: 1 C-08 Common Well Name: 1 CoOS Spud Date: 4/21/1981 Event Name: WORKOVER/RECOMP Start: 7/7/2004 End: Contractor Name: Nabors Alaska Drilling Rig Release: Group: Rig Name: Nabors 3S Rig Number: 3S .. I Sub Date From - To Hours Code, Code Phase Description of Operations , - 7113/2004 02:15 - 02:45 0.50 FISH JAR WRKOVR Worked Hydraulic Jars @ 175k (88k over pipe wt) for app: 30 hits. No movement. Baker recommendation of no more than (90k over) maximum on jars. Decided to stop here before tearing something up. 02:45 - 04:40 1.92 FISH FISH WRKOVR Attempt to release overshot from fish. Unable to turn pipe and unable to release. Beat down on fish to jar grapple free. Attempt to rotate pipe. still binding up. Had a lot of problems with the pipe spinning back after putting a few turns in it. The blocks were trying to spin backwards also. Beat down some more using block weight to beat down on top of pipe wI lifting sub installed. Rotate pipe and released Overshot from fish. 04:40 - 05:45 1.08 FISH CIRC WRKOVR Pulled up 5' above fish and circulated bottoms up + a little @ 5 BPM. Completed circulation 240 bbls, 10.5# in and out. Ordered out Burn shoe and wash over pipe from Baker fishing shop in Deadhorse. 05:45 - 06:45 1.00 RIGMNT RSRV WRKOVR Service Rig and Inspect Derrick & Block post jarring. 06:45 - 12:30 5.75 FISH TRIP WRKOVR Trip 3-1/2" P110 work string OOH. Racked back doubles in the derrick. 12:30 - 19:00 6.50 FISH RURD WRKOVR Start to pick up Kelly and make up for continuation of program. Begin pick up of BHA. 19:00 - 00:00 5.00 FISH TRIP WRKOVR Finished making up BHA & getting it going in the hole.Trip in wI 3-1/2' work string. Had trip slowly as there is minimal bypass on the washover pipe. 7/14/2004 00:00 - 02:45 2.75 FISH TRIP WRKOVR Continued tripping in the hole wI wash over BHA on 3-1/2' P110. Stopped just above fish to circulate hole.and circulated bottoms up + 240 bbls, 10.3# brine. 02:45 - 04:00 1.25 FISH CIRC WRKOVR Circulated bottoms up + 240 bbls, 10.3# brine. While circulating hole was in progress, began slipping and cutting drill line. Fished bottoms up circulation and finished slipping and cutting. 04:00 - 05:15 1.25 FISH RURD WRKOVR Pick up Kelly and make up Kelly hose. Test Kelly. 05:15 - 06:30 1.25 FISH WASH WRKOVR Check Weight Up Wt = 92k & Dwn Wt = 75k. Kicked on pump @ 4 BPM and lowered down to top of fish 8600' (N3s floor). Un able to pass, kept catching on the top. Rotated and fell over. Washed down to 8617' (N3s floor). No problems pretty much free all the way. Stopped rotating pull up to add joint. SID pump. 06:30 - 07:30 1.00 FISH WASH WRKOVR Add Jt and Kick pump back on @ 4 BPM. Started rotating and Wash down to 8647' (N3s floor).. Stopped rotating, pull up to add joint. 07:30 - 11:45 4.25 FISH WASH WRKOVR Add Jt and Kick pump back on @ 4 BPM. Started rotating and Wash down to bottom of GLM. While on GLM @ 8,660' torque average = 5,500-6,000FT/LB. 8,000# of down wt. Free wt = 93,000# 11 :45 - 12:30 0.75 FISH CIRC WRKOVR Perform two bottoms up prior to picking up last joint of tubing to ensure no sticky situations. 12:30 - 14:00 1.50 FISH WASH WRKOVR Tag top of PBR. Pump 30 BBL pill of 3 PPB HEC. Circulate bottoms up. Prepare to POOH and pick up fishing overshot. Dispose of 85 BBLs brine due to contamination of HEC pill. 14:00 - 15:30 1.50 FISH TRIP WRKOVR Rig back Kelly and pick up elevators for POOH. Watching hole fill for loss. Up WT. = 107,000-95,000#. Dragging up hole. 15:30 - 21:30 6.00 FISH TRIP WRKOVR All Tubing racked back started racking back the drill collars and jars. 21 :30 - 23:30 2.00 FISH PULD WRKOVR Lay down the Wash Over assembly. Emptied the Boot Basket, it was full of sand and metal. Cut-rite on the burn shoe was pretty much wore down. Finished laying down all WashlBurn over assembly. It appears that we lost aboput 10 bbls of fluid during the trip. Monitored the hole and it looked to be dropping very slowly. 23:30 - 00:00 0.50 FISH PULD WRKOVR Picked up and made up 5-3/4' Over shot. 7/15/2004 00:00 - 05:15 5.25 FISH TRIP WRKOVR Tripped in hole wI 5-3/4' Overshot on 3-1/2' P110 work string. Lost app: 6 bbls of 10.3# brine during the trip. 05:15 - 06:15 1.00 FISH CIRC WRKOVR Installed pump in sub and circulate bottoms up @ 5 BPM, 10.3# brine, Printed: 8/17/2004 12:56:53 PM ~ ~ ConocoPhillips Alaska Page 5 of 9 Operations Summary Report Legal Well Name: 1 C-08 Common Well Name: 1 C-08 Spud Date: 4/21/1981 Event Name: WORKOVER/RECOMP Start: 7/7/2004 End: Contractor Name: Nabors Alaska Drilling Rig Release: Group: Rig Name: Nabors 3S Rig Number: 3S Date From - To Hours Code Sub Phase Description of Operations Code 7115/2004 05:15 - 06:15 1.00 FISH CIRC WRKOVR 230 bbls. 06:15 - 06:45 0.50 FISH FISH WRKOVR Checked weight, Up wt = 87k & Dwn wt = Eased down to top of fish @ 8600', rotated to get over. Latched up to fish. 06:45 - 07:00 0.25 FISH JAR WRKOVR Pulled up to 125k (37k over pipe wt), set the jars off and fish came free. Pulled up 15' and then went back down. It appears that we have the fish on. The pipe up weight is now 89k. 07:00 - 07:30 0.50 FISH CIRC WRKOVR Installed pump in sub and circulated 1+ BPM @ 450 psi. Seems that there is a little extra restriction. Prepare to come OOH. 07:30 - 13:30 6.00 FISH TRIP WRKOVR Fish to surface. Prepare to handle jars and bumper sub. Prepare for 3.5" tubing. 13:30 - 14:30 1.00 FISH TRIP WRKOVR OOH. Pulled top handling pup out of GLM @ 8,672'. After talking to Anchorage, call out wireline for LIB and possible fish on previous wireline string left in hole. Order out spear and overshot for new rig tools. Spear is to have a 10' catch for passing through the GLM and anchoring up in lower handling pup. 14:30 - 18:00 3.50 FISH SLiN WRKOVR Slickline on location. Begin rig up. Prepare for LIB run. 18:00 - 19:00 1.00 FISH SLiN WRKOVR SIL RIH wI 3.55 LIB to 8672' wlm (N3s Rig floor). POOH. LIB showed a portion of the top of the collar on top of GLM. 19:00 - 20:00 1.00 FISH SLiN WRKOVR SIL RIH wI 2.5' LIB with 2.78" Centralizer to 8672' wlm (N3s Rig floor). POOH. LIB showed the same, a portion of the top of the collar on top of GLM. 20:00 - 21 :00 1.00 FISH SLiN WRKOVR SIL RIH wI 2.66' Swedge with double bow spring centralizers to 8672' wlm (N3s Rig floor) unable to get past. POOH. 21 :00 - 22:30 1.50 FISH SLiN WRKOVR SIL RIH wI 5.5" LIB to 8672' wlm (N3s Rig floor). POOH. LIB a portion of the top of the collar on top of GLM. 22:30 - 00:00 1.50 FISH SLiN WRKOVR SIL RIH w/2.70' LIB with double bow spring centralizers to 8672' wlm (N3s Rig floor). POOH. LIB showed the same, a portion of the top of the collar on top of GLM. 7/16/2004 00:00 - 00:30 0.50 FISH RURD WRKOVR Finish rigging down S/line . 00:30 - 02:00 1.50 FISH PULD WRKOVR Picked up Baker 5-3/4' Extended Overshot wI 4-3/4" Grapple. Prepare floor for Trip in the hole. Made up Jars & drill collars. 02:00 - 06:30 4.50 FISH TRIP WRKOVR Tripped in hole wI 5-3/4' Overshot on 3-1/2" P110 work string. Stopped 1 joint above fish and prepare circulate. 06:30 - 09:00 2.50 FISH CIRC WRKOVR Install pump in sub and circulate bottoms up @ 5 BPM, 10.3# brine. 09:00 - 10:00 1.00 FISH JAR WRKOVR Original up wt = 90K, down wt = 70K. Begin initial pull allowing jars to bleed off, or (soft set), pulled in 10K increments to 200,000#. No down hole movement. Start jarring action with 10 hits @ 110-120K. No movement. 7 hits @ 130K. No movement. 8 hits @ 165K. Lost over pull wt. PUH 8' apparent that we are dragging something. Appears that we are swabbing hole. Attempted to RBIH-made 4' past where we had been setting 25K dwn to allow jars to cock before weight went to neutral. 10:00 - 12:15 2.25 WELCTL CIRC WRKOVR Experienced a 180-PSI kick. Begin well control operations. Perform a pump schedule and circulate out kick. Gained 8 BBLS. Call out vac truck for possible pit gain. 12:15 - 13:30 1.25 CMPL TN PULL WRKOVR Break off head pin and monitor well for flow. No flow. Prepare to POOH with work string and fish. UP WT = 100-110K dragging and swabbing on way to surface. We are experiencing up to 50K over pulls around 7' collars? 13:30-18:00 4.50 WELCTL CIRC WRKOVR Establishing circulation kill methods. As we encounter over pulls a gas influx occurs. On the third attempt to move pipe after circulating work string went on a vacuum while IA had activated fluid. Measured fluid loss in work string to be aprox 8 BBLS. Close bag and begin circulation Printed: 8/17/2004 12:56:53 PM ~ ~ ConocoPhillips Alaska Page 6 of 9 Operations Summary Report Legal Well Name: 1 C-08 Common Well Name: 1 C-08 Spud Date: 4/21/1981 Event Name: WORKOVER/RECOMP Start: 7/7/2004 End: Contractor Name: Nabors Alaska Drilling Rig Release: Group: Rig Name: Nabors 3S Rig Number: 3S Date From - To Hours Code Sub Phase Description of Operations Code 7/16/2004 13:30 - 18:00 4.50 WELCTL CIRC WRKOVR kill holding 700# backpressure while pumping 4 BPM, 900# pump pressure. Attempted to pump past packer by shutting in casing and allowing pressure to reach 800#. No loss. Continue to circulate kill. WELCTL Gas in retums. No gain or loss. 18:00 - 21 :30 3.50 CIRC WRKOVR Circulating a full surface to surface circulation using 10.3# brine. Pump rate a 4 BPM and holding 700 psi on the IA. No gas in returns and no gains or losses. Worked the choke full open slowly and opened the bag. WELCTL Continued circulating through the flowline. Prepare to move tubing. 21 :30 - 00:00 2.50 CIRC WRKOVR SID pump and monitor well. Gas is breaking out of the fluid and well is being to flow. Begin weightinng up brine to 10.5#. Circulating @ 4 BPM. While doing that move the pipe up & down app: 20' attempting to wear out rubber on packer or junk around packer. Pipe weights are Up Wt = 94k & Dwn Wt = 70k. When getting bottoms up started to get a little more gas entrained in the fluid. Closed bag and went through the choke holding 200 psi back pressure. Stopped moving the pipe while the bag is closed and going through the choke. Continued weighting up fluid to 10.5#. 7/17/2004 00:00 - 01 :30 1.50 WELCTL COND WRKOVR Weighted brine up to 10.5#. Circualting using choke and holding 200 psi back pressure on the IA. 10.5# in & 10.5# out. Raise pump rate to 5 BPM & work choke open slowly. SID pump & opened the bag. Observed well and it is dead. Begin taking returns throught the flowline again. Pumping 10.5# brine @ 5 BPM returns 1 for 1. 01 :30 - 03:00 1.50 FISH OTHR WRKOVR Check weights Up Wt = 96k & Dwn Wt = 70k. Started working the pipe up and down again. Found a collar or tight spot @ 8562'. Worked pipe back and forth through this spot. As we pull through it we see about a 6k over pull. keep doing this. Started to pull heavier coming through it, pulled up to 150k before pulling through, but able to go back down. Pull up heavy again pulled up to 150k and would not go thru. Dropped down and sat down then slid back down, pipe free. pulled up to 170k to get thru. Have worked pipe through this spot about 50 times.Stop just above tight spot and will circulate and look at returns before proceeding. 03:00 - 04:00 1.00 FISH CIRC WRKOVR Circulate bottoms up app: 230 bbls. Monitor returns. No gas in retums and the well is dead. 04:00 - 06:00 2.00 FISH OTHR WRKOVR Pulled up slowly on pipe while not pumping to see if it was still swabbing and it was. Pulled out 1 joint and worked pipe while not circulating. Check free pipe weights up Wt = 96k & Dwn Wt = 70k. Set slips on pipe and rotated @ a very slow rpm 2000# torque, pipe rotated freely. Rotated for app: 15 mins. Picked back up on tubing and check to see if swabbing still swabs. Started circulating @ 5 BPM and worked through casing collar @ app: 8515'. Initially was pulling up to 125k to get through and after about 25 times through it is only pulling 105k to get through. SID pump and check to see if it swabs. It appears that we have wom it down as it will swab some but came back if you stop. 06:00 - 08:30 2.50 FISH OTHR WRKOVR Wait for rod packing to be repalced or repaired. Monitor the hole and work pipe slowly. Wait for Rock to fix the well. 08:30 - 18:00 9.50 FISH JAR WRKOVR Utilized various methods in an attempt to loose fish. Several attempts by locking packer seal in casing collar and pressuring up wellbore. Jarring through collars with up to 210,000# up wt. Aprox.120,000# over string wt. After conferring with town decide to RIH to tag top of fill and attempt to back off Bowen overshot. Maximum down wt used was 75K. Maximum torque utilized was 7,000#. Several different styles attempted with no luck. Talked to John Crisp with AOGCC about BOP test due on Sunday. He informed us to give an update in the morning Printed: 8/17/2004 12:56:53 PM ~ ~ ConocoPhillips Alaska Page 7 of 9 Operations Summary Report , Legal Well Name: 1 c-oa Common Well Name: 1 C-08 Spud Date: 4/21/1981 Event Name: WORKOVER/RECOMP Start: 7/7/2004 End: Contractor Name: Nabors Alaska Drilling Rig Release: Group: Rig Name: Nabors 3S Rig Number: 3S I Sub Date From - To Hours Code Code Phase Description of Operations - -, 7117/2004 08:30 - 18:00 9.50 FISH JAR WRKOVR for possible extension. 18:00 - 19:00 1.00 FISH OTHR WRKOVR Rotating pipe and circulating. Circulating pressure increasd 800 psi to 1200 psi @ 3 BPM. Slowly move pipe up to next casing collar pulled 210k to free pipe. Continued moving up and break out 1 joint & 5' of pups. Hook back up the Kelly. 19:00 - 20:30 1.50 FISH OTHR WRKOVR Find next casing collar and pulled heavy (120k) into it. Rotated here, circulating pressure dropped back down to were it had been before 400 psi @ 3 BPM. Continued rotating and circulating here for 1 hour. SID pump and pull up still swabbing. 20:30 - 22:30 2.00 FISH OTHR WRKOVR Begin rotating down through the casing collar and pulling up. It appears that we are wearing the element down as it pulls easier thru the collar and is not swabing so bad. Saw some torque on the rotary and well started drinking fluid at 2 to 3 BPM. Does not pull any extra weight at the collar. Pulled up 2 more joints to get fish above the perf's and circulated losing 2 BPM while circulating @ 3 BPM and losing about 1 BPM just keeping the hole full. 22:30 - 00:00 1.50 FISH CIRC WRKOVR Circulating and watching hole. Lost app: 80 Barrels in an hour. Call for more brine and seawater. 7/18/2004 00:00 - 03:30 3.50 WELCTL CIRC WRKOVR Ran out of brine and loaded hole with seawater. Lost app: 70 more bbls while circulating in 8.5# seawater. After loading hole SID pump and tubing pressure @ 600 psi. Will need at least 10.3# brine. 03:30 - 05:00 1.50 WELCTL CIRC WRKOVR Blend brine in pits and prepare to circulate. 05:00 - 08:00 3.00 WELCTL CIRC WRKOVR Circulated in 10.3# brine 08:00 - 09:00 1.00 WELCTL OBSV WRKOVR 10.3# brine to surface. Shut well in and monitor. Talked to Lou Grimaldi about pushing test for the day. He has given permission as long as we are pulling out of the hole. We weill test prior to RBIH. 09:00 - 12:30 3.50 FISH PULL WRKOVR Begin pulling out of hole. UP WT = 93,000# pulling slowly in case of swabing. After pulling 5 stands brine falling slowly. Lost 4 BBLS during circulation across the top while PUH. Continue to POOH and monitor liquid returns. Ordered 200 BBLS of 10.3 brine for delivery in Kuparuk. 12:30 - 13:30 1.00 FISH CIRC WRKOVR Have fluid swapping out. 10.3 heavy going in 10.3 comming out. Losing to many BBLS. Begin diluting current mud wi. Call out 200 BBLS of 10.2#. 13:30 - 18:00 4.50 FISH PULL WRKOVR Continue to POOH after circulating to 10.2#. 