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Home My WebLink About198-249Originated: Delivered to:17-Jan-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 3B-04 50-029-21323-00 909740412 Kuparuk River Plug Setting Record Field- Final 3-Jan-25 0 12 3H-21 50-103-20094-00 909740216 Kuparuk River Multi Finger Caliper Field & Processed 5-Jan-25 0 13 3H-21 50-103-20094-00 909740216 Kuparuk River Plug Setting Record Field- Final 6-Jan-25 0 14 3H-33A 50-103-20578-01 909740217 Kuparuk River Plug Setting Record Field- Final 29-Dec-24 0 15 3I-13 50-029-21923-00 909619504 Kuparuk River Packer Setting Record Field- Final 2-Nov-24 0 16 3I-13 50-029-21923-00 909619504 Kuparuk River Packer Setting Record Field- Final 3-Nov-24 0 17 3K-24 50-029-22935-00 909619038 Kuparuk River Multi Finger Caliper Field & Processed 7-Nov-24 0 18 3K-24 50-029-22935-00 909619503 Kuparuk River Plug Setting Record Field- Final 30-Oct-24 0 19 3Q-14A 50-029-21665-01 909740219 Kuparuk River Leak Detect Log Field- Final 8-Dec-24 0 110 3Q-14A 50-029-21665-01 909740219 Kuparuk River Multi Finger Caliper Field & Processed 9-Dec-24 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40008T40009T40009T40010T40011T40011T40012T40012185-061188-008209-103189-025198-249214-082T40013T400131/23/202573K-2450-029-22935-00909619038Kuparuk RiverMulti Finger CaliperField & Processed7-Nov-240183K-2450-029-22935-00909619503Kuparuk RiverPlug Setting RecordField- Final30-Oct-2401189 025198-249214 082Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.01.23 15:18:26 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 14073'feet 10196'feet true vertical 6696' feet None feet Effective Depth measured 10196'feet 9973', 10105 feet true vertical 6533'feet 6426', 6493'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)3-1/2" 3-1/2" L-80 L-80 10090' 10124' 6486' 6502' Packers and SSSV (type, measured and true vertical depth)9973' 10105' 6426 6493' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: 5937'4091' Burst Collapse Slotted Liner 10484' 3968' Casing 6634' 6696' 10522' 14073' 5896' 112'Conductor Surface Production 16" 9-5/8" 70' measured TVD 7" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 198-249 50-029-22935-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025519 Kuparuk River Field/ Kuparuk Oil Pool KRU 3K-24 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf MDSize 112' Well Shut-In 324-574 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: SLB BluePack Packer Packer: Baker ZXP Liner Top SSSV: None Adam Klem adam.klem@conocophillips.com (907) 263-4529 RWO/CTD Engineer 10516-14038' 6633-6696' Fra O s 6. A PG , C g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:13 am, Jan 16, 2025 Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem@ conocophillips.com, C=US Reason: I am approving this document Location: Date: 2025.01.16 09:49:29-09'00' Foxit PDF Editor Version: 13.0.0 Adam Klem SFD 2/10/2025JJL 2/7/25 RBDMS JSB 012825 DSR-1/16/25 Page 1/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/17/2024 00:00 11/17/2024 02:00 2.00 MIRU, MOVE RURD P Prep and pull rig off pits, lower derrick, pull rig off well, clean up well site for environmental inspection 0.0 0.0 11/17/2024 02:00 11/17/2024 04:00 2.00 MIRU, MOVE MOB P Mob pits and office to 3K pad // Prep rig for Mob to 3K 0.0 0.0 11/17/2024 04:00 11/17/2024 09:30 5.50 MIRU, MOVE MOB P Mob Rig to 3K, pull rig to 3O-pad access entrance Standby for change out Begin moving sub @ 0630 hrs 0.0 0.0 11/17/2024 09:30 11/17/2024 11:30 2.00 MIRU, MOVE RURD P Hang tree in cellar // Spot well head equipment // Set matting boards and pull out spill containment 0.0 0.0 11/17/2024 11:30 11/17/2024 15:30 4.00 MIRU, MOVE RURD P Spot rig over 3K-24, rig up checklists and safe out rig // Take on seawater 0.0 0.0 11/17/2024 15:30 11/17/2024 18:00 2.50 MIRU, MOVE RURD P PJSM w/crew, Raise Derrick 0.0 0.0 11/17/2024 18:00 11/17/2024 22:00 4.00 MIRU, MOVE RURD P Spot in vac trucks, load pits with workover fluid 14.5 ppg FWP Obtain well pressures T/I/O 2100/2100/40 ****Rig Accepted @ 1800 on 11/17/24**** 0.0 0.0 11/17/2024 22:00 11/18/2024 00:00 2.00 MIRU, MOVE WAIT T Incorrect mud weight in pits. Increase mud weight from 14.2 ppg to 14.5 ppg. Serviced rig, greased and dressed power tongs to LD tubing. 0.0 0.0 11/18/2024 00:00 11/18/2024 01:30 1.50 MIRU, MOVE WAIT T Incorrect mud weight in pits. Increase mud weight from 14.2 ppg to 14.5 ppg. Serviced rig, greased and dressed power tongs to LD tubing. 0.0 0.0 11/18/2024 01:30 11/18/2024 02:00 0.50 MIRU, WELCTL PRTS P Pressure test lines to tiger tank and open top to 4300 psi no leaks lign up to pump down tubing taking returns up the IA to tiger tank 0.0 0.0 11/18/2024 02:00 11/18/2024 03:00 1.00 MIRU, WELCTL DISP P Bleed free gas, pump 4 bbls min down tubing taking returns up IA to tiger tank 0.0 0.0 11/18/2024 03:00 11/18/2024 03:15 0.25 MIRU, WELCTL OTHR P Swap tanks, blow down line to TT 0.0 0.0 11/18/2024 03:15 11/18/2024 06:00 2.75 MIRU, WELCTL DISP P Continue to displace well to 14.5# FWP. 14.3# returns after 525 bbls away. 0.0 0.0 11/18/2024 06:00 11/18/2024 08:30 2.50 MIRU, WELCTL DISP P Line up to take mud back into pits., condition mud to 14.5 ppg 0.0 0.0 11/18/2024 08:30 11/18/2024 11:00 2.50 MIRU, WELCTL DISP P Kill well, 2.5 bpm/360 psi 6665 stks/380 bbls 0.0 0.0 11/18/2024 11:00 11/18/2024 14:00 3.00 MIRU, WELCTL OWFF P Monitor well for flow. 2.5 bph returned @ .031 bpm, total of 14.0 returned, close in 28 psi tubing, 65 psi IA. 0.0 0.0 11/18/2024 14:00 11/18/2024 15:00 1.00 MIRU, WELCTL OWFF P Confer with town team, line up to U-tube IA x Tubing. 0.0 0.0 11/18/2024 15:00 11/18/2024 17:00 2.00 MIRU, WELCTL DISP P Pressures. attempt to bleed down, unsuccessful T=18 IA=18 Attempt to bleed down, unsuccessful Line up to pump down the IA. 0.0 0.0 11/18/2024 17:00 11/18/2024 19:00 2.00 MIRU, WELCTL DISP P Circulate 2.5 bpm down the IA 55 bbls, switch around and pump 144 bbls down TBG. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 2/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/18/2024 19:00 11/18/2024 20:00 1.00 MIRU, WELCTL DISP P Mud weight in pits down to 14.4#. Shut down pumps and flow check while weighting up mud in pits. T=110 IA= 14 0.0 0.0 11/18/2024 20:00 11/18/2024 21:45 1.75 MIRU, WELCTL DISP P Line up to pump 14.5# down IA taking returns through tubing. 110 BBLS away shut down and send light mud in pit 1 to Tiger Tank. Maintaining 14.5# in the pits. 0.0 0.0 11/18/2024 21:45 11/18/2024 23:30 1.75 MIRU, WELCTL DISP P Come back on with pumps. Pump 240 BBLs more, 14.5# in and 14.5# out at the pits. Shut down pumps. 0.0 0.0 11/18/2024 23:30 11/19/2024 00:00 0.50 MIRU, WELCTL OWFF P Observe well for flow, still flowing. T=35 IA=110 0.0 0.0 11/19/2024 00:00 11/19/2024 01:00 1.00 MIRU, WELCTL OWFF P Check weights at wellhead, 14.3# on IA, 14.5# on TBG. Calculate new KWF. 0.0 0.0 11/19/2024 01:00 11/19/2024 04:00 3.00 MIRU, WELCTL DISP P Weight up mud in pits to 14.8#. 0.0 0.0 11/19/2024 04:00 11/19/2024 05:15 1.25 MIRU, WELCTL DISP P Pump 110 BBLs down Tbg taking returns up IA. 0.0 0.0 11/19/2024 05:15 11/19/2024 05:30 0.25 MIRU, WELCTL OWFF P Flow check tubing. Returns diminishing. 0.0 0.0 11/19/2024 05:30 11/19/2024 07:30 2.00 MIRU, WELCTL DISP P Circulate 14.8# FWP down Tbg taking returns up IA. 0.0 0.0 11/19/2024 07:30 11/19/2024 08:00 0.50 MIRU, WELCTL OWFF P Flow check well // IA dead // Tubing spitting some gas and build 5 psi when shut in // Elect to continue circulating. 0.0 0.0 11/19/2024 08:00 11/19/2024 08:30 0.50 MIRU, WELCTL CIRC P Circulate tubing volume down tubing take returns up IA 0.0 0.0 11/19/2024 08:30 11/19/2024 09:30 1.00 MIRU, WELCTL OWFF P OWFF , IA dead, tubing flowing 1 vis cup every 2 min 20 sec 0.0 0.0 11/19/2024 09:30 11/19/2024 12:00 2.50 MIRU, WELCTL CIRC P Circulate down IA up Tubing @ 105 GPM @ 425 PSI ICP, 460 PSI FCP. Circulate 312 BBLS. 0.0 0.0 11/19/2024 12:00 11/19/2024 13:30 1.50 MIRU, WELCTL OWFF P Flow check well, Tubing dead. Flow observed out of IA. Trend constantly decreasing indicating breathing. Cont. to monitor IA. Flow decreased from 1 BBL/ HR to .25 BBLS per hour. 0.0 0.0 11/19/2024 13:30 11/19/2024 14:30 1.00 MIRU, WELCTL MPSP T Attempt to set BPV. Unable to engage threads of tubing hanger. Pull BPV and inspect threads. Drain tree, and attempt to set BPV again. Unable to set BPV. Continue to monitor Flow from IA. Rate decreased to 0.1 BBL/ Min. Still no flow from tubing. 0.0 0.0 11/19/2024 14:30 11/19/2024 15:30 1.00 MIRU, WELCTL MPSP T FMC rep get another BPV, Lubricator and tap. Continue to monitor flow from IA. Flow stopped *OFFLINE: Rig crew build test joints for BOP test and L/D in the pipe shed. 0.0 0.0 11/19/2024 15:30 11/19/2024 16:00 0.50 MIRU, WELCTL MPSP T FMC rep chase threads on hanger and gauge BPV to ensure in spec. Set BPV in hanger. R/U to test BPV from Bellow to 500 PSI. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 3/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/19/2024 16:00 11/19/2024 16:30 0.50 MIRU, WELCTL MPSP P Test BPV from below to 500 PSI for 10 min rolling test: GOOD. Pumped 2.1 BBLS, bled back 1 BBL. 0.0 0.0 11/19/2024 16:30 11/19/2024 17:30 1.00 MIRU, WELCTL OWFF P Monitor IA. Flow diminished. Keep IA open to bucket and monitor. 0.0 0.0 11/19/2024 17:30 11/19/2024 18:30 1.00 MIRU, WHDBOP NUND P ND tree and THA. Inspect hanger lift threads - bad. Install test plug in BPV. 0.0 0.0 11/19/2024 18:30 11/19/2024 21:30 3.00 MIRU, WHDBOP NUND P NU BOPs. Obtain RKB measurements. Install riser. 0.0 0.0 11/19/2024 21:30 11/20/2024 00:00 2.50 MIRU, WHDBOP BOPE P Rig up BOPE testing equipment. Fill stack. Shell test BOPE. 0.0 0.0 11/20/2024 00:00 11/20/2024 07:30 7.50 MIRU, WHDBOP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/4500 PSI for 5 Min each, Tested annular to 250/3500 on 3-1/2" and 4- 1/2" test joints, UVBR's on 3-1/2" and 4- 1/2" test joints, and LVBR's on 3-1/2" and 4-1/2" test joints. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, 3-1/2" FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure= 3050 PSI, after closure= 1650 PSI, 200 PSI attained = 16 sec, full recovery attained =115 sec. UVBR's= 6 sec, Annular= 18 sec. Simulated blinds= 6 sec. LVBR’s= 6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2084 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Guy Cook. 0.0 0.0 11/20/2024 07:30 11/20/2024 08:30 1.00 COMPZN, RPCOMP BOPE P R/D test equipment and blow down lines. 0.0 0.0 11/20/2024 08:30 11/20/2024 09:00 0.50 COMPZN, RPCOMP MPSP P FMC pull test dart and BPV. 0.0 0.0 11/20/2024 09:00 11/20/2024 09:30 0.50 COMPZN, RPCOMP OTHR P P/U Spear, and engage tubing hanger. P/U 10K over to verify grapple bit on tubing. FMC Rep BOLDS. 0.0 0.0 11/20/2024 09:30 11/20/2024 09:30 COMPZN, RPCOMP PULL P Unseat hanger @ 120 K. Attempt to pull hanger to the rig floor, pulled to 199K (165K w/o block weight). Work pipe up to 199K. 0.0 0.0 11/20/2024 09:30 11/20/2024 12:00 2.50 COMPZN, RPCOMP CIRC P CBU 2X. Light spots observed through out fluid column during first bottoms up. 0.0 0.0 11/20/2024 12:00 11/20/2024 15:00 3.00 COMPZN, RPCOMP OTHR T Continue to work pipe up to 200K. No progres, continue to work string F/ 200K to 100K. Increase from 200 K to 220K (90% of 3.5" tensile strenght) work pipe. Increase F/ 220 K to 230K (95%) and work pipe no progress. 0.0 0.0 11/20/2024 15:00 11/20/2024 16:00 1.00 COMPZN, RPCOMP OTHR T Land tubing hanger, FMC rep RILDS. Disengage spear from hanger. L/D Spear. 0.0 0.0 11/20/2024 16:00 11/20/2024 16:30 0.50 COMPZN, RPCOMP WAIT T Wait on E-line. Blow down top drive. Service pipe skate, and rig floor equipment. De-ice derrick. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 4/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/20/2024 16:30 11/20/2024 18:00 1.50 COMPZN, RPCOMP ELNE T Spot in and R/U YJOS E-line. 0.0 0.0 11/20/2024 18:00 11/20/2024 20:45 2.75 COMPZN, RPCOMP ELOG T RIH on E-line w/ 2.75" WellTec cutter drift BHA. Drift to 3,446' RKB, unable to make progress. POOH and add 2 sections of weight bar. RIH T/8,680' RKB with drift. POOH LD drift BHA. 0.0 0.0 11/20/2024 20:45 11/21/2024 00:00 3.25 COMPZN, RPCOMP ELOG T RU WellTec cutter and RIH with WellTec, locate GLM at 3,365' RKB. Correlate and make tubing cut at 3,393' RKB. 0.0 0.0 11/21/2024 00:00 11/21/2024 00:00 COMPZN, RPCOMP 0.0 11/21/2024 00:00 11/21/2024 01:00 1.00 COMPZN, RPCOMP PULL T MU spear and engage tubing hanger. Set down 10K. BOLDS, Pull hanger to rig floor. 62K PUWT 0.0 0.0 11/21/2024 01:00 11/21/2024 02:30 1.50 COMPZN, RPCOMP RURD T MU handling equipment for 4-1/2" tubing. LD tubing hanger pups. 0.0 0.0 11/21/2024 02:30 11/21/2024 04:00 1.50 COMPZN, RPCOMP CIRC T Pump 142 BBLs @ 4BPM. Flow check well. 0.0 0.0 11/21/2024 04:00 11/21/2024 09:45 5.75 COMPZN, RPCOMP PULL T POOH LD 4-1/2", & 3.5" F/ 3393' to surface. Cut joint 9.85' long. 0.0 0.0 11/21/2024 09:45 11/21/2024 10:15 0.50 COMPZN, RPCOMP CLEN T Clean and clear rig floor. R/D power tongs, and change handling equipment. 0.0 0.0 11/21/2024 10:15 11/21/2024 10:45 0.50 COMPZN, RPCOMP OTHR T Install wear bushing, and run in 4 LDS. 0.0 0.0 11/21/2024 10:45 11/21/2024 11:15 0.50 COMPZN, RPCOMP BHAH T M/U BHA #3 (Overshot BHA). P/U M/U jars, bumper sub, and overshot Unable to make up cut lip extension to X/O below overshot bowl. 0.0 26.5 11/21/2024 11:15 11/21/2024 12:15 1.00 COMPZN, RPCOMP BHAH T Unable to make up X/O and cut lip extension to over shot bowl. Take off and attempt to make up second X/O and cut lip extension to bowl with same results. Remove X/O. M/U different cut lip extension directly to overshot bowl. 26.5 26.5 11/21/2024 12:15 11/21/2024 12:45 0.50 COMPZN, RPCOMP BHAH T P/U 6 JTS 4.75" DC, and accelerators. 26.5 258.0 11/21/2024 12:45 11/21/2024 16:15 3.50 COMPZN, RPCOMP PULD T RIH F/ 258' to 3375' picking up singles. PUWT: 75 K SOWT: 60 K 258.0 3,375.0 11/21/2024 16:15 11/21/2024 16:45 0.50 COMPZN, RPCOMP FISH T Slack off and engage top of fish @ 3391'. Slack off and set down 5K @ 3393' (~2' of swallow on overshot). P/U 80K, Slack off and set down 10K. P/U to 200K. Slack off to 50, cock jars and P/U to 125K, and jar 3 times to warm up jars. P/U to 200K each time after jars fired. Slack off to 50K and P/U to 150 and jar 2 times. P/U to 200K after each time jars fired. Slack off to 50K and P/U to 175 and Jar 3 times. P/U to 220K, one time and 240K the last two times. Work string between 100K, to 240K. No string movement. Attempt to turn on pumps, wash pipe leaking on top drive. 3,375.0 3,393.0 11/21/2024 16:45 11/21/2024 17:00 0.25 COMPZN, RPCOMP SVRG T Rig crew tighten and grease wash pipe. 3,393.0 3,393.0 11/21/2024 17:00 11/21/2024 19:00 2.00 COMPZN, RPCOMP JAR T Slack off to 50K and P/U to 175K and jar 114 times, P/U to 250K after each jar lick. No pipe movement. 3,393.0 3,393.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 5/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/21/2024 19:00 11/21/2024 19:30 0.50 COMPZN, RPCOMP CIRC T Pump 42 BBL Hi-Vis sweep, hi-vis in returns at STS to cut depth. Packoff in overshot not sealing. 3,393.0 3,393.0 11/21/2024 19:30 11/21/2024 21:15 1.75 COMPZN, RPCOMP FISH T Attempt to disengage spear from fish. Work torque up to 8K. Unable to release from fish. Confer w/ town engineer, decision made to mobilize RCT and make a cut on E-line. 3,393.0 3,393.0 11/21/2024 21:15 11/21/2024 22:15 1.00 COMPZN, RPCOMP SVRG T Blowdown topdrive and perform derrick inspection. 3,393.0 3,393.0 11/21/2024 22:15 11/21/2024 23:15 1.00 COMPZN, RPCOMP OTHR T Pull string into tension - 142K (18K over calculated string weight). Install FOSV. 3,393.0 11/21/2024 23:15 11/22/2024 00:00 0.75 COMPZN, RPCOMP ELNE T RU E-line to RIH w/ 1.75" RCT cutter. 3,393.0 3,393.0 11/22/2024 00:00 11/22/2024 01:45 1.75 COMPZN, RPCOMP WAIT T Troubleshoot E-line tools. Anchors not opening correctly. 3,393.0 3,393.0 11/22/2024 01:45 11/22/2024 02:30 0.75 COMPZN, RPCOMP ELNE T Confer w/ town engineer. Decision made to RIH w/o anchors on RCT. Configure E -line tools. 3,393.0 3,393.0 11/22/2024 02:30 11/22/2024 03:15 0.75 COMPZN, RPCOMP ELNE T Attempt to RIH w/ E-line tools. Unable to pass through XO below FOSV. POOH w/ E-line. Measure OD on E-line centralizers. 3,393.0 3,393.0 11/22/2024 03:15 11/22/2024 05:30 2.25 COMPZN, RPCOMP ELNE T Wait on smaller OD centralizers to be mobilized from Deadhorse. 3,393.0 3,393.0 11/22/2024 05:30 11/22/2024 06:00 0.50 COMPZN, RPCOMP ELNE T YJOS M/U RCT cutter and new stabilizers on the rig floor. 3,393.0 3,393.0 11/22/2024 06:00 11/22/2024 07:30 1.50 COMPZN, RPCOMP WAIT T Wait on decision for plan forward. 3,393.0 3,393.0 11/22/2024 07:30 11/22/2024 10:30 3.00 COMPZN, RPCOMP ELNE T L/D RCT. YJOS mobilize shot bars, det chord, and detonators for string shot from dead horse. 3,393.0 3,393.0 11/22/2024 10:30 11/22/2024 11:00 0.50 COMPZN, RPCOMP ELNE T YJOS E-Line make up shot bars, and M/U to E-Line assy. 3,393.0 3,393.0 11/22/2024 11:00 11/22/2024 13:45 2.75 COMPZN, RPCOMP ELOG T YJOS RIH F/ surface to 7580'. POOH F/ 7580' to 7425' to perform correlation run. Confirm depths. Space out and place shot rod @ 7468'. Clear rig floor and fire string shot. 3,393.0 3,393.0 11/22/2024 13:45 11/22/2024 14:30 0.75 COMPZN, RPCOMP ELOG T YJOS E-line POOH F/ 7468' to surface. 3,393.0 3,393.0 11/22/2024 14:30 11/22/2024 15:00 0.50 COMPZN, RPCOMP ELNE T YJOS L/D String shot BHA. P/U RCT BHA. 3,393.0 3,393.0 11/22/2024 15:00 11/22/2024 17:00 2.00 COMPZN, RPCOMP ELOG T YJOS RIH to 7560'. POOH to 7412' Corelate w/ CCL, and space out @ 7456.4', Placing cutter @ 7468'. Observed ~400# reduction in line tension after making cut. 3,393.0 3,393.0 11/22/2024 17:00 11/22/2024 18:15 1.25 COMPZN, RPCOMP ELOG T RCT Slagged to pipe YJOS work RCT free. POOH W/ RCT F/ 7456.4' to 3352'. Tools hung up in drill collar. Work String free and POOH. 3,393.0 3,393.0 11/22/2024 18:15 11/22/2024 19:00 0.75 COMPZN, RPCOMP ELNE T YJOS break down tools at surface, RD YJOS E-line. 3,393.0 3,393.0 11/22/2024 19:00 11/22/2024 19:15 0.25 COMPZN, RPCOMP PULL T MU to topdrive, straight pull up to 225K attempt to pull fish free from cut. Work up to 275K. No pipe movement. 3,393.0 3,393.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 6/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/22/2024 19:15 11/22/2024 20:30 1.25 COMPZN, RPCOMP JAR T Slack off to 35K, cock jars and P/U to 125K and jar 3 times to warm up jars. P/U to 275K each time after jars fired. Slack off to 50K and P/U to 150K and jar 2 times. P/U to 275K after each time jars fired. Slack off to 50K and P/U to 175K and jar 18 times. P/U to 275K after each time jars fired. Pump while jarring at 5 BPM. No pipe movement. 3,393.0 3,393.0 11/22/2024 20:30 11/22/2024 21:00 0.50 COMPZN, RPCOMP SVRG T Perform post jarring derrick inspection. 3,393.0 3,393.0 11/22/2024 21:00 11/22/2024 21:30 0.50 COMPZN, RPCOMP OTHR T B/D topdrive. Set string in tension with 180K in slips. (40K over calculated string weight) MU FOSV. 3,393.0 3,393.0 11/22/2024 21:30 11/23/2024 00:00 2.50 COMPZN, RPCOMP ELNE T RU AK E-Line. MU string shot. RIH and fire string shot at 5760' RKB. 3,393.0 3,393.0 11/23/2024 00:00 11/23/2024 00:45 0.75 COMPZN, RPCOMP ELNE T POOH w/ spent string shot F/5760' T/surface. 3,393.0 3,393.0 11/23/2024 00:45 11/23/2024 01:45 1.00 COMPZN, RPCOMP ELNE T RD string shot and MU 1.75" RCT. 3,393.0 3,393.0 11/23/2024 01:45 11/23/2024 03:15 1.50 COMPZN, RPCOMP ELNE T RIH w/ 1.75" RCT on E-Line T/5800', correlate and make cut at 5760' RKB. Good indication of cut. 3,393.0 5,760.0 11/23/2024 03:15 11/23/2024 05:00 1.75 COMPZN, RPCOMP ELNE T POOH and LD E-Line tools. 5,760.0 5,760.0 11/23/2024 05:00 11/23/2024 05:30 0.50 COMPZN, RPCOMP ELNE T P/U on string pipe free. 92 K PUWT (25K over string drill pipe weight) 5,760.0 5,760.0 11/23/2024 05:30 11/23/2024 07:30 2.00 COMPZN, RPCOMP CIRC T CBU, Light fluid coming back, weight up system to 14.8 PPG CBU 3 X to get even weight in and out. 5,760.0 5,760.0 11/23/2024 07:30 11/23/2024 08:00 0.50 COMPZN, RPCOMP OWFF T Rack back stand and OWFF 10 Min: Static. Pump slug. 5,760.0 5,760.0 11/23/2024 08:00 11/23/2024 09:30 1.50 COMPZN, RPCOMP TRIP T POOH F/ 5760' to 2625'. Initial PUWT: 92K. 5,760.0 2,625.0 11/23/2024 09:30 11/23/2024 10:30 1.00 COMPZN, RPCOMP BHAH T L/D BHA F/ 2625' to 2367' 2,625.0 2,367.0 11/23/2024 10:30 11/23/2024 14:00 3.50 COMPZN, RPCOMP PULL T POOH L/D 3.5" tubing F/ 2367' to surface. L/D 75 full jts, and 2 cut jts. 2,367.0 0.0 11/23/2024 14:00 11/23/2024 14:30 0.50 COMPZN, RPCOMP CLEN T Clean and clear rig floor. Change handling equipment on the rig floor. 0.0 0.0 11/23/2024 14:30 11/23/2024 15:00 0.50 COMPZN, RPCOMP BHAH T P/U BHA # 4 (overshot BHA with out collars, jars bumpers, or intensifiers). 0.0 36.5 11/23/2024 15:00 11/23/2024 16:30 1.50 COMPZN, RPCOMP TRIP T RIH w/ BHA F/ 36.5' to 3,159' out of the derrick. 36.5 3,159.0 11/23/2024 16:30 11/23/2024 19:15 2.75 COMPZN, RPCOMP PULD T Cont. RIH F/ 3159' to 5746' picking up drill pipe. 3,159.0 5,746.0 11/23/2024 19:15 11/23/2024 19:30 0.25 COMPZN, RPCOMP FISH T Tag fish at 5757' RKB. Pick up and establish fishing parameters. 20 RPM free torque: 4500 ft-lbs. Circulate 2 BPM @ 615 psi. PUWT: 105K SOWT: 70K 5,746.0 5,757.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 7/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/23/2024 19:30 11/23/2024 19:45 0.25 COMPZN, RPCOMP FISH T Rotate onto fish w/ overshot. Stop rotation at 5K set down. Set down 30K to engage overshot on fish. See pressure increase F/ 615 psi T/ 815 psi at top of fish. Set down 42K to ensure good engagment on overshot. 2.30' total swallow w/ overshot. 5,757.0 5,759.3 11/23/2024 19:45 11/23/2024 20:15 0.50 COMPZN, RPCOMP FISH T Work pipe F/150K T/275K slacking off T/50K after each attempt. No pipe movement. 5,759.3 5,759.3 11/23/2024 20:15 11/23/2024 21:45 1.50 COMPZN, RPCOMP CIRC T Pump 40 BBL Hi-Vis sweep @ 5 - 5.5 BPM Saw signs of viscous fluid at stroke count STS to overshot. Saw signs of viscous fluid again at stroke count STS to cut @ 10087'. Pill strung out while pumping from multiple circulation points. Small amount of scale across shakers. 5,759.3 5,759.3 11/23/2024 21:45 11/23/2024 22:15 0.50 COMPZN, RPCOMP OTHR T B/D TD. MU FOSV, clean slip bowl. Set string at 140K in slips. (16K over calculated string weight) 5,759.3 5,759.3 11/23/2024 22:15 11/23/2024 23:00 0.75 COMPZN, RPCOMP ELNE T RU AK E-Line to run drift WellTec cutter drift through previous RCT cut @ 7468' RKB. 5,759.3 5,759.3 11/23/2024 23:00 11/24/2024 00:00 1.00 COMPZN, RPCOMP ELOG T RIH w/ WellTec cutter drift T/7600' RKB. Small indication of cut on CCL. No indication of pipe movement. 5,759.3 5,759.3 11/24/2024 00:00 11/24/2024 01:45 1.75 COMPZN, RPCOMP ELNE T Continue to POOH w/ drift BHA on E- Line. 5,759.3 5,759.3 11/24/2024 01:45 11/24/2024 02:45 1.00 COMPZN, RPCOMP ELNE T LD drift BHA for WellTec Cutter. MU and FT WellTec cutter tool. 5,759.3 5,759.3 11/24/2024 02:45 11/24/2024 08:00 5.25 COMPZN, RPCOMP ELOG T RIH w/ WellTec tubing cutter on AK E- Line T/7500'. Correlate and make tubing cut at 7478' RKB. POOH w/ E-Line. Tattle-tale @ 2.214" indicating 3.55" depth of cut. 5,759.3 7,478.0 11/24/2024 08:00 11/24/2024 09:00 1.00 COMPZN, RPCOMP ELNE T LD WellTec cutter and stand back AK E- Line. 7,478.0 7,478.0 11/24/2024 09:00 11/24/2024 09:45 0.75 COMPZN, RPCOMP CIRC T Ciculate bottoms up x 1 @ 200 GPM @ 1500 PSI. 7,478.0 7,478.0 11/24/2024 09:45 11/24/2024 13:00 3.25 COMPZN, RPCOMP TRIP T POOH racking back drill pipe F/ 7478' to 1718' 120 K HKLD w/ Fish. 7,478.0 1,718.0 11/24/2024 13:00 11/24/2024 14:00 1.00 COMPZN, RPCOMP BHAH T B/O L/D overshot. Change out elevators and handling equipment. 1,718.0 1,718.0 11/24/2024 14:00 11/24/2024 16:00 2.00 COMPZN, RPCOMP PULL T POOH L/D 3.5" Tubing F/ 1718' to surface 53 jts. 22.05' cut joint, 19.53' cut joint and one GLM. 1,718.0 0.0 11/24/2024 16:00 11/24/2024 16:30 0.50 COMPZN, RPCOMP SVRG T Clean and clear rig floor. Service rig floor equipment. 0.0 0.0 11/24/2024 16:30 11/24/2024 17:00 0.50 COMPZN, RPCOMP BHAH T P/U BHA # 5 ( overshot, X/O, and working single). 35.0 71.0 11/24/2024 17:00 11/24/2024 18:30 1.50 COMPZN, RPCOMP TRIP T RIH w/ stands F/surface T/5713' 71.0 5,713.0 11/24/2024 18:30 11/24/2024 20:00 1.50 COMPZN, RPCOMP PULD T PU DP F/5713' T/7452'. 5,713.0 7,452.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 8/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/24/2024 20:00 11/24/2024 20:15 0.25 COMPZN, RPCOMP FISH T Obtain fishing parameters. Pumps off - PUWT: 127K SOWT: 73K 2 BPM @ 815 psi 3 BPM @ 1015 psi - TQ: 5900 ft-lbs. PUWT:120K SOWT: 67K 4 BPM @ 1400 psi. 7,452.0 7,452.0 11/24/2024 20:15 11/24/2024 20:45 0.50 COMPZN, RPCOMP FISH T Tag tubing stub @ 7473' 7ES RKB. See 100 psi pressure increase. Set down 20K to engage overshot. P/U T/175K. Set down 50K. Work pipe F/275K T/300K 5 times setting down T/50K after each attempt. No pipe movement. 7,452.0 7,473.0 11/24/2024 20:45 11/24/2024 22:15 1.50 COMPZN, RPCOMP CIRC T Pump 25 BBL Hi-Vis pill @ 4 BPM - 1800 psi. No indication of pill in returns. Minimal amount of scale in returns. 7,473.0 7,473.0 11/24/2024 22:15 11/24/2024 23:15 1.00 COMPZN, RPCOMP FISH T Continue circulating and work pipe T/300K while building 40 BBL Hi-Vis pill. 7,473.0 7,473.0 11/24/2024 23:15 11/25/2024 00:00 0.75 COMPZN, RPCOMP CIRC T Pump 40 BBL Hi-Vis pill at 2 BPM. Increase pump rate to 3.5 BPM after tubing volume pumped. 7,473.0 7,473.0 11/25/2024 00:00 11/25/2024 00:45 0.75 COMPZN, RPCOMP CIRC T Circulate out hi-vis sweep at 3.5 - 4 BPM. Hi-vis returns at STS to overshot BHA #5. No noteable debris in returns. 7,473.0 7,473.0 11/25/2024 00:45 11/25/2024 01:00 0.25 COMPZN, RPCOMP FISH T Work pipe up to 300K while pumping. No pipe movement. 7,473.0 7,473.0 11/25/2024 01:00 11/25/2024 01:45 0.75 COMPZN, RPCOMP OTHR T B/D topdrive. MU FOSV. Clean and grease slip bowl Set string in tension at 170K. (18K over calculated string weight) 7,473.0 7,473.0 11/25/2024 01:45 11/25/2024 02:30 0.75 COMPZN, RPCOMP ELNE T Hang E-Line sheaves, RU E-line and MU WellTec cutter. FT WellTec cutter on surface. 7,473.0 7,473.0 11/25/2024 02:30 11/25/2024 06:30 4.00 COMPZN, RPCOMP ELNE T RIH w/ WellTec cutter to 7700'. P/U and attempt to work through tight spot a few times. PUWT over pull increasing each time. Consult town for plan forward. 7,473.0 7,473.0 11/25/2024 06:30 11/25/2024 09:00 2.50 COMPZN, RPCOMP ELNE T E Line POOH w/ WellTec cutter. 7,473.0 7,473.0 11/25/2024 09:00 11/25/2024 09:30 0.50 COMPZN, RPCOMP ELOG T AK E-line, and WellTec L/D tools. 7,473.0 7,473.0 11/25/2024 09:30 11/25/2024 12:00 2.50 COMPZN, RPCOMP CIRC T CBU 2X @ 4 BPM @ 1500 PSI. 7,473.0 7,473.0 11/25/2024 12:00 11/25/2024 12:30 0.50 COMPZN, RPCOMP OTHR T Blow down top drive. Rig up to fill hole across the top. 7,473.0 7,473.0 11/25/2024 12:30 11/25/2024 13:30 1.00 COMPZN, RPCOMP ELNE T R/U AK E-line 7,473.0 7,473.0 11/25/2024 13:30 11/25/2024 16:00 2.50 COMPZN, RPCOMP ELOG T AK E-Line RIH w/ Drift assembly. Couldn't get past 7760'. Make several attempts. Tight spot moving between 7760' and 7745' over pull each time when picking up from 300- 800 Lbs of line tension. Consult town on plan forward. POOH F/ 7700' to surface. 7,473.0 7,473.0 11/25/2024 16:00 11/25/2024 17:30 1.50 COMPZN, RPCOMP ELNE T L/D Drift assy, and P/U WellTec cutter. 7,473.0 7,473.0 11/25/2024 17:30 11/25/2024 22:45 5.25 COMPZN, RPCOMP ELOG T RIH w/ WellTec cutter. Make tubing cut at 7720' RKB. POOH w/ cutter. 7,473.0 7,473.0 11/25/2024 22:45 11/25/2024 23:15 0.50 COMPZN, RPCOMP ELNE T L/D WellTec cutter. Stand back E-Line. 7,473.0 7,473.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 9/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/25/2024 23:15 11/26/2024 00:00 0.75 COMPZN, RPCOMP CIRC T Pick up and circulate bottoms up F/ 7720'. 4 BPM @ 1550 psi. PUWT: 135K 7,473.0 7,469.0 11/26/2024 00:00 11/26/2024 00:15 0.25 COMPZN, RPCOMP OWFF T Finish pumping 204 BBLs bottoms up. Flow check well - no flow. 7,469.0 7,469.0 11/26/2024 00:15 11/26/2024 01:00 0.75 COMPZN, RPCOMP OTHR T LD 2 jts of tubing. Install air slips. Blowdown topdrive. MU handling equipment to rack back drillpipe. 7,469.0 7,428.0 11/26/2024 01:00 11/26/2024 04:45 3.75 COMPZN, RPCOMP TRIP T TOOH racking back drillpipe F/surface T/7442. 7,469.0 35.0 11/26/2024 04:45 11/26/2024 05:00 0.25 COMPZN, RPCOMP RURD T RU handling equipment for 3-1/2" tubing. 35.0 35.0 11/26/2024 05:00 11/26/2024 06:00 1.00 COMPZN, RPCOMP BHAH T LD BHA #5 (overshot grapple) and 11.11' cut joint. 35.0 276.0 11/26/2024 06:00 11/26/2024 06:30 0.50 COMPZN, RPCOMP PULL T LD 3-1/2" tubing section F/7479' T/7720'. 276.0 0.0 11/26/2024 06:30 11/26/2024 07:00 0.50 COMPZN, RPCOMP CLEN T Clean and clear rig floor. 0.0 0.0 11/26/2024 07:00 11/26/2024 07:30 0.50 COMPZN, RPCOMP BHAH T P/U Overshot BHA. 0.0 35.0 11/26/2024 07:30 11/26/2024 10:00 2.50 COMPZN, RPCOMP TRIP T RIH F/ 35' to 7700'. 35.0 11/26/2024 10:00 11/26/2024 10:30 0.50 COMPZN, RPCOMP CIRC T Obtain parameters start pumps to break gel strenght and work pumps up to 4 BBL/Min @ 1480 PSI. PUWT: 127 K SOWT: 75 K ROTWT: 95 K @ 30 RPM @ 6.6 K TQ. 11/26/2024 10:30 11/26/2024 11:00 0.50 COMPZN, RPCOMP FISH T Engage top of stump w/ overshot. Wash down @ 2BPM @ 300 Psi. Tag @ top of stump @ 7711'. Slack off and No go out @ 7714'. Pressure spike to 800 PSI, shut down pumps. Set down 20K, P/U to 150K to confirm overshot engaged on tubing. 11/26/2024 11:00 11/26/2024 11:30 0.50 COMPZN, RPCOMP OTHR T Blow down top drive and rig up circulating lines on the rig floor. 11/26/2024 11:30 11/26/2024 14:00 2.50 COMPZN, RPCOMP CIRC T Pressure up on the tubing up to 500 PSI. Dump pressure, and stage up pressure at various rates to attempt to establish circulation. Close annular and attempt to reverse circulate. Pressure up annulus to 500 PSI. Varrying rates, and dumping pressure. Continue to alternate between pumping down tubing and IA. 11/26/2024 14:00 11/26/2024 15:00 1.00 COMPZN, RPCOMP CIRC T Line up on tubing and stage pressure up to 2000 PSI, work string between 100K HKLD, and 300K HKLD at various up weights. Not able to establish circulation. 11/26/2024 15:00 11/26/2024 16:30 1.50 COMPZN, RPCOMP SLKL T Spot in and R/U HAL E-line on the rig floor. 11/26/2024 16:30 11/26/2024 21:45 5.25 COMPZN, RPCOMP SLKL T HAL Slick line RIH w/2.125" TS and 2" Bailer F/ Surface T/6800' falling at 10 FPM. Unable to make it to depth. Start POOH W/Slickline. 