75,000# up wi. Still losing 15-18 BBLS per hour of returns. Total of 3 slight overpulls while pulling out of hole. Lou Grimaldi waived state witness of weekly BOP test. 18:00 - 21 :30 3.50 FISH PULL WRKOVR Continued Tripping out slowly. Racked back Drill collars and jars. No fish on overshot. Grapple had one slip broken at the bottom and teeth were wom down quite a bit, but in good shape. There were no marks on the outside of the overshot. The boot basket was full of sand & metal shavings. Fluid losses slowed down to about 10 BPH. 21 :30 - 00:00 2.50 WELCTL BOPE WRKOVR Install new choke hose and Begin testing BOPE. Fluid losses have slowed down to about 6 to 8 BPH. 7/19/2004 00:00 - 03:00 3.00 WELCTL BOPE WRKOVR Completed testing BOPE, also replaced Choke line with proper equipment. 03:00 - 04:00 1.00 FISH PULD WRKOVR PU Baker 4-3/4" Jars with 2-1/4' ID. Make up Baker 5-3/4' overshot wI 4-3/4' Grapple. 04:00 - 08:30 4.50 FISH TRIP WRKOVR Trip in wI the above Overshot, 4-3/4" Bumpers, 4-3/4' Hyd Jars, 6- 4-3/4" Drill Collars on 3-1/2"12.95# P110. 08:30 - 12:00 3.50 FISH TRIP WRKOVR Tagged and bumped fish down hole. We are now seeing the same weight annomilies as we RIH. Have attempted several time to grab fish without success. 12:00 - 14:00 2.00 FISH FISH WRKOVR Utilized the bumper sub several times to ensure a good catch. Swallow Printed: 8/17/2004 12:56:53 PM ~ ~ ConocoPhillips Alaska Page 8 of 9 Operations Summary Report Legal Well Name: 1 C-08 Common Well Name: 1 C-08 Spud Date: 4/21/1981 Event Name: WORKOVERIRECOMP Start: 7/7/2004 End: Contractor Name: Nabors Alaska Drilling Rig Release: Group: Rig Name: Nabors 3S Rig Number: 3S Date From - To Hours Code Sub Phase Description of Operations Code - 7119/2004 12:00 - 14:00 2.00 FISH FISH WRKOVR 4' after initial set down depth. Up weight = 97K. Dwn wt = 72K. Circulation press = 1.5 BPM @ 140 PSI initialy. After stabing over fish circulation pressure rose to 360#. 14:00 - 18:00 4.00 FISH PULL WRKOVR Make up and circulate a dry job to POOH»>Begin to POOH. Utilized the bumper sub several times to ensure a good catch. Swallow 4' after initial set down depth. Up weight = 97K. Watching for any signs of swabbing. Hydraulic motor for power tongs currently down--breaking out stands with rig tongs. Start to order out aux power supply for power tongs. 18:00 - 20:30 2.50 FISH PULL WRKOVR Stopped losing fluid and hole fill not right. Stopped and monitored well. Appeared to be flowing slightly or out of balance. 20:30 - 21 :30 1.00 WELCTL CIRC WRKOVR Make up the head pin and begin circulating @ 2.5 BPM, Tbg pressure = 750 psi. Circulated a full surface to surface circulation of 10.2# continued to circulate as we took a 30 bblloss while circulating. SID and observe well. 21 :30 - 22:00 0.50 WELCTL OBSV WRKOVR Observed well flowed back 3 bbls in 30 minutes. 22:00 - 00:00 2.00 WELCTL COND WRKOVR Begin circulating again at a reduced pump rate 1.5 BPM. Add salt to brine to bring weight up to 10.2+#. Continued circulating. Circulated 1.5 times the well bore volume down to 4092' app: 210 bbls. 10.2+# going in and 10.2+ coming out. lost app: 15 bbls during the circulation. SID and monitor the well. 7/20/2004 00:00 - 00:30 0.50 WELCTL OBSV WRKOVR Completed circulation of 10.25# brine all the way around down to 4092' SId pump and monitored well. Hole is drinking fluid now. Prepare to trip OOH. 00:30 - 04:00 3.50 FISH TRIP WRKOVR Tripped OOH recovered Fish. Prepped to lay down the fish. Fluid losses are 4 to 6 BPH 04:00 - 06:00 2.00 FISH PULD WRKOVR Begin laying down the fish found everything below the GLM that we are latched onto to be full of sand the top of the wireline fish was in the GLM. The wireline tools had sand completely packed around them. We were able to get the GLM and the pup below out from around some of the wireline fish but the remainder is stuck tightly in the 1st joint below the GLM and pup. Layed down Packer and PBR packed full of sand. The Packer only had one small piece of the rubber element left on it. The 1 st joint below the packer was full of sand and the Standing valve had sand packed so tightly around it had a hard time breaking the connection apart betweeen the joint and the nipple. 06:00 - 08:00 2.00 FISH PULD WRKOVR Layed down over shot and PU Scraper and Boot Baskets. Continue to monitor well bore fluid for returns. 08:00 - 14:30 6.50 FISH PULD WRKOVR Begin picking up BHA for scraper run. Sent the 30' joint of 3.5' tubing with the wireline string that was trapped inside to the wash bay for extraction. Full recovery on the wireline string. Trip in hole to 9100' wI WELCTL scraper. 96K up wt. 74K dwn wt. No overpull. 14:30 - 18:00 3.50 OTHR WRKOVR Begin circulating. 2 BPM 130# DPP 10# CPo Shut down & monitor well. Pooh to 8860'. Mix and pump 18 bbl calcium carbinate pill. Squeeze in. Well still flowing. 18:00 - 22:30 4.50 WELCTL OTHR WRKOVR Pump 2nd 20 bbl calcium carbonate pill. Attempt to sqeeze; no pressure increase seen. Check well for flow rate...well flowing. Begin circulating hole, adjusting rate to keep well balanced. 140# 2 BPM DDP. 40# SICP during squeeze. 22:30 - 00:00 1.50 WELCTL COND WRKOVR Shut in well; monitor. Well still flowing. Increase mud wgt from 10.21 to 10.24. Continue circulating. 7/21/2004 00:00 - 06:00 6.00 WELCTL CIRC WRKOVR Circulate in new mud wgt, 10.21 to 10.24 until consistent all the way around, 1.5 bpm @ 110 psi. Shut down and monitor. Well drinking. Run Printed: 8/17/2004 12:56:53 PM r--- ~ ConocoPhillips Alaska Page 9 of 9 Operations Summary Report Legal Well Name: 1 C-08 Common Well Name: 1 C-08 Spud Date: 4/21/1981 Event Name: WORKOVERIRECOMP Start: 7n/2004 End: Contractor Name: Nabors Alaska Drilling Rig Release: Group: Rig Name: Nabors 3S Rig Number: 38 Date From - To Hours Code Sub Phase Description of Operations Code --, 7/21/2004 00:00 - 06:00 6.00 WELCTL CIRC WRKOVR scraper to approx 8970'. Begin tripping ooh. 06:00 - 12:00 6.00 CMPL TN PULL WRKOVR OOH with work string. Begin pulling and laying down the drill collars. 12:00 - 15:00 3.00 CMPL TN RURD WRKOVR Break down work string BHA. Load out work string PH-06 send to 1Y-pad. Begin tear down of KELLY. Tear down containment dike for wireline program in the moming on 1C-07. Load out all of the Baker jars and accelerators along with the bumper subs. Will send out the drill collars and the wash pipe in the morning. Begin to collect all Conophillips crossovers for re-stock in inventory. 15:00 - 21:00 6.00 WELCTL EORP WRKOVR Redress BOP wI 4-1/2" inserts, lifting equipment. Perform BOP body to to 4000 psi--good. Cont to prep for running completion. 21 :00 - 00:00 3.00 CMPL TN RUNT WRKOVR Begin running new 4-1/2' completion. 7/22/2004 00:00 - 11 :30 11.50 CMPL TN RUNT CMPL TN Cont. Running new 4-1/2' completion. 11:30 - 13:00 1.50 CMPL TN RUNT CMPL TN Up wt = 70K. Dwn wt = 56K. Prepare to install SSSV with Schlumberger Brent Oberman on location for representation, along with running control line. Begin mixing 20 BBL corrosion inhibition pill. 13:00 - 16:30 3.50 CMPL TN RUNT CMPL TN Continue to RIH banding control line to production pipe. UP WT = 87K DWN WT = 69K. Pick up joint 277 for sace out to set PKR. Well flowing slowly. Monitor for 15 min. No change in rate. Continue with origional plan. 16:30 - 19:15 2.75 CMPL TN SECT CMPL TN Launch ball and rod. 1 3/8' JDC FN. 4' long 2.20' fins. After dropping ball and rod PUH to set depth. Pressure up to 3,500#. PBR sheared out at 130K with 1,000# on tubing for assist. Pressure test tubing for 15 Min. 19:15 - 21:34 2.32 CMPL TN SECT CMPL TN Prepare to land tubing in hanger. Run in lock down screws to proper torque value. PT lower fitting to 5,000# and hold for 10 min. 38 bands total on pipe from 1,812' for control line containment. 21:34 - 00:00 2.43 CMPL TN SECT CMPL TN Re-sting into PBR and pressure test tubing to 2,500# Passed. Pressure test IA to 2,600# while holding 2,100# on tubing. SOY sheared out at 3,000#. Pressure tested SSSV to 1,000# for a total of 30 min. Passed. All test charted and filed into well workover file. Install two way check and test through the IA to 1,000# prior to rigging down BOP. 7/23/2004 00:00 - 10:00 10.00 CMPL TI\ NUND WRKOVR Pull mousehole. Wash and rinse BOPE and choke system with fresh water. Blow down and prepare to tear down. Begin rigging down BOP stack, 1 piece at a time. Clear pipe shed. Inventory and prep to ship out all perpherals. 10:00 - 12:00 2.00 CMPL TN NUND WRKOVR Install tree and pressure test. Begin load out of all peripherals. Pressure tested SSSV control line to 5,000# Passed. Release rig at 12:00 Printed: 8/17/2004 12:56:53 PM ~ ~S /s~/-Q.~,2.. ~ ~ Memory IVlulti-Finger Caliper LOg Results Summary Company: CONOCOPHiLLIPS ALASKA INC Well: 1C-08 ' Log Date: July 25, 2004 Field: Kuparuk Log No.: 5508 .State: Alaska Run No.: 1 API No.: Pipet Desc.: 4.5" 12.6 Ib. Top Log Intvl1.: 8,395 Ft. (MD} Pipet Use: Tubing Bot. Log Intvl1.: 8,821 Ft. (MD) Pipet Desc : 7" 26 Ib. Top Log Intv12.: 8,821 Ft. (MD) Pipet Use : Liner Bot. Log Intvl2.: 9,026 Ft. (MD} Inspection Type : Sidetrack Candidate Tubing fnspection COMMENTS This Caliper data is tied into the Tubing Tai! @ 8,821 ft. (Drillers Depth). This log was run to assess the condition of the tubing and Liner with respect to corrosive and mechanical damages to determine potential side track candidacy. The caliper recordings indicate that the interval of 4.5" tubing logged is in good condition. No significant wall penetrations, areas of cross-sectional wall loss or ID restrictions are recorded in the interval logged. The caliper recordings indicate the interval of 7" Liner logged is in good to poor condition. The caliper recorded a 56% wall penetration in Joint 4 @ 9.019'. Areas of cross-sectional wall loss in excess of 20% are recorded in 3 of the 6 joints (including pups) logged. No significant I.D. restrictions are recorded in the interval of 7" liner logged. A 3-D log plot of the interval of 7" liner logged, as well as cross-sectional drawings of the most significant events are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. ' The joint numbering used in the 4.5"tubing in this report is an estimation based upon the average joint length. The damages recorded in Joints 2, 3 and 4 may be associated with perforated intervals. No wellbore _ information pertaining to perforated intervals was available at the time of this analysis. 4.5" TUBING -MAXIMUM RECORDED WALL PENETRATIONS ' No significant wall penetrations (< 8 %) are recorded throughout the interval logged 4.5" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (< 3 %) are recorded in the interval logged 4.5" TUBING -MAXIMUM RECORDED ID RESTRICTIONS No significant restrictions recorded in the interval logged ProActive Diagnostic Services, Inc. % P.O. Box 1369, Stafford, TX 73737 Phone: (281} or ($88} 565-9085 Fax: (281} 565-1363 E-mail: PDS@rnemorylog.com Prudhoe Bay Field Of#ice Phone: {307) 659-2307 Fax: {90t} 653-2317 • • 7" LINER -MAXIMUM RECORDED WALL PENETRATIONS Line Corrosion (56%) Jt. 4 @ 9,019 Ft. {MD) Line Corrosion (51 °l°) Jt. 3 @ 8,966 Ft. (MD) T' LINER -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS Possible Perf Interval (28%) Jt. 2 @ 8,933 Ft. {MD) Line Corrosion (25%) Jt. 3 @ 8,973 Ft. (MD) Line Corrosion (21 %) Jt. 4 @ 9,004 Ft. (MD) 7" LINER -MAXIMUM RECORDED ID RESTRICTIONS No significant ID restrictions are recorded throughout the interval logged. Field Engineer : N. Kesseru Analyst: J. Thompson Witness: ProActive Diagnostic Services, Jnc, ~ P.O. Box 1369, Stafftrrd, TX 77497 Phone: (2811 or {8138} 565-9085 Fax: (281} 565-1369 E-mail: PDSCa?memorylog.com Prudhoe Bay Field Office Phone: {907) 659-2307 Fax: ('907} 659-2314 ~ ~ • D Lo Plot F DS Multifinger Capper 3 g ~. .~ Company : CONOCOPHILLIPS ALASKA Field : Kuparuk River Unit Well : 1C-08 Date : July 25, 2004 Description : Detail of Caliper Recordings in 7" liner, below 4.5" tubing tail Joint 2 8920 (Poss. Perfs) 8930 7 I i ~ 8940 8950 8960 Joint 3 8970 8980 ~ I 8990 9000 1 Joint 4 90 0 9020 • • PDS Report Overview -~ s~ Body Region Analysis Well: 1 C-08 Survey Date: July 25, 2004 Field: KUPARUK Tool Type: MFC 40 No. 00432 Company: CONOCOPHILLIPS ALASKA INC Tool Size: 2.75 Country: USA No. of Fingers: 40 Analyst: J. Thorn son Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. power len. 4 5 ins 12 6 ppf L-80 3 958 ins 4.5 ins 1.2 ins 1.2 ins Penetration and Metal Loss (% wall) ~ penetration body metal loss body 20 10 -! .:._ 0 0 to "=~ 1 to ~ 10 to 20 to 40 to over 1 `%~ 10°/> 20`%. 40°/, 85`%~ 85% Number of joints analysed (total = 16) pene. 0 16 0 0 0 0 loss 13 3 0 0 0 0 Damage Configuration (body ) 10 Number of 'oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body .;.;~4 metal loss body 0 50 100 280 GLM 1 287 Bottom of Survey = 290.1 Analysis Overview page 2 0 isolated general line ring hole /pons pitting corrosion corrosion corrosion ible hole • PDS REPOR T OIN I ~ T TABULAT EET ON S Pipe: 4.5 in 12.6 ppf L-80 Well: 1C-08 Body Wall: 0.271 in Field: KUPARUK Upset Wall: 0.271 in Company: CONOCOPHILLIPS ALASKA INC Nominal LD.: 3.958 in Country: USA Survey Date: July 25, 2004 Joint No. )t. Depth ~ (Ft.) Pcn. l~l»ct Iln~.) Pen. Body (Ins.) Pen. % Metal Lc~tic ,~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 280 8394 0 0.01 4 3 3.89 281 8426 l1 0.01 5 1 3.94 282 8457 r) 0.01 5 2 3.93 283 8488 (i O.OI 4 1 3.91 284 8519 l) 0.01 5 1 "3.94 284.1 8550 U 0.02 8 0 3.90 PUP 284.2 8558 (~ 0 0 ~~ N A GLM Latch @ 4:00 284.3 8565 n 0.02 6 1 3.92 PUP ~ 285 8573 ~ ~ 0.01 4 1 3.92 285.1 8604 t) 0.02 7 1 3.92 PUP Dc osits. 285.2 8610 ~) 0 0 U N A __ PACKER 286 8648 i ~ 0.01 4 I 3.93 287 8679 n 0.01 3 1 3.94 288 8710 tl 0.01 4 ~' 3.90 289 8741 U 0.01 5 1 3.93 289.1 8773 i 1 0.01 4 0 3.93 PUP 289.2 8779 n 0 0 0 3.81 X NIPPLE 289.3 8782 ~) 0.01 5 1 3.92 PUP 290 8789 ~~ 0.02 6 1 3.93 290.1 8821 U 0 0 U N A TUBING TAIL ®Penetration Body Metal Loss Body Page 1 • • PDS Report Overview 1 s. Body Region Analysis Well: 1 C-08 Survey Date: July 25, 2004 Field: KUPARUK Tool Type: MFC 40 No. 00432 Company: CONOCOPHI LLiPS ALASKA INC Tool Size: 2.75 Country: USA No. of Fingers: 40 Analyst: J. Thompson Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 7 ins 26 f I.80 6.276 ins 7 ins 1.2 ins 1.2 ins Penetration and Metal Loss (% wall) ~ penetration body metal loss body 10 ~- O I ~i ~ 0 to E 1 to 10 to I ~ 20 to 40 to over 1% 10% 20% 40% 85% 85`%, Numb_ er ofLoints analysed Lotal = 6) pene. 1 2 0 0 3 0 loss 1 2 0 3 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole /pons pitting corrosion corrosion corrosion ible hole Number of 'oints darna ed total = 3 0 0 3 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 1 Bottom of Survey = 4 Analysis Overview page 2 • PDS REPOR T INT TABUL ATION ~ET JO Pipe: 7, in 26.0 ppf L-80 Well: l C-08 Body Wall: 0.362 in Fieid: KUPARUK Upset Wall: 0.362 in Company: CONOCOPHILLIPS ALASKA INC Nominal LD.: 6.276 in Country: USA Survey Date: July 25, 2004 Joint No. Jt. Depth (Ft.) F'~~n. lll~~c~t Ilm.j Pen. Body (Ins.) Pen. `% Metal L~~~~ ~~ Min. LD• (Ins.) ~ Comments Damage Profile (%wall) 0 50 100' 1 I - iie21 n 0.00 1 6.23 - - - I I ~ i 1.1 8867 _ I~ 0.01 4 ( 6.23 PUP ~ 1.2 8887 n 0.01 3 L 6.20 PUP ~ ~' 2 8907 a 0.29 79 >ti 6.18 Possible Perf Interval 3 8955 it 0.18 51 25 6.30 Line corrosion. I I 4 9002 i ~ 0.20 56 .' 