11/26/2024 21:45 11/26/2024 22:15 0.50 COMPZN, RPCOMP SLKL T POOH W/Slickline F/6800' T surface Standback Slickline Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 10/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/26/2024 22:15 11/26/2024 23:30 1.25 COMPZN, RPCOMP FISH T Attempted to release from fish. Worked up to 11.3K torque down to fish unable to release from fish. Straight pull up to 300K unable to release from fish. 11/26/2024 23:30 11/27/2024 00:00 0.50 COMPZN, RPCOMP SLKL T Lay down Slickline and move unit out of the way for E-line. 11/27/2024 00:00 11/27/2024 03:30 3.50 COMPZN, RPCOMP ELNE T Spot in E-line and start rigging up to RIH. waiting on hole punch 11/27/2024 03:30 11/27/2024 04:15 0.75 COMPZN, RPCOMP ELNE T RIH with hole punch to 50' set down, POOH W/Eline lay down hole punch MU 1-3/4" bailer and spangs 11/27/2024 04:15 11/27/2024 06:00 1.75 COMPZN, RPCOMP ELNE T RIH W/E-line and bailer to 50' obtain sample of. E-Line pull out of the hole and rig down. 11/27/2024 06:00 11/27/2024 07:00 1.00 COMPZN, RPCOMP FISH T Release over shot. Apply up to 13.5 K right hand torque and work string from 100 K to 175K. Bump down over shot to 50K and continue to work torque down. Repeat until rotation @ 6.5K tq. Turn off rotary. P/U, string moving at original P/U weight 127k. 11/27/2024 07:00 11/27/2024 12:00 5.00 COMPZN, RPCOMP CIRC T Establish circulation @ 2 BBL/Min @ 300 PSI. Staged pumps up to 201 GPM @ 1800 PSI. Circulated until mud PH at correct levels and flow line temp @ 75° F. 11/27/2024 12:00 11/27/2024 15:45 3.75 COMPZN, RPCOMP TRIP T POOH F/ 7711' to 35'. 11/27/2024 15:45 11/27/2024 16:15 0.50 COMPZN, RPCOMP BHAH T L/D BHA # 6 inspect grapple and overshot. 11/27/2024 16:15 11/27/2024 17:30 1.25 COMPZN, RPCOMP CLEN T Clean floor and load BHA #7 In pipe shed 11/27/2024 17:30 11/27/2024 19:30 2.00 COMPZN, RPCOMP SVRG T Pull bushing from table and clean behind inserts and master. 11/27/2024 19:30 11/27/2024 21:00 1.50 COMPZN, RPCOMP BHAH T PU BHA #7 F/0 T/257 0.0 257.0 11/27/2024 21:00 11/27/2024 22:15 1.25 COMPZN, RPCOMP SLKL T RU SL, drift BHA w/2" bailer verify ID. set down at 247' in BHA. Removed 2.125" centralizer set down at 247' in BHA. Stand back SL. 257.0 257.0 11/27/2024 22:15 11/27/2024 23:30 1.25 COMPZN, RPCOMP BHAH T LD BHA pull BS and ID at 2". Removed from BHA. MU BHA W/O BS 257.0 249.8 11/27/2024 23:30 11/28/2024 00:00 0.50 COMPZN, RPCOMP SLKL T RU SL W/2" TS drift BHA to 260' RD SL. 249.8 249.8 11/28/2024 00:00 11/28/2024 03:30 3.50 COMPZN, RPCOMP TRIP T TIH F/249.8 T/7645' PUW=145K SOW=70K 249.8 7,645.0 11/28/2024 03:30 11/28/2024 04:00 0.50 COMPZN, RPCOMP CIRC T Break circulation work up to 3BPM 1100 PSI. 7,645.0 7,645.0 11/28/2024 04:00 11/28/2024 06:00 2.00 COMPZN, RPCOMP SLPC T Slip and cut drilling line while circulating. 7,645.0 7,645.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 11/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/28/2024 06:00 11/28/2024 07:00 1.00 COMPZN, RPCOMP FISH T Obtain parameters. Attempt to latch on to fish w/ over shot.Tag top of fish @ 7717', continue to slack off to 7719' set down 30K P/U to 143K observe what appeared to be grapple slipping, repeat two more times same results. P/U to 7711' and start rotary @ 40 RPM @ 7.7K TQ Set down 30K and P/U to 140- 143K, repeat 4 times with same results. P/U to 7711' stop rotary and start pumps @ 1 BBL/ min @ 530 PSI. Wash down and set down 30K @ 7720'. P/U and observe 140-145K on weight indicator. Repeat two more times. Start rotary again wash and ream down to 7720' and set down 20-30 K and P/U to 140- 143K, repeat 4 times with same results. PUWT: 140K SOWT: 70K ROTWT: 98 K @ 40 RPM @ 7.8-8 K TQ Flow rate: 1 BPM @ 530 PSI 7,645.0 7,720.0 11/28/2024 07:00 11/28/2024 08:30 1.50 COMPZN, RPCOMP CIRC T CBU @ 168 GPM @ 1353 PSI 7,720.0 7,720.0 11/28/2024 08:30 11/28/2024 11:30 3.00 COMPZN, RPCOMP TRIP T POOH F/ 7720' to surface. 7,720.0 264.0 11/28/2024 11:30 11/28/2024 12:30 1.00 COMPZN, RPCOMP BHAH T POOH L/D BHA 264.0 0.0 11/28/2024 12:30 11/28/2024 13:00 0.50 COMPZN, RPCOMP CLEN T Clean and clear rig floor. 0.0 0.0 11/28/2024 13:00 11/28/2024 14:00 1.00 COMPZN, RPCOMP BHAH T P/U Overshot F/ Surface to 266' 0.0 266.0 11/28/2024 14:00 11/28/2024 17:00 3.00 COMPZN, RPCOMP TRIP T RIH F/ 266' to 7680' 266.0 7,680.0 11/28/2024 17:00 11/28/2024 20:15 3.25 COMPZN, RPCOMP CIRC T Circulate 3BPM at 1100 PSI till 14.8# in and out. 7,680.0 7,680.0 11/28/2024 20:15 11/28/2024 20:45 0.50 COMPZN, RPCOMP RURD T Blow down top drive and surface lines. PU pup joint and space out. 7,680.0 7,718.0 11/28/2024 20:45 11/28/2024 22:30 1.75 COMPZN, RPCOMP FISH T PUW = 140K dry 125K wet, SOW=70K. Latch up to fish tagged at 7720' set down 30K confirmed overshot was latched. Start jarring. Hit 50 licks worked up to 305K of yeild for 3.5" L-80. Released from fish. 14.5K torque PUW=120K 7,718.0 7,722.0 11/28/2024 22:30 11/29/2024 00:00 1.50 COMPZN, RPCOMP CIRC T Circulate BUS 3BPM @1100 PSI 7,722.0 11/29/2024 00:00 11/29/2024 00:15 0.25 COMPZN, RPCOMP FISH T Attempted to engage fish. Unable to get grapple to grab. Washed over top of tubing. Appears pack off is blown. 1BPM 880 PSI off fish 990 PSI on fish. Set overshot on top of tubing. bottom of overshot at 7723' 11/29/2024 00:15 11/29/2024 01:15 1.00 COMPZN, RPCOMP RURD T Lay down single and blow down top drive. MU safety valve and X-O's to get slick line on the well. Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 12/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/29/2024 01:15 11/29/2024 05:30 4.25 COMPZN, RPCOMP SLKL T RU Slickline 20' 1-7/8" TS 1.92" Centralizer 1-3/4" bailer. RIH W/1.75" bailer TS to 9430 Pump down at 1.5 BPM 1150 PSI. Unable to fall any further. poor action at 9430' Blow down cement line and POOH. RIH PR=1.5 BPM 1050 PSI. 11/29/2024 05:30 11/29/2024 07:00 1.50 COMPZN, RPCOMP SLKL T Slick line P/U 2" Bailer and RIH tag up @ 9448'. Bailer had scale, 17.8 PPG mud @ 130 vis. Make second run W/ 2" Bailer tag up @ 7748'. POOH and check contents of bailer. Had 19.7 PPG 228 vis mud, and scale . Pump down @ 1.5 BPM @ 1090 PSI 11/29/2024 07:00 11/29/2024 13:30 6.50 COMPZN, RPCOMP SLKL T P/U 1 3/4" Bailer and RIH to 9448'. Attempt to increase flow rate to 2 BPM @ 1450 PSI, tag @ 9448'. POOH and check contents of bailer. P/U and RIH w/ 2" bailer and POOH R/D Slick line Pump down slick line @ 1.5 BPM @ 1090 PSI 11/29/2024 13:30 11/29/2024 14:30 1.00 COMPZN, RPCOMP CIRC T Circulate surface to surface to condition mud. Pump 4.5 BPM @ 1700 PSI. 11/29/2024 14:30 11/29/2024 15:00 0.50 COMPZN, RPCOMP FISH T Attempt to re-latch onto fish with overhsot. 11/29/2024 15:00 11/29/2024 19:30 4.50 COMPZN, RPCOMP TRIP T POOH F/ 7723' to 266.8' 11/29/2024 19:30 11/29/2024 21:30 2.00 COMPZN, RPCOMP BHAH T LD BHA #8 Grapple stripped Packoff still in control but compromised. MU BHA #9 11/29/2024 21:30 11/29/2024 21:45 0.25 COMPZN, RPCOMP SFTY T H2S Table top drill with crew. 11/29/2024 21:45 11/30/2024 00:00 2.25 COMPZN, RPCOMP TRIP T TIH F/269' T/4850' PUW= 11/30/2024 00:00 11/30/2024 01:00 1.00 COMPZN, RPCOMP TRIP T Continue RIH F/4850' T/7650' PUW= 140K SOW=70K 11/30/2024 01:00 11/30/2024 02:15 1.25 COMPZN, RPCOMP CIRC T Circulate BUS 3 BPM at 1150 psi 11/30/2024 02:15 11/30/2024 03:15 1.00 COMPZN, RPCOMP FISH T Space out DP. Engage fish at 7720' Pulled up to 185K in slips. 45K over. 11/30/2024 03:15 11/30/2024 05:30 2.25 COMPZN, RPCOMP ELNE T RU E-Line MU TS & RCT 11/30/2024 05:30 11/30/2024 09:00 3.50 COMPZN, RPCOMP ELOG T E-line RIH F/ Surface to 8811'. Correlate collar locations, and make cut @ 8743'. 11/30/2024 09:00 11/30/2024 10:30 1.50 COMPZN, RPCOMP ELOG T E-Line attempt to pull free, work tool string up to 3300 LBS. Attempt to pump tools down and slack off to release anchors. Consult town for plan forward. Continue to work string. Cable head failure @ 4200 LBS of tension. E- Line POOH. 11/30/2024 10:30 11/30/2024 11:30 1.00 COMPZN, RPCOMP ELNE T R/D AK E-line equipment on the rig floor. 11/30/2024 11:30 11/30/2024 13:30 2.00 COMPZN, RPCOMP SLKL T R/U HAL Slick line on the rig floor. Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 13/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/30/2024 13:30 11/30/2024 18:00 4.50 COMPZN, RPCOMP SLKL T HAL Slick line RIH F/ Surface to 7511' counldn't pass. POOH re-configure BHA. Latch fish. Lady down tool string and E-line TS. RD Slick line. 11/30/2024 18:00 11/30/2024 19:00 1.00 COMPZN, RPCOMP TRIP T TOOH F/8743' PUW=148K 8,743.0 8,550.0 11/30/2024 19:00 11/30/2024 21:00 2.00 COMPZN, RPCOMP CIRC T Circulate BUS 3BPM at 1280 PSI. 8,550.0 8,550.0 11/30/2024 21:00 11/30/2024 21:30 0.50 COMPZN, RPCOMP RURD T Blow down top drive and surface lines. 8,550.0 11/30/2024 21:30 11/30/2024 22:00 0.50 COMPZN, RPCOMP SVRG T Service top drive 8,550.0 8,550.0 11/30/2024 22:00 12/1/2024 00:00 2.00 COMPZN, RPCOMP TRIP T TOOH F/8550' T/4300' PUW=148K 8,550.0 12/1/2024 00:00 12/1/2024 01:00 1.00 COMPZN, RPCOMP TRIP T Continue TOOH F/4300' T/270' 4,300.0 270.0 12/1/2024 01:00 12/1/2024 02:15 1.25 COMPZN, RPCOMP BHAH T LD BHA. Fish in overshot. release overshot from fish. 270.0 1,023.0 12/1/2024 02:15 12/1/2024 02:45 0.50 COMPZN, RPCOMP RURD T RU floor to LD tubing 1,023.0 1,023.0 12/1/2024 02:45 12/1/2024 03:30 0.75 COMPZN, RPCOMP PULL T Remove cut joint from overshot19.84' LD Tubing to cut joint. 1,023.0 1,023.0 12/1/2024 03:30 12/1/2024 09:00 5.50 COMPZN, RPCOMP PULL T L/D Tubing F/ 1023' to surface. Cut joint 8.07' long. 1,023.0 0.0 12/1/2024 09:00 12/1/2024 09:30 0.50 COMPZN, RPCOMP CLEN T Clean and clear rig floor. Changeout pipe handling equipment. 0.0 0.0 12/1/2024 09:30 12/1/2024 10:15 0.75 COMPZN, RPCOMP BHAH T B/U BHA # 10. (overshot BHA). 0.0 264.0 12/1/2024 10:15 12/1/2024 13:15 3.00 COMPZN, RPCOMP TRIP T RIH W/ BHA # 10 F/ 264' to 8679' 150 K PUWT 80 K SOWT 264.0 8,679.0 12/1/2024 13:15 12/1/2024 14:15 1.00 COMPZN, RPCOMP CIRC T CBU @ 168 GPM @ 1350 PSI 8,679.0 8,679.0 12/1/2024 14:15 12/1/2024 15:15 1.00 COMPZN, RPCOMP FISH T RIH and attepmt to latch fish, Slack off to 8706' set down 20K. P/U attempt to slack off again w/ Pumps @ 1 BBL/Min @ 600 PSI Set down 30 K observe 50 PSI pressure increase. P/U and rotate @ 20 RPM 8.5K torque, attempt to work past set down 30K 3 times observe pressure increase. P/U stop rotary and pumps. Slack off and set down 30 K @ 8708'. P/U and observe 80K over pull. Jar on fish 11 times pulling up to 300K. 8,679.0 8,708.0 12/1/2024 15:15 12/1/2024 16:00 0.75 COMPZN, RPCOMP FISH T Release over shot. L/D joint of drill pipe, P/U and M/U 5', and 10' pup joints to string. Slack off and re engage fish P/U to 190 K (string and fish in 30K tension) Set slips. 8,708.0 8,708.0 12/1/2024 16:00 12/1/2024 23:30 7.50 COMPZN, RPCOMP SLKL T R/U HAL Slick line. RIH W/2" pump bailer 1-7/8 TS to 9608. POOH W/Bailer. Recovered heavy barite in bailer. RIH W/2" pump bailer 1-7/8 TS to 9716. POOH W/Bailer. Making deminishing progress. Recovered heavy 22 ppg barite in bailer. 8,708.0 8,708.0 12/1/2024 23:30 12/2/2024 00:00 0.50 COMPZN, RPCOMP SVRG T Service draw works 8,708.0 12/2/2024 00:00 12/2/2024 01:00 1.00 COMPZN, RPCOMP ELNE T RU E-Line Re-head, move equipment to floor. RU RCT tool stirng. Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 14/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/2/2024 01:00 12/2/2024 09:00 8.00 COMPZN, RPCOMP ELNE T AK E-Line RIH F/ Surface to 9561'. Attempt to correlate. Over pullin in GLM @ 9550'. Work free. RIH to 9574'. Attempt to correlate. Hang up in GLM w/ tool string. Work tool string free. Locate, and space out to cut @ 9499' (mid joint 2 full joints above GLM). Fire RCT. No clear indications of cut in E-line unit, or rig floor. Attempt to POOH. E-line overpull 1800 LBS line tension. Work string free. POOH F/ 9499' to surface. 12/2/2024 09:00 12/2/2024 11:30 2.50 COMPZN, RPCOMP ELNE T L/D AK E-line tools. Observe indications of RCT firing. Stand back AK E-line. R/D floor equipment. 12/2/2024 11:30 12/2/2024 12:00 0.50 COMPZN, RPCOMP ELNE T Kelly up to string. Attempt to work pipe free. Work pipe up to 200K 2X, Stage up to 350 K. Pipe did not move. 12/2/2024 12:00 12/2/2024 13:00 1.00 COMPZN, RPCOMP ELNE T R/U Floor equipment, and AK E-line equipment on the rig floor. 12/2/2024 13:00 12/2/2024 23:30 10.50 COMPZN, RPCOMP ELNE T AK E-line RIH w/ RCT tool string F/ Surface to 9489' Fired RCT. POOH inspect cutter. Appears to have misfired. Change out RCT TS and PU Hole punch TS. RIH W/Eline to 9502' ELMD, bottom of TS, unable to pass previous attempted cut at 9499' ELMD W/TS. PU and correlate, punch tubing F/9499'- 9502' ELMD. POOH W/Eline RD Eline 12/2/2024 23:30 12/3/2024 00:00 0.50 COMPZN, RPCOMP SVRG T Service Rough neck 12/3/2024 00:00 12/3/2024 02:30 2.50 COMPZN, RPCOMP CIRC T Circulate SxS attempt to circulate out heavy mud through holes from 9499'- 9502'. PR= 2BPM at 1400 PSI. Add 1.5% 776 Lube to system 4200 StKS= 9500' 14.8# in 15.5# out. Sand in returns. Work DP jar 250K straight pull to 350K. Pipe started moving, continue to work pipe. 14' free movement. LD pup joints. 12/3/2024 02:30 12/3/2024 03:30 1.00 COMPZN, RPCOMP FISH T Continue to work fish free weight broke back to 135K 12/3/2024 03:30 12/3/2024 04:30 1.00 COMPZN, RPCOMP PMPO P Pump out of hole 567' PR=3 BPM @ 1200 PSI. PUW=135K 0.0 0.0 12/3/2024 04:30 12/3/2024 06:00 1.50 COMPZN, RPCOMP CIRC P Circulate BUS 4.5 BPM @ 1900 PSI 0.0 0.0 12/3/2024 06:00 12/3/2024 09:00 3.00 COMPZN, RPCOMP TRIP P TOOH F/8738' T/264.63' 0.0 0.0 12/3/2024 09:00 12/3/2024 10:00 1.00 COMPZN, RPCOMP BHAH P LD BHA #10. 0.0 0.0 12/3/2024 10:00 12/3/2024 10:30 0.50 COMPZN, RPCOMP RURD P RU to Lay down tubing. 9,489.0 0.0 12/3/2024 10:30 12/3/2024 13:30 3.00 COMPZN, RPCOMP PULL P Lay down tubing, cutting with tubing hydraulic shear ram. Attempt to brake connection with floor tongs, successful. 0.0 0.0 12/3/2024 13:30 12/3/2024 14:30 1.00 COMPZN, RPCOMP PULL P Cut joint at surface, no indication of string shot, assuming we pulled free from top cut @ 9,489'. 0.0 0.0 12/3/2024 14:30 12/3/2024 14:45 0.25 COMPZN, RPCOMP CLEN P Clean RF 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 15/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/3/2024 14:45 12/3/2024 15:45 1.00 COMPZN, RPCOMP BHAH P MU Overshot, jars, intensifier, and DC 0.0 0.0 12/3/2024 15:45 12/3/2024 21:15 5.50 COMPZN, RPCOMP TRIP P TIH w/BHA #11 F/Surface T/9211' SOW 82K dropped to 65K. TOOH W/3 stands Single in 9 joints 9211' 0.0 9,211.0 12/3/2024 21:15 12/3/2024 23:00 1.75 COMPZN, RPCOMP WASH P Wash down on stands F/9211' T/9488' 3 BPM 1400 PSI PUW=135K SOW=80K Set down 10K at 9488' Rotate and wash down F/9488' T/9490 Rot 25 RPM 3 BPM 1450 PSI 4.8-5.3K TQ. 14.8# in 15.2# out. 9,211.0 9,490.0 12/3/2024 23:00 12/4/2024 00:00 1.00 COMPZN, RPCOMP CIRC P Circulate condition well 3 BPM at 1700PSI until 14.8# in and out. FCP=1640 PSI 12/4/2024 00:00 12/4/2024 01:30 1.50 COMPZN, RPCOMP FISH P Shut down pumps, walk off fish, 7.2K torque release from fish. Space out DP 3' off floor. 12/4/2024 01:30 12/4/2024 05:30 4.00 COMPZN, RPCOMP SLKL P RU Slickline. TS=21' 1.875" OJ, LSS, 3'x2" DD bailer. RIH T/8498' SLMD tagged obstruction worked through continued to RIH to 9700'. PR=2BPM 1900 PSI, Pump pressure increased, reduced rate, PR=1BPM 1900 PSI, POOH W/SL empty bailer MU 2.125" Centralizer to TS. RIH T/9,740' to 9,740'' PR=2 BPM 1900 PSI. 12/4/2024 05:30 12/4/2024 07:30 2.00 COMPZN, RPCOMP SLKL P TOOH w/SL, MU second 2.125" Centrilized BHA TBIH F/surface T/9,750', pretty clean run, stall out pickup and continue in hole will minimal problems to 9,750'. Unable to make foward progress, POOH w/SL, RD and move SL unit out of way, send SL in for sleep, continue to keep them on standby for E-line assistance. 12/4/2024 07:30 12/4/2024 08:30 1.00 COMPZN, RPCOMP ELNE P Move in Eline and rig up to the floor 12/4/2024 08:30 12/4/2024 10:00 1.50 COMPZN, RPCOMP ELNE T Some problems with eline unit, frozen airlines, work with them to get things rolling, spot in and RU to floor. 12/4/2024 10:00 12/4/2024 16:00 6.00 COMPZN, RPCOMP ELNE P MU Eline BHA, cable head (9/32" wire),. 3ea 1-11/16" weight stems, crossover, bow spring centrilizer, magnet de cetralizers top and bottom, and tubing puncher loaded 3'. 4 spf OAL=21' RIH F/surface T/3,000', bring pump online 1.5 bpm/1,260 psi. Continue IH F/3,000' at 140 fpm T/9,753' Tied into the mandrel at 9,555.5' ELMD punch holes 9,750'-9,753' ELMD, POOH w/Eline RD 12/4/2024 16:00 12/4/2024 17:30 1.50 COMPZN, RPCOMP JAR P Bring pump online @ 3 bpm at 1750 psi Jar on fish 1 Hit straight pull to 310K grapple slipped off fish or tubing parted. 12/4/2024 17:30 12/4/2024 18:30 1.00 COMPZN, RPCOMP TRIP P TOOH F/9488' T/8946' PUW=135K 12/4/2024 18:30 12/4/2024 20:00 1.50 COMPZN, RPCOMP CIRC P Circulate BUS 5 BPM at 2200 PSI. 12/4/2024 20:00 12/4/2024 21:30 1.50 COMPZN, RPCOMP TRIP P TOOH F8946' T/2923 PUW=75K Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 16/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/4/2024 21:30 12/4/2024 22:30 1.00 COMPZN, RPCOMP MPSP P PU Storm packer and RIH to Set storm packer. 98.25' top of twin thread COE at 106.59' 12/4/2024 22:30 12/5/2024 00:00 1.50 COMPZN, RPCOMP BOPE P Pull wear ring set test plug. Fill stack with water. Perform shell test to 4500 PSI. Start testing BOPE. Tested BOPE at 250/4500 PSI for 5 Min each, Tested annular to 250/3500 on 3- 1/2" and 4-1/2" test joints, UVBR's on 3- 1/2" and 4-1/2" test joints, and LVBR's on 3-1/2" and 4-1/2" test joints. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, 3-1/2" FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure= 3050 PSI, after closure= 1650 PSI, 200 PSI attained = 16 sec, full recovery attained =118 sec. UVBR's= 6 sec, Annular= 23 sec. Simulated blinds= 6 sec. LVBR’s= 6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2050 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Guy Cook. 12/5/2024 00:00 12/5/2024 05:30 5.50 COMPZN, RPCOMP BOPE P Tested BOPE at 250/4500 PSI for 5 Min each, Tested annular to 250/3500 on 3- 1/2" and 4-1/2" test joints, UVBR's on 3- 1/2" and 4-1/2" test joints, and LVBR's on 3-1/2" and 4-1/2" test joints. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, 3-1/2" FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure= 3050 PSI, after closure= 1650 PSI, 200 PSI attained = 16 sec, full recovery attained =118 sec. UVBR's= 6 sec, Annular= 23 sec. Simulated blinds= 6 sec. LVBR’s= 6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2050 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Guy Cook. 3,037.0 3,037.0 12/5/2024 05:30 12/5/2024 07:00 1.50 COMPZN, RPCOMP RURD P RD Testing equipment 3,037.0 3,037.0 12/5/2024 07:00 12/5/2024 08:00 1.00 COMPZN, RPCOMP TRIP P PU 1 stand, TIH, pull storm packer, 3,037.0 2,919.0 12/5/2024 08:00 12/5/2024 08:30 0.50 COMPZN, RPCOMP CIRC P Circulate SXS 14.8 ppg in and out, 2,919.0 2,919.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 17/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/5/2024 08:30 12/5/2024 10:30 2.00 COMPZN, RPCOMP SLPC P Slip and cut drill line (122' of drill line) While circulating 2 bpm 14.8 ppg in and out Shut down pump Blow down top drive 2,919.0 2,919.0 12/5/2024 10:30 12/5/2024 12:00 1.50 COMPZN, RPCOMP TRIP P TOOH 2,919.0 249.6 12/5/2024 12:00 12/5/2024 13:00 1.00 COMPZN, RPCOMP BHAH P Stand back DC, LD BHA 1.15' of tubing recovered, unable to remove from grapple. Bring new grapple to rig floor Load 3 joints of 5-3/4" wash pipe into the pipe shed and tally 249.6 0.0 12/5/2024 13:00 12/5/2024 13:30 0.50 COMPZN, RPCOMP SVRG P Service Rig 0.0 0.0 12/5/2024 13:30 12/5/2024 15:30 2.00 COMPZN, RPCOMP BHAH P MU Fishing BHA #13 Working single, crossover, ACC, 6 DC, jars, bumper sub, circ sub (burst disk 4,100 psi), tripple connect bushing, 3 joints of 5-3/4" wash pipe, and a 6' Wavy bottom wash shoe. Inner dress off mill 4-3/4" Paranha Mill 0.0 343.5 12/5/2024 15:30 12/5/2024 19:15 3.75 COMPZN, RPCOMP TRIP P TIH, F/343.51' T9461' PUW=145K SOW=88K 343.5 9,461.0 12/5/2024 19:15 12/5/2024 21:15 2.00 COMPZN, RPCOMP WASH P Establish parameters ROT=30 RPM Free Tq=4.8K-5.2K PR=3.25 BPM @1300 PSI ROT=30 RPM Free Tq=4.8K-5.2K PR=4 BPM @1750 PSI RT WT=105 ROT=30 RPM Free Tq=4.8K-5.2K PR=5 BPM @2100 PSI RT WT=105 Wash and ream down F/top of fish 4BPM 9499' T/9551' 7ES RKB. Circulate BUS 4 BPM @1760 PSI. reciprocating pipe over top of fish. 9510'-9545' 7ES RKB 14.8# in 15.2# back at BUS, Sand in returns. 9,461.0 9,545.0 12/5/2024 21:15 12/5/2024 21:45 0.50 COMPZN, RPCOMP OWFF P OWFF blow down top drive and surface lines. 9,415.0 9,415.0 12/5/2024 21:45 12/6/2024 00:00 2.25 COMPZN, RPCOMP TRIP P TOOH F/9515' T/3685' 9,415.0 3,685.0 12/6/2024 00:00 12/6/2024 01:00 1.00 COMPZN, RPCOMP TRIP P TOOH F/3685' T/343.51' 3,685.0 343.5 12/6/2024 01:00 12/6/2024 02:30 1.50 COMPZN, RPCOMP BHAH P LD BHA 343.5 0.0 12/6/2024 02:30 12/6/2024 03:00 0.50 COMPZN, RPCOMP SVRG P Service Black jack on top drive. Clean floor after trip, move overshot extensions to floor. 0.0 0.0 12/6/2024 03:00 12/6/2024 04:00 1.00 COMPZN, RPCOMP BHAH P MU gutted overshot and circ sub to DP. 0.0 43.7 12/6/2024 04:00 12/6/2024 08:00 4.00 COMPZN, RPCOMP TRIP P TIH F/43.68' T/9495' PUW=145k SOW=80K 43.7 9,495.0 12/6/2024 08:00 12/6/2024 10:00 2.00 COMPZN, RPCOMP CIRC P Circulate and condition well 5BPM 2250 PSI. Reciprocate DP. PUW=145K Set down pipe on top of stump at 9500' Bottom of OS at 9507.47' 7ES RKB. 9,495.0 9,495.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 18/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/6/2024 10:00 12/6/2024 22:00 12.00 COMPZN, RPCOMP SLKL P RU Slick line RIH W/2-1/2" bailer 1-3/4" TS LSSS OJ Unable to drift W/2.5" MU 2-3/8"centralizer and 2.25" Bailer Drift tubing. pump down at 1.5 BPM at 1200 PSI Work down to 9654'. MU Welltec Cutter drift assembly Drift tubing to 9608' PR=2 BPM 1350 PSI. POOH RD SL 9,495.0 9,495.0 12/6/2024 22:00 12/7/2024 00:00 2.00 COMPZN, RPCOMP CIRC P RU and circulate well @ 2 BPM 1500 PSI. Continue circulating at 3BPM@ 1750 PSI Spot in and RU E-Line. 9,495.0 9,495.0 12/7/2024 00:00 12/7/2024 00:30 0.50 COMPZN, RPCOMP CIRC P Continue to circulate 3 BPM 1600 PSI 9,495.0 9,495.0 12/7/2024 00:30 12/7/2024 03:00 2.50 COMPZN, RPCOMP ELNE P Continue to circ 3BPM at 1600 PSI RU E-Line, MU TS and Well-tec cutter, anc, CCL. Function test anchor and cutter. Shut down circulation at 2:15 AM. Blled off pressure Remove night cap. Stab TS in DP. 9,495.0 9,495.0 12/7/2024 03:00 12/7/2024 08:30 5.50 COMPZN, RPCOMP ELNE P RIH W/Well-tec cutter on E-Line at 3AM. Correlate depth. Cut tubing @ 9638' (max depth obtained). POOH w/Well-tec cutter. RD E-line 9,495.0 9,495.0 12/7/2024 08:30 12/7/2024 10:30 2.00 COMPZN, RPCOMP CIRC P PUH 10' off tubing stub. Circulating at 5 bpm. Initial press = 2400 psi Returns: 14.8 ppg in, 14.8 ppg out after 175 bbl (BU = 250 bbl) Circulate 2 BU. Final circulating press = 2330 psi 9,495.0 9,485.0 12/7/2024 10:30 12/7/2024 14:00 3.50 COMPZN, RPCOMP TRIP P TOOH from 9485' to surface. PU wt = 135K# 9,485.0 0.0 12/7/2024 14:00 12/7/2024 15:30 1.50 COMPZN, RPCOMP BHAH P PU / MU fishing BHA 0.0 270.2 12/7/2024 15:30 12/7/2024 19:30 4.00 COMPZN, RPCOMP TRIP P TIH w/fishing BHA T/9477' PUW=140K SOW=90K 0.0 9,477.0 12/7/2024 19:30 12/7/2024 19:45 0.25 COMPZN, RPCOMP FISH P Establish Parameters 2BPM 1200 PSI 3BPM 1400 PSI 30 RPM 5.1-5.3K Tq PURot wt=110K SOW RT WT=100K Wash down to top of fish at 9490.83' at 2 BPM Pressure increased to 2400 PSI Shut down pump, bled off pressure. Set down 30K at 9499' PU to 200K weight broke back to 145K Fish moving freely PUH to 9479 9,477.0 9,497.0 12/7/2024 19:45 12/7/2024 20:45 1.00 COMPZN, RPCOMP CIRC P Circ at 2 BPM pressured up to 2600 PSI no circulation Broke circulation, 5BPM at 2200 PSI 14.8# in 15.2# out at BUS Circulated till clean. 9,497.0 9,479.0 12/7/2024 20:45 12/7/2024 22:15 1.50 COMPZN, RPCOMP TRIP P TOOH F/9479' T/9551' 9,479.0 9,551.0 12/7/2024 22:15 12/7/2024 22:45 0.50 COMPZN, RPCOMP SVRG P Hole fill line developed leak transfered to tripping on pill pit. Service rough neck while transferring fluids. 9,551.0 9,551.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 19/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/7/2024 22:45 12/8/2024 00:00 1.25 COMPZN, RPCOMP TRIP P TOOH F/9551' T/6135' PUW= 130K 9,551.0 6,135.0 12/8/2024 00:00 12/8/2024 02:45 2.75 COMPZN, RPCOMP TRIP P Con't TOOH F/6135' T/270' 6,135.0 270.0 12/8/2024 02:45 12/8/2024 03:30 0.75 COMPZN, RPCOMP BHAH P LD BHA #15 12/8/2024 03:30 12/8/2024 04:45 1.25 COMPZN, RPCOMP PULL P Remove fish F/overshot. 12/8/2024 04:45 12/8/2024 05:30 0.75 COMPZN, RPCOMP RURD P RU to LD tubing/change elevators slips and collar. RU cutter. 12/8/2024 05:30 12/8/2024 06:30 1.00 COMPZN, RPCOMP PULL P LD tubing recovered from well. 138.1' 29.26' cut joint. 12/8/2024 06:30 12/8/2024 07:30 1.00 COMPZN, RPCOMP SVRG P Service rig. Repair hole fill line 12/8/2024 07:30 12/8/2024 08:45 1.25 COMPZN, RPCOMP BHAH P MU BHA #16 Wash-pipe BHA. 0.0 459.3 12/8/2024 08:45 12/8/2024 14:30 5.75 COMPZN, RPCOMP TRIP P TIH W/Wash pipe F/459.3' T/9638' Top of fish 459.3 9,600.0 12/8/2024 14:30 12/8/2024 17:00 2.50 COMPZN, RPCOMP WASH P Wash over shoe @ 9600'. Start pump and rotating: 4 bpm @ 2000 psi, 37 RPM @ 5000 ft-lbs. Rotating weight: 100K# hanging, 110K# up, 90K# down. Start washing over tubing @ 9638', no change in press or torque. Washed down to 9828'. No sit down on fill. Torque and press were constant 9,600.0 9,828.0 12/8/2024 17:00 12/8/2024 19:00 2.00 COMPZN, RPCOMP CIRC P Circulating 20 vicous sweep. Reciprocate 100' Pump till clean 3 BUS 5 BPM at 2000 PSI. 9,828.0 9,828.0 12/8/2024 19:00 12/8/2024 19:15 0.25 COMPZN, RPCOMP OWFF P OWFF for 15 minutes 9,828.0 9,828.0 12/8/2024 19:15 12/8/2024 23:00 3.75 COMPZN, RPCOMP TRIP P TOOH F/9828 T/459.3 PUW140K off bottom 9,828.0 459.3 12/8/2024 23:00 12/9/2024 00:00 1.00 COMPZN, RPCOMP BHAH P LD BHA F/459.3 T/surface Rack back wash pipe. 459.3 0.0 12/9/2024 00:00 12/9/2024 01:00 1.00 COMPZN, RPCOMP BHAH P MU outside cutter BHA. 3' dogs to collar 1.4' knives to cut lip. 0.0 397.0 12/9/2024 01:00 12/9/2024 08:00 7.00 COMPZN, RPCOMP TRIP P TIH F/397' T/9557' PUW=140K SOW=90K 397.0 9,557.0 12/9/2024 08:00 12/9/2024 08:30 0.50 COMPZN, RPCOMP SVRG P Grease wash pipe clean floor 9,557.0 9,557.0 12/9/2024 08:30 12/9/2024 10:30 2.00 COMPZN, RPCOMP CPBO P Establish parameters 45 RPM at 5.8-6K Tq 2BPM at 1225 PSI ROT wt=105 ROT PUW=128k SOW ROT=85K 45 RPM 5.4K-5.6K Wet Cut tubing 9815' work tp to 7.2K Tq. Pulled 9K into cutter TQ dropped back to 5.3K PU WT =130K PUH T/9760' no indication of collar at 9785' 9,815.0 9,760.0 12/9/2024 10:30 12/9/2024 11:45 1.25 COMPZN, RPCOMP CIRC P Circulate BUS=4 BPM 2000 PSI 9,760.0 9,760.0 12/9/2024 11:45 12/9/2024 16:30 4.75 COMPZN, RPCOMP TRIP P TOOH F/9760' PUW=145K T/ 400' 9,760.0 400.0 12/9/2024 16:30 12/9/2024 17:30 1.00 COMPZN, RPCOMP BHAH P Rack 4.75" Drill collars in derrick 400.0 150.0 12/9/2024 17:30 12/9/2024 19:00 1.50 COMPZN, RPCOMP BHAH P Rack back washpipe while laying down 191.3' of 3.5" completion tubing fish. 4 of 5 knife blades broken LIH. 150.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 20/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/9/2024 19:00 12/9/2024 21:00 2.00 COMPZN, RPCOMP CLEN P Clean and clear rig floor RU to TIH w/ Washpipe Load BHA components on floor 0.0 0.0 12/9/2024 21:00 12/9/2024 22:00 1.00 COMPZN, RPCOMP BHAH P Pick up wash pipe BHA# 18 0.0 476.7 12/9/2024 22:00 12/10/2024 00:00 2.00 COMPZN, RPCOMP TRIP P TIH F/476.73' T/2170' PUW=63K 476.7 2,170.0 12/10/2024 00:00 12/10/2024 04:00 4.00 COMPZN, RPCOMP TRIP P TIH F/2170' T/9815' Top of fish 2,170.0 9,800.0 12/10/2024 04:00 12/10/2024 06:45 2.75 COMPZN, RPCOMP WASH P Wash over top of fish F/9815' T10014 Top of pup on mandrel unable to pass 5 attempts PR=3 BPM at 1600PSI 9,800.0 10,014.0 12/10/2024 06:45 12/10/2024 08:15 1.50 COMPZN, RPCOMP CIRC P Pump 70 bbls 140 vis sweep, pump till hole clean sand in returns 10,014.0 10,014.0 12/10/2024 08:15 12/10/2024 10:15 2.00 COMPZN, RPCOMP SLPC P Slip and cut 96' drill line 10,014.0 10,014.0 12/10/2024 10:15 12/10/2024 13:30 3.25 COMPZN, RPCOMP TRIP P TOOH with wash over BHA# 18 10,014.0 476.0 12/10/2024 13:30 12/10/2024 15:00 1.50 COMPZN, RPCOMP BHAH P Rack back wash pipe, lay down boot baskets and bit 476.0 0.0 12/10/2024 15:00 12/10/2024 15:30 0.50 COMPZN, RPCOMP SVRG P Change pin on handler lock on TD 0.0 0.0 12/10/2024 15:30 12/10/2024 16:30 1.00 COMPZN, RPCOMP BHAH P Pick up overshot BHA# 19 0.0 270.0 12/10/2024 16:30 12/10/2024 21:00 4.50 COMPZN, RPCOMP TRIP P TIH W/Overshot BHA #19 PUW 145K/ SOW 94K 270.0 9,815.0 12/10/2024 21:00 12/11/2024 00:00 3.00 COMPZN, RPCOMP JAR P Jarring as per Baker Rep. 2BPM at 1200 psi PUW 135K/ SOW 88K 25 RPM 5.2 - 5.7K Torque and 115K RWT Wash down to 9819' pump pressure increased to 2000 psi. Swallow fish T/9827' with 20K DN. Begin jarring at 200K with 250K straight pull. Call town and get permission to pull 100% of tubing yeild strength. Work up to jarring at 250K with 350K straight pull. No movement after 55 jar hits. 9,815.0 9,819.0 12/11/2024 00:00 12/11/2024 01:00 1.00 COMPZN, RPCOMP JAR P Post jarring inspection. Attempt to fire jars multiple times with no luck. Release from fish, 9,819.0 9,819.0 12/11/2024 01:00 12/11/2024 03:00 2.00 COMPZN, RPCOMP CIRC P Circulate and condition mud 4 BPM at 1900 psi until clean. Flow check well- static. BD top drive. 9,819.0 9,800.0 12/11/2024 03:00 12/11/2024 07:00 4.00 COMPZN, RPCOMP TRIP P TOOH for external cutter 9,800.0 275.0 12/11/2024 07:00 12/11/2024 08:00 1.00 COMPZN, RPCOMP BHAH P Rack back collars and lay down overshot // Found burst disc ruptured, pack-off 275.0 0.0 12/11/2024 08:00 12/11/2024 09:30 1.50 COMPZN, RPCOMP BHAH P Pick up external cutter bha w/ washpipe 0.0 394.0 12/11/2024 09:30 12/11/2024 14:00 4.50 COMPZN, RPCOMP TRIP P TIH with external cutter and washpipe 394.0 9,800.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 21/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/11/2024 14:00 12/11/2024 16:30 2.50 COMPZN, RPCOMP CPBO P Up Wt 143k Dn wt 90k // Drift over top of stump, continue in hole to 9845' stack out on "fill", turn on pumps 3 bpm @ 1,470psi continue to wash in hole T/ 9985' start gaining torque @ 9970', up to 6500 ft lbs from free @ 5500 ft/lbs, unable to determine if cut was made after 45 min, pick up hole 8k overpull broke free, undetermined if fish is in washpipe 9,800.0 9,985.0 12/11/2024 16:30 12/11/2024 17:00 0.50 COMPZN, RPCOMP OWFF P Flow check well, blow down TD, start to TOOH and dragging junk uphole. 9,985.0 9,764.0 12/11/2024 17:00 12/11/2024 18:30 1.50 COMPZN, RPCOMP CIRC P Circulate and condition mud. Pump 5BPM AT 2700 PSI until returns are clean. 9,764.0 9,764.0 12/11/2024 18:30 12/12/2024 00:00 5.50 COMPZN, RPCOMP TRIP P TOOH at 80 FPM F/9764' PUW 145K T/ suface. Cut tubing stub was inside the washpipe. 9,764.0 0.0 12/12/2024 00:00 12/12/2024 02:00 2.00 COMPZN, RPCOMP BHAH P Called phase 3 weather at 00:15 LD outside cutter BHA #20 LD 155.2' tubing fish 155.0 0.0 12/12/2024 02:00 12/12/2024 03:00 1.00 COMPZN, RPCOMP TRIP P TIH with 2555' DP kill string. 0.0 2,555.0 12/12/2024 03:00 12/13/2024 00:00 21.00 COMPZN, RPCOMP WAIT T Shut down for Phase 3 called field wide at 00:15. Circulating 2 BPM at 300 psi to prevent fresh water mud from freezing. 2,555.0 2,555.0 12/13/2024 00:00 12/13/2024 16:30 16.50 COMPZN, RPCOMP WAIT T Phase 3 called field wide at 00:15 on 12/12/24. Circulating 2 BPM at 300 psi to prevent fresh water mud from freezing. 2,555.0 2,555.0 12/13/2024 16:30 12/13/2024 17:30 1.00 COMPZN, RPCOMP SLPC P Slip and cut 55' drill line. Inspect breaks and rollers/. Calibrate blocks. 