1 6.21 Line Corrosion. - I I i Penetration Body Metal Loss Body Page 1 PDS Report Cross Sections ~ S ., Well: 1 C-OS Survey Date: July 25, 2004 Field: KUPARUK Tool Type: MFC 40 No. 00432 Company: CONOCOPHILLIPS ALASKA INC Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 7 ins 26 ppf L-80 Analyst: J. Thompson Cross Section for Joint 2 at depth 8933.02 ft Tool speed = 70 Nominal ID = 6.276 Nominal OD = 7 Tool deviation = 40 C: 28% Cross-sectional wall loss in a possible Perforation Interval Cross Sections page 1 ~ r ~ ~ ~ r ~ ~ ~ ~r ~ ~ ~ ~ ~ ~ ~ ~ ~ S PDS Report Cross Sections 1 Well: 1 C-08 Survey Date: July 25, 2004 Field: KUPARUK Tool Type: MFC 40 No. 00432 Company: CONOCOPHILLIPS ALASKA INC Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: _ _ 7 ins 26 ppf L"80 Analyst: J. Thompson Cross Section for Joint :3 at depth tiy73.U1 tt Tool speed = 70 Nominal ID = 6.276 Nominal OD = 7 Tool deviation = 42 ° • Cross Sections page 2 ALASKA OILAND GAS CONSERVATION ~MISSION 0 i"~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown ~ Stimulate __ Plugging Perforate Pull tubing X Alter casing Repair well X Other m 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development , Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1246' FNL, 668' FWL, Sec. 12, T11N, R10E, UM At top of productive interval 1062' FSL, 1130' FWL, Sec. 2, T11N, R10E, UM At effective depth At total depth 1406' FSL, 749' FWL, Sec. 2, T11N, R10E, UM 12. Present well condition summary Total Depth: measured 9 7 91 ' feet true vertical 7094' feet Plugs (measured) 6. Datum elevation (DF or KB) 94' RKB 7, Unit or Property name Kuparuk River Unit leer 8, Well number 1C-8 9. Permit number/approval number 81-52/90-0~ 10. APl number 5o-029-2058,5 11, Field/Pool Kuparuk River Oil Pool Effective depth: measured 9 6 8 2' feet true vertical 7015' feet Junk (measured) 9456' VANN GUN Casing Length Size Structural 8 0' 1 6" Conductor Surface 2 6 8 3' Intermediate Production 973 6' 7" Liner Perforation depth: measured 8743'-8751',8927' - true vertical 6292'-6298',6433' - Cemented 425 Sx AS II 10-3/4" 3125sxAS II 974 sx AS II 9012', 9018' 6498', 6502' MeasUred depth 111'md 2714'md 9767'md True vertical depth 111 'tvd 2586'tvd 7089'tvd - 9030', 9096' - 6512', 6562' - 9122' - 6582' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 TBG W/ TAIL @ 8808' Packers and SSSV (type and measured depth) Brown "HB" Pkr @ 8737', Baker PBR @ 8724', Camco 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) 'APR 2 4 1990 Treatment description including volumes used and final pressure ~.~.iJ & Gas. Cons. C~m~ Representative Dailv Averaae Produ~ion or Inaction Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector ~ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 05/17/89 Title Area Drilling Engineer SUBMIT IN DUPLICATE ARCO 011 and Gas Company Well History - Initial Report - Dali! Inetructione: Prepare and submit the "lMti.l I~l~d" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior tO sl:mddlng should be summarized on the form giving inclusive dates only. District ~CO ~M.J~SK~ INC. Field KUPARUK RIVER UNIT Auth. or W~l;~n~:)7 88 ICounty, parish or borough SLOPE COMPLETION Title ADL-' 25649 IState 1c,~ell no. RECEIVED APR 2 5 1990 Oil & Com , Comml lon Anchorage Operator ~RCO Spudded or W,O. begun ACCSPT Date and depth aa of 8:00 a.m, 03/11/90 (1) TD: 0 PB: 9682 SUPV: GB 03/12/90 ( TD: 0 PB:. 9682 SUPV:GB 03/13/90 ( TD: 0 PB: 9682 SUPV:GB 03/14/90 ( TD: 0 PB: 9682 SUPV:GB 4) 03/15/90 (5) TD: 0 PB: 9682 SUPV:GB JOate 03/11/90 The above/i.i.~co rrect Signat~,~ ~ For form preparatlop,~d distribution, ~ see Procedures Ma~u_~, Section 10, Drilling, Pages 86 an-d 87. Complete record for each d_ay reported NORDIC 1 IHour ARCO W.L 55, 8533 Prior status if a W.O. DISPLAC WELL TO 12.2 MUD 1~: .0.0 MOVE RIG FROM 1C-5 TO 1C-8, RU LINES, RU E-LINE UNIT, RIH W/ 2" PERF GUN, UNABLE TO GO BELOW 8808', PERF 8743-8751, POH, ASF, PRESSURE TBG TO VERIFY HOLES IN TBG - OK, RD E-LINE 'UNIT, PUMP 100 BBL WATER, FOLLOWED BY 12.2 PPG MUD DAILY:S46,513 CUM:$46,513 ETD~$46,513 EFC:$380,000 POH W/ COMPLETION ASSEMBLY' MW:12.2 LSND CONT DISPLACING WELL TO 12.2 PPG MIFD, WELL DEAD, SET BPV, ND TREE, NU BOPE, TEST BOPE TO 3000 PSI, PULL BPV, BOLDS, PULL TBG HGR, CIRC., POH (APPEARS PKR IS ATTACHED TO TBG), WELL SWABBING, POH SLOW DAILY:S28,651 CUM:$75,164 ETD:S75,164 EFC:$380,000 TIH W/RBP MW:12.2 LSND FINISH POOH W/3-1/2# TBG. STRAP OUT, CHANGE COLLARS AND LD COMP JEWELRY. RECOVER SBR AND FHL PACKER ASSY. RD TONGS, CLEAN UP FLOOR, UNLOAD ALL COMP JEWELRY OFF FLOOR. MU HOWCO REP AND TIH W/3-1/2" DP. LOAD AND TALLY 79 JTS DP IN PIPE SHED. DAILY:S32,937 . CUM:$108,101 ETD:SO EFC:$488,101 POH W/ REP MW:12.3 gel mud ..~:~i!!~NISH TIH W/ RBP. BREAK CIRC, SET RBP AND PRES TO 2000PSI, RELEASE AND RESET RBP AND PRES TO 2000PSI, TEST HEAD PIN, WELL FLOWING OUT DP, CIRC F/15 MIN PULL 3 DP, MU HOWCO RTTS/STORM VALVE, RIH W/2 STDS AND SET RTTS, TEST TO 500 PSI, TEST GOOD. POH 2 STDS. ND BOP STACK RU LINE AND BLEED GAS FROM 10-3/4"X7" ANNULUS. ND FMC WELLHEAD. PULL CSG PACKOFFAND INSTALL NEW PACKOFFANDFMC WELLHEAD. NU BOP STACK AND TEST, TEST GOOD. PU 2 STDS AND LATCH INTO RHS. TEST RAMS AND ANNULAR TO 3000 PSI. PULL RTTS/STORMVALVE AND LAYDOWN. TIH LATCH AND RELEASE RBP. POH AND LD DP DAILY:S28,147 CUM:$136,248 ETD:SO EFC:$516,248 RIH W/ COMP STRING MW:12.3 gel mud FINISH POOH W/HOWCO RBP & LD SAME. RU TO RUN COMP STRING. LOAD, STRAP & DRIFT COMP' JEWELRY. MU XO SUBS ON BAKER SOS, PACKER, & PBR. RIH W/ COMP STRING. WELL FLOWING OVER TBG, CIRC HEAVY MUD. CONT RIH, AT 29 STDS WELL FLOWING OVER AGAIN CBU. CONT RIH W/COMP, SET BROWN HB RET PKR F/2500 PSI, 60K PULL RELEASE, BAKER PBR PINNED F/ 30K PULL RELEASE. RUN GLMS AND CAMPCO TRDP SSSV. TEST C-LINE TO 5000 PSI. WITH TBG TAIL AT 7000' MUD FLOWING OVER TBG TOP. CIRC TBG VOLUME DOWN, STILL FLOWING, CIRC BTMS UP, STILL FLOWING~ MIX 60 BBLS TO 12.3 PPG AND PUMP DOWN. CONT RIH W/COMP STRING. D~ILY:~'~,'~7.. ...... .v.-..~'1"^,C74.~ ~-~---;v~ Number all daily well history forms consecutively as they are prepared for each well. jPage no. AR3B-459-1-D ARCO Oil and Gas Company Daily Well History-Final Report Inatr~,lctiona: Prepare and submit the "Final Rain, Il" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO ~ASKA INC. Field KUPARUK RIVER UNIT Auth. or W.O. no. AK4788 ICounty or Parish NORTH SLOPE Lease or Unit Title COMDLETTON cost center code no. Operator ARCO Spudded or W.O. begun ACCEPT Iotal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well I our ~Prtor status if a W.O. IA.R.Co. W.I. 55.8533 03/11/90 Date and depth as of 8:00 a.m. 03/16/90 (6) TD= 0 PB: 9692 SUPV: GB Complete record for each day reported NORDIC I RIG RELEASED MW: 12.3 gel mud RUN COMPLETION STRING, LAND TUBING, SET BPV, ND BOPE, TEST TREE,DISPLACE WELL TO DIESEL, TEST A~LUS, THAW ICE FROM TANKS,DISPLACE MUD,BLEED ANN. PRESSURE, CHECK CV CLEAN PITS AND CELLAR, RELEASE RIG AT 0100HRS,3/16/90. DAILY: $50,461 CUM: $230,135 ETD: $230,135 EFC: $380,000 RECEIVED Old TO I New TD I Released rig I Date I Classifications (oil, gas, etc.) Producing method Potential test data Naska 011 & Gas i;ons. ~almldstdolt PB Depth Kind of rig Type completion (single, dual, etc.) IOfficial reseeD r name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production oii~n test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Eifective date corrected __ The above/e~correct AR3B-459-3-C Number all daily well history forms consecutiv~ as they are prepared for each well. Division ARCO Oil and Gas Company Well History - Initial Report - Dail~ Inltn~tlenl: prepare and submit the "IMIIII ~ on the first Wednesday after a well is spudded or workover operations are started. Dally work prior to ~ddil~l::~d be lummarized on the form giving inclusive dates only. District ARCO A.~.SK~ II~:: Field KUP~I~UK I~:VER UNIT Auth. or ICounty. parish or ~,(~ugh Lc-- or unitRTHNO SLOPE COMPLETION Title ADL: 25649 IState Operator ~1)~CO Date 03/11/90 I ARCO W.I. IHour IPrior statue 1c.~ell no. 55.8533 Spudded or W.O. ~gun ACCEPT if a W.O. Date and de~h as of 8:~ a.m. 03/11/90 (1) TD: 0 PB: 9682 SUPV:GB 03/12/90 (2) TD: 0 PB: 9682 SUPV:GB 03/13/90 (3) TD: 0 PB: 9682 SUPV:GB 03/14/90 (4) TD: 0 ::~ PB: 9682 SUPV:GB 03/15/90 (5) · D= 0 PB: 9682 SUPV: GB Complete record for ea(:h d_ay reported NORDIC 1 DISPLAC WELL TO 12.2 MUD MW: .0.0 MOVE RIG FROM 1C-5 TO 1C-8, RU LINES, RU E,LINE UNIT, RIH W/ 2" PERF GUN, UNABLE TO GO BELOW 8808', PERF 8743-8751, POH, ASF, PRESSURE TBG TO VERIFY HOLES IN TBG - OK, RD E-LINE UNIT, PUMP 100 BBL WATER, FOLLOWED ~Y 12.2 PPG MUD DAILY:S46,513 CUM:$46,513 ETD:S46,513 EFC:$380,000 POH W/ COMPLETION ASSEMBLY MW:12.2 LSND CONT DISPLACING WELL TO 12.2 PPG MUD, WELL DEAD, SET BPV, ND TREE, NU BOPE, TEST BOPE TO 3000 PSI, PULL BPV, BOLDS, PULL TBG HGR, CIRC., POH (APPEARS PKR IS ATTACHED TO TBG), WELL SWABBING, POH SLOW DAILY:S28,651 CUM:$75,164 ETD:S75,164 EFC:$380,000 TIH W/REP MW: 12.2 LSND FINISH POOH W/3-1/2" TBG. STRAP OUT, CHANGE COLLARS AND LD COMP JEWELRY. RECOVER SBR AND FHL PACKER ASSY. RD TONGS, CLEAN UP FLOOR, UNLOAD ALL COMP JEWELRY OFF FLOOR. MU HOWCO RBP AND TIH W/3-1/2" DP. LOAD AND TALLY 79 JTS DP IN PIPE SHED. DAILY: $32,937 CUM: $108,101 ETD:SO EFC: $488,101 MW:12.3 gel mud W/ REP. BREAK CIRC, SET RBP AND PRES TO 2000PSI, AND RESET RBP AND PRES TO 2000PSI, TEST PIN, WELL FLOWING OUT DP, CIRC F/15 MIN PULL 3 MU HOWCO RTTS/STOP~MVALVE, RIH W/2 STDS AND SET TO 500 PSI, TEST 'GOOD. POH 2 STDS. ND BOP STACK RU LINE AND BLEED GAS FROM 10-3/4"X7" ANNULUS. ND FMC WELLHEAD. PULL CSG PACKOFF AND INSTALL NEW PACKOFF AND FMC WELLHEAD. NU BOP STACK AND TEST, TEST GOOD. PU 2 STDS AND LATCH INTO RHS. TEST RAMS AND ANNULAR TO 3000 PSI. PULL RTTS/STORMVALVE AND LAYDOWN. TIH LATCH AND RELEASE REP. POH AND LDDP DAILY:S28,147 CUM:$136,248 ETD:SO EFC:$516,248 · The above ~cormct Stgnatu~ J ~ ~= Dat~/~ / I Title ~ ~ - - ~ orm preparatlo~ d~tflbutlon, RIH W/ COMP STRING MW:12.3 gel mud FINISH POOH W/HOWCO REP & LD SAME. RU TO RUN COMP STRING. LOAD, STRAP & DRIFT COMP JEWELRY. MU XO SUBS ON BAKER SOS, PACKER, & PBR. RIH W/ COMP STRING. WELL FLOWING OVER TBG, CIRC HEAVY MUD. CONT RIH, AT 29 STDS WELL FLOWING OVER AGAIN CBU. CONT RIH W/COMP, SET BROWN HB RET PKR F/2500 PSI, 60K PULL RELEASE, BAKER PBR PINNED F/ 30K PULL RELEASE. RUN GLMS AND CAMPCO TRDP SSSV. TEST C-LINE TO 5000 PSI. WITH TBG TAIL AT 7000' MUD FLOWING OVER TBG TOP. CIRC TBG VOLUME DOWN, STILL FLOWING, CIRC BTMS UP, STILL FLOWING, MIX 60 BBLS ~ 12.3 PPG AND PUMP DOWN. CONT RIH W/COMP STRING. INumber all dally well history forms consecutively as they are prepared for each well. iPage no. AR3B-459-1-D ARCO Oil and Gas Company Daily Well History-Final Reporl Instructions: Prepare and submit the "Fiaal Reflort" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted al~o when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO ~?,a. SKA INC. Field KUPARUK RIVER UNIT Auth. or W.O. no. AR4788 I County or Parish NORTH Lease or Unit T,t~e COHPL~TION I Accounting State cost center code IWell no. 1F-8 Operator ~O Iotal number of wells (active or inactive) on this Dst center prior to plugging and ~ bandonment of this well I our ] Prior status if a W.O. Spudded or W.O, begun IA.R.Co. W.I. 55.8533 IDate 03/11/90 6) Complete record for each day reported ACC_~PT Date and depth as of 8:00 a.m. Old TD NORDIC I RIG RELEASED MW:12.3 gel mud RUN COMPLETION STRING, LAND TUBING, SET BPV, ND BOPE,TEST TREE,DISPLACE WELL TO DIESEL, TEST Ab'NULUS, THAW ICE FROM TANKS,DISPLACEMUD, BLEED ANN. PRESSURE, CHECK CVCLEAN PITS AND CELLAR, RELEASE RIG AT 0100HRS,3/16/90. DAILY:S50,461 CUM:$230,135 ETD:S230,135 EFC:$380,0~0 Released rig 03/16/90 ( TI): 0 PB: 9662 SUPV: GB Classifications (oil, gas, etc,) Producing method Potential test data New TD Date RECEIVED APR 2 5 1990 ~ & 6a~ Coa~ Commi~m~m IPB Depth Kind of rig Type completion (single, dual, etc.) IOfficial reservo r name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above/levco rrect For form preparation ~d~di;tribution, see Procedures Manu~, Section 10, Drilling, Pages 86 and ~'. AR3B-459-3-C Number all daily well history forms consecutively las they are prepared for each we . iPage no. Olvl~lo~ of AffantlcRIchfleldCompan, 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ 2. Name of Operator APPLICATION FOR SUNDRY APPROVAL X Plugging Pull tubing ~ 5. Type of Well: Development Exploratory Stratigraphic Service ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1246' FNL, 668' FWL, Sec. 12, T11N, R10E, UM At top of productive interval 1062' FSL, 1130' FWL, Sec. 2, T11N, R10E, UM At effective depth At total depth 1406' FSL, 749' FWL, Sec. 2, T11N, R10E, UM Operation Shutdown _ Re-enter suspended well _ Time extension Stimulate Variance Perforate Other 6. Datum elevation (DF or KB) 9791 feet Plugs (measured) 7094' feet 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured 7682' feet Junk (measured) true vertical 701 5' feet Casing Length Size Cemented Structural COnductor 8 0' 1 6" 425 Sx AS II Surface 271 4' 1 0-3/4" 3125 Sx ASII Intermediate Production 9767' 7" 974 Sx ASII Liner Perforation depth: measured 8927'-901 2', 901 8'-9030', 9096'-9122' true vertical 6433'-6498', 650'2'-6512', 6562'-6582' 94' RKB 7. Unit or Property name Kuparuk River Unit 15. 8. Well number 1C-8 Tubing (size, grade, and measured depth 3-1/2", 9.3#, K-55 tbg w/ tail @ 8898' Packers and SSSV (type and measured depth) Baker FHL pkr @ 8824', Camco TRDP SSSV @ 1821' 13. Attachments Description summary of proposal X proposed workover will replace leaking packer. 14. Estimated date for commencing operation March 1990 16. If proposal was verbally approved 9. Permit number 81-52 feet 10. APl number 5o-029-20585 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool None None Measured depth 80' 2714' 9767' Detailed operation program_ True vertical depth 80' 2586' 7089' ,, , BOP sketch X Status of well classification as: Oil X Gas __ Name of approver Date approved S e r vi ce 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. :~: ~ FOR ~MMISS~N USE ONLY Commissioner Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test_ Location clearance ~ Mechanical Integrity Test Subsequent form reouire -- ORIGINAL SIGNED Approved by the order of the Commission Suspended Date Date Form 10-403 Rev 06/15/88 Approvec~ Copy Returned SUBMIT IN TRIPLICATE KUPARUK RIVER UNIT 1C-8 Workover Procedure SUMMARY Kuparuk Well 1C-8 will be worked over to replace a leaking retrievable packer. The well is normally shut-in due to a high GOR and the leaking packer is causing high shut-in pressures on the 7" annulus as well as the tubing. The proposed workover will replace the packer, install AB modified tubing couplings, and upgrade the wellhead from 3000 psi to 5000 psi. This will return the well to a safe condition and provide more certain tubing integrity in the high pressure gas environment. pROCEDURE 1. . . . . . . . . 10. . 10. 11. 12. MIRU Nordic #1. Displace tubing and annulus with 12.0 ppg mud. Set BPV, ND tree, NU BOPs. Pull BPV and test BOPs. Pull 3-1/2" tubing. Changeout couplings to AB modified. RIH with drill pipe and retrieve Baker FHL packer at 8824' and tail pipe. RIH with single completion assembly same as before with new packer and AB couplings. Before RIH with SSSV, make-up storm packer on tubing and run in well. Set packer to hang-off tubing string below wellhead. Pressure test storm packer. ND BOPs and changeout wellhead to 5000 psi. NU BOPS and pull storm packer. Continue running SSSV and remainder of tubing string. Set packer. Shear SBR. Pressure test annulus and tubing. ND BOPs, NU tree. Set BPV. RD, release rig. Pull BPV. Reverse circulate diesel to displace mud out of annulus and tubing above circulating valve in bottom GLM. 1 3. Flow well to tank to clean-up remaining mud below CV in bottom GLM. 15000 PSI BOP ST CK 4 1 C-8 1. 10-3/4" CASING HEAD 11" -3000 PSI FLANGE 2. TUBING HEAD 11" - 3000 PSI X 7 1/6" - 3000 PSI 3. CROSSOVER SPOOL 7 1/6" - 5000 PSI X 11" - 5000 PSI 4. 11" 5000 PSI BLIND RAMS 5. 11" - 5000 PSI PIPE RAMS 6. 11" - 5000 PSI ANNULAR 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 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 FILL BOP STACK AND MANIFOLD WITH BRINE. 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. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 6. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 7. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 8. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. 9. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 1 0. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITION. 1 1 . TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. 14. SIGN AND SEND TO DRILLING SUPERVISOR. 1 5. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NORDIC SRE 9/89 KUPARUK WELL 1C-08 ORIGINAL P, KB: CASING ind TUmNG OETHL.$ M4 H~O lO LINER DETNLS WEIGHT ~ TOP BTId TUBINQ aEWELRY 2.76' 1141 NSC. OATA UAX HOLE ANGLE: 17 dle .oLE MO,.ET~nu KUP:. ~0 cm LAST TA~ 0A~: ' I~TNM.I: it ~I. IK)eS'TRUI~'I1ON: ~ VANN GUN 221.trLONQ pm1): ~ I tl L OAS UFT and FLOW INFORMATION VALVE STN oEpm MANOFEL SIZE 1411 CAN(X) 1' ~ CAMCO 1' 7114 C, NdOC) 1' 171~ ~ I' PERFORATION DATA INTERVAL ZONE FT SPF PHASE 6g~7.601~ 0 M 4 k REVISION DATE: REASON: 06/2M35 I:K~RT SIZE DV DV COIMt, IF. NT ARCO Alaska, Inc. Date: November 13, 1989 Transmittal #: 7603 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File CLerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1C-08 Kuparuk Fluid Level Report 1 1 - 4- 8 9 Casing, Tubing 3A-03 Kuparuk Fluid Level Report 1 1 - 3- 8 9 Tubing !.~::~,O8 Kuparuk Fluid Level Report 1 1 - 2- 8 9 Tubing ,~1 ¢~08 Kuparuk Fluid Level Report 1 1 - 2- 8 9 Casing 3 C- 1 4 Kuparuk Fluid Level Report 1 1 - 5 - 8 9 Tubing Receipt Acknowledged: DISTRIBUTION: BP Chevron Naslm Oil & Gas Cons. ........... nclioraflo D&M Mobil $~te Of Alaska Unocal KUPARUK FLUID LEVEL REPORT CC: DS Engr. .NSK Files sssv - GLM DV or GLy 7'/'/~ Fluid Level Shot Down: /'""~Casing Tubing CSG Press During Shot=-~~#C,~ TBG Press During Shot Reason For Shooting FL: To Determine Operating Valve · Well Status: On Continuous GL .Operating CSG Press GL Rate (if 'Available) On Intermittent GL # MCFD On Time=___._ Min. · Off Time = Hr. Min. · Delta Time From End Of On Cycle= No GL Comments: Min. NSK Files Prod. Foreman .--/.~ SSSV~ GLM DV or GLV KUPARUK FLUID LEVEL REPORT Fluid Level Shot Down: ~~TCuasing bing CSG Press During Shot = .... # TBG Press During Shot = ~/~ Reason For Shooting FL: To Determine Opprating Valve . ~.'. T~ ~ Y~ '~'/I Well Status: On Continuous GL Operating CSG Press = ~ # GL Rate (If Available) MCFD On Intermittent GL On Time=~ Min. Off Time = Hr. Min. Delta Time From End Of On Cycle f.,,~No GL Min. Comments: ECEIVED Nov ! ~ 1~ Alaska .Oil & Gas Cons. Anchorage CC: DS Engr. NSK Files Prod. Foreman SSSV~ GLM DV or GLV KUPARUK FLUID LEVEL REPORT Well /~-'d~ Fluid Leve~ Shot Down: J Casing ,,/ Tubing CSG Press During Shot= ,~060 # TBG Press Dudng Shot= I ~g~) # Reason For Shooting FL: To Determine Operating Valve Well Status: Found ~/;,~ 7 Ft COmments: On Continuous GL Operating CSG Press = ~ # GL Rate (If Available)= On Intermittent GL on Time=~ Min. Off Time = Hr. Min. Delta Time From End Of On Cycle MCFD RECEIVED NOV :t ]9119 Alaska 0il & Gas Cons. Commlssio. t~ Anchorage Min. No GL ARCO Alaska, Inc. Date: August 19, 1988 Transmittal #: 7264 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge-receipt and return one signed copy of this transmittal. 1 G- 1 4 Kuparuk Well Pressure Report 8 - 0 8 - 8 8 Amerada 3 H - 1 4 Kuparuk Fluid Level Report 8 - 1 2 - 8 8 Casing 1 G-07 Kuparuk Fluid Level Report 8 - 1 3- 8 8 Tubing 1R- 1 5 , Kuparuk Fluid Level Report 8 - 1 3 - 8 8 Tubing 1 C-08 Kuparuk Fluid Level Report 8 - 1 2 - 8 8 Tubing Receipt Acknowledged: ........................... Date' - ........... DISTRIBUTION: D&M State of Alaska Unocal SAPC Chevron Mobil ARCO Alaska, Inc. Date: August 5, 1988 Transmittal #: 7249 RETURNTO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. '~ 31-03 Kuparuk Sti.mulation Summary 7-29-88 #230DS361L *~ 1A-10 Kuparuk Stimulation Summary 7-27-88 #230DS10AL ~ 3 C- 08 Kuparuk Fluid Level Report 8,01 - 8 8 Tubing .1 G-06 Kuparuk Fluid Level Report 8- 01 - 8 8 Tubing ~' 3 K- 06 Kuparuk Fluid Level Report 8 - 01 - 8 8 Tubing ', 2 W- 05 Kuparuk Fluid Level Report 8 - 0 2 - 8 8 Tubing ,~ 1 C-08 Kuapruk Fluid Level Report 8- 0 2- 8 8 Casing 3 K- 13 Kuparuk Well Pressure Report 4- 1 8- 8 8 Amerada Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska ., SAPC Mobil Chevron ATTACHMENT II Drill Site lA Wel 1 No. 1A-4 1A-5 1A-7 lA-9 1A-11 1A-12 1A-14 1A-15 1A-16A KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Lo9 Date Drill Site Well No. Lo9 Date 7/6/83 10/29/83 2/8/82 5/7/82 1/25/82 3/23/83 1/19/83 3/21/83 3/8/82 4/1/82 6/5/82 5/11/82 6/8/82 lB 1B-1 12/26/81 1B-2 6/25/81 1B-3 11/16-18/81 3/12/82 1B-6 11/18/81 9/10/82 1B-7 11/23/81 1B-8 12/28/81 8/4/82 1B-9 6/24/82 8/3/84 Drill Site lC Wel 1 ~ No. 1C-1 1C-2 1C-3 1C-4 1C-5 1C-6 1C-7 lC-8" Lo9 Date 5/9/81 518181 7/13/81 11/8/81 3/9/81 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site Well No. Lo9 Date 1D 1D-1 ~ 1/80 5/23/83 1D-3 8/5/80 1D-4 7/30/80 8/13/80 1D-5 6/11/81 1D-6 6/9/81 tD-7 6/8/81 ~...~1D-8 (WS-$) 5/i0/78 Oil & C~ Co:,s ....... Attachment Page 2 Drill Site 1H Drill Site lq Well No. 1H-3 1H-4 1H-6 1H-7 1H-8 Well No. LOglDate 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Log Date Drill Site 1E Wel 1 No. 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 Lo9 Date 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/'27/81 !0/21/81 11/12/82 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 1G Well No. 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 Log Date Drill Site Well No. Log Date 9/7/82 1F 1F-1 9/25/82 1F-2 9/28/82' 1F-3 12/8/84 1F-4 10/13/82 1F-5 11/12/82 1F-6 3/12/83 1F-7 ,,9 C.Bi V4:D Alaska Oil & Gas ~n,s. aommi:z:; Anct~)rage 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 10/28/82 11/19/82 5/7/83 Attachment Page 3' Drill Site Well No. Logo Date 1Y 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 ~6/18/83 1¥-4 7/2/83 1¥-5 6/2~/83 ~¥-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 ~IY.~ 5110183 ~ 11/21/83 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. Lo9 Date 2Z- ~.Z~_ 7/10/83 2Z-2 ': 6/24/83 7/19/83 2Z-3 ' 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 Drill Site Well No. Log Date 2C 2C-4 2/19/85 2/28/85 2C-7 10/15/84 VLF-pg-O052 Oil & Gas Cons. Anchora?: Drill Site lA Wel 1 No. "1A-4 "~1A-5 'X, lA_7 ~IA-9 ~1A-11 '~1A-12 '~1A-14 '~1A-15 ',,1A-16A ATTACHMENT II KUPARUK RIVER UNIT Production Logs L°g Date 7/6/83 10/29/83 2/8/82~x, / 5/7/82// 1/25/82~-~.'-- 3/23/83,, ~ 1/19/83"). '--"- 3/21/83 ," ;' 3/8/82 4/1/82 6/5/82 5/11/82,~ ~ ~- 6/8/82/ ~ Drill Site Well No. Log Date "'18-1 12/26/81 ~18-2 6/25/81 '~18-3 11/16-18/81"-~ '~ 3/12/82 '-18-6 11/18/81~ ',~ 9/10/82/ ~. ~18-7 11/23/81 '~IB-B 12/28/81~. ~ 8/4/82 ~18-9 6/24/82 ~ 8/3/84 18 Drill Site 1C Well No. \ "~1C-1 '~1C-3 "~1C-4 ~IC-5 '~1C-6 "~1C-7 '~ lC-8 · Log'Date 5/9/81 5/8/81 7/13/81 11/8/81> 3/9/81/ 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site Well No. Log Date 1D '~1D-1 ~ 5/23/83 "~1D-3 8/5/80 1D-4 ~7/30/80~ ~ 8/13/80/ ~ ~lD-5 6/11/81 ~1D-6 6/9/81 '~1D-7 6/8/81 XJlD-8 (WS-8) 5/10/78 RECEIVED FEB ~ 1 198Ei 011 & l~s ~ns. ~mmimlon Anchorag~ ARCO Alaska, Inc. ~ej~' Post Office BI_-- ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ETUi~N TO: ARCO ALASKA, iNC. KU:~..~uK OPEKATiONS ENGINEERING RECO.~£ CLERK ATO-!ilSB P.O. bOX 100360 Ai~ChO'.~/aGE, AK 99510 ~ .,, ...... 'r TTED . -~-,..~.:~m~-:.,. NE~L%~iTH AR-.': '."kiL FOLLO%.JiNG iTLiiqS PLLAS-'~ ACKHO;~LEDGE __ l'.,~-Ur~ ONIJ SICi~LD COPY OF ~':iS _RAr~S~.aI~A~.. EQULNCE OF EVEN%~--.~ 51-ii .'A~S~Z'~D. ~RE55URE BUILD-UP 08-24-85 ~.~c,u~, ,~.=~ _.~=~u~E R~PoR= ~.',V=LO.~ ~..~ .... -~,_ COPY OF EACH ~0-28-8~ o~.=~ .a SANw Ou!S ~-lU 09-0S-85 STATIC 'A' ShReD '~'~e~'' z,-~. '08-28-85 PBU 'A' SAND OTiS ~--!2 09-04-85 .... 'C' E~D CAi~CO , F-D 08-17-85 PBU '~' SAND BAKER/LYNES F-5 08-!7-~5 PBU 'C' S~ND B~KER/LYNES Y-5 08-17-85 PBU :A&C: SAND B~iKER/LYNES 2EiPT ': '':"' ' ~CKA U:: .',mu G,". u: ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldComoanv Transmitted herewith are the follc~ing: PI~SE NCTE: BL - BI/I~.rNE, S - SEPIA,. F - F~M, T - TAPE, PC - PHUiIXI)PY ARCO Alaska, Inc.[~,~ Post Office BO~x ,J60 Anchorage, Alaska 99510 Telephone 907 277 5637 March 12, 1952 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Re' Subsequent Notice - Kuparuk 1C-8 Stimulation Gentlemen' Attached are the subsequent Sundry and acid treatment performed on Kuparuk River Field. No'tices for a Mudban Well 1C-8 in the Sincerely, Laura K. Blacker OO~"~' Senior Operations Engineer , slz Attachments cc' E. A. Simonsen AFA-311 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~3 2. Name of Operator 7. Permit No. Arco Alaska, Inc. 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 50- 029-20585-00 OTHER [] 4. Location of Well SL 1246' FNL, 668' FWL, Sec 12, TllN, R10E BHL 1411' FSL, 909' FWL, Sec 2, TllN, RiOE 9. Unit or Lease Name KuParuk 25650 10. Well Number 1C-8 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. _ RKB = 94' ADL 25650 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation I~ Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On November 17 and 18, 1981, Kuparuk Well 1C-8 was stimulated in the Upper and Middle Kuparuk Sands with a mud dispersant, and then with 12% HC1. A coiled tubing unit was used to squeeze 3000 gallons of 2% Dowell Mudban mud dispersant in diesel into the perforated intervals 8927--9012', 9018-9030', 9096-9122'. Diesel was circulated with N2 to displace the Mudban and underbalance the wellbore and help it flow. After the flow period in which no rates were measured, the CTU was used to squeeze 4326 gallons of 12% HC1 with mud and silt remover into the perforations. Nitrogen was again used to displace and underbalance the wellbore. The well was flow tested for 7.25 hours at an average oil rate of 738 BPD and a gas rate of 270 MC.FD. All circulated and produced fluids were flowed to stock tanks and then delivered to a waste disposal well. RECEIVEi) MAR 1 7 ]982 Al3s~ Oil & Gas Cons. Commissi, Anchorage 14. I hereby certify that thug is tru~ %nd correct to the best of mY knowledge. Signed Title Area Operat~mn.~ ~.nS~nmmr The space {~l)ow'for-Co~nmis;ion use,f -- Conditions ~ Approval, if any: Date By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ' STATE OF ALASKA ALAS AND GAS CONSERVATION C(~...,,,IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ' ' 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-52 3. Address 8. APl Number P.0.Box 360, Anchora.qe, AK 99510 50- 029-20585 4. Location of well at surface 12/+6 ' FNL, 668 ' FWL, Sec 12, T11N, R10E ~ UM 9. Unit or Lease Name Kuparuk 256/+9 At mop Producing lnterval 1062'FSL, 11~0'FWL, Sec 2, T11N, R10E, UM 10. WellNumber 1C-8 At Total Depth ,1Aff~'FSL, 2-~I~FWL, .Sec 2, T11N, R10E, UM 11. Field and Pool 1~/~3 ~',,~7 Kuparuk River FieId 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 9/+' RKB ADL 256/+9 Kuparuk River 0il Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 4/21/81 5/7/81 5/16/81I -- feetMSLI 1 · 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey i 20. Depth where SSSV set 21. Thickness of Permafros't 9791 ' ql~ 9682' ~;~)'1~"?~;~1 YES ~X NO []I 1820 feet MD 1650' (approx.) 22. Type Electric or,Other Logs Run DIL/SP/BHCS/GR, CBL/VDL/GR/CCL, FDC/CNL/NGT/CAL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-40 Surf 80' 36" 42S _~x AR TT . · 10 3//+" /+5.55 K-55 S. rf 271/+' 13 t/4 t175 _~w Ag TT 7" 26tf K-55 Surf 9797' 8 'B/g,, 97a'.sx .AS II 24. PerforatiOns open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) ' SIZEI DEPTH SET (MD) PACKER SET (MD) 8927'-9012' w//+ SPF 3 1/2" 8898' 882~.' ., 9018 ' -9030' 9096 ' -9122' 26. ACI D, FRACTURE, CEMENT SQUEEZE, ETC. . . DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED · ' ' ' ~' ' ' I :' r ' Perf Interva! ~7! bb! Mudban !0a. bb! !2% HC! w/MSR · . / 27. PRoDUCTiON TEST ....... Date Firsl~.Production .. . ~ (Flowing, gas lift,.etc.) · Method o,f.Operation .., .. · ,.. 12/16/81 I F~LoWing ~ - : , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-MCF wATER::BB[_ cHOKE sIZE 'GAS-OIL RATIO ' 5/22/81. 10.0· TEST PERIOD !~ .. 17;~ ~ 63: FloW Tubing Casing Pressure· CALCULATED, OIL-BBL GAs-M~cF W~,-~ERiBBL C)~ ~G'~;~VITY-API'~,.o'~'r) . 'Press.120 __ ,. ,. 24.HOUR RATE I~ ./+1.3 ' ,, 15i ' ,_ . 1'i9',5 .'~ , . ,.,. 28. CORE DATA , . ~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit cO~e chips. , "-' ~-' MAR 1 5 1982. " : .~mlm.oi~ & ~s co~ Co~t~ Form 10-407 Submit in·duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ..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 Kuparuk River Form. 8879' 6396' Base Kuparuk River Form. 9439' 6828' 31. LIST OF ATTACHMENTS .............................. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .... Title Area OPs. Engr. Date _ ('1' ~' ...... 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 fQr separate production from more than one interval (multip!.~ 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 TRAi!_SMITTAL" J. J. Pawelek/Ann Simonsen DATE- //~1-,/,1'-~/ WELL,,~,.,;"~"~' . Trans,m, irted herewith arc. the follcwing' PLEASE ,,Ol~' BL - BLL' LIthE, S - SEP!.-., ! F - FILM, T- TAP~ ~ F:,EC~: ?T ~,~... , ,:~.r,, :OWl_ Ef),2i{ .,,,. / ' t.~q~-Z_' DATE' RECEIVED 0(;!- 1 6 1~81 Alaska Oil & Gas Cons. Commission Anchorage ARCO AlaSka, Inc~~ Post Office~L · ..~60 Anchorage. Alaska 99510 Telephone 907 277 5637 October 1, 1981 Mr. William VanAlen "State of Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99504 Attached is well test information for Wells A-i, A-2, B-2, C-l, C-2, C-7,~ The test results were obtained subsequent to the completion of the Well Completion Report (Form 1-407) or Sundry notice (Form 10-403) which was submitted to you. ineer EAS/bl Attachments ARCO Alaska. Inc~ is a Subs~d~,~ry o~ AtlanticRicr~fieidCompany RECEIVED OCT ]98] Oil & Oas Cons. A~Chorage Commission STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1. ,DR, ILLING WELL ~ CO%tPLETED WELL L~ 2. Name of Operator 7. Permit No. ' ARCO Alaska, Inc. 81-52 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 50-029-20585 4. Location of Well 9. Unit or Lease Name 1246' FNL, 668' FWL, Sec 12, TllN, R10E 5. Elevation in feet {indicate KB, DF, etc.) KB = 94' 6. Lease Designation and Serial No. Kuparuk 25649 10. Well Number C-8 OTHER 11. Field and Pool Kuparuk River Field Kuparuk River Oil~Pool ADL 25650 ' . Chec~ Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [~ Abandon [] Stimulation [] Abandonment [] RepairV,,'ell ~ ' Change Plans [] Repairs Made [] Other [] Pull Tubing ,r-q Other ~ Pulling Tubing [] (Note: Reoort multiple completions on Form 10-407 with a submitted Form 10-407 for each comp4-etion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.10.5-170). ARCO Alaska, Inc. proposes to cleanout perforations in cased well C-8. The work will be done using a coiled tubing unit with BOP assembly tested to 4000 psi. A 3000'Psi lubricator will be used for all wire- line work. Ail circulated and flowed fluids will be diverted to tanks on location. The well will be tested subsequent to the cleanout. The expected starting date is 10-25-81. RECEIVED OCT 6 t St Alaska Oil & Gas Cons, Commission Anchorage 14. I hereby certif, y that the foregoing ~s true and correct to the best of my knowledge. ~ n c' '~ Title Operations Area Engineer Date 8-27-81 big e] V",.. ~J · The so-ac~ for Commmsion useJ / ~~,,1 ~, '~,,",~ E~ ~t~.~: ,~' .' October 9, 1981 · Mr. Po A. VanDusen District Drilling Engineer ARCO Alaska, Inc. P. O. Eox 360 Anchorage, Alaska 9~510 Dear Mr. VanDusen~. We have recently received ccmpletion reports on several wells where the reported bottom hole location cannot be verified by the directional surveys that have also }~en submitted. The list of the wells in question is enclosed. We would appreciate your checking to determine the data used in arriving at the bottom hole locations for these wells. Since w~ have an internal progran to cross-check the accuracy of the submitted data, it is necessary to det~mine why the discre- pancies exist. If you could have a member of the department that determines this data call Mrs. Elaine Johnson at 279-1433 it should pin- point where and why there are differences. Thank you for your help in this m~t'ter. Yours very truly, Har~y W. Kugler Commi ssioner Enclosure ~K:be P. A. Van Dusen~ ' ",eptember 2, i981 Incomplete Completion Reports Well Name and Number Comp 1 e t i on / Aba ndo nme nt Suspension Date Prudhoe Bay Unit DS 16-1 Prudhoe Bay Unit DS 14-9A Prudhoe Bay Unit DS 16-4 West Sak 18 Unit DS 16-5 Prudhoe-~y Unit DS 14-19 Prudhoe Bay Unit DS 17-7 Prudhoe Bay Unit DS 14-20 Prudhoe Bay Unit DS 12-11 Kuparuk A-2 Prudhoe Bay Unit DS 17-8 1-9-81 3-21-81 3-27-81 4-17-81 4-21-81 5-15-81 6-6-81 6-10-81 6-30-81 7-1-81 7-2-81 7-2-81 Overdue (?) Completion Reports Prudhoe Bay Unit DS 16-14 Kuparuk B-4 Kuparuk A-3 Prudhoe Bay Unit DS 17-9 Prudhoe Bay Unit DS 12-12 7-9-81 7-14-81 7-24-81 7-25-81 7-26-81 ARCO Alaska, Inc.~~' Post Office Anchorage, Alaska 99510 Telephone 907 277 5637 September 28, 1981 Mr. Harry Kugl~r State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 12-11 DS 16-4 ~/est Sak #18 DS 12-12 DS 16-5 A-2 DS 14-9A DS 16-14 A-3 DS 14-19 DS 17-7 B-4 DS 14-20 DS 17-8 C-8 DS 16-1 DS 17-9 Dear Sir: Enclosed please find the Completion Reports for the following wells: A-2, A-3, B-4 and C-8. Although these Kuparuk wells have been per- forated, production test data has not been obtained; this information will be forwarded to your office when available. Also enclosed are Completion Reports for the following wells: DS 12-12, DS 14-19, DS 14-20, DS 16-4, DS 16-5, DS 17-7, DS 17-8 and DS 17-9. Production test information is not applicable for these wells since they have not yet been perforated but will be submitted to your office when we obtain the information. Previously unreported information such as locations for bottom hole, producing interval and geological forma- tions have been added to the updated Completion Reports. DS 14-9A and West Sak #18 have been plugged and abandoned. An updated Completion Report with Drilling Histories for these wells is enclosed. Information regarding West Sak #18 is of a confidential nature and we would appreciate securely storing the report where it will receive minimum exposure. The initial Gyroscopic Survey for DS 16-1 was unacceptable and a rerun is presently being authorized by our engineering staff. An updated Completion Report for this well will be sent to your office subsequent to our receiving an acceptable survey. The remainder of the requested information - an overdue Completion Report on DS 16-14 and an incomplete Completion Report for DS 12-11 was sent to your office August. 27, 1981 and was apparently enroute at the time of your September 2, 1981 letter to this department. Also included are completion Gyroscopic SurveYs for DS 12-12, DS 17-7 and DS 17-9. sincerely, SEP 3 0 1981 0il & Gas Cons. Commiss)'or~ Anchorag~ ALASKA OIL AND GAS CONSERVATION COMMISSION !'~LL LOCATIO~ DISCREPANCIES Kuparuk 25647 Kuparuk 25648 Kuparuk 25649 A-2 The following are all in the Prudhoe Bay Unit: DS 12-12 DS 14-11 DS 14-19 DS 14-20 DS 16-4 DS 16-5 DS 17-7 DS 17-8 DS 17-9 ", ' .... STATE OF ALASKA ALASI~ ,"/IL AND GAS CONSERVATION ~],,,,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL] I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit · ARCO Alaska, Inc. 3. Address 8. APl (~b_e~0585 P.O. Box 360 Anchorage, AK 99510 5o- 4. Location of well at surface 9. Unit or Lease Name ' - KUparuk 25649 1246' FNL, 668' FWL, Sec 12, T11N, R10E, UM ~-~i~N~r~ At Top Producing Interval VERIFIED i . 10. Well Number 1062' FSL & 1130' FWL, Sec 2, T11N, R10E, UN S~-r.f..E .' C-8 At Total Depth l~,~ IFS/.- ~- ~'~8 IF~,O~, j B. PI. ~ 1 1. Field and Pool 1406; FSL &~ FWL, Sec 2, T11N, R10E, UM · Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. Kuparuk River 0i ] Po01 94' RKBI ADL 25649. 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 4/21/81 5/7/81 , 5/16/81 -- feet MSLI 1 -17. Total Depth (MD+TVD) 18. Plug Back Depth (MD¢I-VD)i 19. Directional Survey 20. Depth where SSSV set J 21. Thickness of Permafrost 9791' MD 9682'MD YEs~X NO[;] 1820 feetMDJ 1650' (approx) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, CBL/VDL/GR/CCL, FDC/CNL/NGT/CAL "23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED '1'6" 65# H-40 Surf 80' 36"' 425 sx' AS It 10 3/4" 45.5# K-55 Surf 2714' 13 3/4" 3125 sx AS II .. 7,, 26# K-55 Surf 9767'..8 3/4" 9.74 sx AS II . , I 24. Perforations open to Production (MDkTVD of Top and B. ottomand . 25. TUBING RECORD , . interval, Size and number) SIZE DEPTH SET (MD) PACKER SET (MD) ~ 3 1/2,, 8898' 88b1' 8927'-9122' w/4 spf · ' 26.' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (M.D). AMOUNT& KIND OF MATERIAL USED . .~ . .. ,-' .,, , .,,,,:, N/A , ,, · · , · ,, . . 27. PRODUCTION TEST , Date'First Production J Method of Operation ~Flow, ing~,gas lift, etm) ~ Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO -TEST PERIOD I~· . Flow.. Tubing ~asin~'Pressure CALCULATED OIL:BBL ' GAS-MCF WATER'BBL I OIL GRAVITY-APl (corr) · Press. .i , ~,..: ' . 24-HouR RATE ~', > , . , 28. ' : ~' ' " ' ' ' ' CORE DATA · Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. . . N/A .- .: ..~.,, ,. ' · · ,-. S'EP .z 0 1981 . , · ... ...... . .,,.,' ,.... ..... ,- .. ~aska Oil & Gas COns. Comrnissior~ " Anchorage .. .., . Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARXERS FORMATION TE'S S . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk 8879' 6396' Top Upper Sand 8928' 6434' N/A Base Upper Sand 9047' 6525' ToP Lower Sand 9299' 6719' '¢ Base Lower Sand 9328' 6741' Base Kuparuk 9439' 6828' · i .... 31. 'LIST OF ATTACHMENTS Drilling History .... 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~ ~, ~~. Title Dist, Dr lgo Eng. Date 9/17/81 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 ~ · '~,:.4, If this well is completed for separate production from more than one interval (multiple completion), s° state in item 16, and in.it'em 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 September'"2, ~1981 ~' Van D~sen Mr.' P~' A- District Drilling Engineer Arco]% A ~ s ka; 'Inc. Anchorage, Alaska 99501 ~e~ ~erdue Data Submission ~ar ~r. Van Dusen= Wells on ~t~e attached lists are those for which Completion ~eports (form 10-407) are either incc~plete or apparently overdue, 'with 'completion,i abandonment, or suspension dates prior~,~to ~AUgust 1,~ 1981. , The first list is of those wells for which an incomplete Completion P~eport was filed, with the comment that the location~ at the top of the producing interval and at the total depth were-"to be submitted' or "N/A." The ccmpletion dates go back to January 9. The ~econd list is of thos~. Wells for which available information indicates the wells have been cc~pleted, but the 30 day filing period has passed withoutI a Completion Report having been submitted. We need to be brought up-to-date on directional survey prcblems that may be responsible for these late filings, or have the required directional survey s~ and reports submitted to us. We would appreciate a respons, e at your earliest convenience. Sincerely yours, Harry Keg ler CommiSsioner h~K/JAL/g lh < ~ IiORTtt 5LOPE EHGInEERIHG TRAi,ISMITTAL # TO' ~-~"~ /-/'~ ,//z~- FROM: J. J. Pawelek/Ann Simonsen D.~T~ o¢-Z,¢--o~/ WELL NAME Transmitted herewith are the following' PLc'~'~,~.L HOTE' BL - BLUELIi~E, S - SEPIA, F - PILM, T -: TAPE DATE' ='~ RETURil [,~u~?T TO' ARCO ALAS~Sq, INC. 'ATTN: ANH SIMOHSE!~ - AFA/311 P.O. BO:< 360 ANCNORAGE, AK 99510 RECEIVED AUG ? 1 1S[~1 Alaska Oil & Gas Cons. Cornmissio,"l Anchorage HORTH 5LOPE ='ilGI'''''r'''~ (i:i.i!.' ,. r,,' ~,-,, iiG , TRAHSMITT;,L fi J. J . Pav:el ;,"/Ann._:. ~Cimons~n_ D,-, Ir_ ~ ~ 0 -'-¢ / WELL ,,A,.,E' Transmitted herewith are the following' PLEASE HOT~.'~- BLUELIiIE, ~- SEPIA, :.,F - PILH, T - TAPE RLTU!UI RLCE!PT TO: ARCO ALAS?I, INC. ' ~ ATTi!: At~;I SIF. ONSEtl - AFA/311 P.O. BO;", 360 A;:Ci{ORAGE, AK 99510 AUG ,',: :t 15;'I [...:. .... ....,t" 0:~1 & G::", £;o~¢. C,;,Inrn!ssion NORTH SLOPE ENGINEERING TO' TRANSMITTAL J. J. Pawelek/Ann Simonsen DATE- ¢'Z ?'-8/ WELL NAME' Transmitted herewith are the following' PLEASE NOTE:~)-BLUELINE, d~~- SEPIA, F - FILM, T - TAPE E RETURN RECEIPT TO' DATE: ARCO ALASKA, INC. ATTN: ANN SI-MONSEN - AFA/311 P.O. BOX 360 ANCHORAGE, AK 99510 RECEIVED AUG - ) 1981 Alaska Oil & Gas Cons, Commission Anchorage NORTH SLOPE ENGINEERIHG TRANSHITTAL # F//~3 Transmitted herewith are the PLEA.~L HOTE' BLUELINE, FROM: WELL NAME' following- ~-SEPIA, J. J. Pawelek/Ann Simonsen F - FILM, T - TAPE RECEIPT ACr,,r,O,'ILEDG E RETURN RECEIPT TO' ARCO ALAStUN, INC. ATTN: ANN SIMONSE!,I P.O. BOX 360 ANCHORAGE, AK 99510 RECEIVED DATE: JUL Rlaalla,.011 & Gas C~ns. Commissiorl A F A/3 ] 1 Anchorage NORTH SLOPE ENGINEERING TRANSMITTAL TO- ~ ~-~/~z~ FROM- J. J. Pawelek/Ann Simonsen DATE' ?~'/Y WELL NAME: mi tted herewi th are the fol'l owing' PLEASE HOTE' BL - BLUELII,IE, S - SEPIA, F - FILM, ~APE , . RECEIVED JUL 1 ? 1~181 PLEASE RETURN RECEIPT TO' ARCO ALASKA, I NC. Alaska Oil & Gas Cons. Commission ATTN' ANN SIMONSEN - AFA/311 Anchorage P.O. BOX 360 ANCHORAGE, AK 99510 NORTH SLOPE ENGINEERING TO' TRANSMITTAL DATE- ~-/~- ~F/ WELL NAME' Transmitted herewith are the following' PLEASE NOT~/L)-BLUELII,IE, ~- SEPIA, J. J. Pawelek/Ann Simonsen F - FILM, T - TAPE RECEI PT ACKI,IOWLEDGED~~ ~E RETURN RECEIPT TO' Alaskt! ~ii & Gas Cons. Commission1 ARCO ALAS KA, I N C. ~ Anchorage ATTN' ANN SIMONSEN - AFA/311 P.O. BOX 36O ANCHORAGE, AK 99510 ARCO Alaska, Inc. Post Otlice Box 360 An ch oragc, sl,,n c,q~-.,..; l" 0 Telephone..,,v/ 27~ 563T June 22, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject' DS 4-13 DS 5-1 DS 12-9 DS 12-10 DS 13-12 DS 14-18 DS 14-19 DS 16-6 DS !6-13 DS 17-7 .A-1 B-2 B-3 Dear Sir' Enclosed please find' / 1 ) The subsequent sundries for DS: 4-13 & DS 5-1. , 2.) 'The monthly reports for DS 12LlO, OS !4~19, DS t6Z13, DS 17'7, ~'~-1 & B-3V' ,/ ,.' 3 ) The completion reports for DS 12L9, DS 13'2! '- . 2, DS 14-13, DS lo-6,. ,,..B-2 & C-S;'/ . ,4/ '"" '/"'/ -"c///8. 4 ) ~'The'GYroscopic'Surveys for DS 12-9,' DS' 1'4/-w~8, DS 16-6 & C ~/~zSincerely' ~ ~. P.A. VanOusen District Drilling..Engineer PAV/KJG'sr Enclosure STATE OF ALASKA ALASKA ' AND GAS CONSERVATION C ~,'MISSION iWELL COMPLETION OR RECOMPLETION REPORT AND LOG '~S Status of Well Classification of Service W,ell . . OIL ~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] - 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-52 3. Address 8. APl Number P.0. Box 360, Anchorage, AK 99510 50-029-20585 4. Location of well at surface 9. Unit or Lease Name - 1246'FNL, 668'FWL, Sec 12, TllN, RIOE, UM Kuparuk 25649 At Top Producing Interval 10. Well Number To be submitted. C-8 At Total Depth 11. Field and Pool To be submitted. Kuparuk River Field 5, Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KuParuk Ri ver 0i 1 Pool- 94' RKB ADL 25649 · , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 4/21/81 5/7/81 5/16/81 ___ feet MSL 1 17. Total Depth (MD+TVD) 9791 ' MD 18. Plug Back Depth (MD+TVD) 9682 ' MD YESX~19' Directional SurveYNo[] I 20. Depth where SSSV set1820 feet MD I21' Thickness Of PermafrOst1650, (approx ~ 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, CBL/VDL/GR/CCL, FDC/CNL/NGT/CAL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM . HOLE SIZE CEMENTING RECORD AMOUNT PULLED · 16" 65# H-40 surf 80' 36,, 425 sx AS II · 10-3/4" 45.5# K-55 surf 2714' 13-3/4" 3125 sx AS II 7" 26# K-55 surf 9767, 8-3/4" ·974 sx AS II · insulat.~d conducto.r 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) ' SIZE DEPTH SET (MD) PACKER SET (MD) 3~" 8898' R~51 ' . . 8927-9122 w/4 spf 26. ACID, FRACTUR E, CEMENT SQUEEZE, ETC. '." .'. DEPTH.INTERVAL <MD) AMOUNT& KIND OF MATERIAL USED . . n/a . ,, · . ,. . 27., . PRODUCTION TEST Da~e First Production. ' .. Method of Operation (Fl"o~Ning., gas lift/etc.) n/aI Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIo · ' ' '"'" TEST PERIOD I~ ~.. : . . Flow Tubing Casing'Pressure " CAL'CULATED.~ OIL-BBL GAS-MCF . WATER-BBL OIL GRAVITY-APl (corr) Press.. ' 24-HOUR RATE .1~ . 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 29. 30. ~ GEOLOGIC MARKERS FORMATION TESTS i NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T Kuparuk 8879' 6396 T Up Sand 8928' 6434' B Up Sand 9047' 6525' n/a T Low Sand 9299' 67] 9' B Low Sand 9328' 674]' B Kuparuk 9439' 6828' ,, 31. LIST OF ATTACHMENTS Drilling Hi story .... ,, 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S,gn., ~. ~. ~~ .T,t,e Dist. Drlg. Eng. Date ~//'?y'/ / .... 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~.1f this well is completed, for separate production from more than one interval (multiple ,completion), so state in item 16, and in ite~r~ 24 show the producing intervals for only the interval repo~ted 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 det'ails 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". Supplementary Test Data A-1 A-2 RU WLU, tested lub. to 2500 psi. RIH with HP, temp tool, gradiomanometer, & fullbore flowmeter. Opened well for flow test and survey. HP tool set at 5933'ss Flowed at rate of 2880 BOPD. GOR=387 FTP=325 psi, FBHP=1860psi. Ran production logs. SI well for PBU, final SI BHP=3094 psi. POH with PL string. Secured well 7-3-81. RU WLU, tested lub. RIH with fullbore spinner, temp. tool, HP, gradiomanometer & CCL. HP tool set at 5948'ss. Opened well for flow test and survey. Flowed at rate of 2971 BOPD. GOR=410, FTP=685, FBHP=2490 .psi. Ran production logs. SI well for PBU, final SI BHP=3091 psi. POH with PL string. Secured well 8-2-81. B-2 C-1 C-2 RU WLU, tested lub. RIH with spinner temp tool, HP and gradio. HP tool set at 6145'ss. Opened well for flow test and survey. Flowed at rate of 2972 BOPD. GOR=350, FTP=380, FBHP=2131 psi. Ran production logs. SI well for PBU, final SI BHP=3173 psi. POH with PL string. Secured well 6-26-81. Production test results: F10w rate = 1482 BOPD, GOR=435, FTP=400 psi, FBHP=1990 psi.. HP tool set at 6329'ss0 SI well for PBU, final SI BHP=3252 psi. POH with PL string. Secured well 5-9-81. RIH with HP, temp tool, gradio and fullbore flow- meter. HP tool set at 6307'ss. Opened well for flow test and survey. Flowed at rate of 976 BOPD. GOR=401 FTP=270 psi, FBHP=1866 psi. Ran production logs. SI well for PBU, final SI BHP=3160 psi. PDH with PL string. Secured well 5-7-81. RECEIVED OCT 198! AJaska 0il & Gas Cons. Commission Anchorage October 1, 1981 Supplementary Test Data Page Two C-7 RU WLU, tested lub. to 25009. RIH with HP, gradio, temp tool and spinner. HP tool set at 6458'ss. Opened well for flow test and survey. Results unreliable due to bad test data SI & secured well on 5-18-81 Retest performed 7-12-81. RIH with production tool, set HP at 6489'ss. Opened well for flow test and survey. Flowed at rate of 1528 BOPD. GOR=344, FTP=170 psi, FBHP=3244 psi. Ran production logs. SI well for PBU, final SI BHP=3240 psi. POH with PL string. Secured well 7-13-81. C-8 RIH with HP, temp tool, gradio, spinner and CCL. HP set at 6448'ss. Opened well for flow test and survey. Flowed pt rate of 413 BOPD. GOR=366, FTP=120 psi, FBHP=2181 psi. Ran porduction logs. SI well for PBU, final SI BHP=3264 psi. POH with PL string. Secured well 5-23-81. 