2,555.0 2,555.0 12/13/2024 17:30 12/13/2024 18:00 0.50 COMPZN, RPCOMP SVRG P Grease crown, blocks, Black Jak, top drive and draw works. 2,555.0 2,555.0 12/13/2024 18:00 12/13/2024 19:00 1.00 COMPZN, RPCOMP TRIP P Trip out of hole for wash pipe BHA. UWT 60K / SOW 55K 2,555.0 0.0 12/13/2024 19:00 12/13/2024 22:00 3.00 COMPZN, RPCOMP BHAH P MU washpipe BHA #21 (wash shoe, 3jts of washpipe, 3200 psi burst sub, 4 3/4" jars, 6 DC's) 0.0 304.0 12/13/2024 22:00 12/14/2024 00:00 2.00 COMPZN, RPCOMP TRIP P Trip in hole with BHA #21 on stands of DP F/304' T/3900' PUW78K / SOW 65K 304.0 3,900.0 12/14/2024 00:00 12/14/2024 03:00 3.00 COMPZN, RPCOMP TRIP P Trip in hole with BHA #21 on stands of DP F/3900' T/9955' PUW 145K / SOW 90K 3,900.0 9,955.0 12/14/2024 03:00 12/14/2024 05:00 2.00 COMPZN, RPCOMP REAM P Reaming and washing to top of GLM at 10,019' 9,955.0 10,008.0 12/14/2024 05:00 12/14/2024 07:30 2.50 COMPZN, RPCOMP CIRC P Circulate Sweeps S x S // 18.2# returns on bottoms up // condition mud for continuing well work 10,008.0 10,006.0 12/14/2024 07:30 12/14/2024 09:00 1.50 COMPZN, RPCOMP TRIP P Blow down TD and stand pipe, OWFF, TOOH for fishing assembly 10,006.0 6,334.0 12/14/2024 09:00 12/14/2024 11:00 2.00 COMPZN, RPCOMP RGRP T Repair drawworks coupler to dynamatic // Install head pin circulate @ 2 bpm 867 psi 6,334.0 6,334.0 12/14/2024 11:00 12/14/2024 13:00 2.00 COMPZN, RPCOMP TRIP P Continue out of hole with wash over BHA 6,334.0 304.0 12/14/2024 13:00 12/14/2024 14:00 1.00 COMPZN, RPCOMP BHAH P Lay down wash pipe BHA # 21 304.0 0.0 12/14/2024 14:00 12/14/2024 15:30 1.50 COMPZN, RPCOMP BHAH P Pick up BHA# 22 overshot fishing BHA, 0.0 224.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 22/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/14/2024 15:30 12/14/2024 19:30 4.00 COMPZN, RPCOMP TRIP P Trip in hole engage fish @ 9965' PUW 145K / SOW 90K 224.0 9,965.0 12/14/2024 19:30 12/14/2024 22:30 3.00 COMPZN, RPCOMP CIRC P Circulate and condition mud at 4 bpm / 1975 psi 20 rpm, 4.5K TQ, 115K PUW, 105K RWT, 100K SOW Swallow tubing stub. Jar on fish 13 licks and 300K overpulls. No movement. Attempt to shear burst disk with 3900 psi no shear. 9,965.0 9,970.0 12/14/2024 22:30 12/14/2024 23:00 0.50 COMPZN, RPCOMP SVRG P Service iron rough neck. 9,970.0 9,970.0 12/14/2024 23:00 12/15/2024 00:00 1.00 COMPZN, RPCOMP SLKL P Safety meeting and RU SL. 9,970.0 9,970.0 12/15/2024 00:00 12/15/2024 03:30 3.50 COMPZN, RPCOMP SLKL P RIH with SL to bail barite and sand down to 10,665'. Tag at 9920'. 9,970.0 9,920.0 12/15/2024 03:30 12/15/2024 16:30 13.00 COMPZN, RPCOMP SLKL P POOH with bailer and attempt to shear out burst disc. Sheared at 3400 psi., continue with bailing operations // unable to make progress past 9996' rig down slick line 9,920.0 9,970.0 12/15/2024 16:30 12/15/2024 22:30 6.00 COMPZN, RPCOMP TRIP P Release grapple and trip out of hole with fishing BHA. F/9970' T/223' UWT 145K/ SOW 90K 9,970.0 223.0 12/15/2024 22:30 12/15/2024 23:30 1.00 COMPZN, RPCOMP BHAH P Lay down fishing BHA #22 Clean and clear rig floor. 223.0 0.0 12/15/2024 23:30 12/16/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service blocks 0.0 0.0 12/16/2024 00:00 12/16/2024 01:00 1.00 COMPZN, RPCOMP BHAH P MU BHA #23 (burn over shoe, 4 jts of wash pipe, 3200 psi burst disc, two boot baskets, two string magnets, 4-3/4" jars and six drill collars). 0.0 378.2 12/16/2024 01:00 12/16/2024 08:00 7.00 COMPZN, RPCOMP TRIP P TIH F/378 T/9970' UWT = 145/ SOW = 90 378.2 9,970.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 23/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/16/2024 08:00 12/16/2024 14:00 6.00 COMPZN, RPCOMP REAM P Burn over GLM @ 10008' // Tag top of fish @ 9971' rot over // Free rot 4700 ft/lbs pump 3.5 bpm @ 1900 psi Up wt 145 Dn wt 95 // wash/ream down to top of GLM 10007' ( 7ES RKB ) // Dry tag top of GLM again 10007' // Pump 3.5 bpm @ 1980 psi Rot 42 rpm @ 4800 ft/lbs 0845 - Start burning over GLM @ 10007' ( 5200 - 6500 ft/lbs ) 2K-5K WOB 0900- 10009' ( 60 RPM @ 5600-6200 Ft/lbs ) PP 1936 psi @ 3.5 bpm 0915- 10009.9 ( 60 RPM @ 5200 - 5600 Ft/lbs ) PP 2000 psi @ 3.5 bpm 0930- 10010.13' ( 60 rpm @ 5400 ft/lbs ) PP 1974 psi @ 3.5 bpm 0945- 10010.57' ( 60 rpm @ 5400 ft/lbs ) PP 1951 psi @ 3.5 bpm 5K-6k WOB 1000- 10011' ( 80 rpm @ 5300 ft/lbs ) PP 1950 psi @ 3.5 bpm 5K-6K WOB 1015- 10011.41' ( 80 rpm @ 5250 ft/lbs ) PP 1988 psi @ 3.5 bpm 5K-6K WOB 1030- 10011.88' ( 80 rpm @ 5260 ft/lbs ) PP 2006 psi @ 3.5 bpm 5K-7K WOB 1100- 10012.68' ( 80 rpm @ 5250 ft/lbs ) PP 2000 psi @ 3.5 bpm 5K-6K WOB 1130- 10013.26' ( 80 rpm @ 5200 ft/lbs ) PP 2040 psi @ 3.5 bpm 5K-6K WOB 1200- 10014.10' ( 80 rpm @ 5150 ft/lbs ) PP 1971 psi @ 3.5 bpm 5K-7K WOB 1230- 10015' ( 80 rpm @ 5300 ft/lbs ) PP 1870 psi @ 3.5 bpm 5K-8K WOB 1300- 10015.85' ( 80 rpm @ 6000 ft/lbs ) PP 1860 psi @ 3.5 bpm 5K-8K WOB 1330- 10015.91' Torque up, work string up above GLM 3 times no increase in pump pressure ( 1890 psi 3.5 bpmi ), max 10k overpull, no formation on shakers, work down to 10016.22' with free torque of 4000 ft/lbs, put 11.5K WOB no increase in torque increase wt on bit T/ 14K no progress .... ~285# of metal returned 9,970.0 10,016.0 12/16/2024 14:00 12/16/2024 15:30 1.50 COMPZN, RPCOMP TRIP P TOOH to inspect BHA. UWT = 145K / SOW = 90 10,016.0 7,120.0 12/16/2024 15:30 12/16/2024 16:00 0.50 COMPZN, RPCOMP SVRG P Rig service grease DW, tongs Blocks and Blackjak. 7,120.0 7,120.0 12/16/2024 16:00 12/16/2024 18:30 2.50 COMPZN, RPCOMP TRIP P TOOH to inspect BHA UWT = 122K / SOW = 70K 7,170.0 378.2 12/16/2024 18:30 12/16/2024 21:00 2.50 COMPZN, RPCOMP BHAH P Lay down BHA #23. Burn over shoe wore out. 378.2 0.0 12/16/2024 21:00 12/16/2024 23:30 2.50 COMPZN, RPCOMP BHAH P PU BHA #24 second burn over shoe 0.0 378.2 12/16/2024 23:30 12/17/2024 00:00 0.50 COMPZN, RPCOMP TRIP P TIH F/378 T/849 UWT=50K / SOW 50K 378.2 849.0 12/17/2024 00:00 12/17/2024 05:00 5.00 COMPZN, RPCOMP TRIP P TIH F/849 T/10,016' UWT=50K / SOW 50K 849.0 10,016.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 24/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/17/2024 05:00 12/17/2024 08:15 3.25 COMPZN, RPCOMP REAM P Dry tag @ 10015.9' // Get free sping numbers = 3.5 bpm @ 1830 psi, Rot 61 rpm @ 5200 ft/lbs, // 0600- 10015.85' ( 60 rpm @ 5500 ft/lbs ) PP 1830 psi @ 3.5 bpm 5K-6K WOB 0730- 10016.39' ( 78 rpm @ 5500 ft/lbs ) PP 1121 psi @ 1 bpm 10K WOB 0815- 10017.05' ( 80 rpm @ 5500-6500 ft/lbs ) PP 833 @ .5 bpm 14K WOB 10,016.0 10,016.0 12/17/2024 08:15 12/17/2024 08:45 0.50 COMPZN, RPCOMP OTHR P Blow down TD. Prep rig floor to trip out of the hole 10,016.0 10,016.0 12/17/2024 08:45 12/17/2024 12:00 3.25 COMPZN, RPCOMP TRIP P POOH F/ 10,016' to 377' 10,016.0 377.0 12/17/2024 12:00 12/17/2024 14:30 2.50 COMPZN, RPCOMP BHAH P L/D BHA F/ 377' to Surface. 377.0 0.0 12/17/2024 14:30 12/17/2024 15:00 0.50 COMPZN, RPCOMP SVRG P Service top drive. 0.0 0.0 12/17/2024 15:00 12/17/2024 15:45 0.75 COMPZN, RPCOMP BHAH P P/U BHA # 25 Overshot fishing BHA F/ Surface to 228' 0.0 228.0 12/17/2024 15:45 12/17/2024 19:45 4.00 COMPZN, RPCOMP TRIP P RIH F/ 228' T/9914' UWT 145K / SOW 95K / RWT 115K 1.5-4 BPM at 1118-1730 psi 228.0 9,914.0 12/17/2024 19:45 12/17/2024 21:00 1.25 COMPZN, RPCOMP FISH P Swallow TBG stub at 9978' Pull 100K over UWT without cocking jars several times. Fish pulled free 9,914.0 9,978.0 12/17/2024 21:00 12/17/2024 23:30 2.50 COMPZN, RPCOMP CIRC P Pump sweep surface to surface. Pump 15 bbl 16.2 ppg dry job. 9,978.0 9,911.0 12/17/2024 23:30 12/18/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service rig, grease crown. 9,911.0 9,911.0 12/18/2024 00:00 12/18/2024 05:00 5.00 COMPZN, RPCOMP TRIP P TOOH F/991' T/332' UWT 145K 9,911.0 332.0 12/18/2024 05:00 12/18/2024 06:30 1.50 COMPZN, RPCOMP BHAH P POOH Racking back/ L/D BHA F/ 332' to 104'. 332.0 104.0 12/18/2024 06:30 12/18/2024 07:30 1.00 COMPZN, RPCOMP PULL P R/U Cutter, and cut GLM. L/D pup Jt. and top portion of GLM. L/D remaining joints of 3.5" tubing. 104.0 0.0 12/18/2024 07:30 12/18/2024 09:00 1.50 COMPZN, RPCOMP BHAH P P/U Overshot, Jars and bumper sub. B/O over shot and remove 4' section of tubing from over shot. RIH w/ stand of wash pipe in the derrick and L/D. 0.0 0.0 12/18/2024 09:00 12/18/2024 11:30 2.50 COMPZN, RPCOMP OTHR P Pull Wear ring, flush stack and set test plug. R/U to test BOP. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 25/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/18/2024 11:30 12/18/2024 16:00 4.50 COMPZN, RPCOMP BOPE P Pull wear ring set test plug. Fill stack with water. Perform shell test to 4500 PSI. Start testing BOPE. Tested BOPE at 250/4500 PSI for 5 Min each, Tested annular to 250/3500 on 3- 1/2" and 4-1/2" test joints, UVBR's on 3- 1/2" and 4-1/2" test joints, and LVBR's on 3-1/2" and 4-1/2" test joints. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, 3-1/2" FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure= 3040 PSI, after closure= 1650 PSI, 200 PSI attained = 18 sec, full recovery attained =114 sec. UVBR's= 6 sec, Annular= 23 sec. Simulated blinds= 6 sec. LVBR’s= 6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2052 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Adam Earl. 0.0 0.0 12/18/2024 16:00 12/18/2024 16:30 0.50 COMPZN, RPCOMP OTHR P R/D Test equipment, Blow down lines. Pull test plug set wear bushing. 0.0 0.0 12/18/2024 16:30 12/18/2024 18:00 1.50 COMPZN, RPCOMP BHAH P P/U BHA # 26 Clean out BHA 0.0 285.0 12/18/2024 18:00 12/18/2024 22:00 4.00 COMPZN, RPCOMP TRIP P TIH F/285' T/9275' UWT 140K / SOW 95K 285.0 9,275.0 12/18/2024 22:00 12/18/2024 23:30 1.50 COMPZN, RPCOMP SLPC P Slip and cut 112' 9,275.0 9,275.0 12/18/2024 23:30 12/19/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service rig floor equipment. 9,275.0 9,275.0 12/19/2024 00:00 12/19/2024 01:15 1.25 COMPZN, RPCOMP TRIP P Tag the top of tubing stub at 10,080 9,275.0 10,080.0 12/19/2024 01:15 12/19/2024 04:00 2.75 COMPZN, RPCOMP MILL P Washing over the outside of the tubing F/10,080 T10,092. Clean up the top of the tubing stub. Milled one foot off tubing stub F/10,080 T/10,081'. 10,080.0 10,092.0 12/19/2024 04:00 12/19/2024 07:30 3.50 COMPZN, RPCOMP CIRC P Pump around 25 BBLS 200 Vis sweep. Increase in barite, and Frac sand over the shakers. Pump second 40 BBL high vis sweep around, increase in barite, and frac sand observed. Continue to circulate until well cleaned up. 10,092.0 10,092.0 12/19/2024 07:30 12/19/2024 08:30 1.00 COMPZN, RPCOMP CIRC P Rack back one stand of drill pipe. R/U to test CSG. attempt to test CSG. Pressure reading 500 PSI on pump gauge, and 0 PSI on chart recorder. Trouble shoot descrepency. Check lines for blockage, Kelly up to string and circulate string volume. 10,092.0 10,028.0 12/19/2024 08:30 12/19/2024 11:00 2.50 COMPZN, RPCOMP PRTS P R/U and pressure test CSG to 500 PSI on chart recorder: GOOD TEST 10,028.0 10,028.0 12/19/2024 11:00 12/19/2024 20:30 9.50 COMPZN, RPCOMP PULD P POOH L/D Drill pipe F/ 10,028' to 285'. UWT 150K / SOW 90K 10,028.0 285.0 12/19/2024 20:30 12/19/2024 23:30 3.00 COMPZN, RPCOMP BHAH P LD CO BHA #26. Pull wear ring. 285.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 26/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/19/2024 23:30 12/20/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service rig, grease iron rough neck and draw works. 0.0 0.0 12/20/2024 00:00 12/20/2024 02:00 2.00 COMPZN, RPCOMP RURD P Jet the stack and wellhead. RU the floor to run tubing. 0.0 0.0 12/20/2024 02:00 12/20/2024 16:30 14.50 COMPZN, RPCOMP PUTB P PU and run 3.5", L-80, EUE-M tubing, TQ to 3030 ftlb. F/ Surface to 10,066' PUWT: 90 K SOWT: 62 K 0.0 10,066.0 12/20/2024 16:30 12/20/2024 19:00 2.50 COMPZN, RPCOMP HOSO P Obtain parameters, continue to slack off. Observe shear screws shear @ 10K @ 10,090' W/ 12 k down. COntinue to slack off to NO GO @ 10093'. Set down 5K to confirm No Go. L/D 3 JTS. Calculate space out. P/U 10.16, 10.19', and 6.19'. P/U Two joints of tubing, M/U tubing hanger, and landing joint. 10,066.0 10,090.0 12/20/2024 19:00 12/20/2024 19:30 0.50 COMPZN, RPCOMP THGR P Land tubing hanger RILDS. Test tubing hanger to 2500 psi for 10 min. Good test. 10,090.8 10,090.8 12/20/2024 19:30 12/20/2024 21:00 1.50 COMPZN, WHDBOP MPSP P LD landing joint. Suck out BOP stack. Set BPV. Pressure test to 500 psi for 10 min. Good test. 0.0 0.0 12/20/2024 21:00 12/20/2024 23:30 2.50 COMPZN, WHDBOP RURD P CO Elevators, flush BOPS w/H2O, BD TD and suck out BOPs. Pull rotary table/steam table and clean out. 0.0 0.0 12/20/2024 23:30 12/21/2024 00:00 0.50 COMPZN, WHDBOP SVRG P Grease rotary table yolks. 0.0 0.0 12/21/2024 00:00 12/21/2024 05:30 5.50 COMPZN, WHDBOP NUND P RD BOPE stack and NU tree. 0.0 0.0 12/21/2024 05:30 12/21/2024 06:00 0.50 COMPZN, WHDBOP SEQP P Test hanger neck seals, and adaptor flange void on tree to 5000 PSI for 10 min. 0.0 0.0 12/21/2024 06:00 12/21/2024 07:30 1.50 COMPZN, WHDBOP SEQP P R/U LRS, and test tree to 5000 PSI for 10 min. On first attempt companion flange on tree valve leaked @ 800 PSI. Tighten bolts. Second attempt Good test to 5000 PSI. 0.0 0.0 12/21/2024 07:30 12/21/2024 07:45 0.25 COMPZN, WHDBOP MPSP P P/U T-bar and pull test dart, and BPV. 0.0 0.0 12/21/2024 07:45 12/21/2024 08:00 0.25 COMPZN, WHDBOP OTHR P PJSM for displacement. 0.0 0.0 12/21/2024 08:00 12/21/2024 09:00 1.00 COMPZN, WHDBOP CIRC P Attempt to reverse circulate. Circulation established @ 1200 PSI @ .5 BBL/Min. 0.0 0.0 12/21/2024 09:00 12/21/2024 13:00 4.00 COMPZN, WHDBOP CIRC P Line up and circulate down tubing, and displace well with 11.3 PPG brine. ICP: 1700 PSI @ 1.5 BBL/ Min FCP: 1480 PSI @ 3 BBL/Min. 0.0 0.0 12/21/2024 13:00 12/21/2024 16:00 3.00 COMPZN, WHDBOP CIRC P Rig up and circulate in 11.3 CI Brine 3 BBL/Min @ 760 PSI. Pump 420 BBLS. Clean CI back to surface. 0.0 0.0 12/21/2024 16:00 12/21/2024 17:00 1.00 COMPZN, WHDBOP OTHR P Blow down lines, and R/U Lubricator extension to drop ball and rod ontop of tree. 0.0 0.0 12/21/2024 17:00 12/21/2024 18:00 1.00 COMPZN, WHDBOP PACK P Drop Ball and Rod (1-5/16" ball x 108" long roller rod without wheels, allow rod to fall for 30 minutes, and RD lubricator. RU to pump down tubing and monitor tubing and IA on chart recorder. Pressure up to 3500 psi and set packer. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Page 27/27 3K-24 Report Printed: 1/14/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/21/2024 18:00 12/21/2024 19:30 1.50 COMPZN, WHDBOP PRTS P Hold 3500 psi on tubing and chart for 30 minutes. Good test. Bleed the tubing pressure to 1000 psi and Pressure up on the IA to 1575 psi and chart for 30 minutes. Good test. Dumped pressure on Tubing and sheared the SOV. Note: Derated the 2500 psi IA test to 1575 psi since we had 11.3 ppg brine in the hole instead of 8.5 ppg. At 6427' TVD (packer depth) there is already 936 psi more pressure due to hydrostatic head. Called and cleared this with on call engineer. 0.0 0.0 12/21/2024 19:30 12/21/2024 21:30 2.00 COMPZN, WHDBOP FRZP P LRS pump 85 bbls diesel FP down IA and up tubing at 2 BPM / 1000 psi. Let well U-tube IA into tubing. 0.0 0.0 12/21/2024 21:30 12/22/2024 00:00 2.50 COMPZN, WHDBOP FRZP P Prep sub/pits for move. RD berming while well is U-tubing. RD IA jumper to Tubing. Release rig at mdnight. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/22/2024 Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: SLM 10,326.03K-24 3/14/2011 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Install GLD, pull B&R, pull RHC plug body3K-24 1/12/2025rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: Foam FCO - lost returns. Deepest point reached was 13550'' CTM.9/26/2000 triplwj Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 42.0 112.0 112.062.58 H-40 Welded SURFACE 9 5/8 8.83 40.4 5,936.8 4,091.0 40.00 L-80 BTC PRODUCTION 7 6.28 38.1 10,521.8 6,633.7 26.00 L-80 BTC-MOD SLOTTED LINER 4 1/2 3.60 10,104.9 14,073.0 12.60 L-80 IBT-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 37.2 Set Depth … 10,090.0 String Max No… 3 1/2 Set Depth … 6,486.4 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 37.237.20.00 Hanger FMC Tubing hanger Gen 5FMC 3,391.4 2,620.5 57.04 Mandrel – GAS LIFT 5.957 Camco MMG 3 1/2"x 1.5" SN: 24758-05 SLB MMG2.920 6,793.5 4,580.0 54.99 Mandrel – GAS LIFT 5.957 Camco MMG 3 1/2"x 1.5" SN 24758- 04 SLB MMG2.920 8,477.6 5,560.7 53.80 Mandrel – GAS LIFT 5.957 Camco MMG 3 1/2"x 1.5" SN 24758- 03 SLB MMG2.920 9,726.5 6,282.2 54.07 Mandrel – GAS LIFT 5.957 Camco MMG 3 1/2"x 1.5" SN 24758 -02 SLB MMG2.920 9,972.86,425.7 56.56 Packer 5.995 SLB BLUE PACK MAX RH SN C24P-0242 BLUPAC K MAX RH SLB 2.894 10,030.26,456.6 58.54 Nipple - X 3.9522.813" X-nipple SN: 0005106937-10 HAL X Nipple 2.813 10,083.1 6,483.1 61.51 Overshot 6.000 Poorboy Overshot 3' off of fully located. PESI PBOS 3.610 Top (ftKB) 10,086.5 Set Depth … 10,124.0 String Max No… 3 1/2 Set Depth … 6,501.9 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,110.16,495.7 63.03 LOCATOR4.500Baker Locator Baker 3.958 10,111.26,496.263.07 SEAL ASSY4.500Baker Seal Assembly Baker 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 10,130.0 6,504.6 63.75 LEAK - TUBING LEAK IDENTIFIED @ ~10,130' (LINER DETAIL TALLY DATED 1/23/98) 11/3/2024 3.600 10,138.5 6,508.364.10 LEAK - TUBING LEAK IDENTIFIED @ BAKER FLAPPER VALVE (LINER DETAIL TALLY DATED 1/23/98) 11/3/2024 3.800 10,195.8 6,532.6 65.36 PLUG 230-450 HEX PLUG, MOE = 10,200' RKB, OAL = 8.40', 2.5" GS FISHING NECK INTERW ELL HEX PLUG SN: 53707 3 10/30/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 3,391.4 2,620.5 57.04 1 GAS LIFT GLV RK 1 1/21,165.01/11/2025 Camco MMG0.188 6,793.5 4,580.0 54.99 2 GAS LIFT GLV RK 1 1/21,170.01/11/2025 Camco MMG0.250 8,477.6 5,560.7 53.80 3 GAS LIFT GLV RK 1 1/21,180.01/11/2025 Camco MMG0.313 9,726.5 6,282.2 54.07 4 GAS LIFT OVRK1 1/21/11/2025 Camco MMG0.313 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,104.9 6,493.3 62.84 PACKER 5.960 BAKER ZXP LINER TOP PACKER 4.430 10,133.6 6,506.1 63.90 NIPPLE 5.375 CAMCO 'DB' NIPPLE 3.750 10,138.5 6,508.3 64.10 VALVE 4.500 BAKER FLAPPER KOIV VALVE 3.810 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 10,516.0 14,038.0 6,632.8 6,695.5 A-1, A-2, A-3, A- 4, 3K-24 1/30/1999 99.0 IPERF Slotted liner. Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 10,516.014,038.0 1 FRAC 7/8/2007 0.00.00 0.00 3K-24, 1/13/2025 9:13:38 AM Vertical schematic (actual) SLOTTED LINER; 10,104.9- 14,073.0 IPERF; 10,516.0-14,038.0 FRAC; 10,516.0 PRODUCTION; 38.1-10,521.8 PLUG; 10,195.8 LEAK - TUBING; 10,138.5 LEAK - TUBING; 10,130.0 Nipple - X; 10,030.2 Packer; 9,972.8 Mandrel – GAS LIFT; 9,726.5 Mandrel – GAS LIFT; 8,477.6 Mandrel – GAS LIFT; 6,793.5 SURFACE; 40.4-5,936.8 Mandrel – GAS LIFT; 3,391.4 CONDUCTOR; 42.0-112.0 KUP PROD KB-Grd (ft) 46.40 RR Date 1/31/1999 Other Elev… 3K-24 ... TD Act Btm (ftKB) 14,073.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292293500 Wellbore Status PROD Max Angle & MD Incl (°) 94.78 MD (ftKB) 11,474.80 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 130 Date 12/22/2013 Comment SSSV: NIPPLE ORIGINATED TRANSMITTAL DATE: 1/7/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5178 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5178 3K-24 50029229350000 Tubing Cut Record 22-Nov-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 198-249 T39931 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.08 08:04:38 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ORIGINATED TRANSMITTAL DATE: 1/7/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5178 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5178 3K-24 50029229350000 Tubing Cut Record 22-Nov-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 198-249 T39931 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.08 08:04:38 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ORIGINATED TRANSMITTAL DATE: 11/22/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5165 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5165 3K-24 50029229350000 Tubing Cut Record 12-Nov-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 198-249 T39794 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.22 09:40:06 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Cc:Roby, David S (OGC); Davies, Stephen F (OGC); Loepp, Victoria T (OGC) Subject:APPROVED: 198-249 3K-24 10-403 Date:Thursday, November 14, 2024 3:22:25 PM Attachments:TOC Email.pdf Grace – This is a rushed approved Sundry ready for the commies. Dave is out of office so we are going to proceed without his signature on the revision (he signed the original). Please add the attached “TOC Email” to the end of the sundry. Thank you! Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 Office (907) 227-2760 Cell CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Klem, Adam To:Lau, Jack J (OGC) Cc:Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]198-249 3K-24 Date:Thursday, November 14, 2024 7:51:40 AM For 3K-24 I show we pumped 210 sacks of cement equaling 245.7 cuft of cement. I calculated 16.7 cuft for the shoe giving us 229cuft in the OA. Assuming gauge hole that is 1806ft of cement, or a TOC of 8715’ MD. I could not find any CBL showing TOC. From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Wednesday, November 13, 2024 11:14 AM To: Klem, Adam <Adam.Klem@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]198-249 3K-24 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Adam – Can you verify where TOC and method of verification method for the 7” production casing? This is a detail we like to see on stacker packer applications. Thanks, Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 Office (907) 227-2760 Cell 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 14073'3365 None Casing Collapse Conductor Surface Production Slotted Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-263-4529 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 10069' 9-5/8" 70'112' Baker ZXP Liner Top SSSV: Camco DB Nipple 6826'10069'6476' 7" 16" KRU 3K-24 10516-14038' 10484' 4-1/2"" 6633-6696' 5896' 10522' Perforation Depth MD (ft): 14073'3968' 4-1/2" X 3-1/2" 6696' 112' 5937' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025519 198-249 P.O. Box 100360, Anchorage, AK 99510 50-029-22935-00-00 ConocoPhillips Alaska, Inc Will perfs require a spacing exception due to property boundaries? AOGCC USE ONLY Tubing MD (ft): 10105'MD/6493'TVD 508'MD/507'TVD 10124' Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Proposed Pools: 4091' Burst 11/10/2024 Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field TVD Perforation Depth TVD (ft): MD 6634' Adam Klem adam.klem@conocophillips.com RWO/CTD Engineer Subsequent Form Required: Suspension Expiration Date: m n P s 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Tubing Grade: L-80 324-574 By Grace Christianson at 1:16 pm, Nov 14, 2024 Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem@ conocophillips.com, C=US Reason: I am approving this document Location: Date: 2024.11.14 12:28:54-09'00' Foxit PDF Editor Version: 13.0.0 Adam Klem SFD 11/14/2024JJL 11/14/24 X 6,696'SFD BOP Test to 4500 psi. Annular to 3500 psi. 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.15 08:22:27 -09'00'11/15/24 RBDMS JSB 111524 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 19, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 3K-24 (PTD# 198-249). Well 3K-24 was drilled in 1999 as a Kuparuk A sand producer. It was subsequently frac’d in 2007. It has never been worked over and has the original tubing, which developed multiple tubing leaks. To bring the well back online, we request approval to proceed with a pre rig tubing cut above the packer and then rig workover to pull and replace the tubing and stack a packer above a pre rig tubing cut stub. The 4.5 x 3.5” tubing will be pulled from a pre-rig cut above the packer, and a new 3.5” completion including a non-sealing overshot, gas lift mandrels, and a stacked packer will be installed. If you have any questions or require any further information, please contact me at 907-263-4529. Adam Klem Rig Workover Engineer CPAI Drilling and Wells Digitally signed by Adam Klem DN: CN=Adam Klem, E= adam.klem@conocophillips.com, C=US Reason: I am approving this document Location: Date: 2024.11.14 12:29:23-09'00' Foxit PDF Editor Version: 13.0.0 Adam Klem 3K-24 Kuparuk Producer Pull and Replace Tubing with Stacked Packer RWO PTD: 198-249 Page 1 of 2 PPre-Rig Work Completed 1. Dummy off all GLM, leaving lowest GLV open for circulation 2. T-POT/PPPOT and IC-POT/PPPOT. a. Passing POTs-Tbg & IC passing PPOTs-Tbg & IC 10/3/24 3. Function test LDS. 4. Pull MA2 plug from nipple at 10,069’ 5. Get updated SBHP 6. Set new plug in the 4.5” liner a. Appears to be leak above plug, below liner top packer Pre-Rig Work Remaining 7. Diagnose leak in liner. Investigate possible plug higher, but unlikely we will be able to isolate well from formation. 8. Cut tubing at ~10,090’ RKB 9. Combo pressure test tubing and casing to 2500psi a. Unlikely if we can’t set a plug above leak in liner 10. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3K-24. No BPV will be set for MIRU due to Nabors 7ES internal risk assessment. 2. Circulate seawater 14.5ppg kill weight mud. Record shut-in pressures on the T & IA. Circulate KWF as needed and complete 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND tree, NU BOPE and test to 250/3,500 4500psi. Test annular 250/3,500 4500psi. Retrieve 4.5” by 3.5” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4.5” by 3.5” tubing down to the pre-rig cut at ~10,090’ RKB. Cleanout to Tubing Stub 6. PU DP. RIH with casing scraper and dress off mill to tubing stub and dress off stub as needed. POOH LD DP. Install 3.5” Completion with Stacked Packer 7. MU new 3.5” completion with non-sealing overshot, packer, nipple profile, and GLMs. RIH to tubing stub. 8. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 9. Land tubing hanger, RILDS, drop ball/rod, and set packer. 10. Pressure test tubing to 3,000 PSI. 11. Pressure test IA to 2,500 PSI. 3500 psi (per drilling engineers email - JJL) 3K-24 Kuparuk Producer Pull and Replace Tubing with Stacked Packer RWO PTD: 198-249 Page 2 of 2 ND BOP, NU Tree 12. Shear out SOV with pressure differential. 13. Install BPV and test. ND BOPE. NU tree. PT Tree and packoffs. 14. Pull BPV and freeze protect well. 15. Pump hi visc brine down IA taking returns up tubing 16. Drop ball and rod. Pressure up to set packer 17. PT tbg to 3,000 psi for 30 minutes and chart. 18. PT IA to 2,500 psi for 30 minutes and chart. 19. Shear out SOV with pressure differential. 20. Pump freeze protect 21. RDMO. PPost-Rig Work 1. Pull DVs and SOV. Install GLD. 2. Pull ball/rod used for setting packer. 3. Pull RBP and catcher. General Well Information: Estimated Start Date: 11/10/2024 Current Operations: Shut-In Well Type: Producer Wellhead Type: FMC Gen 5 casing head top flange. 7-1/16”- 5M tubing head top flange. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams Static BHP: 3,978 4745psi / 6,128’ 6476TVD measured on 10/26/23 10/29/24 MPSP: 3,365 4097psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 4.5 x 3.5” completion to a pre-rig cut, perform cleanout run, install a new 3.5” completion with a stacked packer. Personnel: Workover Engineer: Adam Klem (907-263-4529 / adam.klem@conocophillips.com) Reservoir Surveillance Engineer: Kaylie Plunkett Production Engineer: Sydney Autry Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: SLM 10,326.0 3K-24 3/14/2011 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set plug & catcher, pulled OV left open pocket. Ran Relay LDL 3K-24 2/1/2024rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: Foam FCO - lost returns. Deepest point reached was 13550'' CTM.9/26/2000 triplwj Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 42.0 112.0 112.062.58 H-40 Welded SURFACE 9 5/88.8340.45,936.8 4,091.0 40.00 L-80 BTC PRODUCTION 7 6.28 38.1 10,521.8 6,633.7 26.00 L-80 BTC-MOD SLOTTED LINER 4 1/2 3.60 10,104.9 14,073.0 12.60 L-80 IBT-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 35.9 Set Depth … 10,124.0 Set Depth … 6,501.9 String Max No… 4 1/2 Tubing Description TUBING 4.5"x3.5"@3322' Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-Mod ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.935.90.00 HANGER 10.850 FMC Gen V 4 1/2" Tubing Hanger & Pup, 4 1/2" NSCT landing thread FMCGen V 3.958 507.8 506.5 9.63 NIPPLE 5.030 Camco 'DB' Nipple (3.813" selective)Camco DB 3.813 3,322.32,583.0 57.16 XO Reducing 4.500 CROSSOVER 4.5"x3.5" (ID 2.992", 9.3#, L-80, ABM-EUE) 3.500 3,365.32,606.4 57.16 GAS LIFT 6.018 Camco MMM 3 1/2"Camco MMM 2.920 5,791.0 4,007.6 54.92 GAS LIFT 6.018 Camco MMM 3 1/2"Camco MMM 2.920 7,530.7 5,009.2 54.93 GAS LIFT 6.018 Camco MMM 3 1/2"Camco MMM 2.920 8,620.7 5,644.8 54.36 GAS LIFT 6.018 Camco MMM 3 1/2" Camco MMM 2.920 9,555.5 6,182.3 54.38 GAS LIFT 6.018 Camco MMM 3 1/2" Camco MMM 2.920 10,019.6 6,451.1 58.12 GAS LIFT 6.018 Camco MMM 3 1/2" Camco MMM 2.920 10,069.4 6,476.5 60.53 NIPPLE 4.550 Camco 'W' Nipple (2.812" Selective)Camco W 2.812 10,110.2 6,495.7 63.03 LOCATOR 4.500 Baker Locator Baker 3.958 10,111.2 6,496.2 63.07 SEAL ASSY 4.500 Baker Seal Assembly Baker 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 3,343.02,594.3 57.25 LEAK Suspect Uppermost leak in tubing between 3343' & 3353' (bracketed with holefinder) 11/14/2023 0.000 5,791.0 4,007.6 54.92 LEAK - TUBING Relay LDL identified leak in tubing @ 5791' RKB 1/29/2024 0.000 10,061.0 6,472.3 60.07 CATCHER Set 2.70" Catcher sub on top of plug (OAL = 95") 1/26/2024 0.000 10,069.06,476.360.50 TUBING PLUG 2.812" MA-2 Plug (OAL = 36")1/26/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 3,365.32,606.4 57.16 1 GAS LIFT GLV RK 1 1/21,248.03/14/2011 0.188 5,791.0 4,007.6 54.92 2 GAS LIFT GLV RK 1 1/21,252.03/13/2011 0.188 7,530.7 5,009.2 54.93 3 OPEN 1 1/21/29/2024 Open Pocke t 8,620.7 5,644.8 54.36 4 GAS LIFT DMY RK 1 1/20.012/17/2010 0.000 9,555.5 6,182.3 54.38 5 GAS LIFT DMY RK 1 1/20.0 7/5/2007 0.000 10,019.66,451.1 58.12 6 GAS LIFT DMY RK 1 1/20.012/17/2010 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,104.9 6,493.3 62.84 PACKER 5.960 BAKER ZXP LINER TOP PACKER 4.430 10,133.66,506.163.90 NIPPLE 5.375 CAMCO 'DB' NIPPLE 3.750 10,138.5 6,508.3 64.10 VALVE 4.500 BAKER FLAPPER KOIV VALVE 3.810 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 10,516.014,038.06,632.86,695.5 A-1, A-2, A-3, A- 4, 3K-24 1/30/1999 99.0 IPERF Slotted liner. Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 10,516.014,038.0 1 FRAC 7/8/2007 0.00.00 0.00 3K-24, 2/10/2024 3:57:58 PM Vertical schematic (actual) SLOTTED LINER; 10,104.9- 14,073.0 GUIDE SHOE; 14,071.1- 14,073.0 PACKOFF SUB; 14,037.7- 14,039.0 FRAC; 10,516.0 IPERF; 10,516.0-14,038.0 PRODUCTION; 38.1-10,521.8 FLOAT SHOE; 10,520.4- 10,521.8 FLOAT COLLAR; 10,440.2- 10,441.6 VALVE; 10,138.5-10,140.3 NIPPLE; 10,133.6-10,135.0 HANGER; 10,127.0-10,133.6 SEAL ASSY; 10,111.2 PACKER; 10,104.9-10,127.0 LOCATOR; 10,110.2 TUBING PLUG; 10,069.0 NIPPLE; 10,069.4 CATCHER; 10,061.0 GAS LIFT; 10,019.6 GAS LIFT; 9,555.5 GAS LIFT; 8,620.7 GAS LIFT; 7,530.7 SURFACE; 40.4-5,936.8 FLOAT SHOE; 5,935.1-5,936.8 FLOAT COLLAR; 5,856.2- 5,857.8 GAS LIFT; 5,791.0 LEAK - TUBING; 5,791.0 GAS LIFT; 3,365.3 LEAK; 3,343.0 TAM COLLAR; 1,006.1-1,009.0 NIPPLE; 507.8 CONDUCTOR; 42.0-112.0 HANGER; 40.4-42.4 HANGER; 38.1-40.7 HANGER; 35.9 KUP PROD KB-Grd (ft) 46.40 RR Date 1/31/1999 Other Elev… 3K-24 ... TD Act Btm (ftKB) 14,073.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292293500 Wellbore Status PROD Max Angle & MD Incl (°) 94.78 MD (ftKB) 11,474.80 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 130 Date 12/22/2013 Comment SSSV: NIPPLE 3K-24 Proposed RWO Completion PROPOSED COMPLETION 3.5" 6.5 # L-80 EUE-M 8rd Tubing to surface 3.5" Camco MMG gas lift mandrels @ TBD 3.5" by 7" Packer @ ~9,900' RKB 3.5" X landing nipple (2.812" min ID) 3.5" Non-sealing Overshot @ ~10,090' RKB REMAINING COMPLETION LEFT IN HOLE Baker ZXP Linertop Packer @ 10,105' RKB Camco 3.75" DB nipple @ 10,133' RKB (3.75" ID) 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 14073'3365 None Casing Collapse Conductor Surface Production Slotted Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-263-4529 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 10069' 9-5/8" 70'112' Baker ZXP Liner Top SSSV: Camco DB Nipple 6826'10069'6476' 7" 16" KRU 3K-24 10516-14038' 10484' 4-1/2"" 6633-6696' 5896' 10522' Perforation Depth MD (ft): 14073'3968' 4-1/2" X 3-1/2" 6696' 112' 5937' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025519 198-249 P.O. Box 100360, Anchorage, AK 99510 50-029-22935-00-00 ConocoPhillips Alaska, Inc Will perfs require a spacing exception due to property boundaries? AOGCC USE ONLY Tubing MD (ft): 10105'MD/6493'TVD 508'MD/507'TVD 10124' Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Proposed Pools: 4091' Burst 11/10/2024 Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field TVD Perforation Depth TVD (ft): MD 6634' Adam Klem adam.klem@conocophillips.com RWO/CTD Engineer Subsequent Form Required: Suspension Expiration Date: m n P s 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Tubing Grade: L-80 By Grace Christianson at 10:03 am, Oct 03, 2024 Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem@ conocophillips.com, C=US Reason: I am approving this document Location: Date: 2024.10.02 12:57:12-08'00' Foxit PDF Editor Version: 13.0.0 Adam Klem 324-574 BOP test to 3500 psi 10-404 X SFD 10/26/2024 12/20/24 DSR-10/10/24 683(56('(' P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 19, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 3K-24 (PTD# 198-249). Well 3K-24 was drilled in 1999 as a Kuparuk A sand producer. It was subsequently frac’d in 2007. It has never been worked over and has the original tubing, which developed multiple tubing leaks and is currently secured with a plug and shut in. To bring the well back online, we request approval to proceed with a pre rig tubing cut above the packer and then rig workover to pull and replace the tubing and stack a packer above a pre rig tubing cut stub. The 4.5 x 3.5” tubing will be pulled from a pre-rig cut above the packer, and a new 3.5” completion including a non-sealing overshot, gas lift mandrels, and a stacked packer will be installed. If you have any questions or require any further information, please contact me at 907-263-4529. Adam Klem Rig Workover Engineer CPAI Drilling and Wells Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem @conocophillips.com, C=US Reason: I am approving this document Location: Date: 2024.10.02 12:57:22-08'00' Foxit PDF Editor Version: 13.0.0 Adam Klem 3K-24 Kuparuk Producer Pull and Replace Tubing with Stacked Packer RWO PTD: 198-249 Page 1 of 2 PPre-Rig Work Remaining 1. Dummy off all GLM, leaving lowest GLV open for circulation 2. Pull MA2 plug from nipple at 10,069’ 3. Get updated SBHP 4. Set new plug in the 4.5” liner 5. Cut tubing at ~10,090’ RKB 6. Combo pressure test tubing and casing to 2500psi 7. T-POT/PPPOT and IC-POT/PPPOT. 8. Function test LDS. 9. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3K-24. No BPV will be set for MIRU due to Nabors 7ES internal risk assessment. 2. Circulate seawater. Record shut-in pressures on the T & IA. Circulate KWF as needed and complete 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500 psi. Retrieve 4.5” by 3.5” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4.5” by 3.5” tubing down to the pre-rig cut at ~10,090’ RKB. Cleanout to Tubing Stub 6. PU DP. RIH with casing scraper and dress off mill to tubing stub and dress off stub as needed. POOH LD DP. Install 3.5” Completion with Stacked Packer 7. MU new 3.5” completion with non-sealing overshot, packer, nipple profile, and GLMs. RIH to tubing stub. 8. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 9. Land tubing hanger, RILDS, drop ball/rod, and set packer. 10. Pressure test tubing to 3,000 PSI. 11. Pressure test IA to 2,500 PSI. ND BOP, NU Tree 12. Shear out SOV with pressure differential. 13. Install BPV and test. ND BOPE. NU tree. PT Tree and packoffs. 14. Pull BPV and freeze protect well. 15. RDMO. Post-Rig Work 1. Pull DVs and SOV. Install GLD. 3K-24 Kuparuk Producer Pull and Replace Tubing with Stacked Packer RWO PTD: 198-249 Page 2 of 2 2. Pull ball/rod used for setting packer. 3. Pull RBP and catcher. GGeneral Well Information: Estimated Start Date: 11/10/2024 Current Operations: Shut-In Well Type: Producer Wellhead Type: FMC Gen 5 casing head top flange. 7-1/16”- 5M tubing head top flange. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams Static BHP: 3,978 psi / 6,128’ TVD measured on 10/26/23 MPSP: 3,365 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 4.5 x 3.5” completion to a pre-rig cut, perform cleanout run, install a new 3.5” completion with a stacked packer. Personnel: Workover Engineer: Adam Klem (907-263-4529 / adam.klem@conocophillips.com) Reservoir Surveillance Engineer: Kaylie Plunkett Production Engineer: Sydney Autry Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: SLM 10,326.0 3K-24 3/14/2011 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set plug & catcher, pulled OV left open pocket. Ran Relay LDL 3K-24 2/1/2024rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: Foam FCO - lost returns. Deepest point reached was 13550'' CTM.9/26/2000 triplwj Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 42.0 112.0 112.062.58 H-40 Welded SURFACE 9 5/8 8.83 40.4 5,936.8 4,091.0 40.00 L-80 BTC PRODUCTION 7 6.28 38.1 10,521.8 6,633.7 26.00 L-80 BTC-MOD SLOTTED LINER 4 1/2 3.60 10,104.9 14,073.0 12.60 L-80 IBT-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 35.9 Set Depth … 10,124.0 Set Depth … 6,501.9 String Max No… 4 1/2 Tubing Description TUBING 4.5"x3.5"@3322' Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-Mod ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.935.90.00 HANGER 10.850 FMC Gen V 4 1/2" Tubing Hanger & Pup, 4 1/2" NSCT landing thread FMCGen V 3.958 507.8 506.5 9.63 NIPPLE 5.030 Camco 'DB' Nipple (3.813" selective)Camco DB 3.813 3,322.32,583.0 57.16 XO Reducing 4.500 CROSSOVER 4.5"x3.5" (ID 2.992", 9.3#, L-80, ABM-EUE) 3.500 3,365.32,606.4 57.16 GAS LIFT 6.018 Camco MMM 3 1/2"Camco MMM 2.920 5,791.0 4,007.6 54.92 GAS LIFT 6.018 Camco MMM 3 1/2"Camco MMM 2.920 7,530.7 5,009.2 54.93 GAS LIFT 6.018 Camco MMM 3 1/2"Camco MMM 2.920 8,620.7 5,644.8 54.36 GAS LIFT 6.018 Camco MMM 3 1/2" Camco MMM 2.920 9,555.5 6,182.3 54.38 GAS LIFT 6.018 Camco MMM 3 1/2" Camco MMM 2.920 10,019.6 6,451.1 58.12 GAS LIFT 6.018 Camco MMM 3 1/2" Camco MMM 2.920 10,069.4 6,476.5 60.53 NIPPLE 4.550 Camco 'W' Nipple (2.812" Selective)Camco W 2.812 10,110.2 6,495.7 63.03 LOCATOR 4.500 Baker Locator Baker 3.958 10,111.2 6,496.2 63.07 SEAL ASSY 4.500 Baker Seal Assembly Baker 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 3,343.02,594.3 57.25 LEAK Suspect Uppermost leak in tubing between 3343' & 3353' (bracketed with holefinder) 11/14/2023 0.000 5,791.0 4,007.6 54.92 LEAK - TUBING Relay LDL identified leak in tubing @ 5791' RKB 1/29/2024 0.000 10,061.0 6,472.3 60.07 CATCHER Set 2.70" Catcher sub on top of plug (OAL = 95") 1/26/2024 0.000 10,069.06,476.360.50 TUBING PLUG 2.812" MA-2 Plug (OAL = 36")1/26/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 3,365.32,606.4 57.16 1 GAS LIFT GLV RK 1 1/21,248.03/14/2011 0.188 5,791.0 4,007.6 54.92 2 GAS LIFT GLV RK 1 1/21,252.03/13/2011 0.188 7,530.7 5,009.2 54.93 3 OPEN 1 1/21/29/2024 Open Pocke t 8,620.7 5,644.8 54.36 4 GAS LIFT DMY RK 1 1/20.012/17/2010 0.000 9,555.5 6,182.3 54.38 5 GAS LIFT DMY RK 1 1/20.0 7/5/2007 0.000 10,019.66,451.1 58.12 6 GAS LIFT DMY RK 1 1/20.012/17/2010 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,104.9 6,493.3 62.84 PACKER 5.960 BAKER ZXP LINER TOP PACKER 4.430 10,133.66,506.163.90 NIPPLE 5.375 CAMCO 'DB' NIPPLE 3.750 10,138.5 6,508.3 64.10 VALVE 4.500 BAKER FLAPPER KOIV VALVE 3.810 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 10,516.014,038.06,632.86,695.5 A-1, A-2, A-3, A- 4, 3K-24 1/30/1999 99.0 IPERF Slotted liner. Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 10,516.014,038.0 1 FRAC 7/8/2007 0.00.00 0.00 3K-24, 2/10/2024 3:57:58 PM Vertical schematic (actual) SLOTTED LINER; 10,104.9- 14,073.0 GUIDE SHOE; 14,071.1- 14,073.0 PACKOFF SUB; 14,037.7- 14,039.0 FRAC; 10,516.0 IPERF; 10,516.0-14,038.0 PRODUCTION; 38.1-10,521.8 FLOAT SHOE; 10,520.4- 10,521.8 FLOAT COLLAR; 10,440.2- 10,441.6 VALVE; 10,138.5-10,140.3 NIPPLE; 10,133.6-10,135.0 HANGER; 10,127.0-10,133.6 SEAL ASSY; 10,111.2 PACKER; 10,104.9-10,127.0 LOCATOR; 10,110.2 TUBING PLUG; 10,069.0 NIPPLE; 10,069.4 CATCHER; 10,061.0 GAS LIFT; 10,019.6 GAS LIFT; 9,555.5 GAS LIFT; 8,620.7 GAS LIFT; 7,530.7 SURFACE; 40.4-5,936.8 FLOAT SHOE; 5,935.1-5,936.8 FLOAT COLLAR; 5,856.2- 5,857.8 GAS LIFT; 5,791.0 LEAK - TUBING; 5,791.0 GAS LIFT; 3,365.3 LEAK; 3,343.0 TAM COLLAR; 1,006.1-1,009.0 NIPPLE; 507.8 CONDUCTOR; 42.0-112.0 HANGER; 40.4-42.4 HANGER; 38.1-40.7 HANGER; 35.9 KUP PROD KB-Grd (ft) 46.40 RR Date 1/31/1999 Other Elev… 3K-24 ... TD Act Btm (ftKB) 14,073.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292293500 Wellbore Status PROD Max Angle & MD Incl (°) 94.78 MD (ftKB) 11,474.80 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 130 Date 12/22/2013 Comment SSSV: NIPPLE 3K-24 Proposed RWO Completion PROPOSED COMPLETION 3.5" 6.5 # L-80 EUE-M 8rd Tubing to surface 3.5" Camco MMG gas lift mandrels @ TBD 3.5" by 7" Packer @ ~9,900' RKB 3.5" X landing nipple (2.812" min ID) 3.5" Non-sealing Overshot @ ~10,090' RKB REMAINING COMPLETION LEFT IN HOLE Baker ZXP Linertop Packer @ 10,105' RKB Camco 3.75" DB nipple @ 10,133' RKB (3.75" ID) CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Klem, Adam To:Lau, Jack J (OGC) Cc:Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]198-249 3K-24 Date:Thursday, November 14, 2024 7:51:40 AM For 3K-24 I show we pumped 210 sacks of cement equaling 245.7 cuft of cement. I calculated 16.7 cuft for the shoe giving us 229cuft in the OA. Assuming gauge hole that is 1806ft of cement, or a TOC of 8715’ MD. I could not find any CBL showing TOC. From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Wednesday, November 13, 2024 11:14 AM To: Klem, Adam <Adam.Klem@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]198-249 3K-24 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Adam – Can you verify where TOC and method of verification method for the 7” production casing? This is a detail we like to see on stacker packer applications. Thanks, Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 Office (907) 227-2760 Cell ORIGINATED TRANSMITTAL DATE: 11/12/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5154 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5154 3K-24 50029229350000 Pressure Temprature Survey 3-Nov-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 198-249 T39763 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.12 10:00:36 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Or i g i n a t e d : D e l i v e r e d t o : 1ͲMa r Ͳ24 Ha l l i b u r t o n A l a s k a O i l a n d G a s C o n s e r v a t i o n C o m m . Wi r e l i n e & P e r f o r a t i n g At t n . : Na t u r a l R e s o u r c e T e c h n i c i a n At t n : F a n n y H a r o u n 3 3 3 W e s t 7 t h A v e n u e , S u i t e 1 0 0 69 0 0 A r c t i c B l v d . A n c h o r a g e , A l a s k a 99 5 0 1 An c h o r a g e , A l a s k a 9 9 5 1 8 Of f i c e : 9 0 7 Ͳ27 5 Ͳ26 0 5 FR S _ A N C @ h a l l i b u r t o n . c o m Th e t e c h n i c a l d a t a l i s t e d b e l o w i s b e i n g s u b m i t t e d h e r e w i t h . 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BOX 100360 ANCHORAGE,ALASKA 99510-0360 , .1,-'rC November 5, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNED ' Commissioner Cathy Foerster: 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 attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Aaron Applehans at 907-659-7506, if you have any questions. Sincerely, Aaron Applehans ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 11/8/2016 3K-24,3K-27,2V-09,2S-1,2S-2,2S-3,2S-4,2N-314 Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 3K-24 50029229350000 1982490 NA NA NA NA 1.7 11/5/2016 3K-27 50029227510000 1970460 NA NA NA NA 3.4 11/5/2016 2V-09 50029213000000 1850370 NA NA NA NA 2 11/5/2016 2N-314 50103203550000 2001930 2' NA 2' NA 10.2 11/6/2016 23-01 50103207270000 2152030 1.5' NA .98' 7/2/2016 2.55 11/6/2016 28-02 50103207100000 2150700 2' NA 1' 7/2/2016 3.4 11/6/2016 2S-03 50103207290000 2152050 1.6' NA 1.04' 7/2/2016 3.4 11/6/2016 2S-04 50103207210000 2151590 2.3' NA 1.125' 7/2/2016 3.4 11/6/2016 t • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r PlugPerforationsPull Tubing r Fracture Stimulate r r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing P Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: conductor extension 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 198-249 3.Address: Stratigraphic r Service r 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-22935-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025519 KRU 3K-24 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 14073 feet Plugs(measured) NA true vertical 6696 feet Junk(measured) None Effective Depth measured 12606 feet Packer(measured) 10111 true vertical 6681 feet (true vertical) 6496 Casing Length Size MD TVD Burst Collapse CONDUCTOR 70 16 112 112' SURFACE 5896 9.625 5937 4091' PRODUCTION 10484 7 10522 6634' SLOTTED LINER 3968 4.5 14073 12606' RECEIVED Perforation depth: Measured depth: 10516-14038-slotted liner True Vertical Depth: 6632-6695 slotted liner SEP 2 7 2016 Tubing(size,grade,MD,and WD) 4.53.5, L-80L-80, 3322' 10124' MD,6496 TVD AOGCC Packers&SSSV(type,MD,and TVD) NIPPLE-Camco'DB' Nipple(3.813"selective)@ 508 MD and 506 TVD SEAL ASSY-BAKER SEAL ASSEMBLY @ 10111 MD and 6496 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NAq Treatment descriptions including volumes used and final pressure: SCANNED 13. 7 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Fy Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run 16.Well Status after work: Oil p Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ 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: 316-432 Contact Aaron Applehans Email: aappleh(p�conocophillips.com Printed Name Aaron Applehans Title: WI Field Supervisor Signature Phone: 659-7043 Date /- ,516 I/ri- /0/?/I ,A /074 Form 10-404 Revised 5/2015 RBDMS (,k SEP 2 8 2016 Submit Original Only • • Iry ConocoPh i lli ps Alaska RECEIVED P.O. BOX 100360 )E G 2 7 2016 ANCHORAGE,ALASKA 99510-0360 AOGCC September 23, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 3K-24, PTD 198-249 conductor extension. Please contact me at 659-7506 if you have any questions. Sincerely, % 1r'./ . Aaron Applehans ConocoPhillips Well Integrity Field Supervisor d' N 1 M -,..-, N. : .,,41- . ,,„ ..,:.Y...,k.c., , -, .1',..,,Ii?;,,,,,,:, -,,,,,,,,, ' , - { i t `�t%§' . m t k -t > ° Asx ' v 3 • • r •' V ,... • .a .r n 3'y° x i Alr 4 • I 3K-24 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/23/16 Welded an 8" conductor extension onto the conductor with 16"62.58# .375 conductor material. • OF 7.4 4)",\I y7,,'6 THE STATE Alaska Oil and Gas ti�►�—�� ALASKA Conservation Commission � s}fit 333 West Seventh Avenue " '. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 �"mh � ALASFax: 907.276.7542 www.aogcc.alaska.gov MJ Loveland WI Project Supervisor Sa�� ,1.1-‘,N . 2l fir' ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3K-24 Permit to Drill Number: 198-249 Sundry Number: 316-432 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair S/" DATED this Di day of August, 2016. RBDMS SEP - 1 2016 RECEIVED III STATE OF ALASKA • AUG 2 3 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION O 3!/1 APPLICATION FOR SUNDRY APPROVALS � J. Cr 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r • Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing Other: conductor extension lW 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 198-249 • 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-22935-00 ° 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA ' I Will planned perforations require spacing exception? Yes r No KRU 3K-24 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025519 Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 14073 6696 • 12606' • 6681' 3000 None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 70 16 112' 112' SURFACE 5896 9 5/8 5937' 4091' PRODUCTION 10484 7 10522' 6634' SLOTTED LINER 3968 4 1/2 14073' 12606' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4.5 L-80 3322' 10516-14038-slotted liner ' 6632-6695 slotted liner 3.5 L-80 10124' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) NIPPLE-Camco'DB'Nipple(3.813"selective) • MD=508 TVD=506 SEAL ASSY-BAKER SEAL ASSEMBLY . MD=10111 TVD=6496 12.Attachments: Proposal Summary r WellBore Schematic r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r ' Service r 14.Estimated Date for 15. Well Status after proposed work: 09/15/16 OIL r • WINJ r SPL r Suspended r Commencing Operations: 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: MJ Loveland Printed Name MJ Loveland Phone: 659-7043 Email: MJ.Loveland(@cop.com Title: WI Project Supervisor Signature��/7 a. Date: /9 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `tt.. Rug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Post Initial Injection MIT Req'd? Yes r- No V Spacing Exception Required? Yes r No r✓ Subsequent Form Required: Jd — 'f 0 4 RBDMS t c_._.SEP - 1 2016 P)0.4.4_,V..t......__ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 8,,3/,/c. 744 t/ -/jc. VIL- 6,4,, �-�6 Submn Form ane Form 10-403 Revised 11/2015 3rJvGrfl ifd for 12 months from the date of approval. Attachments in Duplicate INV ConocoPhillips RECEIVED Alaska AUG 23 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC August 19, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3K-24, PTD 198-249 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, 7:Z1C itY MJ oveland ConocoPhillips Well Integrity Projects Supervisor • 0 ConocoPhillips Alaska,Inc. Kuparuk Well 3K-24 (PTD 198-249) SUNDRY NOTICE 10-403 APPROVAL REQUEST 08-19-16 This application for Sundry approval for Kuparuk well 3K-24 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing./At some point during normal operations the conductor subsided about 8". With approval, the conductor extension will require the following general steps: 1. Examine surface casing for any corrosion damage if it is exposed. 2. Extend the conductor to starter head. 3. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor KUP PROD a 3K-24 • ConoccPhiIIips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) + Cmsri,silkpn 500292293500 KUPARUK RIVER UNIT PROD 94.78 11,474.80 14,073.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 3K-24,1/181201se:04.39 AM SSSV:NIPPLE 130 12/22/2013 Last WO: 46.40 1/31/1999 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date l' ..............................................._ Last Tag:SLM 10,326.0 3/14/2011 Rev Reason: SET 8 PULL IBP hipshkf 1/182015 HANGER;35.9- iT Casing Strings r Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 42.0 112.0 112.0 62.58 H-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread I SURFACE 95/8 8.835 40.4 5,936.8 4,091.0 40.00 L-80 BTC - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 38.1 10,521.8 6,633.7 26.00 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SLOTTED LINER 4 1/2 3.598 10,104.9 14,073.0 12.60 L-80 IBT-MOD - ....mi..,Liner Details 11 _ Nominal ID �^-/,.. Top(kKB) Top(TVD)(ftKB) Top Incl(`) Item Des Com (in) _.. 10,104.9 6,493.3 62.84 PACKER BAKER ZXP LINER TOP PACKER 4.430 10,127.0 6,503.2 63.64 HANGER BAKER HMC LINER HANGER 4.420 10,133.6 6,506.1 63.90 NIPPLE CAMCO'DB'NIPPLE 3.750 CONDUCTOR;42.0.112.0 ' 10,138.5 6,508.3 64.10 VALVE BAKER FLAPPER KOIV VALVE 3.810 Tubing Strings NIPPLE;507.8Efl Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(ib/ft) Grade Top Connection TUBING 41/2 3.958 35.9 10,124.0 6,501.9 12.60 L-80 IBT-Mod 4.5"x3.5"@3322' Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl 1°) Item Des Corn (in) 35.9 35.9 0.00 HANGER FMC Gen V 4 1/2"Tubing Hanger 8 Pup,4 1/2"NSCT 3.958 l41-1 landing thread 507.8 506.5 9.63 NIPPLE Camco'DB'Nipple(3.813"selective) I 3.813 3,322.3 2,583.0 57.16 XO Reducing CROSSOVER 4.5"x3.5"(ID 2.992",9.3#,L-80,ABM- 3.500 EUE) GAS LIFT;3,365.3 10,069.4 6,476.5 60.53 NIPPLE Camco W Nipple(2.812"Selective) 2.812 10,110.2 6,495.7 63.03 LOCATOR Baker Locator 3.958 10,111.2 6,496.2 63.07 SEAL ASSY Baker Seal Assembly - 3.958 GAS LIFT;5.791.0 _ Perforations&Slots Shot Dens Top(ND) Btm(ND) (shotsk C Top(f(KB) Btm(ftKB) (ftKB) (ftKB) Zone Date Type Com 10,516.0 14,038.0 6,632.8 6,695.5 A-1,A-2,A-3, 1/30/1999 99.0 IPERF Slotted liner. A-4,3K-24 Stimulations&Treatments SURFACE;40.4-5,936.8-J Min Top Max atm Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com GAS LIFT;7,530.7 _ 10,516.0 14,038.0 6,632.8 6,695.5 FRAC 7/8/2007 A-SAND FRAC Mandrel Inserts St ati • onN Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Com GAS LIFT;6.620.7 /' 3,365.3 2,606.4 Camco MMM 11/2 GAS LIFT I GLV RK 0.188 1,248.0 3/14/2011 2 5,791.0 4,007.6 Camco MMM 1 1/2•GAS LIFT -GLV RK 0.188 1,252.0 3/13/2011 - 3 7,530.7 5,009.2 Camco MMM ' 1 1/2 GAS LIFT OV RK 0.250 0.0 10/25/2014 4- 8,620.7 5,644.8 Camco I MMM 11/2 GAS LIFT 'DMY RK 0.000 0.0 12/17/2010 GAS LIFT;9,555.5 5 9,555.5 6,182.3 Camco MMM 11/2'GAS LIFT 'DMY RK 0.000 0.0 7/5/2007 6 10,019.6 6,451.1 Camco •MMM • 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/17/2010 Notes:General&Safety GAS LIFT;10,019.6III End Date Annotation 8/4/1999 NOTE:Cleanout fill in sloted liner to 14031"RKB. 8/5/1999 NOTE:Unable to get past 13607"CTM after first logging passes. NIPPLE;10,0&9.4 ;, ` 9/26/2000 NOTE:Foam FCO-lost returns. Deepest point reached was 13550"CTM. I LOCATOR;10,110.2 SEAL ASSY;10,111.2 'f 5bl I1 qi ■ PRODUCTION;38.1-10,521.8 !PERF;15516.0-14,038.0 - FRAC;10,516.0E -.we SLOTTED LINER;10,104.9- 14,073.0 z53ck WELL LOG TRANSMITTAL DATA LOGGED 2i 5 no15 M K BENDER To: Alaska Oil and Gas Conservation Comm. January 20, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 i;,:5 E 47.:E E o -EB 052015 RE: Plug Setting Record: 3K-24 Run Date: 12/29/2014 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3K-24 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22935-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton - - - Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 wow Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: )'22,a. 42utJi' Pages NOT Scanned in this Well History File XHVZE Th s page ident ties those terns that were not scanned dur ng the initial scanning proiecL They ar~ ava lable in the or gina fie and viewab e by direct nspection I ~'- ~ File Number of Well History File PAGES TO DELETE RESCAN Color items - Pages: Grayscate, halftones, pictures, graphs, charts - Pages: ~ Poor Quality Original - Pages: Other - Pages: DIGITAL DATA [3 Diskettes, No. n Other, No/Type OVERSIZED .r~ Logs of various kinds n Other Complete COMMENTS: Scanned by: Bevedy Mildred Daretha~°~![ Date: [3 TO RE.CAN Notes: • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 26, 2011 i V 02 nit Commissioner Dan Seamount Ala oii & Gas r a x�s. Alaska Oil and Gas Commission `OT I 333 West 7 Avenue, Suite 100 Atictior Anchorage, AK 99501 ---61<- Commissioner Dan Seamount: 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 corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped 10/18, 10/19 and, 10/21, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. . e Sincerely, ��:.: A'e D r ° i 1 3 J � � u) &O Martin Walters 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 10/26/11 2L, 3K, 3M & 3Q PAD Corrosion Initial top of Vol. of m p cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 2L -301 50103205880000 2081920 10" N/A 10" N/A 1.7 10/18/2011 3K -20 50029230190000 2010880 SF N/A 14" N/A 1.7 10/19/2011 3K -24 50029229350000 1982490 SF N/A 24" N/A 3.5 10/19/2011 3M -01 50029216600000 1870120 SF N/A 12" N/A 5.95 10/21/2011 3M -03A 50029216960100 2081790 SF N/A 18" N/A 5.1 10/21/2011 3M -08 50029217090000 1870280 SF N/A 17" N/A 2.85 10/21/2011 3M -11 50029217180000 1870380 SF N/A 26" N/A 4.25 10/21/2011 3M -21 50029217390000 1870660 SF N/A 15" N/A 3.4 10/21/2011 3Q -03 50029222210000 1911260 SF N/A 18" N/A 3.45 10/19/2011 3Q -07 50029216820000 1861940 SF N/A 17" N/A 4.68 10/21/2011 3Q -08A 50029216810100 1971930 SF N/A 15" N/A 3.55 10/21/2011 3Q -09 50029216740000 1861860 SF N/A 13" N/A 4.4 10/21/2011 ~ ~~ ~ ` ~ 11 /10/08 i~H~I~II1~6~~G~ N0.4957 ~~ ~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 ~ ~x ,~4~~~#3;A,~ ~ .,~,~ ,o ~ ~ ~;~~~ Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD iC-119 11978488 INJECTION PROFILE 10/16/08 1 1 1J-101 11978491 PRODUCTION PROFILE - 10/19/08 1 1 3H-02 12080447 INJECTION PROFILE ~ - '~- ~- 10/24/08 1 i 3K-24 11978500 SBHP 10/26/08 1 1 iJ-120 11978501 PRODUCTION PROFILE ~ - 10/27/08 1 1 3H-24 12080454 INJECTION PROFILE 10/28/08 1 1 3S-15 11978491 SBHP SURVEY 10/18/08 1 1 i H-OB 12100434 INJECTION PROFILE i 10/30/08 1 1 1H-09 12096560 INJECTION PROFILE I~~C La3~~) (~'('.~'~ 10/30/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • . RECEIVED Ancnmô02 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 " Other 0 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. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. 0 Exploratory 0 198-249 1 - Development 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22935-00 .' 7. KB Elevation (ft): 9. Well Name and Number: RKB 41 ' J 3K-24 , 8. Property Designatipn: 10. Field/Pool(s): ADL 25519, ALK 2555 Kuparuk River Field 1 Kuparuk Oil Pool / 11. Present Well Condition Summary: Total Depth measured 14073' feet true vertical 6696' / feet Plugs (measured) Effective Depth measured 10556' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURFACE 5896' 9-5/8" 5937' 4090' PRODUCTION 10481 ' 7" 1 0522' 6631' PRODUCTION 3968' 4-1/2" 14073' 6696' ~ SCANNED AUG 0 3 2007 Perforation depth: Measured depth: 10516'-14038' s\c\\~ - \\'4'<L\ ~ true vertical depth: 6632'-6696' - ?V'-\~I , Tubing (size, grade, and measured depth) 4-1/2" x 3-1/2" , L-80, 3322' x 10124' MD. Packers & SSSV (type & measured depth) no packer Cameo model DB nipple @ 508' 12. Stimulation or cement squeeze summary: !ì'lMI JUS tJtl AUG 0 1 2007 Intervals treated (measured) 10516'-14038' Treatment descriptions including volumes used and final pressure: 325,999# of 16/20 carbo-lite proppant placing 10 ppa on perfs and 325190# behind pipe 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-BbJ Casino Pressure Tubino Pressure Prior to well operation 605 1738 655 -- 162 Subsequent to operation 1817 / 1054 490 -- 156 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after work: Oil0 GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: none Contact John Peirce @ 265-6471 Printed Name John Peirce Title Wells Group Engineer 7/2.~/07 Signature ð~ifR~ Phone: 265-6471 Date PreDared bv Sharon AI/sun-Drake 263-4612 / r - Å> 7· Z. 7.07 . STATE OF ALASKA JUL 2 6 Z007 REP~~~KA;~ ~~~A~~;S:~~~N ~;~~;ION§aska Oi¡ & Gas Cons. C~mm¡$,sÎon Form 10-404 Revised 04/2006 0 R \ G \ N A L k~\ \ ¿Jb;;)J:ø;nIY . 3K-24 Well Events Summary . DATE Summary 6/14/07 DRIFT TBG; STOP FALLING @ 10498' RKB. SET 3" DHSIT ON M-LOCK (18-20" MAX TO KOBE). NOTE: DHSITWILL CLOSE @ 18:13 ON 6/16/07, DHSITWILL OPEN @ 18:13 ON 6/19/07. 6/20/07 PULL DHSIT @ 10,069' RKB. JOB COMPLETE 7/4/07 RUN 2.79" DRIFT TO 10492' SLM. MAKE SEVERAL ATTEMPTS TO PULL STATION #6 AT 10,020' RKB. IN PROGRESS. 7/5/07 SET 2.81" M-A2 LOCK AND TTL PLUG AT 10,069' RKB. SET CATCHER SUB ON TOP OF PLUG. CONFIRM THAT STATION #6 IS EMPTY. PULL 1.5" LGLV AT 9555' RKB AND REPLACE W/ 1.5" DGLV/RK LATCH. IN PROGRESS. NOTE: ****VALVE LOST IN PRODUCTION CASING**** 7/6/07 PULL LGLV'S AND SET 1.5" DGLV'S AT 3365' RKB, 7531' RKB AND 8621' RKB. PULL LGLV AT 5791' RKB, POCKET STILL OPEN. IN PROGRESS. 7/7/07 SET 1.5" DGLV/RKAT 5778' RKB. DRAW DOWN TUBING x IA; 1300#>>>800#. PLUG IS HOLDING. PULL EMPTY CATCHER SUB. CIRC OUT WELL, LOADING BACKSIDE W/ SEAWATER. SET 1.5" DGL V/RK AT 10,020' RKB. PT TxlA TO 3500#/1500#, PT IAxT TO 3500#/1500#--GOOD TEST. BAIL FILL OFF OF PLUG, PULL 2.81" M-A2 PLUG FROM 10069' RKB. BRUSH AND FLUSH TUBING HANGER. 7/8/07 PUMP A SAND FRACTURE TREATMENT USING 50# XL GEL @ 20 BPM. PUMPED A TOTAL OF 325,999# OF 16/20 CARBO-LITE PROPPANT PLACING 10 PPA ON PERFS AND 325,190# BEHIND PIPE. FLUSHED JOB TO COMPLETION WITH 111 BBLS OF 20# LINEAR GEL. ALL TREESAVER RUBBERS ACCOUNTED FOR. 7/9/07 Preform Post Frac Cleanout, RI H with 1.75 nozzle, pumping diesel gel/slick diesel, Good rtns throughout job, Hard tag @ 14017 CTMD. 7/10/07 WORKED THRU SAND BRIDGES TO 10,101' SLM WHILE PUMPING / BAILING. TBG APPEARS TO PLUGGED AGAIN AT THIS POINT. JOB ONGOING; WILL CONTINUE WITH RUNNING GLVD IN A.M. 7/11/07 ATTEMPTED TO SET NEW GAS LIFT DESIGN; TOOLS FOULED BADLY WITH CARBO LITE. PLAN FOR CLEANOUT, RDMO. 7/12/07 WASHED GLM @ 3365',5791',7531', AND 8621'RKB. MADE ATTEMPT TO BULLHEAD DIESEL TO PERF'S @ 10,516'RKB WAS UNSUCCESSFUL, POOH. LDFN. 7/13/07 PERFORMED FILL CLEAN-OUT IN 4.5" SLOTTED LINER FROM 10,520' TO TD @ 14,015'CTM. WASHED ALL GLM'S WHILE COMING OUT OF HOLE. JOB COMPLETE. 7/14/07 TAGGED FORMATION AND FRAC SAND @ 1951' SLM WITH 2.77 GAUGE RING.BAILED CARBOLlTE AND FORMATION SAND FROM 1951' SLM TO 2026' SLM. RDMO FOR COIL. 7/16/07 PERFORMED FCO WITH 1.75" JET SWIRL NOZZLE TO 9000'CTM, WASHED TOP FOUR GLM'S @ 3365',5791',7531', AND 8621'RKB. GOOD 1:1 AND FRAC SAND RETURNS DURING CLEAN-OUT. READY FOR SLlCKLlNE. 7/17/07 ATTEMPTED BRUSH & FLUSH TBG, WELL FOULED WITH CARBO LITE. REPLACED DV @ 3365' RKB WITH 1/4" OV. FLOW WELL TO CLEAN UP. . . ~ ConocoPhillips Alaska ,JUL 0 3 Z007 & P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 2, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED JUL 0 5 2007 ~ùtq \C\~/ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells ftom the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water ftom entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. 