13 Oil & Gas Cons. ~mml~ion ~chorage C-8 Drilling History NU 20" Hydrill & diverter. Spudded well @ 1230 hrs, 4/21/81. Drld 13-3/4" hole to 2728'. Ran multis,hot. Ran DIL/SP/GR/BHCS. Ran.66 jts 10-3/4" K-55 csg w/shoe @ 2714 . Cmtd csg w/3125 sx AS II. ND 20" Hydrill & diverter, instld 10-3/4" pkoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC, cmt, FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Displaced well to oil base mud. Drld 8-3/4" hole to 9776'. Ran DIL/GR/BHCS, CBL/VDL/GR/CCL, FDC/CNL/NGT/CAL. Drld 8-3/4" hole to 9791' TD. Ran 217 jts 7" 26#/ft K-55 Butt csg w/shoe @ 9767'. Cmtd 7" csg w/974 sx Class G. Drld cmt to 9682' PBTD. Instld 7" pack- off & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Displaced well to NaC1. Ran CBL/VDL/CCL/GR. Arctic packed 7" x 10-3/4" annulus w/300 bbls H20, 44 bbls AS II & 112 bbls Arctic Pack. Tstd csg to 3000 psi _o~. Ran 3½" perf completion assy w/tail @ 8898' & pkr @ 8851'. Tstd tbg hanger & pack-off to 3000 psi - ok. Tstd tbg to 3500 psi & ann .to 200 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Displ well to diesel. Dropped perf bar & perfd fr/8927-9122' w/4 spf. Flowed well to tst tanks. SI well. Released perf guns to 9455'. Pumped 320 bbls diesel down tbg & up annulus. Closed SSSV. Secured well & released rig @ 0900 hrs, 5/16/81. 1111 East 80th Anchorage, Alaska 99502 Phone 349-3541 Telex: 25-364 World Leader in Service to the Oil Industry May 10, 1981 Job #5404 North Slope Drilling- Enclosed please find our Gyro Survey on Kuparuk C-8 along with our Vertical Section and Horizontal View maps. Also enclosed you will find the Gyro Film, Field Sheet and Calculations. If any other information is needed please call at 349-3541. Thank you for using Scientific Drilling InternatiOnal and please call again. Sincerely Manager COMPLETION REPORT ARCO ALASKA INC GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDC BY FM LINDSEY G ASSOC 2 JUNE 81 KUPARUK (2-8 KB ELEV 94, FT. JOB NO 5~+02 RECORD OF SURVEY TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES (CLOSURES · STANCE ANGLE D M 0 0 0 0,00 100 0 45 99,99 200 0 30 199,99 300 0 15 299,98 400 0 15 399,98 500 0 15 499.98 600 0 15 599.98 700 0 30 699,98 800 0 15 799,98 900 0 30 1000 0 45 -94,00 N O,OOE 5,99 S62,98W 105.99 N 4,90W 205,98 N65,65E 305,98 S45,78E 405.98 N58.23W 505,98 N 7.33E 605,98 N43,88E 705,98 S 5,56E 899,97 805,97 N83,00W 999,97 905,97 NSO,45W 1100 0 15 1099,96 1005,96 S37,63E 1200 0 15 1199,96 1105,96 S74,55E 1300 0 15 1299,96 1205,96 S53,73E 1400 0 15 1399,96 1305e96 S58,91E 1500 1 30 1499.95 1405,95 N66,10W 1600 6 0 1599.71 1505.71 N59,43W 1700 11 0 1698,58 1604,58 N58,88W 1800 17 30 1795,45 1701.45 N64e83W 1900 21 30' 1889,69 1795,69 N71,85W 2000 25 0 1981,56 1887,56 N73.05W 2100 28 0 2071,04 1977,04 N79.83W 2200 30 30 2158.29 2064.29 N70.76W 2300 30 0 2244,67 2150,67 N70,98W 2400 3! 30 2330,61 2236,61 N78,55W 0,00 S 0,00 W 0.28 N 0.46 W 0.7'3 N 1.27 W 1,26 N 0,96 W 1 · 19N o'5 5 w o. 9 5 'N o, w 1,91 N 1,74 N 1,34 N 1.76 N 1,35 N 1,11 N 0,92 N 0,68 N 0,21 S 2,77 N 10,35 N 21.95 N 34,26 N 46.16 N 56.61 N 69e00 N 85,50 N 98,93 ~N 0,64 W 0,14 W 0,55 W 1,54 W 1,97 W 1,61 W 1,22 W 0,86 W 1,33 W 7,14 W 19,82 W 41,51 W 72.50 W 110,14 W 153.48 W 200e69 W 248.29 W 297,58 W 0,00 S 0 0 0 W 0,54 N 58 30 29 W 1.47 N 60 2 54 W 1,58 N 37 20 6 W 1,31 N 25 7 35 W 1,21 N 3? 43 31 W 1,61 N 34 37 0 W 2,01 N 18 32 40 W 1,74 N ~+ 52 48 W 1,45 N 22 31 49 W 2,34 N 41 9 32 W 2,39 N 55 31 11 W le96 N 55 23 41 W 1.53 N 52 56 4 W 1,10 N 51 35 37 W 1.34 S 80 57 11 W 7,66 N 68 44 14 W 22.36 N 62 25 34 W 46,95 N 62 7 43 W 80.19 N 64 z~2 30 W 119e42 N 67 15 35 W 163,59 N 69 ~+5 9 W 212.22 N 71 1 35 W 262,60 N 70 59 50 W 313,60 N 71 36 39 W D~G LEG SEVERITY DEG/IOOFT 0.000 0.750 0.250 0.250 0.282 0.497 0,271 0.250 0.250 0.250 0.250 0.500 0.158 0,090 0,023 1,25~ 4,501 5.000 6,522 4,110 3,507 3.352 3.~21 0,503 2,553 SECTION DISTANCE 0,00 0,54 1.47 1,44 1,05 1,10 1.43 1,45 0,94 1,11 2,19 1,9o 1,51 1,08 1,07 7,61 22,36 ~6,95 80,12 118.95 162,17 209e71 259.51 309,38 4RCO' KUPARUK C-8 GYROSCOPIC SURVEY JOB NO 5402 2 JUNE 81 RECORD OF SURVEY TRUE qEAS. DRIFT VERTICAL )EPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. 2500 34 30 2414.46 2320.46 N77.56W 2600 36 15 2496.00 2402,00 N73.96W 2700 37 30 2575e99 2481,99 N71,O3W 2800 38 0 2655e06 2561,06 N69,88W 2900 40 0 2732.77 2638.77 N69.35W 3000 41 45 2808.38 2714.38 N69.23W 3100 44 0 2881.66 2787,66 N69.05W 3200 45 45 2952,52 2858,52 N68,20W 3300 48 15 3020.72 2926.72 N68.51W 3400 50 30 3085,82 2991,82 N68,13W 3500 53 45 3147.21 3053.21 N67,68W 3600 56 15 3204.56 3110,56 N67.95W 3700 56 30 3259e94 3165e94 N68.16W 3800 56 45 3314.95 3220.95 N68,38W 3900 56 30 3369.96 3275.96 N68.36W 4000 56 30 3425.16 3331.16 N68.68W 4100 56 30 3480.35 3386.35 N68.10W 4200 56 45 3535.36 3441.36 N67.23W 4300 57 0 3590,01 3496,01 N66.93W 4400 57 15 3644.29 3550.29 N67.20W 4500 57 0 3698,57 3604.57 N67.70W 4600 57 0 3753e03 3659.03 N67,38W 4700 56 45 3807,68 3713.68 N67.31W 4800 56 30 3862,69 3768.69 N67,S1W 4900 56 15 3918.07 3824.07 N67.71W 5000 55 30 3974.17 3880,17 N67.53W 5100 55 0 4031,17 3937e17 N67,68W 5200 55 0 4088,52 3994,52 N67.90W 5300 54 45 4146.06 4052,06 N68.66W TOTAL COORDINATE5 CLOSURES DISTANCE ANGLE D M S DOG LEG SEVERITY DEG/iOOFT 110.19 N 350.86 W 124.42 N 406.97 W 142.47 N 464.19 W 162.94 N 521.88 W 184.86 N 580.87 W 208.00 N 642,08 W 232.2!3 N 705.66 W. 257.94 N 771,36 W 284,91 N ~,839,33 W 367.76 N 72 33 49 W 425,56 N 72 59 57 W 485.56 N 72 56 14 W 546.73 N 72 39 35 W 609e58 N 72 20 45 W 674.93 N 72 2 59 W 742.89 N 71 47 1W 813,34 N 71 30 35 W 886.37 N 71 14 59 W 312.941Ni :909'86 ~W 962.18 N 71 1 9 W i w w 373,55 N 1058,84 W 1122,80 N 70 34 2 W 404.67 N~ 1136'07 W 1205.99 N 70 23 38 W 435.58 N 1213.65 W 1289.45 N 70 15 24 W 466.35 N 1291.28 W 496.88 N 1368.88 W 527.59 N 1446.41 W 559.32 N 1523,65 W 591.93 N 1600.79 W 624.66 N 1678.14 W 656.87 N 1755e70 W 688,90 N 1833.21 W 721.16 N 1910.50 W 753.22 N 1987e60 W 784.93 N 2064e60 W 816.45 N 2141e14 W 847.74 N 2217.11 W 878.71 N 2292e95 W 908.97 N 2368e94 W 1372.92 N 70 8 32 W 1456,27 N 70 2 59 W 1539.63 N 69 57 36 W 1623.07 N 69 50 31W 1706,73 N 69 42 24 W 1790.63 N 69 34 58 W 1874.56 N 69 29 14 W 1958.38 N 69 24 14 W 2042.07 N 69 19 11W 2125e54 N 69 14 42 W 2208.77 N 69 11 1W 2291.53 N 69 7 38 W 2373,66 N 69 4 29 W 2455e56 N 69 1 ~5 W 2537.34 N 69 0 28 W 5,017 2.156 1.657 0.663 2,012 1.751 2.252 1.804 2.506 2,262 3.263 2.507 0.292 0,292 0,250 0.264 0,486 0e656 0.327 0.313 0.431 0,266 0.254 0.286 0,286 0.760 0,510 0.177 0.569 SECTION DISTANCE 361.7("% 418.03 477.06 537,64 600.05 664.98 732.52 802.63 875.34 950.80 1029,33 1110.85 1193.68 1275.72 1359.75 1442.63 1525.53~ 1608.66 1692.10 1775.78 1859.42 1942.92 2026.33 2109.49 2192,39 2274e80 2356,60 2438.12 2519.45 ARCO' KUPARUK C=8 GYROSCOPIC SURVEY JOB NO 54O2 2 JUNE 81 RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M S DOG LEG SEVER I TY DEG/IOOFT 5400 54 45 4203.77 4109.77 N62.70W 942.58 N 2443,32 W 5500 54 45 4261,49 4167.49 N66.38W 977.68 N 2517.04 W 5600 54 0 4319.74 4225.74 N65.61W 1010.74 N 2591.30 W 5700 54 0 4378.51 4284.51 N65.66W 1044.11N 2665.00 W 5800 53 45 4437.47 4343.47 N65,21W 1077.68 N 2738,47 W 5900 53 30 4496.78 4402.78 N64e63W 1111.810 N 2811.39 W 6000 53 45 4556.08 4462.08 N64ellW 1146.62 N 2883.99 W 6100 54 30 4614.68 4520,68 N64,70W 1181,$2 N 2957.07 W 6200 54 30 4672.75 4578,75 N63.78W 1217.00 N ~3030,39 W 2618,83 N 68 54 15 W 2700.25 N 68 46 21 W 2781.45 N 68 41 29 W 2862,24 N 68 36 19 W 2942.89 N 68 31 7 W 3023.25 N 68 25 22 W 3103.57 N 68 19 5 W 3184,41N 68 13 7 W 3265.63 N 68 7 10 W 6300 55 15 4730,29 4636,29 N63.45W 1253.35::N 3103.66 W 3347,18 N 68 0 34 W 6400 55 0 4787.47 ~+693.47 N63.38W 1290.06iN' 3177'03 w 3428.96 N 67 5'3 59 W 6500 55 30 4844,47 4750.47 N62.65W 1327.34 N :3250.25 W 6600 55 30 4901.11 4807.11 N62.O5W 1365.59 N3323.25 W 6700 56 0 4957,39 4863.39 N62.60W 1403.98 N 3396.45 W 6800 56 0 5013.31 4919,31 N62.00W 1442.51N 3469.85 W 6900 56 0 5069.23 4975.23 N62.00W 1481.43 N 3543,05 W 7000 56 30 5124.79 5030.79 N60.53W 1521.41 N 3615.96 W 7100 56 0 5180.34 5086.34 N59.78W 1562,78 N 3688.08 W 7200 55 15 5236.80 5142.80 N59.48W 1604.50 N 3759,29 W 7300 54 30 5294.34 5200,34 N57.63W 1647,17 N 3829.07 W 7400 52 30 5353.82 5259.82 N56.55W 1690.84 N 3896,55 W 7500 51 15 5415.55 5321,55 N55.00W 1735.08 N 3961,59 W 7600 50 0 5478.99 5384.99 N54.20W 1779.86 N 4024,60 W 7700 49 0 5543.94 5449.94 N53.65W 1824.63 N 4086.06 W 7800 47 45 5610.36 5516.36 N52.21W 1869,69 N 4145.70 W 7900 47 0 5678.08 5584.08 N52.00W 1914.88 N 4203.77 W 8000 46 15 5746.76 5652.76 NE1,78W 1959,73 N 4260,96 W 8100 45 0 5816,69 5722e69 NE1.81W 2003.94 N 4317,13 W 8200 44 30 5887.71 5793.71 NE1.91W 2047.41 N 4372.51 W 3510.83 N 67 47 8 W 3592.88 N 67 39 40 W 3675,19 N 67 32 29 W 3757.76 N 67 25 33 W 3840.30 N 67 18 32 W 3922.99 N 67 lO 52 W 4005,52 N 67 2 8 W 4087.38 N 66 53 12 W 4168.32 N 66 43 25 W 4247.59 N 66 32 32 W 4324.90 N 66 20 51W 4400.60 N 66 8 34 W 4474.95 N 65 56 12 W 4547.81N 65 43 29 W 4619.36 N 65 30 36 W 4690.03 N 65 18 3 W 4759.56 N 65 6 0 W 4828.12 N 64 54 31 W 4,872 3,008 0,902 0,040 0,385 0.452 0,419 0,844 0.746 0.783 0,254 0,706 0.494 0.627 0.497 0.000 1,136 0.718 0,777 1.437 2.113 1.566 1.335 1.048 1.476 0.759 0.758 1.250 0.502 SECTION DISTANCE 2600, . 2682.51 2763.61 282~4,37 2925.01 3005,44 3085,89 3166.86 3248.22 3329,98 3~+12.01 3494.16 3576.57 3659.23 3742.14- 3825,04 3908, ]~ 3991.2 . 4073,72 4155.34 4235,40 4313.57 4390.19 4/+65.44 4539.21 4611.65 4683.16 4753.46 4822.72 ~RCO- KUPARUK C-8 GYROSCOPIC SURVEY JOB NO 5402 2 JUNE RECORD OF SURVEY TRUE ~EAS, DRIFT VERTICAL )EPTH ANGLE DEPTH D H SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES C L O $ U R E 5 DISTANCE ANGLE D M 5 DOG LEG SEVERITY DEG/IOOFT 8300 42 30 5960,24 5866,24 N51,05W 2090.27 M ~426,36 8400 42 15 6034.12 5940,12' NSO.98W 2132,67 N 4478,75 8500 42 0 6108.28 6014.28 N49.96W 2175.36 N 4530.49 8600 41 0 6183.18 6089.I8 N4?.6iW 2219.01N 4580,34 8700 40 0 6259,22 6165J22 N46,46W 2263,27 N 4627,87 8800 40 I5 6335,68 6241,68 N49,58W 2306,36 N 46?5,77 8900 40 0 6412.15 631'8e15 N47.56W 2349e00 N 4724,09 9000 40 0 6488.75 6394e75 N47,10W 2392,56 N 4771.36 4895,10 N 64 43 18 W 4960.60 N 64 32 14 W 5025.69 N 64 21 5 W 5089.55 N 64 9 5 W 5151.65 N 63 56 20 W 5213.65 N 63 44 41 W 5275,88 N 63 33 41W 9337,62 N 63 22 7 W 9100 40 15 6565,22 6471,22 N45,75W 2436,99.N ~4818,04 W 5399,30 N 63 10 10 W 9200 39 30 6641,96 6547,96 N45,45W 2481,8~i~!iN '4863,85~W 5460,46 N 62 57 59 W 9300 39 0 6719.40 6625,40 N45,28W 2526,29~iiiN ~ 4908,87 iW 5520.80 N 62 46 4 W 9400 38 15 6797,52 6703,52 N45.01W 2570,32~.N~ ~4953,13 W 5580.32 N 62 34 26 W , 9500 37 34 6876,41 6782.41 N44,78W 2613.84 N 4996.51W 5638,91N 62 23 3 W 9600 37 0 6955,97 6861,97 N44,76W 2656,85 N 5039.18 W 5696.68 N 62 12 0 W ?79!~; ~ ~to7,~3 ~.~;6~' ~,oo ~ ~,~o. &~ ~ ~OTTOH HOLE CLOSURE 5696,68 FEET AT N 62 12 0 W ~,039 0.252 0,519 1.422 1.107 1.325 0.870 0.300 0.617 0.760 0.504 0,757 0,672 0,583 SECTIO~ DISTANCE 4890,35?'~ 5086.60 5149.28 5211,7~ 5274e39 5336,51 5~98.53 5459.97 5520.53 5580,21 5638.88 5696,68 ARCO' KUPARUK C-8 GYROSCOPIC SURVEY JOB NO 5402 INTERPOLATED TRUE VERTICAL DEPTHS~ COORDINATES AND CLOSURES FOR GIVEN DEPTHS CODE MEASURED NAME DEPTH TRUE VERTICAL DEPTH TOTAL COORDINATES CLOSURE DISTANCE ANGLE D M 2 JUNE SUB SEA K-14 2990 K-13 4858 W SAK SND 4547 K-12 505i K-lO 5906 K-5 7206 K-4 7769 K-3 7920 K-2 8337 BGRS 8615 K-1 8750 D 8879 TK 8879 C4 8928 TUS 8928 CB 8959 C2 9047 BUS 9047 C! 9085 TMS 9085 B 912I BMS 9121 A4 9299 TLS 9299 A3 9306 A2 9328 BLS 9328 A1 9372 KNGAK SH 9439 BK 9439 2800,91 3894,76 3724,22 4003,15 4500,34 5240,22 5589,59 5691,74 5987,54 6194,51 6297,49 6396,07 6396,07 6433e60 6433,60 6457,34 6524,72 6524,72 6553,76 6553,76 6581,26 6581,26 6718,62 6718,62 6724,06 6741,19 6741e19 6775,57 6828,21 6828,21 205,93 N 772,11 N 670,49 N 832,84 N 1113,92 N 1607,05 N 1856,01 N 1923,89 N 2106,05N 635,76 W 668,28 N 72 3 6 W 2706,91 2032,09 W 2173,83 N 69 11 42 W 3800,76 1792,69 W 1913,98 N 69 29 36 W 363.9,22 2179,77 W 2333e46 N 69 5 21 W 3909,15 2815,73 W 3028,06 N 68 24 57 W 4406,34 3763,51 W 4092,27 N 66 52 37 W 5146,22 4127,19 W 4525,31 N 65 47 10 W 5495,59 4215,27 W 4633,56 N 65 28 3 W 5597,74 4445e72 W 4919,34 N 64 39 6 W 5893,54 5098,94 N 64 7 7 W 6100,51 5182,41 N 63 50 1W 6203,49 5262,75 N 63 35 46 W 6302,07 ~i14713'75 W 5262,75 N 63 35 46 W 6302,07 ~i~473;7'26 Wi ~ ! 5293,13 N 63 30 22 W 6339,60 ~4737,26 W 5293,13 N 63 30 22 W 6339,60 2225,72 N 4587,52 W 2340,31N ~ii 4713,75 W 2340,31 N 2361,27 N 2361,27 N 2374,86 N 2413,37 N 2413,37 N 2430,50 N 2430,50 N 2446,56 N 2446,56 N 2526,14 N 2526,14 N 2528,96 N 2538,72 N 2538,72 N 2558,15 N 2587,40 N 2587,40 N 4751,83 W 4793,31 W 4793,31 W 4810,84 W 4810,84 W 4827,62 W 4827,62 W ~908,14 W 4908,14 W 4911e54 W 4921,31 W 4921.31W 4940,73 W 4970,09 W 4970,09 W 5312,24 N 63 26 42 W 6363,34 5366,58 N 63 16 30 W 6430,72 5366,58 N 63 16 30 W 6430,72 5389,95 N 63 11 47 W 6459,76 5389,95 N 63 11 47 W 6459,76 5412,18 N 63 7 29 W 6487e26 5412,18 N 63 7 29 W 6487e26 5520,08 N 62 45 57 W 6624e62 5520,08 N 62 45 57 W 6624,62 5524e39 N 62 45 21 W 6630e06 5537,54 N 62 42 44 W 6647,19 5537,54 N 62 42 44 W 6647,19 5563,71 N 62 37 34 W 6681,57 5603,25 N 62 29 55 W 6734,21 5603,25 N 62 29 55 W 6734e21 ARCO- KUPARUK C-8 - GYROSCOPIC SURVEY JOB NO 5402 qEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, 2 JUNE 81 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATE5 194 194, 100 0 '0 294 294, 200 0 0 394 394, 300 0 0 494. 494. 400 0 0 594 594, 500 0 0 694 694, 600 0 0 794 794, 700 0 0 894 894, 800 0 0 994 994e 900 0 0 1094 1094e 1000 0 0 1194 1194, 1100 0 0 1294 1294, 1200 0 0 1394 1394, 1300 0 0 1494 1494e 1400 0 0 1594 1594, 1500 0 0 1695 1694. 1600 1 1798 1794. 1700 4 1905 1894, 1800 10 6 2014 1994. 1900 19 9 2126 2094e 2000 32 13 2241 2194, 2100 47 15 2357 2294e 2200 63 16 2475 2394. 2300 81 18 2597 2494. 2400 103 22 2723 2594. 2500 128 25 2850 2694, 2600 155 27 2981 2794, 2700 186 31 3117 2894, 2800 223 37 3260 2994. 2900 266 43 3413 3094, 3000 318 52 3581 3194. 3100 387 69 3761 3294. 3200 467 80 3943 3394. 3300 549 82 4124 3494e 3400 630 81 4307 3594. 3500 713 83 0,67 N 1.27 W 1.25 N 0,99 W 1,21 N 0.57 W 0,94 N 0.72 W 1.30 N 0.92 W 1.87 N 0.67 W le77 N Oe14 W 1,34 N 0,51 W 1.72 N le48 W 1,39 N 2,01 W 1,11 N 1,64 W 0e93 N 1.24 W 0.69 N 0.88 W 0,20 $ 1,23 W 2,50 N 6.60 W 10.00 N 18,95 W 22,01 N 40e82 W 34,81 N 74,11 W 47.83 N 115.75 W 59,21 N 165,54 W 76,09 N 220,19 W 94.28 N 275e78 W 107,59 N 337,09 W 124.67 N 405,08 W 147.03 N 477,26 W 174,10 N 550.94 W 203.74 N 630.05 W 236,49 N 716,71 W 274.25 N 811,72 W 316.72 N 919e19 W 368e48 N 1043,89 W 423.74 N 1183,28 W 479.78 N 1324.53 W 535.13 N 1464.96 W 594,32 N 1606,16 W ARCO' KUPARUK C-8 GYROSCOPIC SURVEY JOB NO 5402 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. 2 JUNE 81 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 4491 3694, 4675 3794. 4856 3894, 5035 3994. 5209 4094, 5383 4194. 5556 4294, 5726 4394. 5895 4494. 6064 4594. 6236 4694. 6411 4794. 6587 4894. 6765 4994. 6944 5094, 7124 5194, 7299 5294. 7465 5394, 7623 5494, 7775 5594e 7923 5694, 8068 5794, 8209 5894, 8346 5994. 8481 6094. 8614 6194, 8745 6294e 8876 6394. 9007 6494, 9137 6594, 9267 6694, 9395 6794. 9522 6894, 3600 797 84. 3700 881 84 3800 962 81 3900 1041 79 4000 1115 74 4100 1189 74 4200 1262 73 4300 1332 70 4400 1401 69 4500 1470 ~ii? 69 4600 1542 ~ 72 4700 1617 4800 1693 4900 1771 5000 1850 5100 1930 654.52 N 713.46 N 771.46 N 827.68 N 881,58 N 937.06 N 996.44 N 1052,99 N 1110.58 N 1169.32 N 1230,33 N .75 1294.16 N 76 ; 13 61. O0 N 79 ~ ~ 1498,83 N 80 1573,02 N 5200 2005 75 5300 2071 66 5400 2129 58 5500 2181 52 5600 2229 48 5700 2274 45 5800 2315 41 5900 2352 37 6000 2387 35 6100 2420 33 6200 2451 31 6300 2482 31 6400 2512 30 6500 2543 31 6600 2573 30 6700 2601 28 6800 2628 27 1647.40 N 1719.75 N 1790.22 N 1858.75 N 1925.24 N 1990,33 N 2051,28 N 2109.79 N 2167,80 N 2225,27 N 2283.13 N 2339.00 N 2395,57 N 2453.84 N 2511,87 N 2568.24 N 2623,48 N 1748,50 W 1891,06 W 2030.55 W 2167,61 W 2299,74 W 2430,60 W 2558.64 W 2684.06 W 2807,52 W 2930,52 W 3056,95 W 3185,05 W 3313,55 W 3444,03 W 3575,17 W 3705e12 W 3827.96 W 3938.90 W 4038.81 W 4130.72 W 4216.98 W 4298e75 W 4377e30 W 4450,27 W 4520.02 W 4587,04 W 4648.94 W 4712.33 W 4774,57 W 4834,90 W 4893,88 W 4950,82 W 5005.81 W ~,RCO~ KUPARUK C-8 GYROSCOPIC SURVEY JOB NO 5402 INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH, TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA' TOTAL COORDINATES 1000 999. 