4¡~ M.J. Loveland ConocoPhillips Well Integrity Supervisor e-------- . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/1/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft na qal 1 C-19 203-054 28" none 28" na 12 6/24/2007 1 C-123 201-084 22" none 22" na 24 7/1/2007 1C-127 201-114 18" none 18" na 12 7/1/2007 1 C-133 201-077 16" none 16" na 8.5 7/1/2007 1C-190 203-003 27" none 27" na 10 ~ ~ ~ - :n I none 6" na 3 6/24/2007 3K-19 201-108 6" none 6" na 3 6/24/2007 3K-20 201-088 4" none 4" na 1 6/24/2007 3K-23 197-097 8" none 8" na 5 6/24/2007 3K-24 198-249 4" none 4" na 1 6/24/2007 3K-25 198-081 6" none 6" na 3 6/24/2007 3K-26 197-077 8" none 8" na 5 6/24/2007 3K-27 197-046 6" none 6" na 3 6/24/2007 3K-31 198-082 8" none 8" na 5 6/24/2007 3K-34 198-077 7" none 7" na 4 6/24/2007 3K-35 197-109 3" none 3" na 2 6/24/2007 198-249-0 KUPARUK RIV UNIT 3K-24 50- 029-22935-00 PHILLIPS ALASKA INC Roll #1: Start: Stop Roll #2: Start Stop MD _14073_ TVD_0_6696 Completion Date: 1/30/99 Completed Status: 1-OIL Current: T Name Interval t//D 9125 1-6 SPERRY MPT/GR/EWR4 OH ///D 9303 1 PDS PROD/GLS CH L,/15 DGR/EWR4-MD FINAL 121-14073 ,~/~ ..~' OH JL DGR/EWR4-TVD FINAL 121-6696 ~" ~ OH /~,t/ CH 5 t,,'/L GLS FINAL 220-10250 8/5/99 i//L PROD FINAL 10275-14037 8/5/99 tvjlav' CH 5 R SRVY RPT SPERRY 0-14073. OH Sent Received T/C/D 4/22/99 4/21/99 8/10/99 8/10/99 4/27/99 4/27/99 4/27/99 4/27/99 8/10/99 8/10/99 D 8/10/99 8/10/99 D 2/9/99 2/10/99 Thursday, February 01,2001 Page 1 of 1 MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor FROM: John Crisp, SUBJECT- Petroleum Inspector DATE: May 18, 2001 Safety Valve Tests Kuparuk River Unit 3K ~Pad May 18,2001' I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, SSV on 3K-27 would not pass the DP test. The valve was serviced & passed the re-test The AOGCC test report is attached for reference. I inspected 14 well houses on lQ Pad w/no problems witnessed. SUMMARy: I witnessed SVS testing in Kuparuk River Field. 14 wells, 28 components tested. 1 failure witnessed. 3.57% failure rate. 14 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc CC; NON-CONFIDENTIAL SVS KRU 3K 5-18-0ljc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Submitted By: Date: 5/18/01 Operator Rep: Emie Barndt Field/Unit/Pad: Kupamk River Unit 3K Pad AOGCC Rep: John Crisp Separator psi: LPS 65 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 3K-01 1861010 65 70 50 P P OIL , 3K-03 1861030 65 70 55 P P OILi 3K-06 1861240 65 70 50 P P OIL ,, 3K-09A 1861740 65 60! 54 P P OILl 3K-10 1861630 65 701 52 P P OIL 3K- 11 1861640 65 70, 50 P P OIL 3K-14 1861370 65 60 58 P P OIL '3K-16 1861390 65 70 70 P P OIL 3K-l'~" 1861520 ' 65 60 35 p p " OIL , 3K-23 1970970 65 70 58 P P OIL ~~,~--?'"': 1982490, 65 70 50 P P OIL , 3K-27 1970460 65 70 52 P 4 OIL 3K-32 1970760 65 70 55 P P 0IL 3K-35 1971090 65 70 50 P P , Wells: 14 Components: 28 Failures: 1 Failure Rate: 3.57% 1-1 o0 var Remarks: RJF 1/16/01 Page 1 ofl SVS KRU 3K 5-18-01jc W ELL 1.0 .... TRAtV$/v/iTTAL ProActive Diagnostic Services, Inc. To~ ARCO Alaska, Inc. AOGCC Lori Taylor 3010 Porcupine Drive 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' Carl Jablonski/Robert Richey PDS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 LOG DIGITAL MYLAR / BLUE LINE WELL DATE TYPE DATA SEPIA FILM PRINT[S) Res. Eval. CH I I I Signed · Print Name: ProActive Diagnostic Services, Date' ' !ti !0 !999 Inc., Pouch 340112, Prudhoe Bay, AK 99734 Phone: (907)659-2307 Fax: (907)659-2314 E-mail: pdsprudhoe@NA800.net Website: www.memorylog.com C:hMy Documents\Excel_Word_DocumentskDistribution_FormskArco_kup__form.doc 0 Ft I L_I_I IM G SE FIL/I ~-- ~: S WELL LOG TRANS~,HTTAL To: State of Alaska April 27, 1999 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 3K-24, AK-MM-90057 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 3K-24: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22935-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22935-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia ~q~ka Oil& Gas ',: ~ ' ' · guns. L;omrnl~lOn An~orage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company r'~ !=t I L_.L_ I I~J I~ S El !:! ~/I ~- !iii S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cotton. Attn.: Lori Taylor 3001 Porcupine Dr. ,,; Anchorage, Alaska 99501 ' ~" April 22, 1999 RE: MWD Formation Evaluation Logs 3K-24, AK-MM-90057 1 LDWG forma_rted Disc with verificahon API#: 50-029-22935-00 PLEASE ACKNOWLEDGE RECEIIrI' BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSM1TrAL LETTER TO THE ATTENTION OF:. Sperry-Sun Drilling Service Attn: Jim Gal~ 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 * Fax (907) 273-3535 A Halliburton Company 3/9/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'i'N: Sherrie NO. 12412 Compan~ Alaska Oil & Gas Cons Comm Attn: Loft Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Point Mclntyre Color Floppy LIS Well Job # Log Description Date Print Sepia Disk Tape P2-22 99109 USIT 980129 1 P2-09 99113 USIT GR CORRELATION (RUN #1) 980510 1 P2-09 99113 USIT GR CORRELATION (RUN #2) 980510 1 P2-09 99113 USIT GR CORRELATION (RUN #3) 980510 1 ,, , DATE .,l., it SIGNE · ' ~ ..... ~ "~ ~ ~* ,,,, ~ · ' ' '~,',1"' ' Please sign and retur~ne copy of this transmi~al to Sherrie at lhe above address or fax to (907) 562-6521. J~ STATE OF ALASKA ALASK/.. :,L AND GAS CONSERVATION COMMIb~..~ ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon -- Alter casing Change appr-E-ved program __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1322' FSL, 317' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 2379' FSL, 158' FEL, Sec. 26, T13N, R9E, UM At effective depth At total depth 631' FNL, 1105' FEL, Sec. 26, T13N, R9E, UM Suspend __ Operation Shutdown Re-enter suspended well Repair well Plugging Time extension Stimulate Variance Perforate Other X -- -- Pull tubing__ 5. Type of Well: Development X Exploratory Stratigraphic Z Service -- 6. Datum elevation (DF or KB) Annular Injection 41' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-24 9. Permit number 98-249 10. APl number 50-029-22935 11. Field/Pool Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: (approx) measured true vertical Length 80' 5896' 10481' Casing Structural Conductor Surface Intermediate Production Liner 14073 6694 12606 6681 Size 16" 9.625" 7" feet feet feet feet Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 9cuyds High Early 121' 121' 780 sx AS III LW & 5937' 4090' 685 sx Class G 210 sx Class G 10522' 6631' Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A 0RI61NAL 13. Attachments Description summary of proposal X Detailed operation program BOP sketch X Contact Chip Alvord at 265-6120 with any questions. LOT-t-~st, surface cement details and casing deta-~l'sheets X 14. Estimated date for commencing operation January 31, 1999 Oil __ 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregmng ~s true and correct to the best of my knowledge. Signed /t~_~ ~, ~ Title Kuparuk Team Leader FOR COMMISSION USE ONLY 15. Status of well classification as: Gas Suspended X Date Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical I n~grity Test Subseque~'form require 10- -- Approved by the order of the Commission Form 10-403 Rev 06/15/88 OP,!GINAL s%GNED'BY p~obert N. Chdstenson Commissioner jJAppr°val No~ ..- SUBMIT IN TRIPLICATE CASING TEST and FORMATION INTEGRITY TEST Well Name: 3K-24 Date: 1/8/99 Supervisor: Don Breeden Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 40# LS0 BTC Casing Setting Depth: 5,937' TMD 4091' TVD Hole Depth: 5,967' TMD 4,108' TVD Mud Weight: 8.4 ppg Length of Open Hole: 30' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 1,005 psi + 8.4 ppg 0.052 x 4,108' EMW = 13.1 ppg at shoe Pump output = 0.1010 bps Fluid Pumped = 3.8 bbl 3,500 psi 3.400 psi 3,300 psi 3, 2(]0 psi 3,100 psi 3,000 psi 2,900 psi 2,800 psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,800 psi 1,700 psi 1,600 psi 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,1 O0 psi 1,9~ psi ~si 800 psi 700 psi -- 600 psi 500 psi 400 psi 300 psi 200 psi psi psi J ITiMELINE : : : 0 2 4 6 8 ~~~2~4~6~82~22242628~~323436384~424446485~525456586~626466687~~274~6788~828486889~929496981~1~1~1~1~11 Ill k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k kstststststststst k k k k k k k k sTROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE .................... b--~i~-'--,,'- .... -6%T .... 1 ................ [---~-~-t'~F--[ ..... ~--I~'~ .... -,"' 4StkS ! 55Psi ,: i 4stks i 37 psi iiiiiiiiiiiiiiiliii iH! _ iiiiiii _ i iEii ................ ................ .. ............... ~. ................ 12stks ,,' 129 psi i i 12stks i 530 psi ............................................... I' ............... f ............... t ............. r---I ................. .!P_?_t_.k_?__i__~_8_A_P_?j___i L ............... L__-1..4__s__t_k_?___,~___P__41 P_?_L_4 20 stks J 539 psi J [ _l__6__s__t_k__s___[ __7__2_2___p__s_[4 24stks i 678 psi i i 18stks [ 830 psi 28stks ] 819 psi ~ ~ 20stks ~ 919 psi i- .............. ..,- .............. ~ ................ ,~ i. ............... ~. ............... ~. ................ ,' ................. __S&_s!k_?__i__l_,__O_9_S__ P_ ~ L j ................ L __2__2__s__t_k__s___[ _ !,_0__1__0__ _P_S_]'!, 36stks [ 980 psi l ................. -~-~-~ii~-'t---~:f-~;~-i---I .............................. +,,' ................ ! ............... ~, .............. ? ................ i, ! ! , ............... + .............. + ................ .............................. ~ ................ ' ............... r .............. ................ SHUT IN TIME J SHUT IN PRESSURE o.o min , ~ ............................ ~ ................ 1.Omin ~ ~ 842 psi 1 ~.Z~.m~_.~ .............. 5__~_e~J.__i 3.0min ' ! 825 psi l 4.0min ! 820 psi ~ .............................. ~ ................ .__5:~_m,~_ ................ ,__~!~_e~J___~ _~:~_m~_.} .............. L_~!~2~L_! J 24stks J 1,120psi ~ ............... f ............... f .............. .;_-~ ................ i___~.?_~_t_k_~__i_j,~_8_.8___p~,_. ................ L.~.8__s_.t_k_~__[_ j,_3__s__~___p~L J 30stks J 1,510psi ................ L __~..2_ ~_t_k_ ~ __ L !,_6__~_9__ _p~L [ 34stks i 1,860psi ................ f ............... t ................ ................ k __~__6_~_t_k_ ~ __~_ ~,_2__2Z _ _P~L ~ : 38stks i 2,386 psi ' ................ L_.4_.o_~_t_k__s___L_2_,_5__l_3___p.s_!_J ................ L __C~_ 2_t_k_ ~ __[_ ?__0__0__ _P~!_ ] i 44stks i 3,150 psi I ' i SHUT IN TIME j . SHUT IN PRESSURE r ............... r ............... r ................ "-,, , , L__O....o_..m_!_n___[ ............... L ..3;_l__S..o___P.S.!..~ L__!-..°_..m_!.~___[ ............... [ _ _3_ ;_! .q _°_ _ _ps!_ ," ! 2.0min i ! 3,150 psi ................ I"- ............. t ................. , 4.0min j j 3,150 psi j ...............................r r ................ 5.0 min ! ! 3,145 psi ................ ~ ............... ~ ................ __6_..o_ ..m_!.n___[ ............... [2:_! _4_9_ __p~]_ ," ,__Z-.°_..m_L".__L ............... 8.0min [ ! 3,140 psi · , , · 9.0mm ~ j 3,140ps~ ,__! .5_ .. .0_ . .m_ ! .n_ _ [ ............... 8.0min : i 808 psi i ,20'0min i ! 3,130 psij ~- .......... r-~--{--, ............ -I-, ......... ,---,---~ ............... f ............... f ................ , 9.0 mln ~ ~. 806 ps, i 25.0 rain i i 3,120 psi_) NOTE': TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 3K-24 Date: 1/14/99 Supervisor: Don Breeden Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 40# LS0 BTC & 7" 26# LS0 BTC Casing Setting Depth: 10,522' TMD 6,633' TVD Hole Depth: 10,522' TMD 6,633' TVD Mud Weight: 8.4 ppg Length of Open Hole: 0' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 990 psi + 8.4 ppg 0.052 x 4,091' EMW = 13.0 ppg at 9 5/8" shoe Pump output = 0.0580 bps Fluid Pumped = 1.3 bbl TIME LINE 3,000 psi 2,900 psi 2,800 psi 2,700 psi 2,800 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,(~)0 psi 1,800 psi 1,700 psi 1,600 psi 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 1 00 psi 0 psi _ //_'IONE MINUTE TICKS / ___ = LEAK-OFF TEST __ - --e--CASING TEST .......... ;~..,., LOT SHUT IN TIME .- ..... ~--CASIN® TEST SHUT IN TIME _ ~..TIME LINE -- -- 0stk 2stk4stk6stk8stk10stk 12stk 14stk 16stk 18st~ 20stk 22stk 24stk 26stk 28stk 30stk 32stk 34stk 36stk 38stk 40stk STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ................................ ~- .......... %- .... ~ ................ ;- ............... ? ........... .- ...... 0stks : 0ps~ , : 0stks : 0ps~ .............................. + ................ ! ................ t ............... t ................. 2stks i 410psi ~ ................ [ ............... :, ................. iiiiiiZiiii4_-iH!EEiXEfEEEi ................ [ ............... ................. .................. _?__s_!_k__s___ i ___E_8__O___P__S± __j .................. _8___s_!_k__s___ i _ _6__4__O___P__Si __j ! 10stks ! 720 psi : 12stks ! 790 psi ! 14stks : 840 psi : ............... ..i- .............. ~ ................ ................. ! __ P__°___P__SL _j 18stks i 975 psi i i.. .............. ~ .............. .J. ................ 20stks i 990 psi : 22stks i 960 psi i .............................. T ................ I ! , ! i i i- .............................. -~ ................ , , , ...................... ~ ........ ..~ ................ 4 i i i ! ! i i , ! ................ i. ............... ~. ................ i , , , , ' i i I . i i i i i I , SHUT IN TIME i SHUT IN PRESSURE ......................... L .... ! ................ ',, ............... [ ..... .... i ............... · .i- .............. -.i- ................ .~ i- ...............!- ...............!. ................ , , , ~ , , , 1.0 min : : l- ............... i. ............... i. ................ : : : , 2.0 mini : : i SHUT IN TIME SHUT IN PRESSURE 3.0 mir : -~;-~ ~J'~- T---~-~-~]---] ............................... 4.0 m,n' =' ~:' ................ i '"' ............................... 1.0 min T ~: ~'i-"] ~- .............. 5.0 min 'i ............... "' ................ -'" ................................... ; ................ .4' i 2.0min j i 700 psi i 6.0min i J i- .............. ~ .............. ~ ................ .~ i. i i 3.0min : i 685 psi ! ' 7.0min i : 4.0 min : 675 psi : 8.0 min : : ............... ~- .............. t ................ ~ ............... ~ ............... ~ ................ ! ____5_..O._..m_i..n__,'.. .............. ~_._6__6._5_._p__s_i___] 9.0 Bin , , r ............... r ............... I- ................ .-t i · i i i 6.0min j : 650 psi : 10.0m~n: : : .............................. 4- ................................................. t ................ ~___7:.o___m_Ln__± ....... : ...... i___6!_o__R?l__j j_ _s_ ._ _o_ pin_ [ ............... .~ ................ 8.0min ' J 650 psi i ' 20.0min J J ' .............. + .............. + ................ t ' ............... f ............ ~--f ........ - ....... 9.0 min & _~ 630 psi i 25.0 min: ' ' ............................................................. ~ ............... ~ ................ _]_g:.°____m_i.n__i .............. i___6_2__°__R_s, kj .__3__°_._g___m!n__[ ......... l ..... [ ................ j NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ARCO Alaska, Inc. Cementing Details Well Name: 3K-24 Report Date: 01/08,/99 Report Number: 8 Rig Name: RIG 245 AFC No.: AK9821 Field: Kuparuk River Unit 9-5/8" 12-1/4" 55* Slant 5937' FC @ 5856' Centralizers State type used, intervals covered and spacing Comments: 15 Gemoco Bow Spring Centralizers: 1 / Jt on first 15 joints, first two on stop rings in middle of float joints. 2 ROTCO Rigid Straight Blade Centralizers: One on joint on either side of TAM Port Collar. Mud Weight: PV(pdor cond): PV(after cond): YP(pdor cond): YP(after cond): Comments: 9.6 ppg 37 21 56 24 Gels before: Gels after:. Total Volume Circulated: 24/60 5/7 1500 Bbls Wash I Type: Volume: Weight: Comments: ARCO Wash 20 Bbls 8.34 ppg Spacer 2 Type: Volume: .Weight: Comments: ARCO B45 46 Bbls 10.5 ppg Lead Cement 3 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: AS Ill LW 75* F 780 sx 10.7 ppg 4.43 cfs Additives: Class G + 9.0% D44 + 0.4% D46 + 30% D53 + 1.5% D79 + 50% D124 + 1.5% S1 Tail Cement 4 Type: Mix wtr tamp: No. of Sacks: Weight: I Yield: Comments: G 75* F 685 sx 15.8 PPgI 1.17 cfs Additives: Class G + 0.2% D46 + 0.3% D65 + 1% S1 Displacement 5 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 7.1 BPM to 7.8 BPM 6.9 BPM 250K# (75K# Blocks) Reciprocation length: Reciprocation speed: Str. Wt. Down: 15' -20 fpm 160K# (75K# Blocks) Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 444 Bbls 450 Bbls 140K# Calculated top of cement: CP: Bumped plug: Floats held: Cemented to Surface Date:l/8/99 Yes Yes Time:0210 hrs Remarks: Circulated & conditioned mud & hole for cementing, 1500 Bbls, 8 BPM, 500 psi. Reciprocated piPe, 250K# Up, 160K# Down, 75K# BlockS. Dowell flush lines with 3 Bbls water & test lines to 3500 psi. Pump 20 Bbls ARCO pre-flush, with celloflakes in first 3 Bbls. Pump 46 Bbls, 10.5 ppg ARCO Spacer. Mix & pump 610 Bbls, 780 sx, 10.7 ppg AS III LW Lead Cement, 7.1 BPM, 250 psi. Drop bottom plug. Mix & pump 134 Bbls, 15.8 ppg Class G Tail Cement, 6.3 BPM, 350 psi. Drop top plug. Chase plug with 5 Bbls Tail Cement (685 sx total Tail) & 20 Bbls wash-up water. Displace with mud using rig pump, 7.8 BPM to 6.9 BPM, 500 psi to 1300 psi. Bumped plug. Pressured up to 2500 psi & held 2 minutes, OK. Checked floats, OK. Full returns throughout. Got about 270 bbls of good 10.7 ppg to 11.2 ppg Lead Cement returns to surface. Reciprocated casing until 225 Bbls of Lead Cement had rounded the shoe, then set down on hanger. CIP @ 0210 hrs, 1/8/99. i Cement Company: Rig Contractor: Parker Approved By: Don E. Breeden Dowell CASING ! TUBING ! LINER DETAIL 9-5/8" Surface Casing ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL: 3K-24 KRU DATE: 1/7/99 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS 40.38 25 Jts 126 Jts 2 Jts RKB to Landing Ring - Parker Rig #245 FMC Gen 5 Fluted Mandrel Casing Hanger & 47#, NSCC x BTC pup 9-5/8", 40#, L-80, BTC Casing (Joints #129 - #153~) TAM Port Collar 9-5/8", 40#, L-80, BTC Casing Gemoco Float Collar (~Joint #3 - #128~) 9-5/8", 40#, L-80, BTC Casing Gemoco Float Shoe (Joints #1 & #2~) 1.98 963.70 2.93 4847.24 1.53 77.36 1.70 Bottom of Shoe ==>> TD of 12-1/4" Hole = 5947' MD (-10' of Rathole) Baker Lok thru Float Collar Install TAM Port Collar on top of Jt # 128 Run FMC Handler on Top of Joint # 153 15 Bow Spfina. Centralizers: 1 / Jt on first 15 joints, first 2 on stop rin~l in middle of joint 40.38 42.36 1006.06 1008.99 5856.23 5857.76 5935.12 5936.82 2 Ria. id Straia. ht Blade Centralizers: Slide I on Jts #128 & #129 Leave OUT 7_ioints: Jts #154 thru #160 ~.~. :~ .~. .,. ~ ~ ,:' ~ ~-'-~ Remarks: String Weights with Blocks: 250K~ Up, 160K~ Dn, 75K~ Blocks. Ran 53 joints of casing. Drifted casing with 8.679" plastic rabbit. Calipered 47~ pup on hanger to veri~ 8-1/2" bit would pa Used Arctic Grade APl Modified No Lead thread cOmpound on all connections. Torqued connec' to the base of the triangle stamp. Parker Ri~ #245 Drillin~l Supervisor: Don E. Breeden ARCO ALASKA INC CASING TALLY PAGE: 1 of .1 WELL NUMBER: 3K-24 Kuparuk River Unit RIG: Parker Rig #245 CASING DESCRIPTION: 9-5/8", 40#, L-80, BTC Casing Range 3 - Class A DATE: 1/7/99 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 I Column 8 No Feet No Feet No Feet No Feet No Feet No Feet NoI Feet~1 No Feet I I 1 ' 38.13 26 39.85 51 39,18 76 38,60 101 38,86 126 38,90 151 I 39.00 1176 i 2 39.23 27 38.96 52 38,84 77 37.36 102 38.34 127 39.11 1521 39,40 I 177 I I I I ~.3 37.99 28 38.75 53 38,09 78 36.01 103 38.97 128 39.10 1531 39.05 ! 178 i~'4 39.08 29 39,18 54 38,97 79 39.16 104 38.89 129 39.O0 ~~~ 179 i~~' 5" 37.91 30 38.85 55 37,59 80 37.93 105 36.70 130 38.82 ~~ 180 i:: 7~ 38.71 32 36.70 57 37,36 82 38.84 107 ~.~ 132 ~7.7~ ?: 8.:~ ~,~ 33 ~.~ ] 5~ ~,~ ~3 ~.7~ 10~ ~&~ 133 ~.~ 1~3 ~'S 39.10 34 39.33 5S 39,35 8~ 38,84 10S 39.05 134 39.02 ~ 184 ~:.i0' 38.00 35 38.87 60 38.78 S5 38.38 110 39.16 135 39.11 ~:i1: 38.86 3~ 36,48 61 37.50 8~ 34.74 111 38.96 13~ 39.01 1~1 1~ ~.12 38.98 37 39.36 62 38,67 87 39.10 112 38.97 137 39.30 162 187 ~; 13: 36.52 38 38.86 63 37,43 88 37.24 113 39.29 138 39.17 1~3 188 ~.::14 40,50 39 36.75 64 39.10 89 39,06 114 39,18 139 39,10 164 189 ~-'15 38,10 40 37.40 65 37,94 90 38,66 115 39,13 140 38,42 165 190 16 39,08 41 37,06 66 38,15 91 36,40 116 38,96 141 39.14 166 191 17 36,98 42 38,80 67 39,10 92 39,59 117 39,30 142 39,13 167 192 18 38,64 43 38,05 68 39,07 93 38,99 118 38,62 143 39,11 168 193 19 39.13 44 38,87 69 38.34 94 38,34 119 38,82 144 38,67 169 194 20 38,96 45 35,95 70 38.55 95 39,33 120 I 39,32 145 35,03 170 195 . 21 38,17 46 38,93 71 38.98 96 38.52 121 38,16 146 37,35 171 196 22 38.95 47 38,74 72 38.80 97 37,09 122 38.18 147 38,63 172 197 23 38,67 48 39,11 73 39,18 98. 39,15 123 38,97 148 38,26 173 198 24 38,68 49 36,53 74 39,12 99 39.19 124 37,39 149 38.97 174 199 25 38.80 50 38,84 75 38,03 100 39.30 125 36,56 150 35.19 175 200 Tot 964.83 Tot 958,15 Tot 962.67 Tot 957.60 Tot 964,24 Tot 963.36 Tot 387.98 Tot TOTAL LENGTH THIS PAGE = TOTAL JOINTS THIS PAGE = 6158.83 160 DIRECTIONS: RKB to Landin,q Ring = 40,38' FMC Fluted Mandrel Casing Hanger = 1.98' TAM Port Collar = 2.93' Gemoco Float Collar = 1.53' GemOco Float Shoe = 1.70' Landing Joint = 46.75' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [] Gas [] Suspended [] Abandoned [] Service [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 98-249 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-22935 4. Location of well at surface · 1 ~'~¢'~.,~-_~ 9. Unit or Lease Name 1322' FSL, 317' FWL, Sec. 35, T13N, R9E, UM¢:~, .... ; i '-'¢~, ' i Kuparuk River Unit At Top Producing Interval 1873' FSL, 466' FEL, SEC 26, T13N, R9E, UM' At Total Depth . ~__,~ i i! ~~:.% 11. Field and Pool 609' FNL, 1151' FEL, SEC 26, T13N, RgE, UM -' · Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 41 feetI ADL 25519 ALK 2555 Kuparuk River Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions January4, 1999 January25, 1999 January30, 1999 I N/A feetMSL 1 ~17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 14073' MD / 6696' TVD 14038' MD / 6696' TVD YES [] No []I N/A feet MD 1764' (approx) 22. Type Electric or Other Logs Run GR/Res 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT. PER FT. GRADE TOP BO-FI-OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 41' 121' 20" 111 sxAS I 9.625" 40# L-80 41' 5937' 12.25" 780 sx AS III LW & 685 sx Class G 7" 26# L-80 41' 10522' 8.5" 210 Sx Class G 4.5" 12.6# L-80 10105' 14073' 6.125" N/A - slotted liner 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) 4.5" x 3.5" 3322'/10124' N/A 10516'-14038' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. slotted liner DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 24, 1999 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 2/24/1999 18.0 Test Period > 2960 1760 27 124 718 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. 50 psi 0 24-Hour Rate > 3601 2586 36 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. · This 10-407 is submitted as directed per the 10-401 form approved (Permit fl98-249) Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Kuparuk C Bottom Kuparuk C Top Kuparuk A Bottom Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH 10180' 1O278' TRUE VERT. DEPTH 6526' 6566' 6651' 10719' 14073' 6696' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations and Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Signe.d~/~.,t,l,~--- ~ U(/~,~'~' -. Title Drilling Team Leade, Date Chip Alvord INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 2/19/99 ARC© ALASKA INC. Page: 1 WELL SErMMARY REPORT "'.ii~'~i~-!~ !~'~ -~ i ~ ~ ~ ~ ~ WELL:3K-24 WELL_ID: AK9821 TYPE: AFC: AK9821 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:01/04/99 START COMP: RIG:RIG # 245 WI: 0% SECURITY:0 API N-JMBER: 50-029-22935-00 BLOCK: FINAL:01/30/99 01/01/99 (D1) TD: 121' (121) SUPV:G.R. WHITLOCK MW: 0.0 VISC: MOVING RIG 0 PV/YP: 0/ 0 Prep rig for move. Move to 3K pad. APIWL: 0.0 01/02/99 (D2) TD: 121'( 0) SUPV:G.R. WHITLOCK MW: 0.0 VISC: MOVING RIG TO 3K PAD 0 PV/YP: 0/ 0 Continue to move rig and camp to 3K pad. APIWL: 0.0 01/03/99 (D3) TD: 121'( 0) SUPV:G.R. WHITLOCK MW: 8.7 VISC: 105 PV/YP: 38/41 DRILLING @ 330' AP IWL: 9.2 Move rig over well. Accept rig ~ 0900 hrs. 1/3/99. N/U diverter. 01/04/99 (D4) TD: 1809' (1688) SUPV:G.R. WHITLOCK MW: 9.6 VISC: 132 PV/YP: 28/40 DRILLING ~ 2558' APIWL: 7.0 Function test diverter. Drill from 121' to 1809' 01/05/99 (D5) TD: 4668' (2859) SUPV:DON E. BREEDEN MW: 9.5 VISC: 140 PV/YP: 25/37 DRILLING AT 5330' APIWL: 6.4 Drill from 1809' to 4555' Mud motor acting like its locked up. Drill to 4668' 01/06/99 (D6) MW: 9.7 VISC: 135 PV/YP: 38/50 APIWL: 6.0 TD: 5947'(1279) POH WITH HOLE OPENER. SUPV:DON E. BREEDEN / SCOTT GOLDBER Drill from 4668' to 5947' Mud gas cut to 8.8 ppg at 4977' Circulate lo/hi visc sweeps around and circulate hole clean. Pump slug. POH. Some swabbing from 1906' to 1439' RIH w/hole opener. Work thru small bridges between 2835' & 3021' 01/07/99 (D7) MW: 9.6 VISC: 68 PV/YP: 21/23 APIWL: 6.8 TD: 5947'( 0) NU FMC WELLHEADS & BOPE SUPV:DON E. BREEDEN / SCOTT GOLDBER Circulate lo/hi visc sweeps around. Backream from 2182' to 1990' due to swabbing. Run 9-5/8" casing. Cement casing. Date: 2/19/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 01/08/99 (D8) TD: 5947'( 0) SUPV:DON E. BREEDEN 01/09/99 (D9) TD: 8120' (2173) SUPV:DON E. BREEDEN 01/10/99 (D10) TD:10000'(1880) SUPV:DON E. BREEDEN 01/11/99 (Dll) TD:10359' (359) SUPV:DON E. BREEDEN 01/12/99 (D12) TD:10536' (177) SUPV:DON E. BREEDEN 01/13/99 (D13) TD:10536' ( 0) SUPV:DON E. BREEDEN 01/14/99 (D14) TD:10536'( 0) SUPV:DON E. BREEDEN 01/15/99 (D15) TD:10635' ( 99) SUPV:DON E. BREEDEN MW: 9.0 VISC: 46 PV/YP: 12/38 APIWL: 12.5 TESTED FORMATION - LOT @ 13.1 PPG EMW, DRILLING AT 5967' Cement 9-5/8" casing. ND diverter. NU BOPE and test to 300/500 psi. Circulate contaminated cement. Drill firm cement from 5810' to 5838' MW: 9.3 VISC: 45 PV/YP: 12/17 APIWL: 6.2 DRILLING @ 8780' Drill out cement and float equipment from 5838' to 5937' Drill 20' of new hole to 5967' Perform LOT, 13.1 ppg EMW. Drill from 5967' to 8120' MW: 10.4 VISC: 54 PV/YP: 20/29 APIWL: 5.5 POH FOR SHORT TRIP TO SHOE (PD = 10,049' MD) Drill from 8120' to 10000' MW: 10.5 VISC: 50 PV/YP: 18/24 APIWL: 4.4 CBU AT 10,536' MD - TD OF INTERMEDIATE HOLE Drill from 10000' to 10049'. Re-test formation integrity, no leak-off - 14.4 ppg EMW. Drill to 10359' MW: 10.4 VISC: 52 PV/YP: 23/29 APIWL: 4.4 RUNNING 7" CASING - 240 JOINTS OF 252 JOINTS RUN Drill from 10359' to 10536' Circulate hole clean. Run 7" intermediate casing. MW: 10.4 VISC: 53 PV/YP: 20/28 APIWL: 4.4 RIH PU 3-1/2" DP Run 7" intermediate casing. Cement casing. Test BOPE to 300/5000 psi. MW: 10.5 VISC: 52 PV/YP: 20/28 APIWL: 4.4 DRILLING @ 10,542' MD RIH w/3.5" DP. Check LWD tools, no pulse. POH. Change-out pulsar. RBIH w/3.5" DP. Tag cement at 10412' MW: 10.4 VISC: 62 PV/YP: 18/42 APIWL: 4.0 DRILLING ~ 10,710' MD Drill out cement & float equipment from 10412' to 10522' Drill 10' of new hole to 10546'. Test formation to 10.4 ppg mud, no leak-off, 14.5 ppg EMW-FIT. Drill from 10546' to 10635' Date: 2/19/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 01/16/99 (D16) TD:11278'(643) SUPV:DON E. BREEDEN 01/17/99 (D17) TD:l1319'( 41) SUPV:DON E. BREEDEN 01/18/99 (D18) TD:11772' (453) SUPV:DON E. BREEDEN 01/19/99 (D19) TD:l1912' 140) SUPV:G.R. WHITLOCK 01/20/99 D20) TD:12041' 129) SUPV:G.R. WHITLOCK 01/21/99 D21) TD:12307' 266) SUPV:G.R. WHITLOCK 01/22/99 D22) TD:12705' 398) SUPV:G.R. WHITLOCK 01/23/99 (D23) TD:13297' 592) SUPV:G.Ro WHITLOCK 01/24/99 (D24) TD:13780' (483) SUPV:G.R. WHITLOCK MW: 10.4 VISC: 56 PV/YP: 18/37 APIWL: 3.7 SHORT TRIPPED INTO SHOE FROM 11,298' SERVICING RIG ~ 0400 Drill from 10635' to 11278'. MW: 10.5 VISC: 58 PV/YP: 19/35 APIWL: 3.2 DRILLING AT 11448' Drill from 11278' to 11299' POH. Download LWD tools. Change out pulsar - found pulsar seat broken & 1/4 of same missing. Drill from 11299' to 11319'. MW: 10.4 VISC: 56 PV/YP: 17/39 APIWL: 3.2 DRILLING AT 11,840' Drill from 11319' to 11772' MW: 10.4 VISC: 57 PV/YP: 19/43 APIWL: 2.5 P/U BHA Drill from 11772' to 11912'. Circ low vis sweep to surface while rotating and reciprocating. Pump out of hole 17 stands to casing shoe. had tight hole e 11625' and 10650' MW: 10.4 VISC: 60 PV/YP: 18/39 APIWL: 3.2 DRILLING ~ 12181' Test BOPE to 300/500 psi. Circ out oil and gas cut mud. MW cut to 9.1 ppg. Drill from 11912' to 12041' MW: 10.4 VISC: 56 PV/YP: 20/40 APIWL: 2.8 DRILLING ~ 12450 Drill from 12041' to 12235' Make wiper trip to shoe. Drill from 12235' to 12307' MW: 10.4 VISC: 58 PV/YP: 18/42 APIWL: 3.2 DRILLING 8 12840' Drill from 12307' to 12705' MW: 10.4 VISC: 57 PV/YP: 19/46 APIWL: 2.6 WIPER TRIP @ 13317' Drill from 12705' to 13297' MW: 10.5 VISC: 56 PV/YP: 19/42 APIWL: 2.5 DRILLING @ 14050 Circ low-vis sweep around. Pump out of hole. Try to POOH w/o pump but hole not taking correct fill. Pump out of hole Date: 2/19/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 01/25/99 (D25) TD:14073'(293) SUPV:G.R. WHITLOCK 01/26/99 (D26) TD:14073'( 0) SUPV:G.R. WHITLOCK 01/27/99 D27) TD:14073' 0) SUPV:G.R. WHITLOCK 01/28/99 (D28) TD:14073' 0) SUPV:G.R. WHITLOCK 01/29/99 D29) TD:14073' 0) SUPV:G.R. WHITLOCK 01/30/99 D30) TD:14073' 0) SUPV:G.R. WHITLOCK 01/31/99 (D31) TD:14073' ( 0) SUPV:G.R. WHITLOCK to shoe. Change grabs and saversub in top drive. RIH. CBU, no gas. Drill from 13317' to 13780' CIRC MW: 10.7 VISC: 57 PV/YP: 19/39 APIWL: 2.2 Drill from 13780' to 14073'. Circ low-vis sweep. Pump out of hole-not taking proper fill. Raise mud weight to 10.7 ppg. No flow. MW: 11.0 VISC: 61 PV/YP: 21/39 LAYING DOWN DRILL PIPE APIWL: 2.8 Finish pumping out 3 stands. Monitor well, no flow. CBU, no gas cut mud. Pump pill and POOH to 9300' Hole taking insufficient fill. Monitor well. Circ pill out of hole. RIH to bottom. CBU. Circ up gas/oil cut mud. Raise mud weight to 11 ppg. Pump out of hole to shoe. Monitor well. Pull 10 stands wet. Well not taking correct fill. Pump out of hole. MW: 11.1 VISC: 67 PV/YP: 26/44 APIWL: 2.8 RUNNING 4-1/2" SLOTTED LINER 5 STDS OFF BOTTOM POOH to run liner. RIH w/4.5" slotted liner. MW: 11.0 VISC: 28 PV/YP: 0/ 0 CIRC AND FILTER COMPLETION FLUID APIWL: 0.0 RIH to 14073'. Circ slow to prevent setting liner hanger. Displace mud w/hi-vis sweep and brine. Spot enzyme pill displaced by brine. Drop liner hanger setting ball. Pump ball down w/brine. Set hanger and liner top packer. MW: 11.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 Spot 70 bbl enzyme breaker pill inside slotted liner. Run 4.5" x 3.5" tubing. MW: 11.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 L/D 5" DRILLPIPE Finish running 4.5" x 3.5" tubing string. N/D BOPE. N/U tree and test to 5000 psi. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Released rig ~ 1200 hrs. 1/31/99. ARCO Alaska, Inc. "' ' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 26, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3K-24 (Permit No. 98-249) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3K-24. If there are any questions, please call 265-6120. Sincerely, G. L. Alvord Drilling Engineer AAI Drilling GLA/skad 0 !:! I I_1_ I I~1G S ~ !::! ~./I r- G S 09-Feb-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3K-24 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 14,073.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 3K, Slot 3K-24 3K-24 MWD Job No. AKMM90057, Surveyed: 25 January, 1999 SURVEY REPORT ORI61NA 8 February, 1999 Your Ref: AP1-500292293500 KBE 75.3 Surface Coordinates: 6008316.31 N, 529306.13 E (70026, 01.6746" N, 149° 45' 39.9441" W) DRI L.~L~INS SERVICES A I'L~LLII~URTO~ CONfi~A.~'Y Survey Ref: svy8227 Sperry-Sun Drilling Services Survey Report for 3K-24 MWD Your Ref: API-500292293500 Job No. AKMM90057, Surveyed: 25 January, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 0.00 0.000 0.000 -75.30 121.00 0.000 0.000 45.70 163.00 0.400 74.000 87.70 256.00 1.250 84.000 180.69 344.00 4.100 68.000 268.59 434.00 7.000 68.000 358.15 559.56 11.470 74.700 482.06 651.68 13.400 66.550 572.02 742.44 14.910 63.060 660.02 832.57 16.400 57.530 746.81 923.34 19.770 51.190 833.09 1014.47 23.210 48.690 917.88 1106.00 24,610 46.040 1001.55 1199.79 26.400 44.920 1086.20 1293.34 28.400 43.940 1169.25 1386.38 31.310 45.180 1249.94 1480.14 31.680 44,540 1329.88 1574.05 32.910 44.690 1409.27 1668.04 35.250 41.920 1487.11 1760.98 35.990 40.870 1562.66 1851.00 40.080 38.250 1633.56 1944.54 44.710 37.780 1702.62 2036.87 49.590 37.940 1765.39 2130.74 52.470 37.980 1824.42 2221.48 53.970 37.110 1878.75 Vertical Depth (ft) 0.00 121.00 163.00 255.99 343.89 433.45 557.36 647.32 735.32 822.11 908.39 993.18 1076,85 1161.50 1244.55 1325.24 1405.18 1484.57 1562,41 1637.96 1708,86 1777.92 1840.69 1899.72 1954.05 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 6008316.31 N 529306.13 E 0.00 N 0.00 E 6008316.31N 529306.13 E 0.04 N 0.14 E 6008316.35 N 529306.27 E 0.24 N 1.46 E 6008316.55 N 529307.59 E 1.52 N 5.33 E 6008317,85 N 529311.46 E 4.78 N 13,40 E 6008321,14 N 529319.51 E 10.94 N 32.55 E 6008327.38 N 529338,64 E 17.60 N 51.18 E 6008334.12 N 529357.24 E 27.08 N 71.24 E 6008343.67 N 529377.26 E 39.17 N 92.31E 6008355.84 N 529398.29 E 55,67 N 115.09 E 6008372.43 N 529421.01E 77.19 N 140.60 E 6008394.06 N 529446.43 E 102.33 N 167.87 E 6008419,30 N 529473.60 E 130.65 N 196.65 E 6008447.74 N 529502.27 E 161.40 N 226.78 E 6008478.60 N 529532,27 E 194.38 N 259.29 E 6008511.71 N 529564,65 E 229.11N 293.84 E 6008546.57 N 529599.07 E 264.82 N 329,08 E 6008582.42 N 529634.16 E 303.16 N 365.16 E 6008620.90 N 529670.10 E 343.77 N 400.95 E 6008661,65 N 529705.73 E 386,55 N 436.22 E 6008704.57 N 529740.82 E 436.23 N 475.04 E 6008754.40 N 529779.45 E 489.65 N 516,57 E 6008807.99 N 529820,77 E 547.19 N 561.46 E 6008865,70 N 529865.43 E 604.81 N 605.74 E 6008923.50 N 529909.49 E Alaska State Plane Zone 4 Kuparuk 3K Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.00 0.000 0.00 0.952 0.09 0.924 0.81 3.317 3.54 3.222 9,78 3,656 23.16 2.827 36.78 1.910 53.56 2.338 73,13 4.294 97.43 3.906 127.42 1.927 161.44 1.976 198.98 2.192 239.28 3.197 282,58 0.532 328.30 1.313 375.21 2.987 424,86 1.033 476.47 4.884 529.85 4.961 590.98 5.287 656,63 3.068 727,40 1.823 798.00 Continued... 8 February, 1999-15:03 -2- DrlllQuest Sperry-Sun Drilling Services Survey Report for 3K-24 MWD Your Ref: API-500292293500 Job No. AKMM90057, Surveyed: 25 January, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2409.29 55.600 37.110 1987.05 2062.35 2691.13 53.730 37.840 2150.04 2225.34 2968.07 55.290 36.020 2310.83 2386.13 3341.06 57.260 35.550 2517.91 2593.21 3716.32 55.650 36.580 2725.27 2800.57 4094.59 54.060 37.420 2943.01 3018.31 4467.25 53.760 37.920 3162.53 3237.83 4836.45 54.500 37.290 3378.86 3454.16 5208.26 54.660 36.430 3594.36 3669.66 5580.79 54.370 35.760 3810.61 3885.91 5898.15 55.200 37.880 3993.62 4068.92 6047.20 54.860 37.310 4079.05 4154.35 6327.14 54.080 36.790 4241.73 4317.03 6608.62 56.900 36.080 4401.19 4476.49 6886.38 54.030 36.280 4558.64 4633.94 7166.75 54.230 36.180 4722.92 4798.22 7447.37 54.760 35.750 4885.90 4961.20 7729.53 55.320 '35.370 5047.58 5122.88 8014.17 53.990 36.790 5212.24 5287.54 8200.00 54.090 35.960 5321.37 5396.67 8384.95 53.530 36.800 5430.57 5505.87 8573.95 54.090 36.120 5542.17 5617.47 8759.44 55.180 37.410 5649.53 5724.83 8942.18 55.090 36.980 5753.99 5829.29 9128.58 54.860 36.770 5860.98 5936.28 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 727.18 N 698.32 E 6009046.22 N 530001.58 E 909.64 N 838.18 E 6009229.24 N 530140.73 E 1089.90 N 973.62 E 6009410.02 N 530275.46 E 1341.55 N 1155.00 E 6009662.39 N 530455.85 E 1594.37 N 1339.09 E 6009915.93 N 530638.95 E 1841.40 N 1525.21 E 6010163.69 N 530824.10 E 2079.77 N 1709.24 E 6010402.78 N 531007.19 E 2316.79 N 1891.80 E 6010640.51N 531188.81E 2559.22 N 2073.55 E 6010883.65 N 531369.61E 2804.32 N 2252.26 E 6011129.46 N 531547.35 E 3011.85 N 2407.65 E 6011337.59 N 531701.93 E 3108.62 N 2482.16 E 6011434.66 N 531776.06 E 3290.44 N 2619.43 E 6011617.02 N 531912.61 E 3477.04 N 2757.15 E 6011804.16 N 532049.60 E 3661.72 N 2892.20 E 6011989.36 N 532183.92 E 3844.99 N 3026.48 E 6012173.16 N 532317.48 E 4029.88 N 3160.64 E 6012358.58 N 532450.92 E 4218.00 N 3295.12 E 6012547.23 N 532584.65 E 4405.65 N 3431.82 E 6012735.41 N 532720.62 E 4526.75 N 3521.03 E 6012856.86 N 532809.35 E 4646.93 N 3609.56 E 6012977.38 N 532897.41 E 4769.61 N 3700.20 E 6013100.42 N 532987.56 E 4890.77 N 3790.74 E 6013221.94 N 533077.63 E 5010.21 N 3881.39 E 6013341.73 N 533167.80 E 5132.32 N 3972.98 E 6013464.20 N 533258.92 E Alaska State Plane Zone 4 Kuparuk 3K Dogleg Vertical Rate Section (°/100ft) (fi) Comment 0.868 947.34 0.696 1170.76 0.777 1390.37 0.538 1693.85 0.486 1999.50 0.458 2300.67 0.135 2593.08 0.244 2883.65 0.193 3178.85 0.166 3475.26 0.605 3727.88 0.388 3846.51 0.317 4068.29 1.023 4294.63 1.035 4518.13 0.077 4740.03 0.226 4963.37 0.227 5189.79 0.620 5416.67 0.366 5563.50 0.475 5709.20 0.415 5858.04 0.817 6005.46 0.199 6151.34 0.154 6300.04 Continued... 8 February, 1999 - 15:03 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 3K-24 MWD Your Ref: API-500292293500 Job No. AKMM90057, Surveyed: 25 January, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 9313.95 55.090 36.860 5967.37 6042.67 9500.59 54.440 36.660 6075.04 6150.34 9686.38 54.230 36.740 6183.37 6258.67 9780.08 53.860 36.820 6238.38 6313.68 9874.68 53.710 36.740 6294.27 6369.57 9912.51 54.630 37.160 6316.42 6391.72 9944.46 55.720 36.720 6334,67 6409.97 9974.64 56.610 36.270 6351.47 6426.77 10006.18 57.600 36.660 6368.60 6443.90 10036.97 58.800 35.660 6384.82 6460.12 10068.30 60.450 35.250 6400.67 6475.97 10098.45 62.610 33.810 6415.04 6490.34 10129.66 63.740 32.830 6429.12 6504.42 10157.03 64.860 32.460 6440.99 6516.29 10190.76 65.300 32.310 6455.20 6530.50 10221.91 65.690 31.920 6468.12 6543.42 10253.80 66.440 31.560 6481.06 6556.36 10284.00 67.090 31.140 6492.97 6568.27 10315.57 68.400 30.790 6504.93 6580.23 10345.43 69.850 30.970 6515.57 6590.87 10377.10 71.700 29.970 6526.00 6601.30 10397.21 73.240 30.950 6532.06 6607.36 10438.51 76.690 30.880 6542.77 6618.07 10464.71 78.680 31.270 6548.36' 6623.66 10564.27 82.740 32.870 6564.43 6639.73 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 5253.84 N 4063.95 E 6013586.08 N 533349.40 E 5375.97 N 4155.18 E 6013708.57 N 533440.16 E 5497.00 N 4245.39 E 6013829.94 N 533529.89 E 5557.75 N 4290.80 E 6013890.87 N 533575.06 E 5618.88 N 4336.50 E 6013952.18 N 533620.52 E 5643.39 N 4354.94 E 6013976.76 N 533638.86 E 5664.35 N 4370.70 E 6013997.79 N 533654.54 E 5684.50 N 4385.61 E 6014018.00 N 533669.37 E 5705.80 N 4401.35 E 6014039.36 N 533685,03 E 5726.93 N 4416.79 E 6014060.55 N 533700.38 E 5748.94 N 4432.46 E 6014082.63 N 533715.97 E 5770.78 N 4447.48 E 6014104.52 N 533730.90 E 5794.05 N 4462.78 E 6014127.85 N 533746.11E 5814.82 N 4476.08 E 6014148.67 N 533759.33 E 5840.65 N 4492.47 E 6014174.57 N 533775.61 E 5864.66 N 4507.53 E 6014198.63 N 533790.59 E 5889.45 N 4522.87 E 6014223.48 N 533805.82 E 5913.15 N 4537.31 E 6014247.24 N 533820.17 E 5938.20 N 4552.34 E 6014272.35 N 533835.10 E 5962.14 N 4566.66 E 6014296.35 N 533849.33 E 5987.92 N 4581.82 E 6014322.18 N 533864.39 E 6004.44 N 4591.54 E 6014338.75 N 533874.04 E 6038.66 N 4612.03 E 6014373.04 N 533894.40 E 6060.58 N 4625.24 E 6014395.02 N 533907.52 E 6143.82 N 4677.40 E 6014478.46 N 533959.36 E Alaska State Plane Zone 4 Kuparuk 3K Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.130 6447.96 0.359 6596.54 0.118 6743.70 0.401 6817.62 0.173 6892.00 2.593 6921.87 3.594 6947.41 3.198 6971.87 3.306 6997.71 4.776 7023.28 5.386 7049.75 8.304 7075.79 4.578 7103.26 4.270 7127.63 1.365 7157.88 1.693 7185.93 2.568 7214.80 2.503 7242.31 4.274 7271.31 4.889 7298.99 6.558 7328.70 8.957 7347.74 8.355 7387.32 7.733 7412.71 4.375 7509.93 Continued... 8February, 1999- 15:03 -4- DrillQuest Sperry-Sun Drilling Services Survey Report for 3K-24 MWD Your Ref: API-500292293500 Job No, AKMM90057, Surveyed: 25 January, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 10594.21 84.100 34.080 6567.86 6643.16 10625.09 85.680 34.420 6570.61 6645.91 10655.83 86.420 34.800 6572.72 6648.02 10687.92 87.110 33.810 6574.54 6649.84 10719.11 87.780 34.350 6575.93 6651.23 10750.08 88.340 33.700 6576.97 6652.27 10780.74 88.710 32.880 6577.76 6653.06 10812.03 89.020 32.690 6578.38 6653.68 10842.76 89.130 31.140 6578.88 6654.18 10873.05 89.510 32.430 6579.24 6654.54 10903.10 89.380 32.260 6579.53 6654.83 10933.94 88.270 31.220 6580.16 6655.46 10964.39 87.350 31.310 6581.33 6656.63 10995.40 86.920 29.890 6582.88 6658.18 11026.32 86.060 29.600 6584.77 6660.07 11056.82 85.880 29.710 6586.91 6662.21 11087.98 86.240 30.710 6589.05 6664.35 11118.57 86.850 31.200 6590.90 6666.20 11150.26 87.470 32.470 6592.47 6667.77 11181.45 88.020 31.120 6593.69 6668.99 11212.15 88.520 30.130 6594.62 6669.92 11258.05 88.920 29.790 6595.65 6670.95 11289.95 89.570 31.710 6596.07 6671.37 11320.27 90.530 31.260 6596.04' 6671.34 11351.54 91.390 28.850 6595.52 6670.82 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 6168.63 N 4693.81E 6014503.33 N 533975.67 E 6194.05 N 4711.12 E 6014528.82 N 533992.88 E 6219.29 N 4728.54 E 6014554.13 N 534010.20 E 6245.75 N 4746.59 E 6014580.66 N 534028.15 E 6271.56 N 4764.05 E 6014606.54 N 534045.51E 6297.21 N 4781.37 E 6014632.26 N 534062.72 E 6322.83 N 4798.19 E 6014657.95 N 534079.45 E 6349.13 N 4815.13 E 6014684.31 N 534096.28 E 6375.21 N 4831.38 E 6014710.46 N 534112.42 E 6400.96 N 4847.33 E 6014736.26 N 534128.28 E 6426.35 N 4863.41 E 6014761.71 N 534144.25 E 6452.57 N 4879.63 E 6014788.00 N 534160.37 E 6478.58 N 4895.42 E 6014814.07 N 534176.06 E 6505.23 N 4911.18 E 6014840.79 N 534191.72 E 6532.03 N 4926.50 E 6014867.64 N 534206.92 E 6558.47 N 4941.55 E 6014894.14 N 534221.87 E 6585.33 N 4957.19 E 6014921.07 N 534237.41 E 6611.52 N 4972.90 E 6014947.31 N 534253.01 E 6638.41 N 4989.59 E 6014974.27 N 534269.60 E 6664.90 N 5006.01E 6015000.82 N 534285.92 E 6691.30 N 5021.64 E 6015027.29 N 534301.45 E 6731.06 N 5044.56 E 6015067.13 N 534324.21 E 6758.47 N 5060.87 E 6015094.61 N 534340.41 E 6784.32 N 5076.70 E 6015120.53 N 534356.14 E 6811.38 N 5092.36 E 6015147.65 N 534371.69 E Alaska State Plane Zone 4 Kuparuk 3K Dogleg Vertical Rate Section (°/100fi) (ft) Comment 6.062 7539.25 5.233 7569.50 2.705 7599.62. 3.756 7631.13 2.758 7661.79 2.769 7692.25 2.933 7722.49 1.162 7753.39 5.056 7783.81 4.439 7813.80 0.712 7843.52 4.932 7874.06 3.036 7904.23 4.779 7934.99 2.935 7965.69 0.691 7995.95 3.404 8026.85 2.556 8057.15 4.455 8088.49 4.671 8119.35 3.611 8149.82 1.144 8195.45 6.354 8227.11 3.497 8257.16 8.182 8288.24 Continued... 8February, 1999-15:03 -5- DrlllQuest Sperry-Sun Drilling Services Survey Report for 3K-24 MWD Your Ref: API-500292293500 Job No, AKMM90057, Surveyed: 25 January, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 11382.32 92.830 29.890 6594.38 11412.55 93.730 28.270 6592.65 11443.72 94.420 28.810 6590.44 11474.80 94.780 28,040 6587.95 11505.18 94.680 25.890 6585.44 11536.24 94.170 24.910 6583.04 11567.25 93.210 21.730 6581.o5 11597.72 92.990 21.70o 6579.40 11628.69 92.870 22.050 6577.82 11658.18 93.230 19,440 6576.25 11689.07 92.860 18.610 6574.61 11720.61 91.910 16.920 6573.29 11751.61 91.380 13.680 6572.40 11782.58 91.54o 12.170 6571.62 11813.25 90.740 12.320 6571.o0 11845.67 91.170 12.010 6570.46 11875.95 91.85o 11.53o 6569.67 11907.14 91.850 11,020 6568.66 11937.94 88,260 8.08o 6568.63 11968.47 83.730 5.200 6570.76 11999.54 82.460 3.600 6574.50 12030.40 82.590 0.540 6578.51 12060.79 83.550 359.700 6582.18 12092.37 84.080 357,760 6585.58 12123.44 85.010 355.160 6588.54 Vertical Depth (ft) 6669.68 6667.95 6665.74 6663.25 6660.74 6658.34 6656.35 6654.70 6653.12 6651.55 6649.91 6648.59 6647.70 6646.92 6646.30 6645.76 6644.97 6643.96 6643.93 6646.06 6649.80 6653.81 6657.48 · 6660.88 6663.84 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 6838.19 N 5107.45 E 6015174.51 N 534386.67 E 6864.56 N 5122.11 E 6015200.94 N 534401.23 E 6891.88 N 5136.97 E 6015228.32 N 534415.98 E 6919.12 N 5151.72 E 6015255.62 N 534430.62 E 6946.10 N 5165.44 E 6015282.65 N 534444.24 E 6974.08 N 5178.73 E 6015310.68 N 534457.42 E 7002.49 N 5190.97 E 6015339.14 N 534469.55 E 7030.76 N 5202.23 E 6015367.45 N 534480.70 E 7059.46 N 5213.75 E 6015396.20 N 534492.11E 7087.00 N 5224.18 E 6015423.78 N 534502.43 E 7116.16 N 5234.24 E 6015452.98 N 534512.37 E 7146.17 N 5243.85 E 6015483.02 N 534521,87 E 7176.05 N 5252.03 E 6015512.94 N 534529.93 E 7206.23 N 5258.95 E 6015543.14 N 534536.73 E 7236.19 N 5265.46 E 6015573.13 N 534543.12 E 7267.88 N 5272.29 E 6015604.85 N 534549.82 E 7297.51N 5278.46 E 6015634.50 N 534555.88 E 7328.08 N 5284.56 E 6015665.10 N 534561.86 E 7358.45 N 5289.67 E 6015695.48 N 534566.85 E 7388.69 N 5293.19 E 6015725.74 N 534570.25 E 7419.44 N 5295.56 E 6015756.50 N 534572.50 E 7450.02 N 5296.66 E 6015787.08 N 534573.48 E 7480.18 N 5296.72 E 6015817.24 N 534573.42 E 7511.57 N 5296.03 E 6015848.63 N 534572.60 E 7542.44 N 5294.12 E 6015879.49 N 534570.57 E Alaska State Plane Zone 4 Kuparuk 3K Dogleg Vertical Rate Section (°ll00ff) (ft) Comment 5.770 8318.85 6.123 8348.91 2,808 8379.89 2,728 8410.77 7.061 8441.00 3.549 8471.96 10.691 8502.90 0.729 8533.30 1.193 8564.21 8.922 8593.62 2.938 8624.36 6.143 8655.69 10.586 8686.33 4.901 8716.73 2.654, 8746.77 1.635 8778.51 2.749 8808.11 1.634 8838.54 15.065 8868.38 17.569 8897.47 6.545 8926.55 9.840 8954.97 4.184 8982.59 6.334 9011.02 8.852 9038.48 Continued... 8 February, 1999- 15:03 -6- DrlllQuest Sperry-Sun Drilling Services Survey Report for 3K-24 MWD .Your Ref: API-500292293500 Job No. AKMM90057, Surveyed: 25 January, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 12153.76 85.090 352.800 6591.15 6666.45 12185.35 85.250 349.680 6593.81 6669.11 12216.13 85.530 348.110 6596.29 6671.59 12246.66 84.720 348.280 6598.88 6674.18 12277.55 83.920 344.510 6601.94 6677.24 12308.51 83.310 341.510 6605.38 6680.68 12339.03 83.060 339.450 6609.01 6684.31 12370.11 84.810 335.780 6612.29 6687.59 12400.58 87.780 330.280 6614.26 6689.56 12431.79 91.080 327.960 6614.57 6689.87 12462.88 93.360 325.070 6613.37 6688.67 12494.49 93.960 323.150 6611.35 6686.65 12524.80 93.630 320.690 6609.34 6684.64 12555.92 93.440 319.420 6607.42 6682.72 12586.94 91.910 319.340 6605.98 6681.28 12617.45 89.910 318.580 6605.49 6680.79 12648.31 89.110 317.630 6605.76 6681.06 12679.22 88.060 '317.670 6606.52 6681.82 12710.62 86.580 318.130 6607.99 6683.29 12741.46 85.920 316.950 6610.00 6685.30 12772.67 85.320 314.380 6612.39 6687.69 12803.39 85.270 312.230 6614.91 6690.21 12834.45 86.300 309.190 6617.19 6692.49 12865.52 88.270 308.510 6618.66' 6693.96 12895.88 89.880 306.050 6619.15 6694.45 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 7572.47 N 5290.95 E 6015909.51 N 534567.29 E 7603.58 N 5286.16 E 6015940.60 N 534562.37 E 7633.69 N 5280.25 E 6015970.68 N 534556.34 E 7663.46 N 5274.02 E 6016000.43 N 534550.00 E 7693.33 N 5266.80 E 6016030.28 N 534542.66 E 7722.75 N 5257.81 E 6016059.66 N 534533.55 E 7751.32 N 5247.68 E 6016088.18 N 534523.32 E 7779.89 N 5235.91 E 6016116.71 N 534511.44 E 7806.97 N 5222.13 E 6016143.74 N 534497.54 E 7833.75 N 5206.11 E 6016170.45 N 534481.43 E 7859.66 N 5188.98 E 6016196.29 N 534464.19 E 7885.21N 5170.48 E 6016221.77 N 534445.59 E 7909.02 N 5151.83 E 6016245.51N 534426.85 E 7932.83 N 5131.89 E 6016269.24 N 534406.81 E 7956.35 N 5111.72 E 6016292.68 N 534386.55 E 7979.35 N 5091.69 E 6016315.61 N 534366.43 E 8002.32 N 5071.08 E 6016338.50 N 534345.73 E 8025.16 N 5050.27 E 6016361.25 N 534324.83 E 8048.43 N 5029.24 E 6016384.44 N 534303.71 E 8071.14 N 5008.47 E 6016407.06 N 534282.85 E 8093.39 N 4986.72 E 6016429.23 N 534261.01E 8114.39 N 4964.44 E 6016450.14 N 534238.65 E 8134.59 N 4940.96 E 6016470.25 N 534215.10 E 8154.06 N 4916.79 E 6016489.62 N 534190.85 E 8172.44 N 4892.64 E 6016507.91 N 534166.63 E Alaska State Plane Zone 4 Kuparuk 3K Dogleg Vertical Rate Section (°/lOOff) (fi) Comment 7.759 9064.68 9.854 9091.19 5.165 9116.34 2.711 9141.06 12.418 9165.47 9.829 9188.75 6.752 9210.78 13.022 9232.16 20.479 9251.37 12.924 9269.39 11.834 9286.16 6.352 9302.07 8.171 9316.3o 4.119 9330.03 4.939 9343.39 7.012 9356.34 4.024 9369.03 3.399 9381.51 4.935 9394.30 4.377 9406.67 8.433 9418.24 6.977 9428.45 10.309 9437.44 6.707 9445.48 9.683 9452.54 Continued... 8 February, 1999-15:03 - 7- DrlllQuest Sperry-Sun Drilling Services Survey Report for 3K-24 MWD Your Ref: AP1-$00292293500 Job No. AKMM90057, Surveyed: 25 January, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 12927.14 90.000 303.850 6619.19 12957.77 89.850 303.120 6619.23 12988.22 89.510 301.180 6619.40 13019.11 88.980 300.840 6619.80 13050.04 88.550 299.610 6620.47 13080.44 88.910 298.010 6621.14 13111.46 89.200 296.490 6621.66 13142.28 89.170 294.740 6622.09 13174.14 89.100 292.510 6622.58 13205.21 89.720 290.040 6622.90 13236.16 90.650 289.430 6622.80 13266.85 91.820 288.570 6622.13 13297.67 92.460 288.670 6620.98 13328.64 92.710 287.840 6619.59 13359.12 92.990 287.730 6618.07 13390.32 93.240 288.800 6616.38 13421.26 93.270 289.540 6614.62 13451.85 90.620 289.650 6613.58 13483.11 90.000 289.390 6613.41 13518.90 89.810 289.600 6613.47 13544.60 89.910 290.060 6613.53 13575.75 90.060 290.200 6613.54 13606.29 90.370 291.230 6613.43 13637.21 89.850 291.020 6613.37 13668.66 89.010 290.810 6613.68 Vertical Depth (ft) 6694.49 6694.53 6694.70 6695.10 6695.77 6696.44 6696.96 6697.39 6697.88 6698.20 6698.10 6697.43 6696.28 6694.89 6693.37 6691.68 6689.92 6688.88 6688.71 6688.77 6688.83 6688.84 6688.73 · 6688.67 6688.98 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 8190.35 N 4867.02 E 6016525.72 N 534140.94 E 8207.25 N 4841.48 E 6016542.52 N 534115.32 E 8223.45 N 4815.70 E 6016558.62 N 534089.48 E 8239.36 N 4789.22 E 6016574.43 N 534062.95 E 8254.93 N 4762.51 E 6016589.89 N 534036.17 E 8269.58 N 4735.88 E 6016604.43 N 534009.48 E 8283.78 N 4708.30 E 6016618.52 N 533981.85 E 8297.10 N 4680.52 E 6016631.73 N 533954.01 E 8309.86 N 4651.33 E 6016644.38 N 533924.78 E 8321.14 N 4622.38 E 6016655.54 N 533895.79 E 8331.59 N 4593.25 E 6016665.88 N 533866.61 E 8341.58 N 4564.24 E 6016675.75 N 533837.56 E 8351.41N 4535.06 E 6016685.47 N 533808.34 E 8361.10 N 4505.67 E 6016695.05 N 533778.92 E 8370.40 N 4476.69 E 6016704.23 N 533749.90 E 8380.16 N 4447.10 E 6016713.88 N 533720.27 E 8390.31 N 4417.93 E 6016723.91 N 533691.06 E 8400.56 N 4389.13 E 6016734.05 N 533662.22 E 8411.00 N 4359.66 E 6016744.38 N 533632.71 E 8422.95 N 4325.93 E 6016756.19 N 533598.93 E 8431.67 N 4301.75 E 6016764.81 N 533574.72 E 8442.39 N 4272.50 E 6016775.42 N 533545.43 E 8453.19 N 4243.94 E 6016786.11 N 533516.82 E 8464.33 N 4215.10 E 6016797.14 N 533487.94 E 8475.56 N 4185.72 E 6016808.25 N 533458.52 E Alaska State Plane Zone 4 Kuparuk 3K Dogleg Vertical Rate Section (°/100ft) (ft) Comment 7.048 9458.56 2.433 9463.70 6.468 9468.10 2.038 9471.96 4.212 9475.41 5.393 9478.04 4.988 9479.89 5.678 9480.85 7.002 9480.73 8.196 9479.35 3.594 9477.13 4.731 9474.55 2.102 9471.75 2.796 9468.74 0.987 9465.54 3.517 9462.51 2.390 9460.00 8.670 9457.74 2.151 9455.39 0.791 9452.69 1.832 9450.89 0.659 9448.88 3.522 9447.22 1.814 9445.76 2.753 9444.16 Continued... 8February, 1999- 15:03 -8- DrillQuest Sperry-Sun Drilling Services Survey Report for 3K-24 MWD Your Ref: API-500292293500 Job No. AKMM90057, Surveyed: 25 January, 1999 Prudhoe Bay Unit Measured sUb-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 13699.65 88.610 289.800 6614.32 6689.62 8486.31 N 4156.66 E 6016818.89 N 533429.42 E 13730.05 88.580 290.610 6615.07 6690.37 8496.81 N 4128.14 E 6016829.27 N 533400.86 E 13761.43 88.700 291.030 6615.81 6691.11 8507.96 N 4098.82 E 6016840.30 N 533371.49 E 13792.19 88.770 292.410 6616.49 6691.79 8519.34 N 4070.25 E 6016851.57 N 533342.88 E 13822.87 88.880 292.070 6617.12 6692.42 8530.95 N 4041.86 E 6016863.07 N 533314.44 E 13854.39 88.950 292.470 6617.72 6693.02 8542.89 N 4012.70 E 6016874.90 N 533285.23 E 13885.39 89.130 292.550 6618.24 6693.54 8554.76 N 3984.06 E 6016886.65 N 533256.55 E 13916.82 89.240 292.750 6618.69 6693.99 8566.86 N 3955.06 E 6016898.64 N 533227.50 E 13947.74 89.230 293.060 6619.10 6694.40 8578.89 N 3926.58 E 6016910.56 N 533198.97 E 13978.69 89.380 293.470 6619.47 6694.77 8591.12 N 3898.15 E 6016922.67 N 533170.49 E 14012.41 89.240 293.660 6619.88 6695.18 8604.60 N 3867.24 E 6016936.03 N 533139.54 E 14073.00 89.240 293.660 6620.68 6695.98 8628.91 N 3811.75 E 6016960.13 N 533083.95 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. · ' Magnetic Declination at Surface is 27.215° (25-Jan-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 23.833° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14073.00ft., The Bottom Hole Displacement is 9433.32ft, in the Direction of 23.833° (True). Alaska State Plane Zone 4 Kuparuk 3K Dogleg Rate (°/100ft) Vertical Section (ft) Comment 3.505 2.665 1.392 4.491 1.165 1.288 0.635 0.726 1.003 1.41o 0.700 0.000 9442.25 9440.33 9438.68 9437.54 9436.69 9435.83 9435.12 9434.47 9433.97 9433.66 9433.50 9433.32 Projected Survey Continued... 8 February, 1999 - 15:03 - 9 - DrillQuest Sperry-Sun Drilling Services Survey Report for 3K-24 MWD Your Ref: API-500292293500 Job No. AKMM90057, Surveyed: 25 January, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 3K Comments Measured Depth (ft) 14073.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6695.98 8628.91 N 3811.75 E Comment Projected Survey 8 February, 1999- 15:03 - 10- DrlllQuest ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 22, 1998 Mr. Blair Wondzell Senior Petroleum Engineer State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3K-24 Dear Mr. Wondzell: This is notification that we are planning to use the Parker #245 rig to drill the well 3K-24, instead of Doyon #19 as we previously mentioned in the original Permit to Drill. Enclosed are the BOP diagrams for the Parker #245 rig. If there are any questions, please call 263-4622. Sincerely, S. A. Goldberg Drilling Engineer AAI Drilling SG/skad MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson~,F- DATE: Chairman THRU: Blair Wondzell, .~_ FILE NO: P. I. Supervisor-'-~[/5'~ FROM: Lou Grimaldi,~/~o.~ SUBJECT: Petroleum Inspector Januaw 8,1999 ACXJAHGE.DOC BOP Test, Parker 245 Arco well # 3K-24 Kuparuk River field PTD #98-0249 Non-Confidential Friday, January 8, 1999; I witnessed the initial BOP test on Parker 245 drilling Arco well # 3K-24 in the Prudhoe Bay field. The rig was not ready to test when I arrived and began within two hours. The BOP equipment all tested "OK" and as usual I found this rigs test procedure to be sure and methodical. I toured the rig and its surrounding area with Ricky Ainsworth (Toolpusher). I found the rig and location to be neat and clean. SUMMARY: The initial BOPE test I witnessed on Parker 245 revealed the following; four test hours, No Failures observed. Attachments: ACXJAHGE.XLS cc; Mike Zanghi (Drilling Supt.) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: Parker Rig No. 245 PTD # Arco Alaska Rep.: 3K-24 Rig Rep.: Set @ Location: Sec. Weekly Other DATE: 1/8/99 98-249 Rig Ph.# 659-7670 Don Breden Ricky Ainsworfh 35 T. 13N R. 9E Meridian Umiat MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign P Drl. Rig P Hazard Sec. P Quan. Test Press. P/F 1 250/3500 P 1 250/5, 000 P 1 250/5, 000 P 1 250/5,000 P 1 250/5,000 P 2 250/5, 000 P 1 250/5,000 P N/A 250/5,000 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Moth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quan. Pressure P/F I 250/5, 000 P 250/5,000 P 250/5,000 P 250/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 16 250/5,000 P 38 250/5,000 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: 6 Bottles 1900 Average 3,000 1,750 P minutes 45 sec. minutes 20 sec. Remote: P Psig. Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good test, No failures. Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES Yes NO 24 HOUR NOTICE GIVEN YES Yes NO Waived By: Witnessed By: Louis R. Grimaldi FI-021L (Rev. 12/94) ACXJAHGE.xIs TONY KNOWLE$, GOVERNOR ALASKA OIL A~D GAS CONSERVATION COMMISSION December 21, 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Chip Alvord Drilling Team Leader ARCO Alaska. Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kupamk River Unit 3K-24 ARCO Alaska, Inc. Permit No: 98-249 Sur Loc: 1322'FSL, 317'FWL, SEC 35, T13N, R09E, UM Btmholc Loc. 631'FNL, 1105'FEL, SEC 26, T13N? R09E, UM Dear Mr. Alvord: Enclosed is thc approved application for permit to drill thc above referenced well. Annular disposal of drilling wastes will not bc approved for this well until sufficient data is submitted to ensure that thc requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data. and any CQLs must be submitted to the Commission on form 10403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which arc pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 3K must comply with thc requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through thc annular space of a single well or to usc that well for disposal purposcs for a period longer than one .,,,car. The permit to drill docs not exempt you from obtaining additional pcrlnits required by laxv from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Commissionc~.~~) BY ORDER OF 'rile COMMISSlO,~ dlffEnclosures Department of Fish & Game, {[abitat Section w/o encl. Department of Environmental Conservation w,"o encl. STATE OF ALASKA OIL AND GAS CONSERVATION COMi'~,~;~3SION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll X Reddll I lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 34' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25519, ALK 2555 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1322' FSL, 317' FWL, Sec.35, T13N, RDE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2379' FSL, 158' FEL, Sec. 26, T13N, RDE, UM 3K-24 #U-630610 At total depth 9. Approximate spud date Amount 631' FNL, 1105' FFL, Sec. 26, T13N, RDE, UM 12/20/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line 3K-5 13995' MD 158' @ Target feet 10' @ 422' feet 2560 6647' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 92.4° Maximum surface 2769 psig At total depth (TVD) 3500 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Wei~lht Grade Coupling Length MD TVD MD TVD (include sta~e data) 20" 16" 62.5# H-40 Weld 80' 41' 41' 117' 117' +_200 CF 12.25" 9.625" 40# L-80 BTC 5895' 41' 41' 5936' 4090' 1) 230 Sx Arcticset III L & 690 Sx Class G 2) 530 sx ASlll L & 60 sx ASI 8.55" 7" 26# L-80 BTC-M 10416' 41' 41' 10455' 6610' 170 sxClass G 6.125" 4.5" 12.6# L-80 BTC-M 3740' 10255' 6554' 13995' 6647' N/A - slotted liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat X BOP Sketch X DiverterSketch X Drilling program X Drilling fluid program X Timevs depth plot ~i Refraction analysis E~ Seabed report Fi 20AA025.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~,..~'o ~ Title Drilling Team Leader Date it Commission Use Only Permit Number I AP, number I Approva, date I "~...~ l:% I See cover letter for ~;~,,~7. ~ ~/~' 50- '~ ~ ~ -- .2- ~ ~ 3 ~' other requirements Cond'iti~ns of approval Samples required [--~ Yes ~ No Mud'lo~req'u~red [~ Yes J~ No Hydrogen sulfide measures 'J~ Yes [~ No Directional survey required ~ Yes r~ No Required working pressure for BOPE E~ 2M [~ 3M [~0 [~ 1OM [~ 15M Other: Approved by ])svid W. ,,0hnston Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate ORigiNAL ARCO Alaska, Inc. Posi Office ]~r~'i~ 'I00360 Anchorage, Alaska 99510~0360 Telephone 907 276 !2!5 November 25, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill 3K-24 Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Kuparuk 3K pad in the Kuparuk River Unit (KRU). The anticipated spud date for this well is December 20, 1998. It is intended that Doyon Rig 19 be used to drill the well. The well is designed as a horizontal production well using a 9 5/8" surface casing string, a 7" intermediate casing string, a 4 1/2" slotted liner and 3 ½" production tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for you review. Pertinent information attached to this application includes the following: 10. 11. 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. Plat, identifying the property and location of the proposed 3K-24 well. 4. A proposed drilling program, including a request for approval of annular pumping operations. 5. A drilling fluids program summary, description and diagrams of the drilling fluid system. 6. Proposed completion diagram plus description of casing / tubing. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Proposed cementing program and calculations. 9. A diagram and description of the BOP equipment as required by 20 ACC 25.035 (a) (1). A diagram and description of the diverter equipment as required by 20 ACC 25.035 (b). Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Based on close offset information, no over-pressured strata is predicted for well 3K-24. Attached is a copy of reservoir pressure prediction map (based on well test data. This work indicates that 3K-24 should not drill into an over-pressured reservoir fault block. No shallow gas / hyd~....,e problems were encountered in th~--~ffset 3K wells. Please note, ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment operating on well 3K-24. Also note, that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations are planned. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Chip Alvord at 265-6120. Sincerely, Brian Robertson Senior Drilling Engineer CC: 3K-24 Well File Chip AIvord Sharon AIIsup-Drake Guy Schwartz Doug Chester ATO -1030 ATO -1054 ATO -1280 ANO - 382 13/3/971 DCS BCM PI (SB# K96140ACS '~ ~ /~ OIJKTOK PT. ~.~. ~_~ o,:~ ~~~ ~ o 2 .