2000 1981. 3000 2808, 4000 3425. 5000 3974. 6000 4556. 7000 5124. 8000 57Z+6. 9000 6488. 905. 1.77 N 1.54 W 1887. 46,45 N 110,04 W 2714, 208.31 N 641.96 W 3331. 497.59 N 1368.60 W 3880. 817.28 N 2140.80 W 4462. 1147,10 N 2883.76 W 5030, 1521,74 N 3615.77 W 5652. 1960.12 N 4260.65 W 6394, 2392.84 N 4771e10 W 2 JUNE 81 . HORIZ(~'TAL VIEW ARCO A[.-,$KA INC. WELL KUPARUK C-8 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE I"= I000' dUNE 2~ 1981 ALL DEPTHS SHOWN ARE TVD ~L/~.~TI C AL SECTION ARCO ALASKA INC. WELL KUPARUK C-8 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE i" = I000' JUNE 2~ 1981 400 8OO 1200 1600 SURFACE LOCATION . 1246 FNL, 'J668 FWL SEC. TIIN~ RIOE, U.M. 3200 ~ 3600 ....... 4000 . 440 0 ~ 5200 36 O0 --~ ...... !' ...... : 6000 6400 6s°°~ TVD = 6956' TMD · Check Form for timely compliance with our rcx~ulations. · -Operator, ~ei 1/Nam~ and N - Reports and Materials to be received by: Wel 1 History Samples Mud Log Core Chips Core Description Registered Survey Plat Inclination Survey Directional Surv Drill St~ Test Repo~s Production Test Reports Digitized Log Data Required Date Received Remarks Yes Yes NORTH SLOPE ENGINEERING J. J. Pawelek / Leo Las Date: Transmitted herewith are the following: FrOm: d I~ FAT TEC Please note: BL - Blueline, S - Sepia, F - Film, T - Tape RECEIPT ACKNO~ED: PIFASE RETURN RECEIPT TO: ARCO Alaska, Inc. Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 DATE: JUN 1 8 1981 Gas Cons, Comm~ ARCO Alaska, Inc.~ Post Office~ J60 Anchorage, Alaska 99510 Telephone 907 277 5637 May 13, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 5-1 DS 5-10 DS 9-18 DS 12-9 DS 14-18 DS 16-5 DS 16-6 DS 16-13 B-2 C-7 C-8 T-3C CONFIDENTIAL W. Sak #18 CONFIDENTIAL Dear Sir- Enclosed please fi nd' · e The Completion Report for DS 16-5. The Co~pletion Reports and Gyroscopic Surveys for C-7, W. Sak#18& T-3C. (Please note that W. Sak #18 & T-3C are to be considered confidential). · The Monthly Reports of Drilling & Workover Operations for DS 5-1, DS 14-18, DS 12-9, DS 16-6, DS 16-13, B-2 & C-8. 4. The Subsequent Sundry Notices for DS 5-10 and DS 9-18. Sincerely~ P. A. VanDusen District Drilling Engineer PAV/KJG'sp Enclosures ,f , [ ..... STATE OF ALASKA ( , -' ALASK/~' ~_AND GAS CONSERVATION C~ ,MISSION MONTHLY REPORT'OF DRILLING AND WOI KOVER OPERATIONS 1. Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, ]:nc. 81-52 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 5o_029-20585 9. Unit or Lease Name 4. Location of Well at surface 1246'FNL, 668' FWL, Sec 12, TllN, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 94' RKB 6. Lease Designation and Serial No. ADL Kuparuk 25649 10. Well No. C-8 11. Field and Pool Prudhoe Bay Field Kuparuk River Oil Pool For the Month of April ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1230 hrs, 4/21/81. Drld 8-3/4" hole to 6300', as of 4/30/81. (See attached Drilling History). 13. Casing or liner run and quantities of cement, results of pressure tests 16" conductor to 80~, Cmtd w/200 sx Permafrost. 10-3/4" csg w/shoe @ 2714'. Cmtd w/3125 sx AS II. (See attached Drilling History). 14. Coring resume and brief description n/a 15. Logs run and depth where run Ran DIL/SP/GR/BHCS. RECEIVED Alaska Oil & Gas Con;. Comrnissiort Anchorage 16. DST data, perforating data, shows of H2S, miscellaneous data None to date. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED . ,'~/1~. -. _ TITLE Dist. Drilling Engineer NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 C-8 Drill ing History NU 20" Hydrill & diverter. Spudded well @ 1230 hrs, 4/21/81. Drld 13-3/4" hole to 2728'. Ran multishot. Ran DIL/SP/GR/BHCS. Ran 66 jts 10-3/4" K-55 csg w/shoe @ 2714'. Cmtd csg w/3125 sx AS II. ND 20" Hydrill & diverter, instld 10-3/4" pkoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC, cmt, FS & 10' new form. Tstd form to 12.5 ppg EMW ~ ok. Displaced well to oil base mud. Drld 8-3/4" hole to 6300',"'as of 4/30/81. ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. HamiltoJ~ Chairman Thru: Lonnie C. Smith Commissioner Doug Amos ~ Petroleum Inspector April 29, 1981 Witness B.O.P.E. Te$1t -on ARCO'S KUPARUK C-8 Well Sec. 12, TllN, R10E, UM Permit #81-52 on Rowan Rig #34. Monday April 27, 1981~ I traveled this date from Van Guard #3 to Rowan Rig No. 34 to witness the B.O,P.E. test, The B.O.P.E. test commenced at 1~00 pm and was concluded at 6:00 pm.. There were no failures, I filled out an A.O,G,C.C. B.O.P,E. test report which is attached. In summary, I witnessed the B.O.P,E. test on ARCO'S KU.PARUK C-8 well, there was no failures and I filled out an A.O.G.C.C. B,O.P.E. test report which is attached. O&G a/e ('~ STATE OF ALASKA ALASKA OIL & -GAS ODNSERVATION CGMMJSSION B .O.P.E. Inspection Report .Inspector Date Operator Well /~"~?' Location: Sec /Z T/i/JR 2~ Dril linq Contractor ~O1~ ~m Rig Representative. mr~it # Set Representat ire Location, Genera] Well Sign, Ceneral Hous ekeep lng Peserve pit Rig ACCUMULATOR SYSTEM Ful 1 Charge Pres sure Pressure After Closure Pump incr. clos. pres. 200 psig, Full Charge Pressure Attained: N2 /~3'~/ ZI.~ Z Controls: Master ~' psig psig 4 psig min ~L sec. min ~ sec. _ Remote ~/~ Blinds switch cover BOPE Stack Annular Preventer / Pipe Rams Blind Rams Choke Line Valves.__ H.C.R. Valve L Kil 1 Line Valves Check Valve Test Pres sure z ]! l Kelly and Floor Safety Valves- Upper Kelly / Test Pressure Lower Kelly. , Bali Wpe,__ / InS ide BOP / Choke Manifold No. Valves,, ~No. flanges A~j ustab le Chokes Hydrauically operated choke Test Pressure Tes~ Pressure '/ Test Pres sure /, ,/ Test Pressure__ Test Results: Failures. /V~./J~,, Test Time' ~ Repair or Replacement of failed 'equipment to he made within.. Inspector/Ccmmission office notified. Remarks: .... hrs ~ , days and Distribution orig. - AO&CCC ",. ... cc - Operator . cc - Supervisor Inspector April 14, 1981 Mr. P. A. VanDusen District Drilling Engineer .ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Kuparuk 25649 C-8 ARCO Ala skJ, Inc. Permit No. 81-52 SUr. Loc.: 1246'FNL, 668'FWL, Sec 12, TllN, R10E, UM. Bottomhole Loc.: 1625'FSL, 750'FWL, Sec 2, TllN, R10E, UM. Dear Mr. VanDusen: Enclosed is the approved application for permit to drill the above re ferenced wel 1. Well samples and a mud log are not required. A directional survey i8 re~ired. If available, a tab containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. ~ny rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50. 870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may ~ contacted by the ~abitat Coordinator's office, Department of Fish and Game. Pollution of any ~ters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen Kuparuk 25649 C-8 -2- Apri! 14, 1981 commencing operations you may be contacted by a representative of the Depar*_ment of Environmenta! Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface ca.sing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present:. Very truly yours, H. ~mtlton ~i~n of BY ORDER O~ T;~E ~' Alaska Oil · ~s Conservation Commission Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. ARCO Alaska, Inc.[BI~' Post Office 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 10, 1981 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, A1 aska 99501 Subject: Kuparuk C-8 Dear Sir: Enclosed please find the following: 2. 3. 4. 5. 6. The Application for Permit to Drill Kuparuk C-8 and a $100.00 check for the application fee. A diagram showing the proposed horizontal and vertical projections of the wellbore. An as-built drawi.ng of "C" pad indicating the proposed surfaCe location. A proximity map indicating any and all wells within 200' of the proposed wellbore. A diagram and description of the surface hole diverter sys tern. A diagram and description of the BOP equipment. In addition, it is our intention to continue our efforts to mitigate the "C" pad surface gas bubbling problem. For well C-8, these efforts will include the following, once again. 1. Continued use of insulated conductor and conductor cementing technique as utilized for wells C-5, C-6, and C-7. 2. Continued use of sub-base ventilation system as used for wells C-5, C-6, and C-7. 3. Continued use of recording gas detector to monitor cellar gas, if any. 4. Continued effort to maintain drilling fluid temperature as low as is practical with available equipment. The above items have proven to be very effective in controlling surface gas bubbling at wells C-5, C-6, and C-7. We trust that you will find their continued use at well C-8~b~e acceptable. J~ J: [,'~ VED Si ncerely yours, P.A. VanDusen District Drilling Engineer Alaska 0il & Gas Cons. CommiSsion Anchorage PAV: TJ B: sg ARCO Alaska, Inc. is a Subsidiary of At~anticRichfieldCompany PERMIT TO DRILL 20 AAC 25.005 la. Type of work.' DRILL ~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC REDRILL [] DEVELOPMENT OILr~ SINGLE ZONE~ DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, ]~nc. 3. Address . P.O. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name 1246'FNL, 668'FWL, Sec. 12, T11N RIOE UM APR 1 0 198~ Kuoaruk 25649 At top of proposed producing interval s s 10.'Well number Alaska Oil & Gas Cons. Corn:,.,- · ~C-8 1320'FSL, 1320'FWL, Sec. 2, T11N, R10E, UN Anchorage "~l~JlTj~eld and pool At total depth 1625'FSL. 750'FWI..~P_c. 2. T11N. RIlIF. IIM Prudhoe Bay 5. Elevation in feet (indicate KB~ DF etc.) ' ] -6.'L~ase designation and serial no. Kuparuk Ri ver 0i 1 Pool 5.5' GL, 60'Pad:. 94' RKBI ADL 25649 12. Bond information (see 20 AAC 25.025) Type Statewide Surety a.d/or .umber Fed. ]:ns. Co. 8088-26-27 Amount:.:_$500_~i0~0 · 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi NW of Deadhorsff miles (.at TM) 750 feet well (at surf.) 120 ,feet, 16. Proposed depth (MD & TVD) 17, Number of acres in lease 18. ApprOximate spud date 9776' MD/6970 ' TVD feet 2560 4/20/81 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures ~'/{J~ psig@ 6{] Surface KICK OFF POINT1500feet. MAXIMUM HOLE ANGLE53oI (see 20 AAC 25.035 (c) (2) _~5__psig@. 6474 ft.)~ (TVD) . 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER ' SETTING DEPTH QUANTITY OF CEMENT . Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) " ' " 114' 425 sx AS 36 16" 65# H-40 Welded 80 Pad I Pad 114,1 L3,3/4."10-3/4" 45.5# K'-55 BT&C 2764' Pad ~Pad 2798I 2700' 3300 sx AS II 8-3/4" 7" 26# rK__55 'BT&C 9742' Pad I~Pad 97761 6970 · 7.00 sx Class "G" ' I I ,16" insulated condu :tor '~ t .... 1 , 22. Describe proposed program: ARCO Alaska, ]:nc. proposes to drill a Prudhoe Bay Kuparuk River 0il Pool development well to approximatel~v + 9776' MD, + 6970' TVD. Selected intervals will be logged. A 20" X 2000 psi annular-diverter wi1--1 be installed on the 16" conductor while drillin.g the surface hole. A 13-5/8" 5000 psi RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. ]:1: will be tested upon installation and weekl~v thereafter. Test pressure will be 3000 psig. Expected maximum surface pressure will be 2702 psig.* The we1.1 will be completed with 3½" 9.2# J-55 bUttress tubing. Non-freezing fluids will be ' left on uncemented annul1 thru the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon conclusion of job. · Based on cooling of gas bubble rising at constant volume.. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge ..... 'SIGNED ~~. ~~ TITLEDistrict Drig. Engineer DATE 4/10/81 The space b'el~)w'for Comr~ission ~se .... CONDITIONS OF APPROVAL Samples required Mud Icg required Directional Survey required "I APl number I--lYES J~NO I-lYES [~'N O ~YES []NOI 50-- ~ '~"~' ~ 7'"~ Permit number Approval date ~,-$z. 04/;L4/81 I SEE COVER LETTER FOR OTHER REQUIREMENTS ~,/ v ~,- ~ r/ ' ~' ' by order of the Commission Form 10-401 Submit i n triplicate Rev. 7-1-80 ARCO ALASKA, INC. '~/ PAD C, NELL NRI: 8 PRRIPOSED KUPRRUK FIELD, NRIRTH SLRIPE, RLRSKR · ERSTHAN WHIPSTOCK, INC. 0 SURFACE lOOO 2000 3000 4000 5000 6000 ?000 I' SCALE ;1 IN. = 000 FEET; ;-~ I , ' ~5287 FT (TO TARGET) KOP 16000 15000 4000 13000 2000 i1000 I0 ..'.. 0 r~ ~ ' TVD:lSO0 TMD:lSO0 DEP:O : !: ~. : .. 3917:FT BASE PERHRFROST TVD=l'/34 THD:l'/35 DE?=14 i '' i' ''~3~' ~f' [' PER lO0 ET : : !' ' ~'' '~.'j : i ! i i..,~.~:!'''''~ TVD:2'/OO THD:2'/98 DEP=424; i' :' ':" i ! ..... i !l 2 1 CR$ING POINT . . ~ -. : . : . I 8 EOC TVD=3019 THD=325'/ DEP=752 ~-- ! J.: ..... ~ '! .... i. '~-i -:,, ;~- '.':".F?--: .............. ~ ' 'J" , ,, ; ~. . : : , , ] j "' ; . . ; ' '~ [ ..... j- TVD=6474 -;'; 'i' i~ '"-,,~ , . ~; · .];..'41:i ' ' '. .... ' .~ ''i : '' ' : .... ' ~.'-; · ?' ;WEST .46~8 '. 'AVERAGE ANGLE., :_. ~ :..~ 52 BEG 4! HIN ..... -0 ~ K-S TVB=5ll4 THD=6]J3 BEP=3502 ........... i .... · , ~. t~ ]-- ._TRR6ET (TRIP KUP SANDS) TVD=64'/4 THD=8957. DEP=5~8-/ ~. I TOP LOWER SRND$ TVD=6744 THD=9403 DEP=5641 : ;BRSE KUP $RND$ TVD:6849 THD=9576 DEP=5779 ~ ~ ~ ~ TD TVD=6970 THD=9776 DEP=5938- 1000 2000 3000 4000 5000 ': ' 6000 - ... ; . . . ~ ! .. ] J ' .~...,. , VERTICRL SECTION i i .... !~ ;.'; ] Ii' 'j . ' ~ ;: ..i.' ! ........ t t WELL ~I Y = 5,968,522o46 × = 562,372°05 LAT = 70°~9~28~285'' LONG = lh9°29'39~295'' WELL ~2 Y = 5,q68.SSq.53 X : 562.271..78 LAT = 70°19'28-953'' LONG = 149°29~42~204'' WELL 33 y.= .,c 968,o55,.42 X = 562,172..58 LAT = 70°19S29o610'' LONG = 149°29'45.O84'' ' WELL ~4 Y = 5,968,722.03 X = 562,072.98 LAT : 70°19'30.273'' LONG : 149°29'47.975'' WELL :-:5 Y : 5,968,788.41 X -- 561 ,973 LAT = 70019' 30,934" LONG = 149°29'50.$78'' ,;ELL .-:G ',' = 5,96B,SS'-r..gq X 561 ''~72 6': LAT = 70°19:31 LONG - 1 ?.a~53o'/Cl'' I HEREBY CERTIFY THAT i AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAflD SURVEYI THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A;9 AS- BUILT SURVEY HADE BY ME, AND THAT AL'L D IHENSIONS AND OTHER DETAILS ARE CORRECT, AS n:-. WELL ~'7 Y = 5,9680921.16 X = 561,772o33 LAT = 70°1.9:32o256'' LONG = 149029'56.689'' WE LL Y = X = LAT = LOHG = 5, ~68, ~ 7.86 APR 1 0 1981 561,6' 70°19 ' 32 Off ' % ' .......................... "i ...........' AtlanticRichfietdCompany ~;~ DRAWING No: NORTH AMERICAN PRODUCING DIVISION "z.~/'~O ' -'.'"' ALASKA DISTRICT ·" - KUPARUK ! t/ _ .:..----: -~ ~-----: _ :.- : : ,~ , .~ .... ;: -.~._ ...~_ : -__: .......... ~ -- , ~e~ ,, ~ ~ :~ 5OO 400 _ 300 200 .... 100 .. K~ ..0 ......... ;- EASTMAN NHIPSTOCK, INC. NORTH SCRLE ! IN. = 100 FT. 400 300 200 1 O0 0 1 O0 200 300 40C I I I I I I I I 1942 ~74 '? Ni~1802 \ 2702 '~S,1567 ' 2623 . ................... ..... . Alaska Oil & Gas Cons. Commission . . ................ -..=, ............................ :~ .............. ~chorago .............. :.: ........ . . . . ~ . ' ...... ~ . - ? ~ ... ~ ~ -- ...................... ,...~ ~ .... 'i ~i'!~;~ Y;~'.----~_, '~:~ ....... ~ =. i~-...' ....... -'!i ~'.'i '-~'~ :.., ~.: ......... L.-, ...... i .......... ; ..... i ....... ;.- > i-. ...... ..': ............... ,, .... _: ..... ~, .............. ~.: ........ ~... ..... : .... ~ ........... i ........ . . . Surface Div~-cer System 1. 16" Bradenhead. 2. 16" x 20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/iO" side outlets. 4. 10" ball valves, hyraulically actuated, w/10" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell nipple. · ~.. a~n ance'& Operat~'o · ' ~'.' 