~ ~ ~ ~ ~ VIC/N/TY MAP o 6 SCALE: 1" = 2 MILES ~ 25 · o 7 2~ · o ~ ~E~END o EXIS~NG CONDUCTORS o I0 ~ 30 · · NEW CONDUCTOR L o 11 ~2 ~ 12 o ,j N JJ $ ~ 0 14 ~ O 15 ~ , 0 o ~Y o ~ i I J5 T. 13 N. [ ~ T. 12 N. SEE SHE~ ~ 2 FOR NOTES ~D LO~TION INFORMATION 2 B LOUNSBURY ~[ & ASSOCIATES, INC. ~ EN~ P~NE~ ~ ~ co~aucm~s ~22-2~, 3o-~ LKB311D9 03/01/97 CEA-D3KX-6311D9 1 ~' 2 1 ~xcloO~,~ou K TOK PT. v.,,f \~,o.s.~ NO~S 1. COORDINATES SHO~ ARE A.S.P. ZONE 4, N.A.D. 2Z ELEVATIONS EHO~ ARE BRITISH PETROLEUM MEAN SEA LEAL. 2. BASIS OF LOCAT~NS AND ELEVA~ONS ARE D.S. 5-K MONUMENTS PER LHD AND ASSOCIATES. TO,SHIP lJ NORTH, RANGE 9 EAS~ UMIAT MERIDIAN. 5. DATE OF SUR~' 02~26-27/97. FB: 97-04, PG 54-62, o3/o~/97. FB: 97-04, PG ~. OmLL m~ Z-K cmo NO~ ~S ~OT~TEO ~9' 5~' 5O" ~ST FROM A.5. P. ZONE 4 GRID NORTH VICINITY MAP Sec. 35, T. 13 N., R. 9 E.. U.M. SC~L~: ~"= 2 ~L~S Well SEC SEC PAD O. G. No. ,y, A.S.P.s 'X' LA TITUDE LONGITUDE LINE i LINE ~ o/s o/s ELE~ ELE~ , i F.S.L. ~ F. ~L. I ~ i 22 6,00&366.54 ~ 529,306.21 70" 26' 02. 169" ~ 149" 45' 39.936" 1372' . 318' 34.3 23 &OO&341.52 ~ 529,306. 10 70' 26' 01.923" 149" 45' 39.942" 1347' 318' 34.3 24 = 6,00&316. Jl i 529,306.13 70' 26' 01.675" 149' 45' 39.944" 1322' 317' 34.3 25 ~ &OO&291.50 529,306. 13 70' 26' 01.431" 149" 45' 39.947" 1297' 317' 34.3 29.0 26 ~ 6,008,266.25 529,305.78 70" 26' 01.182" 149' 45' 39.960" 1272' 317' 34.3 29.0 27 6,008,241.56 529,305.97 70' 26' 00.939" 149' 45' 39.957" 1247' 317' 34.3 29.1 30 6,00&141.37 529,306.04 70" 25' 59.954" : 149' 45' 39.967" 1147' 316' 34.3 29.9 31 6,00&116.37 529,305.88 70' 25' 59.708" 149' 45' 39.974" 1122' 316' 34.3 30.0 32 6,00&091.62 529,305.51 70' 25' 59.465" 149' 45' 39.988" 1097' 316' 34.3 30.0 33 6,00&066.76 529,305.49 70' 25' 59.220" 149' 45' 39.992" 1073' 316' 34.3 30.0 34 6,008,041.51 529,505.79 70" 25' 5&972" 149' 45' 39.986" 1047' 316' 34.3 30.0 35 6,00&016.48 529,305.79 70' 25' 5&726" 149' 45' 39.989" 1022' 316' 34.3 30,0 36 . 6,007.991.38 529,305.46 70' 25' 58.479" 149" 45' 40.001" 997' 315' 34.3 30.0 ~*~_ O~ ~"~, SUR~YOR'S CERTIFICA ~ ~ ~,,* ~ .,,,_~& I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND ~ ~ ~-%,. ~ LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ~ ~ 49th ~ ~'~ ~ ~L~SK~ ANO rH~r TH~S PLAT ~EPRESENTS ~ SURVEY THAT ALL DIMENSIONS AND OTHE~ DETAILS A~E CORRECT ~ BRIAN G. MANGOLD ~ ~ ~ ~S OF ~CH 2, 1997. ............ , ssoc z s. e~°~ss~o.~~ AREA' 3K MODULE' XX UNIT' ARCO Alaska, Inc. ~[t CONDUCTORS ~t2-t7, 30-36 LOCA~ON AS-BUILT LK6311D9 03/01/97 CEA-D3KX-6311D9 2 ~ 2 1 SEC. SEC. PAD O. G. We// A.S.P.s LA TITUDE LONGITUDE LINE LINE No. 'Y' 'X' O/S O/S ELEV. ELEV. F.S.L. F. W.L. 22 6,008,366.54 529, J06.21 70' 26' 02.169" 149' 45' Jg. 936" 1372' 318' 34.3 28.6 2J 6,008, J41.52 529, J06.10 70' 26' 01.92J" 149' 45' J9.942" 1J47' J18' J4. J 28.8 24 6,008, J16. Jl 529,$06.1,7 70' 26' 01.675" 149' 45' J9.944" 1J22' $17' J4. J 28.9 25 6,008,291.50 529, J06. lJ 70' 26' 01.431" 149' 45' J9.947" 1297' J17' J4. J 29.0 26 6,008,266.25 529,305.78 70' 26' 01.182" 149' 45' 39.960" 1272' J17' J4. J 29.0 27 6,008,241.56 529, J05.97 70' 26' 00.939" 149' 45' J9.957" 1247' 317' J4. J 29.1 JO 6,008,141. J7 529, J06.04 70' 25' 59.954" 149' 45' J9.967" 1147' 316' J4. J 29.9 Jl 6,008,116. J7 529,305.88 70' 25' 59.708" 149' 45' J9.974" 1122' 316' J4. J JO.O J2 6,008,091.62 529, J05.51 70' 25' 59.465" 149' 45' J9.988" 1097' J16' J4. J J0.0 JJ 6,008,066.76 529,305.49 70' 25' 59.220" 149' 45' J9.992" 107J' 316' J4. J JO.O 34 6,008,041.51 529,305.79 70' 25' 58.972" 149' 45' J9.986" 1047' 316' J4. J JO.O J5 6,008,016.48 529, J05.79 70' 25' 58.726" 149' 45' J9.989" 1022' J16' J4.3 J0.0 36 6,007.991.38 529, J05.46 70' 25' 58.479" 149' 45' 40.001" 997' $15' $4.$ JO.O 3K-24 PROPOSED DRILLING PROGRAM , 3. 4. 5. 6. 7. , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. Procedure Move in drilling rig. Install diverter and function test. (16" conductor pre-installed) Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run 9 5/8" surface casing. Perform two stage cement job to ensure cement returns to surface. Install and test BOPE to 3500 psi. Clean out cementing equipment. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Displace hole to LSND mud system. Drill 8 ~" intermediate hole as per the directional plan. Section TD to be 50 ft TVD depth into the B Shale above the Kuparuk A sands. Note LWD (GR / Res) will be run over this section. Run 7" inch casing to TD and cement casing string as per program. Pump enough cement to allow for 800 ft of annular fill to ensure compliance with Rule 20 AC 25.030 (d) (3). Freeze protect 9 5/8" x 7" annulus. Clean out cementing equipment. Pressure test casing to 3500 psi. Drill out 20' of new hole. Perform leak off test. Displace hole to Drill-in fluid. Drill 6-1/8" horizontal production hole as per the directional plan. Note LWD (GR / Res) will be run over this section. Run 4 1/2" slotted liner. Set liner hanger to allow for 200 ft liner lap within the 7" casing. Displace well to solids free, viscosified, brine. Run 3 Y=", 9.3 #, L-80 gas lift completion. Space out. Sting into liner top PBR / land tubing hanger. Test tubing to 3500 psi. Maintain 2000 psi pressure in tubing and test annulus to 3500 psi. Bleed off tubing pressure and shear rupture disk in gas lift mandrel. Confirm circulation. Set BPV. Nipple down BOP. Nipple up x-tree. Pressure test to 5000 psi. Pull BPV. Freeze protect annulus /tubing. Set BPV and secure well. Move rig off. Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. Consideration will be given to ellipse of uncertainty for well trajectories to ensure collision avoidance. Drillinq Area Risks: Most problems encountered from drilling off the 3K pad have related to over-pressured fault blocks within the Kuparuk reservoir (due to water / gas injection operations). Note that on 3K-24, reservoir analysis has indicated that the reservoir should be at approximately virgin pressure (or slightly depleted). Maximum anticipated reservoir pore pressure is 3500 psi (10.1 ppg EMW). Reservoir over-pressure .... .~'impacted recent wells where the produ..c_~.,n hole has also had Iow strength upper formations open. Due to the challenging directional profile required in 3K-24, there will be a 7" intermediate casing string set above the Kuparuk. The need for higher mud weights in the reservoir section will therefore not impact these upper lower strength formations. Annular Pumpin.q Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3K-24 surface/intermediate casing annulus will be filled with diesel after setting intermediate casing. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 3K-24 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300- 500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (4090') + 1,500 psi Max Pressure - 4,052 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 40 L-80 3 BTC 3,090 psi 2,627 psi 5,750 psi 47888 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 47599 psi 7,240 psi 6,154 psi 31/=" 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). 3K-24 DRILLING FLUID PROGRAM SPUD to Intermediate Hole Production Hole 9-5/8"surface casing Section- 8-1/2" Section- 6-1/8" point- 12-1/4" Density 8.6 - 10 ppg 8.8 - 9.4 ppg 10.3 ppg PV 15 - 35 8 - 20 YP 20- 35 4 - 7 (tau0) 6 - 8 (tau0) Funnel Viscosity 150 - 75 35 - 50 Initial Gels 10 - 25 APl Filtrate (cc/30 min) NC - 10 4 - 6 (final) < 6 pH 8.5 - 9.0 9 - 10 8.5 - 9.5 Spud to Base Permafrost: Standard Kuparuk spud mud, consisting of an extended bentonite slurry. Initial viscosities in 150 sec/qt range. Density to be 9.5 ppg prior to drilling the base of the permafrost. Base Permafrost to Surface Hole TD: Maintain high Iow end rheology, maintain sufficient pump rates to ensure good hole cleaning. Maintain mud weight < 10 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Standard Kuparuk LSND mud system. Ensure good hole cleaning by maintaining Iow end rheology and pumping of regular sweep. Maximise fluid annular velocity. There is potential for lost circulation in this section. Maintain mud weight at or below 9.4 ppg and be prepared to add loss circulation material. Production Hole Section (Horizontal): Drill in fluid to be utilized to ensure minimal formation damage. Fluid density to be maintained at 10.3 ppg (or as required to overcome formation pore pressure). Maintain good hole cleaning by use of regular hi-vis sweeps and mechanical agitation due to drill string rotation. Drillin.q Fluid System: 3 - Derrick 4 panel Hi-G Shale Shakers Demco Desanders Derrick 20 cone Desilter Derrick DE-1000Centrifuge Pit Level Indicators, Trip Tank, Fluid Flow Sensor, Fluid Agitators Pit Confiquration: Capacity (BBLS) Pit 1 183 Pit 2 171 Trip Tank 137 Mini-trip Tank 22 Water Tank 247 Pit 3 175 Pit 4 172 Pit 5 139 Pill Tank 47 Pit 6 156 U~91530 SB30N~30 dn ~oouon~ TIE[ :IgOH ~00'~1~ OJ. _ _~k:~t._ \k _.0/ 3Nh BRZYM ~3SSY030 ~ $~30~nB ~ I m [] ~ I I I I I '~~ 1~ dHnd 3Ob"~HO TIIJq TIV~ O.L NnO ann /C '~/N~3~4OVgd~IO '13C::llO 1:104 B3ddOH 3K-24 CASING AND TUBING INFORMATION. Casing / Tubing Configuration Hole Size Csgrrbg Wt/Ft Grade Conn. Length Top Btm OD MDrrVD MDrrVD 24" 16" 62# H-40 WLD 80 GL 117/117 12-1/4" 9 5/8" 40# L-80 BTC 5895 GL 5936/4090 8-1/2" 7" 26# L-80 BTC-M 10416 GL 10455/6610 6-1/8" 4-1/2" slotted L-80 BTC-M 3740 10255 13995/6647 Completion 3-1/2" 9.3# L-80 EUE 8rd- 10216 GL 10255/6554 Mod Casing / Tubing Properties Csg/Tbg Wt/Ft Grade Conn. Internal Collapse Tensile Tensile OD Yield (psi) Body Connection (psi) (1000 lbs) (1000 lbs) 16" 62# H-40 WLD Conductor Pipe 9-5/8" 40# L-80 BTC 5750,3090, 916 979 7" 26# L-80 BTC-M 7240I I 5410 604 667 4-1/2" 12.6# L-80 BTC-M Slotted Liner 3-1/2" 9.3# L-80 8rd-M 10160 1105301 207 I 202 There follows a proposed casing / completion schematic. All depths reference D-19 75 RKB Weatherford Gemoco 9-5/8" DV Stage Collar Stnd. Grade BTC Threads ~et +/- 200' TVD below permafrost - approx. 2050' MD) Surface csg. 9 5/8" 40# L-80 BTC (5936' MD / 4090' TVD) 4-1/2" Liner Top: 200' above 7" shoe (10255' MD / 6554' TVD) K- LI 3K-24 Proposed Completib i H. 3-1/2"5M FMC GenVtubinghangerwith3-1/2"L-80EUE8RD-Mod pin down (X/O, 4-1/2" x 3-1/2" under hanger) G. 3-1/2" 9.3# L-80 EUE 8RD-Mod tubing to surface F. 3-1/2" Camco"DS" landing nipple w/2.81" iD, EUE 8RD-Mod, 3-1/2" x 6' pups on either side @ +/- 500' MD. E. 3-1/2" 9.3# L-80 EUE 8RD-Mod tubing to DS nipple w/3-1/2"x 1.5" Camco 'MUM' mandrels w/DV's & BK latches, EUE 8RD-Mod connections, 3-1/2" x 6' pups installed. Spaced out as follows: GLM # TVD-RKBMD-RKB TBD TBD TBD D. 1 jt 3-1/2" L-80 EUE 8RD-Mod tubing C. 3-1/2" Camco "D" landing nipple w/2.75" ID, NoGo profile, EUE 8RD- Mod, 3 1/2" x 6' pups on either side B. 1 jt 3-1/2" L-80 EUE 8RD-Mod tubing A. Baker 3-1/2" 'GBH-22' Seal Assembly w/10' of seals and Iocator to locate in liner tieback sleeve. Locator 5.125" OD, seals 4.75" ID. 3-1/2" x 6' L-80 handling pup installed on top Intermediate csg. 7" 26# L-80 BTC-Mod set 50' TVD into B ShaPe (10455' MD / 6610' TVD) Top A3 @ 10634' MD / 6641' TVD Liner Assembly (run on drillpipe): -- Baker 'C-2' tieback sleeve with Iocator, 6' -- Baker 5" x 7" 'ZXP' Liner Top Isolation Packer -- Baker 5" x 7" 'HMO' Hydraulic Liner Hanger -- Baker '80-40' 12' Seal Bore Extension (4.75" ID seal bore), 4-1/2" BTC-Mod -- 4-1/2" 12.6# L-80 BTC-Mod Blank Liner -- Baker 3.725" XN Nipple in Liner -- 4-1/2" 12.6 # L-80 BTC-Mod Liner (To top A3 Sand) SLOTTED Liner 4-1/2" 12.6# L-80 BTC-Mod (13995' MD / 6647' TVD) 3K-24 .~ PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of the Kaparuk 3K-24 well · Casing Size (in) Csg Setting Fracture Pore pressure ASP Drilling Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 117 / 117 10.9 49 53 9 5/8 5936 / 4090 15.0 1888 2366 7" 10455 / 6610 15.5 3093 2769 4-1/2" slotted 13995 / 6647 15.5 3500 N/A · NOTE: 5000 psi BOP equipment is adequate. 3500 psi BOPE test is adequate. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP=[(FGx0.052)-0.11]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.11 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB 2) ASP = FPP- (0.11 x D) OR Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.11} D = [(10.9 x 0.052) - 0.11] x 117 = 53 psi OR ASP = FPP - (0.11 x D) = 1888- (0.11 x 4090') = 1438 psi 2. Drilling below surface casing (9 5/8") ASP = -- ASP = -- [(FG x 0.052) - 0.11} D [(15 x 0.052) - 0.11] x 4090 = 2740 psi OR FPP - (0.11 x D) 3093 - (0.11 x 6610') = 2366 psi 3. Drilling below intermediate casing (7") ASP = ASP = [(FG x 0.052) - 0.11} D [(15.5 x 0.052) - 0.11] x 6610 = 4600 psi OR FPP - (0.11 x D) = 3500 - (0.11 x 6647') = 2769 psi 3K-24 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT -1000 -2000 -3000 -4000 -5000 -6000 -7000 8 9 10 11 12 13 14 15 16 EQUIVALENT MUD WEIGHT = 3K-23 (TVD) --,lB-- 3K-30 (TVD) -- -- 3K-22 (TVD) 3K-24 OFFSET WELLS - ACTUAL MUD WEIGHTS 1000 0 -1000 -2000 -3000 -4000 -5000 -6000 -7000 8.0 9.0 10.0 11.0 MUD WEIGHT (PPG) Sheet1 CGM saved as C:\Program FiIes~AAI\DAPPER~A3map.cgm 3K-24 Pressure Map Default: AS STRUCTURE Refcr~e'uaZ Date: Thlz Ocg 29 ~2:47:04 AKST 199B Page I Kuparuk Development 3K-24. Surface String Cement Loads and CemCADE Summary. 2 Stage, Tool at 2050' MD, 45% Excess Below Frost, 300% Above, 12- 1/4" Hole, 9-5/8" Casing: TMD 5936'. Base of permafrost at 1830' MD Pump Schedule: Pump 20 bbls ARCO Wash, 50 bbls Spacer @ 10.5 ppg Cement from MD of 5936' to 500' above top of West Sak (4254' MD) with Class G + Adds @ 15.8 ppg, and from 4254' to surface with AS 3 Lite. Stage 1: Tail Slurry: (5936'- 4254') x 0.3132 ft3/ft x 1.45 (45% Excess) = 763.9 ft3 80' shoe x 0.4110 ft3/ft = 32.9 ft3 796.8 ft3/1.17 ft3/sk = 690 sacks cement (rounded up from 681) System; Class G with 1% SI, 0.2% D46 and 0.3% D65, 1.17 ft3/sk, 15.8 ppg Lead Slurry: (4254-2050') x 0.3132 ft3/ft x 1.45 (45% excess) -- 1000.9 ft3 1000.9 ft3/4.43 ft3/sk = 230 sacks (rounded up from 226) Arctic Set 3 Lite @ 10.7 ppg, Class G with 50% D124, 9.0% D44, 0.4% D46, 30% D53, 1.5% S 1 and 1.5% D79, 4.43 ft3/sk Stage 2: Est. Circ. W/30 bbl FW. Cement from 2050' (tool) to surf, with AS 3 Lite and 60 sacks AS 1. 300% Excess above 1830', 45% Excess below 1830' (2050-1830') x 0.3132 ft3/ft x 1.45 (45% Excess) = 99.9 ft3 1830' x 0.3132 ft3/ft x 4 (300% Excess) = 2292.6 ft3 2392.5 Total Volume Tail Slurry 60 sacks Arctic Set 1, 0.93 ft3/sk = 55.8 ft3 2392.5 -55.8 ft3 = 2336.7 ft3, 2336.7 ft3/4.43 ft3/sk = 527 sacks. Round up to 530 Sacks Lead Arctic Set 3 Lite @ 10.5 ppg, Class G with 50% D124, 9.0% D44, 0.4% D46, 30% D53, 1.5% S 1 and 1.5% D79, 4.43 ft3/sk Summary: Stage 1:20 BBL wash, 50 bbl 10.5 ppg ARCO spacer, 230 sacks (181 bbls) AS3 Lite, 690 sacks (144 bbls) Class G. Stage 2:30 bbl water, 530 sacks (418 bbls) Arctic Set 3 Lite, 60 sacks (10 bbls) AS 1. CemCADE Summary: CIRCULATION: Mud circulation over 12 BPM risks formation breakdown. Circualtion and cementing at or under 8 bpm is within safe ECD to avoid breaking down any formations. Recommend dropping displacement rate towards end of displacement, if necessary, to maintain 1:1 returns. Recommended cementing displacement rate is 8 BPM for Mud removal and avoiding breakdown. Expected pressure to bump plug on stage 1 is 680 psi. At 8 BPM, U-tubing (vaccum) expected, 30-40 minutes, 10-15 prior to and 15-25 minutes dropping top plug. Recommended Conditioned Mud Properties: = 9.5 -10.0 ppg, Pv = under 25, Ty = under 25, +/- 60-80 FV B. Dean can be reached at office, home or by cellular for additional details and/or assistance on this job design 694-2770(H) or 223-5148(M) or 265-6205(0). BKD 11-24-98 Kuparuk, 3K-24 Intermediate Cementing Loads, CemCADE Summary 75 % Excess, 800' Annular Fill 7" Intermediate Casing, 8-1/2" OH, Run to 10455' MD Pump Schedule: 20 BBL ARCO Wash, Pump 40 bbls ARCO Spacer (12.0 ppg, Pv=25 cp, Ty = 30 lbf/100ft2.) Cement from MD of 10455' to 800' above shoe (TOC +/- 9655' MD) with Class G + Adds @ 15.8 ppg, Slurry: 800' x 0.1268 ft3/ft x 1.75 (75% Excess) = 177.5 ft3 80' shoe x 0.2086 ft3/ft = 16.7 ft3 194.2 ft3/1.17 ft3/sk = 170 sacks cement (rounded up from 166) System; Class G with 0.1% D800, 0.2% D46 and 0.3% D65, 1.17 ft3/sk, 15.8 ppg CemCADE Summary: Fluid Sequence: 20 bbl ARCO Wash, 40 bbl 12.0 ppg ARCO Spacer, 170 sacks (35 bbls) Class G. (Spacer needs 0.2 #/bbl Biozan to meet visc. req.) Mud circulation over 11.0 BPM risks formation breakdown. Circualtion and cementing at or under 8.0 BPM is within safe ECD to avoid breaking down any formations. Recommend dropping displacement rate if necessary to maintain 1:1 returns towards end of displacement to avoid losses. Recommended cementing displacement rate is 8 BPM for Mud removal and avoiding breakdown. Expected pressure to bump plug is 1100 psi. At 8 BPM, minimal, if any, U-tubing (vaccum) expected. SPACER AND MUD NOTES: For effective mud removal in laminar flow across pay zone, with proposed Centralizer program, the following conditions applied. Centralizer 1/jr Weatherford bow spring (Model S 1102570) from shoe to 800' above shoe (20 its). Most Effective Rates for Mud Removal are 6.4 BPM to 9.0 BPM. Recommended Conditioned Mud Wt. =9.8 to 10.5 ppg, Pv = Under 25, Ty = Under 30, +/- 80-90 FV B. Dean can be reached at office, home or by cellular for additional details and/or assistance on this job design 694-2770(H) or 223-5148(M) or 265-6205(0). BKD 11-24-98 3K-24 ..... DOYON 19 13-5/8" 5,000 PSI BOP COMPONENTS I/ 3 1/8", 5000 psi HCR J Valve lactuated) I-- 3" CHOKE LIN 3 1/8", 5000 psi Manual Gate Valve ~ J I DrillingSp°°l [ ~[ IWellhead ~_~~---"~1 L1 13-5/8", 5000 psi WP, Hydril Type GK Annular Preventer, studded top/ flanged bottom. Single 13-5/8", 5000 psi WP, Hydril MPL BOP w/ pipe rams Single 13-5/8", 5000 psi WP, Hydril MPL BOP w/ blind / shear rams L_ 1 3 1/8", 5000 psi HCR Valve lactuated) "~...~~ 3 l/8"'G5a0t0e0vPa~ 'veM a n u a ' i I pipe rams 3K-24 Diverter Schematic Doyon 19 Flowline 3 1/8", 5000 psi HCR Valve (actuated~ 21¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet 3 1/8", 5000 psi Manual Gate Valve 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 150psi WP HYDRAULIC KNIFE VALVE ~~/ 16" OD DIVERTER LINE 16" 62 ppf CONDUCTOR PIPE set at 60' (GL) lOOO 5OO 500 1aa0 1500 2000 2500 3000 3500 4000 4500 5000 55OO 6OOO 6500 7000 7500 ARCO Alaska, ....... Ino. J Struofur~: Pad 3K W$11: 24 FlJld: Kuporuk Rlv~r Unit Location : North SlopJ, Alaska Crm:~ed by: Andre~ For: I~RrSON Dote pl~t~: 24-No~ ~nat~ are In f~ ~eren~ .~t f24. Tr~ V~I~I ~pthl or~ ~eren~ RKB CPar~ t Tie on - 0.00 Ina, 0.00 Md, 0.00 Tvd, 0.00 Vs mrna - ,~.~)/ Start of Nudge W-~L PROFILE DATA 9.00 Begin Turn to Target ..... Point ..... bid Ina Drr 1VD North T~o gn / RKB [1~ 75' 0.~ 0.~ 75.~ 0.~ 0.~ o.a0 o.00 14.04 KOP / ~oH of Nudge~00.~ 0.~ 75,~ 300.~ 0,~ 0.00 0.00 ~9.48 ~gln Turn to TargM6~ ....... ~ 10 ~ 75 ~ 63t ~ 7 51 2B 03 ~ 92 ~ Bo~ ~rmo~r~ 17~47 41.~ ~g~7 1~0.00 ~1.86 ~72.10 489,26 h 25.17 DLS: 3.00 deg per 100 ft Eoc ~.~ 54.70 ~6,67 19~.~ 590~9 57~.e~ 817.07 ~ Bo~ W~ 5ok ~0) ~gO.lO ~0,~ 2806.47 2~4.00 ~.0~ ~ 00.00 C20 (HRZ Mid Point) 9402~ ...... 614~00 55~0 412~6 67N.57 ~ 42 72 Bose Permafrost so. HRZ 950~11 ~05.~ 542~76 4t7~7 ~ '48 64 ,-~ M=~r 97~A5 65t5.00~.35 4269.~ 7~4.64 ~ · B~;n ~d~urn to To~M 9907.01 54.70 36.67 8384.685632~7 4528.107105.02 ~ Top C5 I~15~9 68.95 ~.~ 55~.00 5~93 ~ 7572.18 ~ Top Ct 1~69.42 69.~ ~.56 6~.00 ~91.66 4515.42 7421.67 ~ Top a S~W ~02a=.eo ~.e4 54.4a e5~=o =so=.=s ~20,s4 ~ ~" coaJn9 ~ ~55.16 75.45 5~.~ 6610.~ 605~47 4612.78 759~70 ~ JTorg~ I 10615.89 90.7t 52.00 6~.00 ~7.30 4~5.43 795~1 / ~ J~In Dir'l Thru Formation 11~.00 90.71 ~.00 6~3~B 6749~2 ~6~.01 TANGENT ANGLE 54.70 DEG xBose West Sok (WS10) g 5/8 Coslng Pt 37.17 AZIMUTH .... 7953' (TO TARGET TARGET ANGLE INITIAL: 90.71 MIN: 87.38 DEG MAX: 90.40 DEG 0 (HRZ Mid Point) Bose HR . . eqm Budd/Tum to Torget Tot-et 8 / TD '~- 29 Top C4~;z~' LOC Top C~ ft ~ , , Top C1 ~ T T ~ Begin Directional Thru Formation Top B Shale' ~ ~ T~rget 1 / LOC I Top 7 Coslng Point D~j/IO0 o.oo o.oo 3.00 3.00 3,00 0,00 O.OO 4.00 4.00 4,0~ 4.00 4.00 4.00 4.00 0.00 5.0C O.OC i i i i i i i i i i i i i i i i i i i i i i i i i i i i i Ii i i i i i i i i i i i i i I i i i 500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8§00 9000 9500 10000 10500 1100O Vertical Section (feet) -> Azimuth 57.17 with reference 0.00 N, 0,00 E from slot #24 1800 1200 600 0 I I I I I I I SURFACE LOCATION: 1522' FSL, 517' FWL SEC. 55, TI`3N, R9E ARCO Alaska, Struofure: Pad 5K Wall : Field : Kuparuk Rtver Unlf Loaaflon : North Slope, Alaska WELL PROFILE DATA ..... Point. ..... MD Inc O~' TVD North East V. Sect Dog/O( 00~ T~e on 0.00 Q. O07~.00 0.00 0.00 (~00 0.00 End of Hold 500.00 0,00 75,00 300.00 0.00 0.00 0.00 0,00 KOP 6~5.3Z, iO.O0 75.00 B31.64. 7.5i 28.I).t 22.92 5,00 End of Bu~d/rum Z204.50 54..70 38.67 1953.55 590.29 575J~5 817.07 3,00 End of Hold 9907.01 34,70 56.67 6384-.1~6 5632.27 4~28.1 ID 7105.02 Torgefl 5K-24 T1 ~ 0 10813.89 90.71 32.00 6650.00 65~7.ZI0 480~45 7953.21 4.00 End of Hold 11300,00 90.71 32.00 664G,98 674g-52 5065.01 8,t-57.51 0.00 t I Boo.g0 89..,~9 17.06 6645.70 7021.67 5 ! 87.20 8729.20 5.00 End of Drop/Turn End of Orop~Tum 12O00.00 87.,.~1 5,57.15 66'55.08 7416.42 5256.4.5 9075.4~:J End of Bu~d/Tum 12400.00 89.5g 557.26 6665.77 7804..55 514~.51 9529.57 5.0(] End of Bul]d/Tum 12518.00 90.00 551.58 6666.20 7910.66 5097.20 93~5.19 5.00 12718.00 90.00 52.1 ~ 6666.20 8076.99 4988.60 9448.90 5.00 End of Turn 'End of Build/Turn 12868.00 90.65 515.g! 6665.55 8187.75 4~5.61 9476.14. 5.00 IKOP 12918.00 92.~-2 512.14 6664.01 822.1.85 4~-g.07 9481.25 5,00 iEnd of Drop/rum 1.5485.27 90.,:,~1. 28~.~- 6650.06 8485.22 ~ 7 9591-58 5.00 Fr, D. & Target 5K-24 T~ t&gg§..:~O 90.54- 3P~.~4. 664.7.00 86~7.25 Z~.~,8.1fi 9189.58 East (feet) -> 1800 2400 5000 5600 4200 4800 5400 6000 I I I I I I I I I I I I I I I I 6600 7200 I I I I LTD LOCATION: 6`31' FNL, 1105' FEL SEC. 26, T15N, R9E TARGET 8 / TO ~D=6647 ~D=13995 DEP=g190 NORTH 8607 EAST .3858 · ~7""~-~UTarget ~8~ TD ~~_~ ~1 K-24 T7 Rvsd OS-Nov-g8 ~------~3K-24 T6 Rvsd 17-Nov-98 ~'~5K-24 T5 Rvsd 17-Nov-98 ~ ~K-24 Rvsd 17-Nov-98 ~ · T4 2379' FSL, 158' FEL I SEC. 26, T13N, R9E TARG~ 1~:6650 ~/', //5~-24T2 Rvsd 17-Nov-98 ~D=10814 ~/~ ~ Begin Directional Thru FormoUon DEP=7955 / NOR~ 6357 /Torg / EOC ~ST 4805 ~ et 1 7 Cosing Poln[ "Top Top Shale Top m[ld/Tu~ to Target ~i~ Po~nt) 7800 I 5/8 Casing Pt Bose West Sak (WSIO) 600 1200 I I I I EOC Base Permafrost Beqin Turn to Target KOP / Start ot: Nudge 8400 I 96OO 9O00 8400 78OO 7200 66OO 6000 5400 A I z 4800 0 -.-i- 4200 ~ 3600 v 3000 240O 1800 1200 6OO 6OO Creoted by: Andrews For: ROBF'RTSON1 Dote plotted : 24-Nay-98 Plot Reference la 24 Ver~lon j~7. Coordinates ore in feet reference slot i124. [True VerGcol Depths o .... f .... ce RKO CPorker IJr245).[ I ~ / ARCO Alaska, Inc. Sfruofure: Pad 3K Well: 24 Field : Kuparuk River Unit Location : Norlh Slope, Alaska WELL PROFILE DATA ..... Po~'nt. ..... MD Inc Dir 'WO Nor%h Eo~t. V. ,~ctD~g/lOO ~ln Bu~d~urn to ~;~ 9~7.01 ~.70 ~87 ~.~ ~7 4~&10 -28~14 0.~ Top ~ 101~.15 ~4 ~.17 ~10~ 5~.~ ~39 -~ 4.~ ~e~ C1 I~42 ~ ~ ~.~ 5~1~5 4515.42 -2g75~ 78~ 461~78-~ ~op ~3) tO~ ~56 ~.61 6~1.~ 51~1 47Q~15-~75 4.~ E~ 1~7 90.34 2~54 ~.~6 ~ 43~37 -2197~1 Tgrg~ ~ / 10 I~30 g~34 2~84 ~7.00 ~07~5 ~15 - 6100 - 6200 - 6500 - Q_ 6400 6500 6600 6700 I v 6800 69OO 7000 urn to Target 58.38 Top C4 / _ 6_2_'$5 ...... ~Top ..C.,:7, ../ 66.32 DLS: 4.00 de(] per 1 O0 ft Top B Shalelop b ~/' .... To ~OC A(3) ./_ '~= /u.z~ / . .... Begin Directional Thru Formation / ~. .~-"'~78.24 7 Casing Point - - ' ~ ~3.4~. ~ 8 ' i EOC Torget 8 / TD i i i i i i i i i i i i i i i I i i i i i i i i i i I i i i i i i i i i i i i i i i i i i i i i 5700 5600 .5500 3400 3300 5200 51 O0 3000 2900 2800 2700 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 1600 1500 1400 13 Vertical Section (feet) -> Azimuth 285.84 with reference 0.00 N, 0.00 E from slot #24 ~20 ARCO Alaska, Inc. Sfruotur~: Pad 3K Well : 24 Field : Kuperuk River Unlf Location: North Slope, Alaska Eosf (feet) 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 240 260 I I I I I I I I I I I I I I I I I I I I I I I I I ;600 320 500 300 280 1200 280 260 26O 240 22O 200 180 ,A I 16o -I- Q,1 140 r 120 0 1100 1200 240 220 3300 80C 100 ~ 80 60 40 20 20 40 60 90 1000 900 1100 ;300 t 800 )0 ~700 ½600 500 200 180 310 ~00 ,500 50C 50 900 90O 2600 / 267.. ¢oo 4OO 3100 1100 1101 1000 /0/900 .~00 130 ~4000 go0 500 1300 3500 3600 34,0( 7~ 330, 500 1500 1700 1800 1600 1 7~, 14.0( / / ~100 1900 200 160 I 140 120 100 8O 60 20 20 40 I I I I t I I I I I I I I I 60 60 40 20 0 20 ~0 §'0 8'0 1 O0 1~0 140 1 ~0 1 ~0 260 2~0 240 2*0 Eosf (feet) -> Z 0 2000 1900 1800 1700 16OO 15OO 1400 1500 A I 12oo 100 r 1000 0 Z 900 5OO 400 A. CO Sfruature: Pad 3K Well : Field: Kuparuk River Unlt Loaatlon: NoHh Slope, Alaska/ I Easf (feet) -> 200 500 400 500 600 700 800 go0 1000 1100 1200 1500 1400 1500 1600 1700 IIIIIIII I lllllllllllllll,~ 2600 2800 3500 700 I400 5500 ;100 4800 5200 ;700 2000 / / "/31 O0 / / / 3000 / / 2/2900 1700 / / ~_..8 O0 16oo / / / 1500 2700 1400 190~/ / / 1800"/ / / ./2600 / / / 2500 t00 3800 5700 160C 900 ~300 2500 O0 24-00 100 2400 / / /./2,~oo / / ! ~300 / / / 19oo 1800 1300 A 1200 I z 1100 m© 1000 --~ --i- 9OO 50O 000 500 1900 200 700 200 5OO 100 ~ , , , , , , , , , , , , , , , ~ , t , , , , , , , 100 200 300 400 500 600 700 800 900 1000 1100 1200 1500 1400 1500 1600 1700 Easf (feet) -> 2200~ ? O0 800 2100./ 800 / O0 / 900 700 / <~/' 700 1900 O0 200/0~ / 600 / 2600 600 500 400 92OO 88OO 8400 8OOO 7600 6000 I ~ 5600 -I-- 5200 0 4800 Z ARCO Alaska, nc.[ ~fruafure : Pad 3K W.II : F~eld: Kuparuk River Unit Lo~aflon: North Slope, AIosko/ I East (feet) -> 400 800 1200 1600 2000 2400 2800 5200 3600 4000 4400 4800 5200 5600 6000 6400 I I I I I I I I I I I I I I I I I I I I [ I I I I I I I I I I \ \ \ \ 7200 I / / 6800 / ~oo / 64O0 600 / /¢6650 6400 0/6600 / / / 76400 4400 6400 /5200/ ./'[000/6600 4000 !00 / ooo 5800 _4600 3600 £ ,/6400 .5600 · 5400 Z/' 44000,~626200 .5200 5200 ,,, 4-200 0.~600000 2800 460.0 /6600 ~'/~800 X4;7u , oo/ OO ~ / /5000 2400 / 6200 ,5400/4800 0/3000]'/4200 ,6oo 600 ,ooo i i i i i i i i i i i i i i i i i i i i i 400 800 1200 1600 2000 2400 2800 .5200 5600 4000 4400 4800 5200 5600 6000 6400 East (feet) -> 92OO 8800 8400 8000 7600 7200 6800 6400 6000 5600 5200 4800 4400 4000 3600 3200 2800 2400 2000 1600 ARCO Alaska, Inc. Pad 3K 24 slot #24 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE Baker Hughes INTEQ REPORT Your ref : 24 Version #7 Our ref : prop3196 License : Date printed : 24-Nov-98 Date created : 17-Nov-98 Last revised : 24-Nov-98 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on nT0 25 48.667,w149 45 49.2 Slot location is nT0 26 1.669,w149 45 39.898 Slot Grid coordinates are N 6008315.697, E 529307.707 Slot local coordinates are 1322.00 N 317.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <121 - 10462'>,,23,Pad 3K PMSS <463-10375'>,,30,Pad 3K PMSS <834 - 11690'>,,26,Pad 3K PMSS <345 - 10170'>,,25,Pad 3K PMSS (SS) <648-11180'>,,22,Pad 3K PGMS <0-8500 PGMS <0-8500 PGMS <0-8100 PGMS <0-8140 PGMS <0-8980 PGMS <0-8900 PGMS <0-9960 PGMS <0-9150 >,,8,Pad 3K >,,7,Pad 3K >,,6,Pad 3K >,,5,Pad 3K >,,4,Pad 3K >,,3,Pad 3K >,,2,Pad 3K >,,1,Pad 3K 34 (DO) Version #1,,34,Pad 3K PMSS <0 - 12681'>Depth Shifted,,34,Pad 3K 31 (DO) Version #1,,31,Pad 3K PMSS <1089 - 6906'> Depth Shifted,,31,Pad 3K PGMS <0-9000'>,,35 PMSS <10187 - 10456'> PGMS <0-9038'>,,16 PGMS <0-9584'>,,17 PGMS <0-9843'>,,18 PGMS <0-9275'>,,15 PGMS <0-8960'>,,14 PGMS <0-8580'>,,13 PGMS <0-7853'>,,11 PGMS <0-7300'>,,10 Pad 3K ,27,Pad 3K .Pad 3K .Pad 3K .Pad 3K .Pad 3K .Pad 3K Pad 3K .Pad 3K .Pad 3K PMSS <5275 - 7443'>,,9,Pad 3K Closest approach with 3-D Minimum Distance method Last revised Distance 5-Nov-98 24.9 5-Nov-98 5-Nov-98 15-0ct-98 15-0ct-98 15-0ct-98 15-0ct-98 15-Oct-98 15-0ct-98 15-0ct-98 15-0ct-98 15-Oct- iS-Oct- 26-May- 26-May- 12 -Jun- 12 - Jun- 6 -Apr- 16-Jul- 10-Oct- 10-Oct- 10-Oct- 10-Oct- 10-Oct- 10-Oct- 10-Oct- 10-Oct- 10-Oct- 174.5 49.1 25.0 46.7 62.8 37 0 11 1 10 2 37 0 52 1 98 85 9 98 112 0 98 10385 1 98 272.7 98 4553.3 98 200.0 98 297.8 97 74.3 96 313.0 96 337.0 96 363.0 96 288.0 96 262.0 96 238.0 96 187.0 96 162.0 96 85.8 588.9 333.3 366.7 100.0 433.3 260.0 344.4 260.0 422.2 20.0 1222.2 544.4 20.0 6260.0 344 4 4380 0 100 0 355 6 220 0 2O 0 2O 0 2O 0 2O 0 2O 0 2O 0 2O 0 2O 0 366 7 Diverging from M.D. 9900.0 333.3 13560.0 13995.3 13995.3 13995.3 344.4 13995.3 13995.3 13995.3 1222.2 13995.3 13995.3 6260.0 344.4 4380.0 13500.0 13995.3 220.0 13995.3 13995.3 13995.3 13995.3 13995.3 13995.3 13995.3 13995.3 13995.3 PGMS <0-7580'>,,9A, i 3K PGMS <0-10944'>,,32,Pad 3K PGMS <0-7770'>,,12,Pad 3K 10-0ct-96 18-Jun-97 10-0ct-96 85.8 225.0 212.5 366., ~ 120.0 322.2 13620.0 120.0 13995.3 ARCO Alaska, Inc. Pad 3K slot #24 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref = 24 Version #7 Our ref = prop3196 License = Date printed = 24-Nov-98 Date created = 1?-Nov-98 Last revised = 24-Nov-98 Field is centred on n?0 16 18.576,w150 5 56.536 Structure is centred on nT0 25 48.667,w149 45 49.2 Slot locatlon is nT0 26 1.669,w149 45 39.898 Slot Grid coordinates are N 6008315.697, E 52930?.?0? Slot local coordinates are 1322.00 N 317.00 E Projection type= alaska - Zone 4, Spheroid= Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 3K,24 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O 0 R D I N A T E S 0.00 0.00 75.00 0.00 0.00 N 0.00 E 300.00 0.00 75.00 300.00 0.00 N 0.00 E 400.00 3.00 75.00 399.95 0.68 N 2.53 E 500.00 6.00 75.00 499.63 2.71 N 10.11 E 600.00 9.00 75.00 598.77 6.09 N 22.71 E 633.33 10.00 75.00 631.64 7.51 N 28.03 E 700.00 11.53 68.07 697.14 11.50 N 39.80 E 800.00 14.04 60.64 794.66 21.18 N 59.65 E 900.00 16.72 55.48 891.07 35.28 N 82.08 E 1000.00 19.48 51.73 986.12 53.76 N 107.02 E 1100.00 22.31 48.89 1079.54 76.57 N 134.42 E 1200.00 25.17 46.66 1171.07 103.65 N 164.19 E 1300.00 28.06 44.86 1260.46 134.93 N 196.25 E 1400.00 30.97 43.38 1347.48 170.31 N 230.52 E 1500.00 33.89 42.12 1431.87 209.70 N 266.90 E 1600.00 36.83 41.05 1513.42 252.99 N 305.29 E 1700.00 39.77 40.11 1591.89 300.07 N 345.59 E 1763.47 41.64 39.57 1640.00 331.85 N 372.10 E 1800.00 42.72 39.28 1667.07 350.80 N 387.68 E 1900.00 45.68 38.54 1738.76 405.05 N 431.46 E 2000.00 48.64 37.87 1806.75 462.66 N 476.79 E 2100.00 51.60 37.26 1870.86 523.49 N 523.56 E 2200.00 54.56 36.70 1930.92 587.35 N 571.64 E 2204.50 54.70 36.67 1933.53 590.29 N 573.83 E 2500.00 54.70 36.67 2104.29 783.73 N 717.86 E 3000.00 54.70 36.67 2393.23 1111.02 N 961.56 E 3500.00 54.70 36.67 2682.17 1438.32 N 1205.27 E 4000.00 54.70 36.67 2971.11 1765.61 N 1448.97 E 4500.00 54.70 36.67 3260.05 2092.90 N 1692.68 E 5000.00 54.70 36.67 3548.99 2420.20 N 1936.38 E 5500.00 54.70 36.67 3837.94 2747.49 N 2180.09 5590.10 54.70 36.67 3890.00 2806.47 N 2224.00 5936.19 54.70 36.67 4090.00 3033.02 N 2392.69 6000.00 54.70 36.67 4126.88 3074.79 N 2423.79 6500.00 54.70 36.67 4415.82 3402.08 N 2667.49 PROPOSAL LISTIN~ Page 1 Your ref : 24 Version #7 Last revised : 24-Nov-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 0.00 0.00 KOP / Start of Nudge 2.07 8.26 18.57 22.92 Begin Turn to Target 33.21 52.92 77.70 107.50 3.00 142.23 3.00 181.80 3.00 226.09 3.00 274.99 3.00 328.36 3.00 386.05 3.00 447.91 3.00 489.26 Base Permafrost 3.00 513.77 3.00 583.44 3.00 656.74 3.00 733.47 3.00 813.41 3.00 817.07 EOC 0.00 1058.23 0.00 1466.28 0.00 1874.32 0.00 2282.37 0.00 2690.41 0.00 3098.46 0.00 3506.50 0.00 3580.03 Base West Sak (WS10) 0.00 3862.47 9 5/8" Casing Pt 0.00 3914.55 0.00 4322.59 7000.00 54.70 36.67 4704.76 3729.38 N 2911.20 E 0.00 4730.64 7500.00 54.70 36.67 4993.70 4056.67 N 3154.90 E 0.00 5138.68 8000.00 54.70 36.67 5282.64 4383.96 N 3398.61 E 0.00 5546.73 8500.00 54.70 36.67 5571.58 4711.26 N 3642.31 E 0.00 5954.77 9000.00 54.70 36.67 5860.52 5038.55 N 3886.02 E 0.00 6362.82 9423.07 54.70 36.67 6105.00 5315.49 N 4092.22 E 0.00 6708.08 C30 (K-2) 9492.29 54.70 36.67 6145.00 5360.80 N 4125.96 E 0.00 6764.57 C20 (HRZ Mid Point) 9500.00 54.70 36.67 6149.46 5365.85 N 4129.72 E 0.00 6770.86 9596.11 54.70 36.67 6205.00 5428.76 N 4176.57 E 0.00 6849.30 Base HRZ 9786.46 54.70 36.67 6315.00 5553.36 N 4269.35 E 0.00 7004.64 K-1 Marker 9907.01 54.70 36.67 6384.66 5632.27 N 4328.10 E 0.00 7103.02 Begin Build/Turn to Target 10000.00 58.38 36.07 6435.92 5694.73 N 4374.09 E 4.00 7180.58 10100.00 62.35 35.48 6485.36 5765.24 N 4424.89 E 4.00 7267.45 10155.13 64.54 35.17 6510.00 5805.48 N 4453.39 E 4.00 7316.73 Top C4 10200.00 66.32 34.92 6528.66 5838.89 N 4476.83 E 4.00 7357.52 All data is in feet unless otherwise stated. Coordinates from slot #24 and TVD from RKB (Parker #245) (75.00 Ft above mean sea level). Bottom hole distance is 9432.37 on azimuth 24.14 degrees from wellhead. Total Dogleg for wellpath is 202.67 degrees. Vertical section is from wellhead on azimuth 37.