121 i !ili! iiilil ~r ne ~y~b'I ~~h~~i~~!ir 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not shut in well under any circums'~'a~ce's. 16" Conductor ~c~or~ c°r~i~oa 5/8 " 5000 PSI RSRRA BOP STACf P. NNUL.q~ 9 BL ! ND 1-I 8 ) [ ) ( _ P I ?E R,q,"1S > ( ) ~ G~ ~.D.m'!LLiNG ' SP6OOL .. ?. 4 TBG ri c$o HD ~ 1 ~as~ Oil & Gas Cons. · . I. 16" Bradenhead 2. 16" 2000 PSI x 10" 3000 PSI casing head 3. 10" 3000 PSI tubing head 4. 10" 3000 PSI x 13-5/8" 5000 PSi adapter spool 5. 13-5/8" 5000 PSI pipe rams 6. 13-5/8" 5000 PSI drilling spool w/choke and kill lines 7. 13-5/8" 5000 PSI pipe rams 8. 13-5/8" 5000 PSI blind rams 9. 13-5/8" 5000 PSI annular ACCUHULATOR CAPACITY TEST 1. C~ECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCU?IULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATCR. 3. OBSERVE TI~.~E. THEN CLOSE ALL UNITS SIMULTANE- OUSLY AND RECORD THE TIME AND PRESSURE REMAIN- IHG AFTER ALL UNITS ARE CLOSED WITH CHA?,GiHG PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LCWER LIMIT IS 45 SECONDS CLOS!HG TIHE AND 1200 PSI REHAINING PRESSURE. 1~-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE- TRACTED. PREDETERMIHE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DO'JN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON HANIFOLD. '[EST ALL COMPONENTS TO 250 PSI AND HOLD FOR l0 MIHUTES. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR l0 MI,qUTES. BLEED TO ZERO PSI. OPEN ANHULAR PREVENTER AND CLOSE TOP SET OF PIPE RP~.IS. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR lO HINUTES. 8. CLOSE VALVES DIRECTLY UPSTRE~'.I OF CHOKES. BLEED DOWNSIREAH PRESSURE TO ZERO PSI lO TEST VALVES. lEST REI-1AINIHG UNTESTED HANIFOLD VALVES, IF ANY, NITH 3000 PSI UPSTREAM OF VALVE AHD ZERO PSI DOWNSTRE~I. BLEED SYSTEi4" 10 ZERO PSI. - 9. OPEH TOP SET OF PIPE RA~.IS AND CLOSE BOTTCH SET OF PIPE RAMS. lO. IHCREASE PRESSURE TO.3000 PSI AND HOLD FOR l0 HI~;UTES. BLEED TO ZERO PSI. ll. OPEN BOTTCH SET OF PIPE RAMS. BACK OFF RUN- NIHG JOIHT AND PULL OUT OF HOLE. CLOSE BLIND P&'.IS AN.D. TEST TO 3000 PSI FOR l0 IIINUTES. BLEED lO ZERO PSI. 12. OPEN BLI:;D RA,'.1S AND RECOVER TEST PLUG.,'-'"vr,,-..~,,. SURE HAHIFOLD A:~D LIliES ARE FULL CF ARCTIC DIESEL AND ALL VALVES ARE SET IN CRILLi:;3 POSITION. 13. TEST ST$;;'.CPIPE VALVES TO 30C0 PSI. 14. ~EST KELLY COCKS A;;D INSICE BC? TO 30CO PSI '~ITH KCC::EY PbMP. 15. 'RECS,qD TEST I:;FCP:.!ATIO'I C:; ~LC'xOUT P~E'.'E;iTER TEST FCR:I~,~'G:i Ai, D SEND TO 3Ri)L::,S. SUPER- VIS:SR. 16. PERFCF:l CS~'.PLETE BCPE TEST ONCE A '~E£K A,'~D FU:',CTIGNALLY OPE.qATE BOPE ~AILY. ,, · .. CHECK LIST FOR NEW WELL PERMITS IT~4 APPROVE DATE (1) Fee (2) Loc (3) ktmin ~~ ¥'~"~'~ ~(9/thru 11) (4) Casg~ ~/-/$.F1 20) (5) (6) Lease & Well No. YES NO 1. Is the permit fee attached ......................................... / 2. Is ~11 to be located in a defined pool ............................. .~., 3. Is ~11 located proper distance from property line ..... ............ 4. Is mi1 located proper distance from other ~lls ........ . ........... ,'~~_. '" 5. Is sufficient undedicated acreage available in this pool 6. Is ~11 to be deviated and is ~11 bore plat' inCluded 7. Is Operator the Only affected party ..................... ..... , ..... 8. Can permit be approved before ten-day %nit ......................... ~. . 9~ 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. Does operator have a bond in force ........... ' ...................... Is a conservation order needed ...................................... Is administratiTM approval needed ........................................ Is conductor string provided ................................. '... Is enough cement used to circulate gn gonductor and ~rface Will cement tie in SUrface and intermediate or production strings ..~ Will cement co~r all known productive horizons .' .................. Will SUrface casing protect fresh ~ter zones ...................... Will all casing give adequate safety in collapse, tension and burst. Is this ~11 to be kicked off from an existing ~llbore '. ......... ,. Is old wellbore abandonment procedure included on 10-403 ......... ~.. Is adequate ~11 bore separation proposed ........................... Is a diverter system required ................................. ~.. _ :. Are necessary diagrams of diverter and BOP equltm~nt'at~ached ...... Does BOPE have sufficient presSUre rating - Test to ~.~o psig . Does the choke m~nifold comply w/API RP-53 (Feb. 7$) .................. 25. Additional requirements Additional R~marks:/_, 7("/";,.~ ~S Ceology: Engine~er. ing: rev: 03/10/81 INITIAL "' GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,. Well Histocy File APPENDIX Information of detailed nature that is not Particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special'effort has been made to chronologically organize this category of information. _ · 1 LVP OOg.HO] VERIFICATION BISTING ** REEL HEADER ** SERVi" ~£ NAME :SERVIC DATE :$I/06/24 REEL ~AME :REEL ID CONTINUATION # :0! PREVIOOS REEL : COMMENTS :REEL COMMENTS ** TAPS HEADER SERVICE NA~E :SERVIC DATE :81106/24 ORIGIN :1070 TAPE NAME :61704 CONTINdATION # PREVIOUS TAPE COMME~T~ :TAPE COMMENTS ** FIGE HEADER FILE ~AME :SERVIC,O01 SERVICC NA~E : VERSION # DATE : MAXI~U~ LENGTH : 1024 FILE TYPE : PREVI~S FILE ** INFORMATION RECORDS MNEM CO~TENTS CN : AT~ANTIC RICHFIELD CO. WN : KUPARUK C-8 FN : KOPARUK RANG: 10 E TOWN: 11N SECT: 2 COUN: N. SLOPE STAT: ALASKA CTR¥: U.S.A. MNEM CONTENTS ~:-:_ ~i:.~- __ ---_-.~.:.i-: -;~_.: , _~- _ .: · . - : .Z -,-~. ":.' ,; '-'-'-- ~' -' 'Z' ~: - ' '- ' -' - ·' ~_'~ .i-;. ,.:' :: ./ '-i~ !- "~':: : -', . - '. · -.,; :-" ' C TE SZZ CODS :' ', . -:' -:-- , - :M~'-W,~ ~ m'- ' ~.~'~:~ ~':~-~. ~:. ~:~ ~ ~ ~ ~;~ ~ ~ . ;.;;.'? :,.'-_ -.;::.: -:. : ¢ ,~ ~'*;- ": .;: / ,. ¢ - ..... ·' '"~'" 00"0 ' 0 O0 0'12 06 5- :--*.'*'--. :¢--:'-"? O.OO.. 000.:-' ' :008 ¢ '06.5 ' '- "':::~ "~ "'"-0-00 :000 '004:~ ' 065 '::.' ::':::.¥' : :'~-':000:':: :O00., ~.~.: 004::::: :'065. "~:: .... ' ':~:~ .... ' 000::' 000'~ 00i: 065 -':: ~.::..:~ .~ :.?:~'_?-0:.0.0 :_~.~':000-.-~: ':0-08..: ,-06:5 O'O 0 00'0 ' 006' 065 .: :;~,::~;;:~;..: ._-:: '.;~-;;.~ ~. :- :'00;0: · :000 .:~-006 '.. 065 . ~- '::; :'::-;;':;';2 UNt::~ / -' :.~:'YP,:~: .:: -: CA T::E..:_ ':..StZg...: 'CODE PRES: NEDIT4F RECORD TYPE ~047 · -: ".. RECO~-D TYPE 047: JOB # 't0707,61703 RUN ~1, LOGGED 25'APR'81 BOTTOM LOG INTERVAL : 2721 FT. TOP Lt:iIG INTERVAL : 80 FT BIT SIZE = 14.75 TYPE HObE DENSITY VISCOSITY PH FLU RM RMF JOB LYP BDTTO~ LOG INTERVAL TOP LOC; INTERVAL BIT SIZ5 TYP~ HOLE FLUID DENSITY VISCOSITY FLUID bOSS ANDSTONE F~ ' 27'ie FI' ' ~ 9762~ · .__ . .-: .. · :, ./ _ /.:.~ . :~'.. . : .. _ DATA FORMAT RECORD ENTRY BLOCKS TYPE 4 8 4 " ' 73" ...... '-60 ' ' 5 0 i ' ' ~6 O' UNIT AP~ :API ARI',.'. A'P~,_-.F.t:bg,..:..S:~'ZE-~ :PROC: ' SAf4PLE REPR ~OG TgPB C~ASS 'MOD '~'NO*~' ~""- .... 'L~VE~b '- CODE OOa OH~M FUN rUN OHM~ 0 ' 12 46 0 '~ 0 ~ ' '-" 0 I ': '68 tSD MV 0 1 0.:~..- 0-'~". 0:. ~ :.~ 0'::'.' -~'- 1 ..: :~:. :. 68 FUN US/F 0 52 ' 32 O' ~: ':0 -~ A .... O' ~ '" ' 68~ ....... FUN ," :.'--~0-':.:~:' ~,~:~0::'_.~':~:::~:.-~::~,:~ .:~:"~'-:~.~:','-.: .~." 9~.:: : ".t ' ~ '68 NUX ~ O' ~0 '-~'4' ~} ' ~: I '68 ~'IUX :- :.. 0 .~; :~:'0.:-.::' ~:~.~:~-4~': -,. '~'0~..-- 'I - 68 ~UX IN 0 28 3 '0 ...... 0" ' :'~ 0 - i~ ': 0 ~, U X P P M 0 · hl'UX PU 0 0 0 0 0 N U X O' DATUM SPECIFICATION MNE~ ~,.~RVzCE SERVICE ID ORDER # DEPT SP DT GR RHOB NPHI GR SGR CALI DRHO THOR URAN POTA NRA~ NCNb bVP 009.H03 FCNL VERIFICATION 5ISTING O' 34 DEPT SP NPHI DRHO NRAT DEPT SP NPHI DRHO NRAT DEPT SP NPHI DRHO NRAT DEPT SP NPHI DRHO NRAT DEPT SP NPHI DRHO NRAT DEPT SP NPHI DRHO NRAT DEPT SP NPHI DRHO NRAT DEPT NPHI DRHO NRAT DEPT q775.000 SFLU -999.250 DT -999.250 GR -999.250 THOR -999.250 NCNb 9700.000 SFLU -999.250 DT -999.250 GR -999.250 THOR -999.250 NCNb 9600.000 SFLU -999.250 DT -999.250 GR 999,250 THOR -'999.250 NCNb .95O0.000 SFLU -99 250 GR .-999.250 THOR 999.250 NCNb 9400.000 SFDU -999.250 DT 34.473 GR 0.047 THOR 3.059 NCNb 300 000 SFLU 34.570 GR 0.054 THOR 3.037 NCNb 9200.000 SFLU -999,250 DT 33,105 GR 0.04! THOR 3.000 NCNb 9100 000 SFLU -999i25o DT 29 541 GR 0.051 THOR 2.760 NCNb 9000.000 SFbU -999.250 DT .103, ~50 ' 'GR'~,/...1~0!6', i,': :RHUB_i: :: ' ..>,999,"250... -: ' :999; 2-50' ~g99;250 :-""CALI .... "999 ~250 - 999:~ 2 50 '. URAN :~.. '/-' ' ::::.:' :: :.> .999~'.2.5:0 .- . - ' 96 · 375 '.-GR~-' 5:'=. ?.':::.'..:' .-:~:;:'999:;::~:2:50:::: · "- ' 999.250 ' 999 · 250 = .... .... ' 999 :' 250 URAN ' ::_-:,:,: .:."~,. 999-:.~50'_- .,': ' -999:250 ' 'FCN~: '~" ' ' :' - ' ~'" 999.250:.:~ U'RAN<: ~ 0: .... "999 "250 ~-- FCNI;: · ~": "~-"' :'"999:::;250 ~: :~' ......... :~ '999'2 .~ 0 I'~M ......... 3,52!<'~':::'::;<!!ii!:: I'~D 3. 422 : :' ': ' g 4 · I'88 :".OR'.:: ' ":= -' '.::~ :.2"A49 ~' 64'* 438 :S~R-"--': :"-' ..... '85 := :' 9 ;227 ' ' ..' ::~.':'POTA:.: .:".'::<: :":".:::.: O:,0~8:: :'. 9 9 9. 91 '375'' '~.:;::.:~R~OB,:.." : ':: : - ' 7 2 :'063 ':' 'SGR - ~:': ...............88;5'-B3 ':CA L~:i' .... : " 8;898 · 1.1,305 .-< URAN<;. ::-::- :::::.....<~:::::>:.::/?~i: -~.?..'PO~A-.:-. <.> :-:::. ~.:-'.:':. ::: .O:~:O:i9. < ~ .: - 250'~ 9'4..7 5.0.-:.: 'GR..<:~.: ~''...--<. ::::::::::::::::::::::::: ,::.O.0;O-~.::::~ .:-<. ;.: :L <:.2.4.57 ~ .: 74;~25': SO'~ ...... " .......... >82;750'~ :CA'CZ : "' 9;1'4i ' 2 0' g 3,3 75.'' ~:GR. ':.' ::~.~: 'RHOB.~ ::· :: .':-: ::~ :-2:~':.30 9' :- . 55,938 SGR' : ~- :::::67 ;:813 C'ALI " 9; 102 2 l0,047 _ --URAN: :-, ,'-:-:-~:':.::::1.~':'-,.:4:8:4 :::~ POTA'::':--:: O~O 11- - : , -' .o,oo.o .3, -ooo · ' '- LVP oo9.H03 NPHI DRHO NRAT DEPT SP NPHI DRHO NRA2: DBPT SP DRHO NEAT DEPT SP NPHI NEAT DEPT NPHI DRHO NEAT DEPT SP NPHI DRHO NR~T DEP$ SP NPHI DRHO NRAT DEP~ SP NPHI DRHO NRA~ DEPT SP NPHI DRHO NRA~ DEPT SP NPHt VERIFICATION 24.609 GR 0.064 THOR 2,535 NCNL 9O 000 SFLU 25 D~ 31,104 GR 0.024 THOR 2,924 NCN5 800 000 SFSU -999. 250 GR -999.250 THOR -999.250 NCNL B70 000 SF[~U -999,~50 GR '999. 50 THOR -999.250 NCNL {~1600 , 000 SFLU -999.250 DT -999 50 THOR -999,250 NCNL 8500 000 SFLU -999:250 DT -999.250 GR -999.250 THOR -999,250 NCNL ~400.000 SFSU -999.250 DT -999.250 GR -999,250 THOR -999,250 NCNb ~300.000 SFSU =999.250 DT -999.250 GR -999,2§0 THOR . 999.250 NCNL ~200.000 SFLU -999.250 DT -999.250 GR -999.250 THOR -999.250 NCNL i0~,000 SFLU ~99 .250 DT -999.25u GR 5ISTING _. <-/_' !:j: <...</:_/--?- .:;.- :~: . .:': . . .._ .. ~ 6. -99~,z50- ' II~M · _- ~'!'.' -,"=='2"900 ~IhD/ _-'. 2.914 94.563 GR ~ 'I25~;875'': RHOB' ' ' 2'500 ~05~ 625: .SGR ' "'<-~. ' ~.i2'2~8t3 ~" CAL;t -. 91852 iT;~6& URAC~' ....... :2;'~0'- 'POtA ' ' '0;026 . . . . -9~ -9~ '9~ -999.250. '99:9~' 250 - · -999. 250 .~ ~bM~ ~:- ~ '~:- :-~'~ ~:.':;'2:,9:78-:;I:h;Q:~:.~- ~.. 1,9:5.1 999,:250 · ~SG-R ;' :999,250 -999,256 O~N:- .~ '. - .~::~9-9;'2~g6 ' POTA'"" ~ 999;25'0 -999.250 ' ~ ~' '- 9' ' ;~ '- = : .... -~ -999. 95. 999. ' ' ' ' '~ 0 ' : ~" : ' - -: - 99 9.250 ~,375" '~'E ~-'~' R~OB -' 99g, 2BO 999. 999 .'2 -999 ..250 -999.250-- -999-250:-. . ' .' '- - <; :."T- : :.:.e -,'- .' '::' : ~- - ~ "- - "- ~ ' - - ' ii0;I88 ' GR' ' :':":X28;000-: RHOB ~g99;2~0 ' POT'A-''~ :: ~ggg:250 '999,250 -: I 999, ~ -; ~ Q . . : . · ' 99-9.2 50: I h:~i ~' ~-.-' '.:'" ::?:-':-:,:<::..':~-'3-~:::&g--::~ I.~:D::'::-< ~.:: '::': ~..: ~ :~>3,5'70: <-. LVP NRAT DEPT NPHI DRHO NRAT DEPT SP NPHI DRHO NRAT DEPT SP NPHI DRHO NRAT DEPT SP NPHI DRHO NRAT DEPT NPHI DRHO NRAT DEPT SP NPHI DRHD NRAT DEPT SP NPHI DRHO NRAT DEPT SP NPHI DRHO NRAT SP NPHI DRHO 009.H03 VERIFICATION -999,250 THOR -999,250 NCNL RO00.O00 SFbU -999,250 DT -999,250 GR -999,250 THOR -999.250 NCNb 7900,000 SFLU -999,250 DT -999,250 GR -999,250 THOR -999,250 NCNb 7500.000 SFLU -999,250 DT -999,250 GR -999,250 THOR -999,250 NCNb 7700.000 SFLU -999,250 DT -999,250 GR -999.~) THOR -999. 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SFbU '~ DT GR THOR ' NCNL ~999~.250. FCN~ SFLU 999~ GR : ~99,.25.0: :SG.~ '.'."<..:: ..~9>9:9:~.~25Q:.~. CA~I':.:' :.': ~999,.250 THOR = U~:N:' '9:99; 25:0 THOR :999: UR~N NCN~ .25~...::. ':..: ~FbO T HO R ' 999; N C N ~ ~:':~ ::'~ S F L U THOR ~ NCNL' : 999,:'2:50 :::~C:: :: ::,. DT ~ THO R :' 999; 250 ...... ~R:~N ' S.FLU ~ ~ .99:9~ DT I:06 ;::i88 GR N C N b 173?6 bVP DEPT SP NPHI DRHO NRAT DEPT SP NPHI NRAT DEPT SP NPHI DRHO NRAT DEPT SP NPHI DRHO NRAT DEPT D~HO NRAT DEPT SP NPHI DRHO NRAT DEPT SP NPHI DRHO NRAT DEPT SP NPHI DRHO NRAT DEPT SP NPHI DRHO NRAT 009.H03 VERIFICATION 5200.00'0 SFbU -999 250 DF 37:988 GR 0.016 THOR 3.301 NCNb 6i00.000 SFLU -999.250 DT 30.859 GR 0.010 THOR 2.920 NCNb 6000.000 SFLU -999.250 DT 48~975 GR 0.021 THOR 3.869 NCNb 5900.000 SFLU -999.250 DT 40.918 GR 0 02 4 THOR 443 NCNb 5800.000 SFLU -999.250 T 41.357 ~R 0.043 THOR 3,4'92 NCNb 5700.000 SFbU -999,250 DT 38.818 GR 0,01! 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':".~-':'"-: ...... 1..I3 ,-'0~O0-.~,.::..::': :: · :: · 8 ' 875 ':~:'" SG:R"'" ':' ......... 'C:A~:'I~ ..... 0';:'3'4'4 :' ~ 2.., 328-..~:...~ -UR/A::N-~':::-.:-~;:~'. :.:: :::~:: ~ ::::::::::::::::/:::: ~::'. :': ~: .0 ,~:0 ~9_ 1'16 ,'3 7.5 .-.: ::: :'G R-- '75; 8:75 ~ :. :8 ..-8:7_5 .:,, U 1 t'0 .:0:O0 :.- 76 ~8'-75 .... $'GR' ': i 0. t8 8 ., .: .'. . URA N-:::': :.,::....::.::..'::~:: ~1,3:..:~ ~-. ?:. ,:::.: :.~: ::.:. 0-,.023: 746. i 1.7.56~. : . ,:.:-'.RHD:~-.~::. _...: ::.:: :,. '2-2 73 5~; 594 :' S~:R: :'-": ...... C~'I .... ' ....... I 0 ;547 .'::-9,65 ~ LVP DEPT SP NPHZ DRHO NRAY DEP? SP NPHI DRHO NRAT DEPT SP NPHI DRHO NRAT DEPT SP NPHI DRHO NRAT DEPT SP NPHI DRHO NRAT DEPT SP NPHI DRHO NRAT DEPT SP NPHi DRHO NRAT DEPT SP NPHI DRHO NRAT DEPT SP NPHi DRHO NRAT DEPT 009.H03 VERiFI 300.000 -5999.250 42.090 0.036 3.549 5200.000 -999.250 40.137 O.O32 3.436 5100,000 -999.250 29.150 0,052 2.8X4 5~0.000 - 9.250 39.746 0.016 3.465 ~900. 999. 42. O. 3. 800. ~999; 4700. -999* 42. 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'4' UR ........ 8 688' SGR : .... '~' 70;Z25 :" ~'CA~I ' ~0;563 ~: 059,. URAN. ·: :.? <:::-?:' .,'.2,~'1.'9:3- ~, POTA :'- :- ':~ - .< <0.015 ~ . 17 t_,O00 '999.250.. 4~. v s.ooo .... : "- · 116.7 50 -:-;..G..R: .O:O-:':,<>-:R'HO;B;: ." <:...:.: ;:/::. ',.: :<2'342" ': :-,' 67. & ~8 SG~ .... ' '' ........ ':'""*'89';3'f2 ':-C'A'~'I¢' -' .... 10'; 1:4~' ' .e, 64~..- _ ::<-'..~:: :;:: .::-O-.,..O2&: :'~ - ~ . 7 ,000' · i:8 8 < G-fl; :.< ..:.;;:~ <.::::: &~:O00':?: .~RH~BB'<:.<?¢~:.< ,., ; 2'~::287--- :- : '- . , 969'"8GR :'' ..... ':'"' ....... ':~ ~""~'~"80';'i25-"" CAUi"'" ..... - ' ':'~ 9 ;695 ' ' _ - . ~ · . .. _.... ..... ~ '.':.:..8.-2¢8.¢- -~::.':. ::.:.-¢:~; ~.. O.,Ol~ , .' 59 , 906 S-G'R~,'~ · .... ; ..... 85'";'i'25 'CAb:'~ .... - .... ":'-' ' '~-;-'469' '' ' 7,535 .URAN:~'~::,~..c~:..: ::::<:.??~2, ..'~<'<'~O;~A ?:.~--::~: ':?:_:.: _-.0;:.;0.:20. .... ... -.- . . 1524. 000 FCN5.<...>:.-.?=. .~.~t3~ ;.000:.. .... -.. ..... ..~. , ,., .... 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PO'.~'~A :-=.' .~999.250 .'' · '999.2~,0 Fd-Nb ~ '~"999;250 96 '999 '999, '999, 750 GR -:-~:_.'_ ':2 :-64 · 438 RHOB ~999', 250 · -999. ~50 URAN;..--,-~ .,,-~-~99',250.,~,;,POTA' -- -999.250 -999. 50 FeNs'"' '9~99'~'2~0 '- - 999 ~'6 ~8'~~, ' "' ~:~":'~': ' '" "9'~'~; 2s'O-- 'c ~9'~'0-'~':' '":';'~:'-~- ...... 9~'9~'~'6 'CALI 9992250 :9~9.~ -, . -9-99 250 999,250 FCN5 "999,250 . 56.594 OR".~' ' <~-.~..~.~19~-,984~"RH0"- _ ',.~ -]9'9. +.2.{. -999,250 'U~N-~ .999~250.~ · 56~ 594: 'GR J-. ~= '-~=, '1999:"250 ' 999,250~ FCN5 ~ 999' 250 MAXI~U~ LE[,TGTH : 1024 F I b E '£ Y P E : , ** TAPE TRAILER SERVICE MA~4E :SERVIC DATE :81/06/24 ORIGi~'~ :1070 TAPE ?,i A F~E :61704 CONT I i,~i. JaT I 0~ # NEXT TAPE NA~4E .~APE COMMENTS ** REEL TRAILER SERVICE NAME :SERVIC DATE :81/06/24 ORIGI~ : REE~ ~AME :REEL ID CONTINUATION ~ :01 NEXT REEL NAME COMMENTS :REEL COMMENTS