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 3K,24 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 10215.99 66.95 34.84 6535.00 5850.93 N 4485.22 E 10269.42 69.08 34.56 6555.00 5891.66 N 4513.42 E 10283.60 69.64 34.48 6560.00 5902.59 N 4520.94 E 10300.00 70.29 34.40 6565.62 5915.30 N 4529.65 E 10400.00 74.26 33.91 6596.06 5994.11 N 4583.12 E 10455.16 76.45 33.64 6610.00 6038.47 N 4612.78 B 10500.00 78.24 33.43 6619.82 6074.94 N 4636.95 E 10600.00 82.21 32.97 6636.80 6157.39 N 4690.90 E 10633.87 83.56 32.81 6641.00 6185.61 N 4709.15 E 10700.00 86.18 32.51 6646.91 6241.05 N 4744.69 E 10800.00 90.16 32.06 6650.11 6325.53 N 4798.07 E 10813.87 90.71 32.00 6650.00 6337.29 N 4805.42 E 10813.89 90.71 32.00 6650.00 6337.30 N 4805.43 E 11000.00 90.71 32.00 6647.69 6495.12 N 4904.05 E 11300.00 90.71 32.00 6643.98 6749.52 N 5063.01 E PROPOSAL LISTING Page Your re~ ~ 24 Version Last revised : 24-Nov-98 Dogleg Vert Deg/100ft Sect 4.00 7372.18 Top C3 4.00 7421.67 Top C1 4.00 7434.93 Top B Shale 4.00 7450.32 4.00 7545.42 4.00 7598.70 7" Casing Point 4.00 7642.36 4.00 7740.65 4.00 7774.16 Top A(3) 4.00 7839.82 4.00 7939.38 4.00 7953.20 Target i / EOC 4.00 7953.21 3K-24 T1 Rvsd 05-Nov-98 0.00 8138.55 0.00 8437.31 Begin Directional Thru Formation 11400.00 90.27 27.02 6643.12 6836.52 N 5112.25 E 5.00 8536.38 11500.00 89.83 22.04 6643.03 6927.46 N 5153.75 E 5.00 8633.92 11600.00 89.39 17.06 6643.70 7021.67 N 5187.20 E 5.00 8729.20 11700.00 88.87 12.08 6645.22 7118.41 N 5212.35 E 5.00 8821.48 11800.00 88.36 7.11 6647.63 7216.95 N 5229.01 E 5.00 8910.07 11900.00 87.86 2.13 6650.93 7316.54 N 5237.06 E 5.00 8994.28 12000.00 87.38 357.15 6655.08 7416.42 N 5236.43 E 5.00 9073.49 12100.00 87.91 352.17 6659.18 7515.87 N 5227.14 E 5.00 9147.12 12200.00 88.46 347.20 6662.35 7614.17 N 5209.25 E 5.00 9214.65 12300.00 89.02 342.23 6664.55 7710.58 N 5182.91 E 5.00 9275.55 12400.00 89.59 337.26 6665.77 7804.36 N 5148.31 E 5.00 9329.37 12500.00 89.94 332.28 6666.19 7894.79 N 5105.69 E 5.00 9375.68 12518.00 90.00 331.38 6666.20 7910.66 N 5097.20 E 5.00 9383.19 12600.00 90.00 327.28 6666.20 7981.17 N 5055.38 E 5.00 9414.11 12700.00 90.00 322.28 6666.20 8062.84 N 4997.72 E 5.00 9444.34 12718.00 90.00 321.38 6666.20 8076.99 N 4986.60 E 5.00 9448.90 12800.00 90.36 317.29 6665.95 8139.18 N 4933.17 E 5.00 9466.17 12868.00 90.65 313.91 6665.35 8187.75 N 4885.61 E 5.00 9476.14 12900.00 91.78 312.77 6664.67 8209.71 N 4862.34 E 5.00 9479.57 12918.00 92.42 312.14 6664.01 8221.85 N 4849.07 E 5.00 9481.23 13000.00 92.14 308.04 6660.75 8274.61 N 4786.40 E 5.00 9485.40 13100.00 91.79 303.05 6657.31 8332.69 N 4705.11 E 5.00 9482.57 13200.00 91.43 298.06 6654.50 8383.50 N 4619.06 E 5.00 9471.06 13300.00 91.06 293.08 6652.33 8426.63 N 4528.90 E 5.00 9450.96 13400.00 90.67 288.09 6650.82 8461.78 N 4435.33 E 5.00 9422.42 13485.27 90.34 283.84 6650.06 8485.22 N 4353.37 E 5.00 9391.58 EOC 13500.00 90.34 283.84 6649.97 8488.75 N 4339.07 E 0.00 9385.75 13995.29 90.34 283.84 6647.00 8607.22 N 3858.16 E 0.00 9189.59 Target 8 / TD 13995.30 90.34 283.84 6647.00 8607.23 N 3858.15 E 0.00 9189.58 3K-24 T8 Rvsd 17-Nov-98 All data is in feet unless otherwise stated. Coordinates from slot #24 and TVD from RKB (Parker #245) (75.00 Ft above mean sea level). Bottom hole distance is 9432.37 on azimuth 24.14 degrees from wellhead. Total Dogleg for wellpath is 202.67 degrees. Vertical section is from wellhead on azimuth 37.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 3K,24 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref = 24 Version #? Last revised = 24-Nov-98 Comments in we11path MD TVD Rectangular Coords. Comment 300.00 300.00 0.00 N 0.00 E KOP / Start of Nudge 633.33 631.64 ?.51 N 28.03 E Begin Turn to Target 1763.47 16%0.00 331.85 N 372.10 E Base Permafrost 220%.50 1933.53 590.29 N 573.83 E EOC 5590.10 3890.00 2806.%7 N 222%.00 E Base West Sak (WS10) 5936.19 4090.00 3033.02 N 2392.69 E 9 5/8" Casing Pt 9%23.07 6105.00 5315.49 N %092.22 E C30 (K-2) 9%92.29 6145.00 5360.80 N %125.96 E C20 (HRZ Mid Point) 9596.11 6205.00 5%28.76 N 4176.57 E Base HRZ 9786.46 6315.00 5553.36 N %269.35 E K-1 Marker 9907.01 638%.66 5632.27 N %328.10 E Begin Build/Turn to Target 10155.13 6510.00 5805.%8 N 4%53.39 E Top C% 10215.99 6535.00 5850.93 N 4%85.22 E Top C3 10269.42 6555.00 5891.66 N 4513.42 E Top C1 10283.60 6560.00 5902.59 N 4520.9% E Top B Shale 10%55.16 6610.00 6038.47 N 4612.78 E 7" Casing Point 10633.87 6641.00 6185.61 N %709.15 E Top A(3) 10813.87 6650.00 6337.29 N 4805.42 E Target i / EOC 10813.89 6650.00 6337.30 N 4805.43 E 3K-2% T1 Rvsd 05-Nov-98 11300.00 6643.98 67%9.52 N 5063.01 E Begin Directlonal Thrn Formation 13485.27 6650.06 8485.22 N 4353.37 E EOC 13995.29 6647.00 8607.22 N 3858.16 E Target 8 / TD 13995.30 6647.00 8607.23 N 3858.15 E 3K-2% T8 Rvsd 1?-Nov-98 Casing positions in string IA' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 5936.19 4090.00 3033.02N 2392.69E 9 5/8" Casing 0.00 0.00 0.00N 0.00E 10455.16 6610.00 6038.47N 4612.78E 7" Casing Targets associated with this we11path Target n~me Geographic Location T.V.D. Rectangular Coordinates Revised 3K-2% T1 Rvsd 05-Nov 53%088.000,6014671.000,0.0000 3K-2% T8 Rvsd 1?-Nov 533132.000,6016937.000,0.0000 3K-2% T2 Rvsd 17-Nov 534497.000,6015365.000,0.0000 3K-2% T3 Rvsd 17-Nov 534715.000,6015813.000,0.0000 3K-2% T% Rvsd 1?-Nov 53%570.000,6016132.000,0.0000 3K-2% T5 Rvsd 17-Nov 534458.000,6016272.000,0.0000 3K-24 T6 Rvsd 17-Nov 53409%.000,6016%91.000,0.0000 3K-24 T7 Rvsd 05-Nov 533679.000,601679%.000,0.0000 6650.00 6337.30N 4805.43E 5-Nov-98 66%7.00 8607.23N 3858.15E 5-Nov-98 66%0.00 7029.78N 5217.17E 5-Nov-98 6633.00 7476.97N 5436.93E 5-Nov-98 6657.00 7796.56N 5293.16E 5-Nov-98 6665.00 7937.01N 5181.69E 5-Nov-98 666%.99 8157.45N 4818.51E 5-Nov-98 6648.00 8462.09N %404.65E 5-Nov-98 ARCO Alaska, Inc. Pad 3K,24 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 1 Your ref : 24 Version #7 Last revised = 24-Nov-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 75.00 0.00 1322.00 N 317.00 E 0.00 0.00 300.00 0.00 75.00 300.00 1322.00 N 317.00 E 0.00 0.00 400.00 3.00 75.00 399.95 1322.68 N 319.53 E 3.00 2.07 500.00 6.00 75.00 499.63 1324.71 N 327.11 E 3.00 8.26 600.00 9.00 75.00 598.77 1328.09 N 339.71 E 3.00 18.57 633.33 10.00 75.00 631.64 1329.51 N 345.03 E 3.00 22.92 700.00 11.53 68.07 697.14 1333.50 N 356.80 E 3.00 33.21 800.00 14.04 60.64 794.66 1343.18 N 376.65 E 3.00 52.92 900.00 16.72 55.48 891.07 1357.28 N 399.08 E 3.00 77.70 1000.00 19.48 51.73 986.12 1375.76 N 424.02 E 3.00 107.50 1100.00 22.31 48.89 1079.54 1398.57 N 451.42 E 3.00 142.23 1200.00 25.17 46.66 1171.07 1425.65 N 481.19 E 3.00 181.80 1300.00 28.06 44.86 1260.46 1456.93 N 513.25 E 3.00 226.09 1400.00 30.97 43.38 1347.48 1492.31 N 547.52 E 3.00 274.99 1500.00 33.89 42.12 1431.87 1531.70 N 583.90 E 3.00 328.36 1600.00 36.83 41.05 1513.42 1574.99 N 622.29 E 3.00 386.05 1700.00 39.77 40.11 1591.89 1622.07 N 662.59 E 3.00 447.91 1763.47 41.64 39.57 1640.00 1653.85 N 689.10 E 3.00 489.26 1800.00 42.72 39.28 1667.07 1672.80 N 704.68 E 3.00 513.77 1900.00 45.68 38.54 1738.76 1727.05 N 748.46 E 3.00 583.44 2000.00 48.64 37.87 1806.75 1784.66 N 793.79 E 3.00 656.74 2100.00 51.60 37.26 1870.86 1845.49 N 840.56 E 3.00 733.47 2200.00 54.56 36.70 1930.92 1909.35 N 888.64 E 3.00 813.41 2204.50 54.70 36.67 1933.53 1912.29 N 890.83 E 3.00 817.07 2500.00 54.70 36.67 2104.29 2105.73 N 1034.86 E 0.00 1058.23 3000.00 54.70 36.67 2393.23 2433.02 N 1278.56 E 0.00 1466.28 3500.00 54.70 36.67 2682.17 2760.32 N 1522.27 E 0.00 1874.32 4000.00 54.70 36.67 2971.11 3087.61 N 1765.97 E 0.00 2282.37 4500.00 54.70 36.67 3260.05 3414.90 N 2009.68 E 0.00 2690.41 5000.00 54.70 36.67 3548.99 3742.20 N 2253.38 E 0.00 3098.46 5500.00 54.70 36.67 3837.94 4069.49 N 2497.09 E 0.00 3506.50 5590.10 54.70 36.67 3890.00 4128.47 N 2541.00 E 0.00 3580.03 5936.19 54.70 36.67 4090.00 4355.02 N 2709.69 E 0.00 3862.47 6000.00 54.70 36.67 4126.88 4396.79 N 2740.79 E 0.00 3914.55 6500.00 54.70 36.67 4415.82 4724.08 N 2984.49 E 0.00 4322.59 7000.00 54.70 36.67 4704.76 5051.38 N 3228.20 E 0.00 4730.64 7500.00 54.70 36.67 4993.70 5378.67 N 3471.90 E 0.00 5138.68 8000.00 54.70 36.67 5282.64 5705.96 N 3715.61 E 0.00 5546.73 8500.00 54.70 36.67 5571.58 6033.26 N 3959.31 E 0.00 5954.77 9000.00 54.70 36.67 5860.52 6360.55 N 4203.02 E 0.00 6362.82 9423.07 54.70 36.67 6105.00 6637.49 N 4409.22 E 0.00 6708.08 9492.29 54.70 36.67 6145.00 6682.80 N 4442.96 E 0.00 6764.57 9500.00 54.70 36.67 6149.46 6687.85 N 4446.72 E 0.00 6770.86 9596.11 54.70 36.67 6205.00 6750.76 N 4493.57 E 0.00 6849.30 9786.46 54.70 36.67 6315.00 6875.36 N 4586.35 E 0.00 7004.64 9907.01 54.70 36.67 6384.66 6954.27 N 4645.10 E 0.00 7103.02 10000.00 58.38 36.07 6435.92 7016.73 N 4691.09 E 4.00 7180.58 10100.00 62.35 35.48 6485.36 7087.24 N 4741.89 E 4.00 7267.45 10155.13 64.54 35.17 6510.00 7127.48 N 6770.39 E 4.00 7316.73 10200.00 66.32 34.92 6528.66 7160.89 N 4793.83 E 4.00 7357.52 KOP / Start of Nudge Begin Turn to Target Base Permafrost EOC Base West Sak (WS10) 9 5/8" Casing Pt C30 (K-2) C20 (HRZ Mid Point) Base B~Z K-1 Marker Begin Build/Turn to Target Top C4 All data is in feet unless otherwise stated. Coordinates from SW Corner of Sec. 35, T13N, R9E and TVD from RKB (Parker #245) (75.00 Ft above mean sea level). Bottom hole distance is 9432.37 on azimuth 24.14 degrees from wellhead. Total Dogleg for wellpath is 202.67 degrees. Vertical section is from wellhead on azimuth 37.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 3K,24 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G Depth Degrees Degrees Depth C 0 0 R D I N 10215.99 66.95 34.84 6535.00 7172.93 N 10269.42 69.08 34.56 6555.00 7213.66 N 10283.60 69.64 34.48 6560.00 7224.59 N 10300.00 70.29 34.40 6565.62 7237.30 N 10400.00 74.26 33.91 6596.06 7316.11 N 10455.16 76.45 33.64 6610.00 7360.47 N 10500.00 78.24 33.43 6619.82 7396.94 N 10600.00 82.21 32.97 6636.80 7479.39 N 10633.87 83.56 32.81 6641.00 7507.61 N 10700.00 86.18 32.51 6646.91 7563.05 N 10800.00 90.16 32.06 6650.11 7647.53 N 10813.87 90.71 32.00 6650.00 7659.29 N 10813.89 90.71 32.00 6650.00 7659.30 N 11000.00 90.71 32.00 6647.69 7817.12 N 11300.00 90.71 32.00 6643.98 8071.52 N PROPOSAL LISTING Page 2 Your ref : 24 Version #7 Last revised : 24-Nov-98 U L A R Dogleg Vert A T E S Deg/100ft Sect 4802.22 E 4.00 7372.18 Top C3 4830.42 E 4.00 7421.67 Top C1 4837.94 ~ 4.00 7434.93 Top B Shale 4846.65 E 4.00 7450.32 4900.12 E 4.00 7545.42 4929.78 E 4.00 7598.70 7" Casing Point 4953.95 E 4.00 7642.36 5007.90 ~ 4.00 7740.65 5026.15 E 4.00 7774.16 Top A(3) 5061.69 E 4.00 7839.82 5115.07 E 4.00 7939.38 5122.42 E 4.00 7953.20 Target I / EOC 5122.43 E 4.00 7953.21 3K-24 T1 Rvsd 05-Nov-98 5221.05 E 0.00 8138.55 5380.01 E 0.00 8437.31 Begin Directional Thru Formation 11400.00 90.27 27.02 6643.12 8158.52 N 5429.25 E 5.00 8536.38 11500.00 89.83 22.04 6643.03 8249.46 N 5470.75 ~ 5.00 8633.92 11600.00 89.39 17.06 6643.70 8343.67 N 5504.20 E 5.00 8729.20 11700.00 88.87 12.08 6645.22 8440.41 N 5529.35 E 5.00 8821.48 11800.00 88.36 7.11 6647.63 8538.95 N 5546.01 E 5.00 8910.07 11900.00 87.86 2.13 6650.93 8638.54 N 5554.06 E 5.00 8994.28 12000.00 87.38 357.15 6655.08 8738.42 N 5553.43 E 5.00 9073.49 12100.00 87.91 352.17 6659.18 8837.87 N 5544.14 E 5.00 9147.12 12200.00 88.46 347.20 6662.35 8936.17 N 5526.25 E 5.00 9214.65 12300.00 89.02 342.23 6664.55 9032.58 N 5499.91 E 5.00 9275.55 12400.00 89.59 337.26 6665.77 9126.36 N 5465.31 E 5.00 9329.37 12500.00 89.94 332.28 6666.19 9216.79 N 5422.69 E 5.00 9375.68 12518.00 90.00 331.38 6666.20 9232.66 N 5414.20 E 5.00 9383.19 12600.00 90.00 327.28 6666.20 9303.17 N 5372.38 E 5.00 9414.11 12700.00 90.00 322.28 6666.20 9384.84 N 5314.72 E 5.00 9444.34 12718.00 90.00 321.38 6666.20 9398.99 N 5303.60 E 5.00 9448.90 12800.00 90.36 317.29 6665.95 9461.18 N 5250.17 E 5.00 9466.17 12868.00 90.65 313.91 6665.35 9509.75 N 5202.61 E 5.00 9476.14 12900.00 91.78 312.77 6664.67 9531.71 N 5179.34 E 5.00 9479.57 12918.00 92.42 312.14 6664.01 9543.85 N 5166.07 E 5.00 9481.23 13000.00 92.14 308.04 6660.75 9596.61 N 5103.40 E 5.00 9485.40 13100.00 91.79 303.05 6657.31 9654.69 N 5022.11 E 5.00 9482.57 13200.00 91.43 298.06 6654.50 9705.50 N 4936.06 E 5.00 9471.06 13300.00 91.06 293.08 6652.33 9748.63 N 4845.90 E 5.00 9450.96 13400.00 90.67 288.09 6650.82 9783.78 N 4752.33 E 5.00 9422.42 13485.27 90.34 283.84 6650.06 9807.22 N 4670.37 E 5.00 9391.58 EOC 13500.00 90.34 283.84 6649.97 9810.75 N 4656.07 E 0.00 9385.75 13995.29 90.34 283.84 6647.00 9929.22 N 4175.16 E 0.00 9189.59 Target 8 / TD 13995.30 90.34 283.84 6647.00 9929.23 N 4175.15 E 0.00 9189.58 3K-24 T8 Rvsd 17-Nov-98 All data is in feet unless otherwise stated. Coordinates from SW Corner of Sec. 35, T13N, RgE and TVD from RKB (Parker #245) (75.00 Ft above mean sea level). Bottom hole distance is 9432.37 on azimuth 24.14 degrees from wellhead. Total Dogleg for wellpath is 202.67 degrees. Vertical section is from wellhead on azimuth 37.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 3K,24 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref = 24 Version Last revised : 24-Nov-98 Comments in wellpath MD TVD Rectangular Coords. Comment 300.00 300.00 1322.00 N 317 00 E KOP / Start of Nudge 633 1763 2204 5590 5936 9423 9492 9596 9786 9907 10155 10215 10269 10283 10455 10633 10813 10813 11300 13485 13995 13995 .33 631.64 1329.51 N 345 .47 1640.00 1653.85 N 689 · 50 1933.53 1912.29 N 890 .10 3890.00 4128.47 N 2541 .19 4090.00 4355.02 N 2709 .07 6105.00 6637.49 N 4409 29 6145.00 6682.80 N 4442 11 6205.00 6750.?6 N 4493 46 6315.00 68?5.36 N 4586 01 6384.66 6954.27 N 4645 13 6510.00 7127.48 N 4770 99 6535.00 7172.93 N 4802 42 6555.00 7213.66 N 4830 60 6560.00 7224.59 N 4837 16 6610.00 7360.47 N 4929 87 6641.00 7507.61 N 5026 .87 6650.00 7659.29 N 5122 .89 6650.00 7659.30 N 5122 .00 6643.98 8071.52 N 5380 .27 6650.06 980?.22 N 4670 .29 6647.00 9929.22 N 4175 .30 6647.00 9929.23 N 4175 03 E Begin Turn to Target 10 E Base Permafrost 83 E EOC 00 E Base West Sak (WS10) 69 E 9 5/8" Casing Pt 22 E C30 (K-2) 96 E C20 (HRZ Mid Point) 57 E Base HRZ 35 E K-1 Marker 10 E Begin Build/Turn to Target 39 E Top C4 22 E Top C3 42 E Top C1 94 E Top B Shale 78 E 7" Casing Point 15 E Top A(3) 42 E Target i / EOC 43 E 3K-24 T1 Rvsd 05-Nov-98 01 E Begin Directional Thru Formation 37 E EOC 16 E Target 8 / TD 15 E 3K-24 T8 Rvsd 17-Nov-98 Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 1322.00N 317.00E 5936.19 4090.00 4355.02N 2709.69E 9 5/8" Casing 0.00 0.00 1322.00N 317.00E 10455.16 6610.00 7360.47N 4929.78E 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 3K-24 T1 Rvsd 05-Nov 534088.000,6014671 3K-24 T8 Rvsd 17-Nov 533132.000,601693? 3K-24 T2 Rvsd 17-Nov 534497.000,6015365 3K-24 T3 Rvsd 17-Nov 534715.000,6015813 3K-24 T4 Rvsd 17-Nov 534570.000,6016132 3K-24 T5 Rvsd 17-Nov 534458.000,6016272 3K-24 T6 Rvsd 17-Nov 534094.000,6016491 3K-24 T7 Rvsd 05-Nov 533679.000,6016794 000,0.0000 6650.00 000,0.0000 6647.00 000,0.0000 6640.00 000,0.0000 6633.00 000,0.0000 6657.00 000,0.0000 6665.00 000,0.0000 6664.99 000,0.0000 6648.00 7659 30N 9929 23N 8351 78N 8798 9?N 9118 56N 9259 01N 9479.45N 9784.09N 5122.43E 5-Nov-98 4175.15E 5-Nov-98 5534.17E 5-Nov-98 5753.93E 5-Nov-98 5610.16E 5-Nov-98 5498.69E 5-Nov-98 5135.51E 5-Nov-98 4721.65E 5-Nov-98 ARCO Alaska, Inc. Pad 3K,24 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref = 2% Version #7 Last revised = 24-Nov-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 0.00 0.00 75.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 300.00 0.00 75.00 300.00 0.00 N 0.00 E 0.00 0.78 0.78 0.45 N/A 400.00 3.00 75.00 399.95 0.68 N 2.53 E 2.07 1.06 1.05 0.60 75.00 500.00 6.00 75.00 499.63 2.71 N 10.11 E 8.26 1.%2 1.32 0.75 75.00 600.00 9.00 75.00 598.77 6.09 N 22.71 E 18.57 1.94 1.60 0.90 75.00 633.33 10.00 75.00 631.6% 7.51 N 28.03 E 22.92 2.14 1.70 0.96 75.00 700.00 11.53 68.07 697.14 11.50 N 39.80 E 33.21 2.61 1.90 1.06 73.10 800.00 14.04 60.64 794.66 21.18 N 59.65 E 52.92 3.%9 2.22 1.22 68.87 900.00 16.72 55.48 891.07 35.28 N 82.08 E 77.70 4.58 2.57 1.39 6%.92 1000.00 19.48 51.73 986.12 53.76 N 107.02 E 107.50 5.90 2.94 1.58 61.46 1100.00 22.31 48.89 1079.54 76.57 N 134.42 E 1%2.23 7.45 3.34 1.78 58.48 1200.00 25.17 46.66 1171.07 103.65 N 164.19 E 181.80 9.25 3.77 2.00 55.92 1300.00 28.06 44.86 1260.46 134.93 N 196.25 E 226.09 11.30 4.22 2.25 53.72 1400.00 30.97 43.38 1347.48 170.31 N 230.52 E 27%.99 13.62 4.70 2.54 51.81 1500.00 33.89 42.12 1431.87 209.70 N 266.90 E 328.36 16.21 5.20 2.87 50.15 1600.00 36.83 41.05 1513.42 252.99 N 305.29 E 386.05 19.07 5.72 3.2% %8.70 1700.00 39.77 40.11 1591.89 300.07 N 345.59 E %47.91 22.20 6.25 3.67 %7.41 1763.47 41.64 39.57 1640.00 331.85 N 372.10 E %89.26 24.35 6.60 3.97 46.69 1800.00 42.72 39.28 1667.07 350.80 N 387.68 E 513.77 25.60 6.79 %.14 46.27 1900.00 45.68 38.54 1738.76 405.05 N 431.46 E 583.44 29.26 7.34 4.67 %5.25 2000.00 48.64 37.87 1806.75 462.66 N 476.79 E 656.74 33.18 7.88 5.26 %4.34 2100.00 51.60 37.26 1870.86 523.49 N 523.56 E 733.47 37.35 8.41 5.90 %3.51 2200.00 54.56 36.70 1930.92 587.35 N 571.64 E 813.41 41.75 8.94 6.60 %2.76 2204.50 54.70 36.67 1933.53 590.29 N 573.83 E 817.07 41.95 8.96 6.63 %2.73 2500.00 54.70 36.67 2104.29 783.73 N 717.86 E 1058.23 55.08 10.51 8.7% %1.24 3000.00 54.70 36.67 2393.23 1111.02 N 961.56 E 1%66.28 77.42 13.13 12.35 39.89 3500.00 54.70 36.67 2682.17 1438.32 N 1205.27 E 1874.32 99.83 15.76 15.99 39.15 4000.00 54.70 36.67 2971.11 1765.61 N 1448.97 E 2282.37 122.27 18.40 19.65 38.69 4500.00 54.70 36.67 3260.05 2092.90 N 1692.68 E 2690.%1 1%4.72 21.0% 23.31 38.37 5000.00 54.70 36.67 3548.99 2420.20 N 1936.38 E 3098.%6 167.18 23.68 26.97 38.14 5500.00 54.70 36.67 3837.94 2747.49 N 2180.09 E 3506.50 189.65 26.32 30.63 37.97 5590.10 54.70 36.67 3890.00 2806.47 N 222%.00 E 3580.03 193.70 26.80 31.29 37.94 5936.19 54.70 36.67 4090.00 3033.02 N 2392.69 E 3862.%7 209.26 28.63 33.83 37.85 6000.00 54.70 36.67 4126.88 3074.79 N 2423.79 E 3914.55 212.12 28.97 34.30 37.83 6500.00 54.70 36.67 4415.82 3402.08 N 2667.49 E %322.59 234.60 31.62 37.96 37.72 7000.00 54.70 36.67 4704.76 3729.38 N 2911.20 E 4730.64 257.08 34.27 41.63 37.62 7500.00 54.70 36.67 4993.70 4056.67 N 3154.90 E 5138.68 279.56 36.91 45.30 37.55 8000.00 54.70 36.67 5282.64 4383.96 N 3398.61 E 5546.73 302.0% 39.56 48.97 37.%8 8500.00 5%.70 36.67 5571.58 4711.26 N 3642.31 E 595%.77 324.52 42.21 52.64 37.43 9000.00 54.70 36.67 5860.52 5038.55 N 3886.02 E 6362.82 347.01 44.86 56.31 37.38 9423.07 54.70 36.67 6105.00 5315.49 N %092.22 E 6708.08 366.03 %7.11 59.41 37.34 9492.29 54.70 36.67 6145.00 5360.80 N 4125.96 E 6764.57 369.15 47.%7 59.92 37.33 9500.00 5%.70 36.67 6149.46 5365.85 N %129.72 E 6770.86 369.49 47.51 59.98 37.33 9596.11 54.70 36.67 6205.00 5428.76 N %176.57 E 6849.30 373.81 %8.02 60.68 37.33 9786.46 54.70 36.67 6315.00 5553.36 N 4269.35 E 7004.64 382.37 49.03 62.08 37.31 9907.01 5%.70 36.67 6384.66 5632.27 N 4328.10 E 7103.02 387.80 49.67 62.96 37.30 10000.00 58.38 36.07 6435.92 5694.73 N 4374.09 E 7180.58 392.23 50.14 63.70 37.29 10100.00 62.35 35.48 6485.36 5765.24 N 4424.89 E 7267.45 397.27 50.61 64.55 37.26 10155.13 64.54 35.17 6510.00 5805.48 N 4453.39 E 7316.73 400.17 50.85 65.06 37.25 10200.00 66.32 34.92 6528.66 5838.89 N 4%76.83 E 7357.52 %02.53 51.0% 65.46 37.23 All data is in feet unless otherwise stated. Coordinates from slot #24 and TVD from RKB (Parker #245) (75.00 Ft above mean sea level). Bottom hole distance is 9432.37 on azimuth 2%.1% degrees from wellhead. Vertical section is from wellhead on azimuth 37.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 3K,24 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref = 24 Version #7 Last revised : 24-Nov-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 10215.99 66.95 34.84 6535.00 5850.93 N 4485.22 E 7372.18 403.40 51.10 65.62 37.23 10269.42 69.08 34.56 6555.00 5891.66 N 4513.42 E 7421.67 406.32 51.30 66.13 37.21 10283.60 69.64 34.48 6560.00 5902.59 N 4520.94 E 7434.93 407.09 51.35 66.27 37.20 10300.00 70.29 34.40 6565.62 5915.30 N 4529.65 E 7450.32 407.99 51.41 66.42 37.20 10400.00 74.26 33.91 6596.06 5994.11 N 4583.12 E 7545.42 413.60 51.74 67.43 37.15 10455.16 76.45 33.64 6610.00 6038.47 N 4612.78 E 7598.70 416.75 51.88 68.00 37.12 10500.00 78.24 33.43 6619.82 6074.94 N 4636.95 E 7642.36 419.32 52.00 68.46 37.10 10600.00 82.21 32.97 6636.80 6157.39 N 4690.90 E 7740.65 425.10 52.20 69.52 37.04 10633.87 83.56 32.81 6641.00 6185.61 N 4709.15 E 7774.16 427.07 52.24 69.89 37.02 10700.00 86.18 32.51 6646.91 6241.05 N 4744.69 E 7839.82 430.90 52.33 70.60 36.98 10800.00 90.16 32.06 6650.11 6325.53 N 4798.07 E 7939.38 436.68 52.40 71.69 36.91 10813.87 90.71 32.00 6650.00 6337.29 N 4805.42 E 7953.20 437.48 52.41 71.84 36.91 10813.89 90.71 32.00 6650.00 6337.30 N 4805.43 E 7953.21 437.48 52.41 71.84 36.91 11000.00 90.71 32.00 6647.69 6495.12 N 4904.05 E 8138.55 448.22 52.52 73.86 36.79 11300.00 90.71 32.00 6643.98 6749.52 N 5063.01 E 8437.31 465.54 52.70 77.12 36.61 11400.00 90.27 27.02 6643.12 6836.52 N 5112.25 E 8536.38 470.75 52.77 78.21 36.50 11500.00 89.83 22.04 6643.03 6927.46 N 5153.75 E 8633.92 475.35 52.84 79.30 36.35 11600.00 89.39 17.06 6643.70 7021.67 N 5187.20 E 8729.20 479.33 52.92 80.38 36.19 11700.00 88.87 12.08 6645.22 7118.41 N 5212.35 E 8821.48 482.66 53.00 81.47 36.01 11800.00 88.36 7.11 6647.63 7216.95 N 5229.01 E 8910.07 485.36 53.10 82.55 35.83 11900.00 87.86 2.13 6650.93 7316.54 N 5237.06 E 8994.28 487.46 53.25 83.63 35.66 12000.00 87.38 357.15 6655.08 7416.42 N 5236.43 E 9073.49 488.99 53.46 84.71 35.52 12100.00 87.91 352.17 6659.18 7515.87 N 5227.14 E 9147.12 490.01 53.79 85.80 35.41 12200.00 88.46 347.20 6662.35 7614.17 N 5209.25 E 9214.65 490.59 54.31 86.88 35.33 12300.00 89.02 342.23 6664.55 7710.58 N 5182.91 E 9275.55 490.79 55.11 87.96 35.29 12400.00 89.59 337.26 6665.77 7804.36 N 5148.31 E 9329.37 490.71 56.29 89.05 35.30 12500.00 89.94 332.28 6666.19 7894.79 N 5105.69 E 9375.68 490.42 57.98 90.13 35.36 12518.00 90.00 331.38 6666.20 7910.66 N 5097.20 E 9383.19 490.36 58.32 90.33 35.37 12600.00 90.00 327.28 6666.20 7981.17 N 5055.38 E 9414.11 490.03 60.22 91.22 35.46 12700.00 90.00 322.28 6666.20 8062.84 N 4997.72 E 9444.34 489.59 63.18 92.30 35.63 12718.00 90.00 321.38 6666.20 8076.99 N 4986.60 E 9448.90 489.52 63.77 92.50 35.66 12800.00 90.36 317.29 6665.95 8139.18 N 4933.17 E 9466.17 489.21 66.80 93.38 35.84 12868.00 90.65 313.91 6665.35 8187.75 N 4885.61 E 9476.14 489.01 69.66 94.12 36.01 12900.00 91.78 312.77 6664.67 8209.71 N 4862.34 E 9479.57 488.93 71.09 94.47 36.09 12918.00 92.42 312.14 6664.01 8221.85 N 4849.07 E 9481.23 488.88 71.92 94.66 36.14 13000.00 92.14 308.04 6660.75 8274.61 N 4786.40 E 9485.40 488.83 76.01 95.55 36.40 13100.00 91.79 303.05 6657.31 8332.69 N 4705.11 E 9482.57 489.03 81.53 96.64 36.76 13200.00 91.43 298.06 6654.50 8383.50 N 4619.06 E 9471.06 489.56 87.49 97.72 37.17 13300.00 91.06 293.08 6652.33 8426.63 N 4528.90 E 9450.96 490.46 93.75 98.80 37.62 13400.00 90.67 288.09 6650.82 8461.78 N 4435.33 E 9422.42 491.76 100.16 99.89 38.11 13485.27 90.34 283.84 6650.06 8485.22 N 4353.37 E 9391.58 493.19 105.63 100.81 38.55 13500.00 90.34 283.84 6649.97 8488.75 N 4339.07 E 9385.75 493.44 106.59 100.97 38.63 13995.29 90.34 283.84 6647.00 8607.22 N 3858.16 E 9189.59 502.75 139.10 106.34 41.40 13995.30 90.34 283.84 6647.00 8607.23 N 3858.15 E 9189.58 502.75 139.10 106.34 41.40 All data is in feet unless otherwise stated. Coordinates from slot #24 and TVD from RKB (Parker #245) (75.00 Pt above mean sea level). Bottom hole distance is 9432.37 on azimuth 24.14 degrees from wellhead. Vertical section is from wellhead on azimuth 37.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 3K,24 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTIN0 Page 3 Your ref : 24 version #7 Last revised : 24-Nov-98 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 13995 ARCO (H.A. Mag) User specified 502.75 139.10 106.34 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. Comments in wellpath MD TVD Rectangular Coords. Comment 300.00 300.00 0.00 N 0.00 E KOP / Start of Nudge 633.33 631.64 7.51 N 28.03 E Begin Turn to Target 1763.47 1640.00 2204.50 1933.53 5590.10 3890.00 5936.19 4090.00 9423.07 6105.00 9492.29 6145.00 9596.11 6205.00 9786.46 6315 00 9907.01 6384 66 10155.13 6510 00 10215.99 6535 00 10269.42 6555 00 10283.60 6560 00 10455.16 6610 00 10633.87 6641 00 10813.87 6650.00 10813.89 6650.00 11300.00 6643.98 13485.27 6650.06 13995.29 6647.00 13995.30 6647.00 331.85 590.29 2806.47 3033.02 5315.49 5360.80 5428.76 5553 36 5632 27 5805 48 5850 93 5891 66 5902 59 6038 47 6185 61 6337 29 6337 30 6749.52 8485.22 8607.22 8607.23 N 372.10 E Base Permafrost N 573.83 E EOC N 2224.00 E Base West Sak (WS10) N 2392.69 E 9 5/8" Casing Pt N 4092.22 E C30 (K-2) N 4125.96 E C20 (~IRZ Mid Point) N 4176.57 E Base ~Z N 4269.35 E K-1 Marker N 4328.10 E Begin Build/Turn to Target N 4453.39 E Top C4 N 4485.22 E Top C3 N 4513.42 E Top C1 N 4520.94 E Top B Shale N 4612.78 E 7" Casing Point N 4709.15 E Top A(3) N 4805.42 E Target i / EOC N 4805.43 E 3K-24 71 Rvsd 05-Nov-98 N 5063.01 E Begin Directional Thru Formation N 4353.37 E EOC N 3858.16 E Target 8 / TD N 3858.15 E 3K-24 78 Rvsd 17-Nov-98 Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 5936.19 4090.00 3033.02N 2392.69E 9 5/8" Casing 0.00 0.00 0.00N 0.00E 10455.16 6610.00 6038.47N 4612.78E 7" Casing Targets associated with this wellpath Target name Oeographic Location T.V.D. Rectangular Coordinates Revised 3K-24 71 Rvsd 05-Nov 534088.000,6014671.000,0.0000 3K-24 78 Rvsd 17-Nov 533132.000,6016937.000,0.0000 3K-24 72 Rvsd 17-Nov 534497.000,6015365.000,0.0000 3K-24 73 Rvsd 17-Nov 534715.000,6015813.000,0.0000 3K-24 74 Rvsd 17-Nov 534570.000,6016132.000,0.0000 3K-24 75 Rvsd 17-Nov 534458.000,6016272.000,0.0000 3K-24 76 Rvsd 17-Nov 534094.000,6016491.000,0.0000 3K-24 77 Rvsd 05-Nov 533679.000,6016794.000,0.0000 6650.00 6337.30N 4805.43E 5-Nov-98 6647.00 8607.23N 3858.15E 5-Nov-98 6640.00 7029.78N 5217.17E 5-Nov-98 6633.00 7476.97N 5436.93E 5-Nov-98 6657.00 7796.56N 5293.16E 5-Nov-98 6665.00 7937.01N 5181.69E 5-Nov-98 6664.99 8157.45N 4818.51E 5-Nov-98 6648.00 8462.09N 4404.65E S-Nov-98 ARCO Alaska, Inc. PROPOSAL LISTING Page 1 Pad 3K,24 Your ref : 24 Version #7 Kuparuk River Unit,North Slope, Alaska Last revised : 24-Nov-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing 0.00 0.00 75.00 0.00 0.00N 0.00E 0.00 0.00 529307.71 6008315.70 300.00 0.00 75.00 300.00 0.00N 0.00E 0.00 0.00 529307.71 6008315.70 400.00 3.00 75.00 399.95 0.68N 2.53E 3.00 2.07 529310.23 6008316.38 500.00 6.00 75.00 499.63 2.71N 10.11E 3.00 8.26 529317.80 6008318.44 600.00 9.00 75.00 598.77 6.09N 22.71E 3.00 18.57 529330.39 6008321.87 633.33 10.00 75.00 631.64 7.51N 28.03E 3.00 22.92 529335.70 6008323.31 700.00 11.53 68.07 697.14 11.50N 39.80E 3.00 33.21 529347.46 6008327.35 800.00 14.04 60.64 794.66 21.18N 59.65E 3.00 52.92 529367.27 6008337.10 900.00 16.72 55.48 891.07 35.28N 82.08E 3.00 77.70 529389.64 6008351.29 1000.00 19.48 51.73 986.12 53.76N 107.02E 3.00 107.50 529414.51 6008369.87 1100.00 22.31 48.89 1079.54 76.57N 134.42E 3.00 142.23 529441.81 6008392.79 1200.00 25.17 46.66 1171.07 103.65N 164.19E 3.00 181.80 529471.48 6008419.98 1300.00 28.06 44.86 1260.46 134.93N 196.25E 3.00 226.09 529503.41 6008451.37 1400.00 30.97 43.38 1347.48 170.31N 230.52E 3.00 274.99 529537.54 6008486.88 1500.00 33.89 42.12 1431.87 209.70N 266.90E 3.00 328.36 529573.76 6008526.41 1600.00 36.83 41.05 1513.42 252.99N 305.29E 3.00 386.05 529611.98 6008569.85 1700.00 39.77 40.11 1591.89 300.07N 345.59E 3.00 447.91 529652.09 6008617.08 1763.47 41.64 39.57 1640.00 331.85N 372.10E 3.00 489.26 529678.48 6008648.96 1800.00 42.72 39.28 1667.07 350.80N 387.68E 3.00 513.77 529693.98 6008667.97 1900.00 45.68 38.54 1738.76 405.05N 431.46E 3.00 583.44 529737.54 6008722.38 2000.00 48.64 37.87 1806.75 462.66N 476.79E 3.00 656.74 529782.65 6008780.16 2100.00 51.60 37.26 1870.86 523.49N 523.56E 3.00 733.47 529829.18 6008841.16 2200.00 54.56 36.70 1930.92 587.35N 571.64E 3.00 813.41 529877.00 6008905.21 2204.50 54.70 36.67 1933.53 590.29N 573.83E 3.00 817.07 529879.18 6008908.16 2500.00 54.70 36.67 2104.29 783.73N 717.86E 0.00 1058.23 530022.44 6009102.13 3000.00 54.70 36.67 2393.23 1111.02N 961.56E 0.00 1466.28 530264.85 6009430.34 3500.00 54.70 36.67 2682.17 1438.32N 1205.27E 0.00 1874.32 530507.26 6009758.54 4000.00 54.70 36.67 2971.11 1765.61N 1448.97E 0.00 2282.37 530749.66 6010086.75 4500.00 54.70 36.67 3260.05 2092.90N 1692.68E 0.00 2690.41 530992.07 6010414.96 5000.00 54.70 36.67 3548.99 2420.20N 1936.38E 0.00 3098.46 531234.48 6010743.16 5500.00 54.70 36.67 3837.94 2747.49N 2180.09E 0.00 3506.50 531476.88 6011071.37 5590.10 54.70 36.67 3890.00 2806.47N 2224.00E 0.00 3580.03 531520.56 6011130.51 5936.19 54.70 36.67 4090.00 3033.02N 2392.69E 0.00 3862.47 531688.35 6011357.69 6000.00 54.70 36.67 4126.88 3074.79N 2423.79E 0.00 3914.55 531719.29 6011399.57 6500.00 54.70 36.67 4415.82 3402.08N 2667.49E 0.00 4322.59 531961.70 6011727.78 7000.00 54.70 36.67 4704.76 3729.38N 2911.20E 0.00 4730.64 532204.10 6012055.99 7500.00 54.70 36.67 4993.70 4056.67N 3154.90E 0.00 5138.68 532446.51 6012384.19 8000.00 54.70 36.67 5282.64 4383.96N 3398.61E 0.00 5546.73 532688.92 6012712.40 8500.00 54.70 36.67 5571.58 4711.26N 3642.31E 0.00 5954.77 532931.32 6013040.61 9000.00 54.70 36.67 5860.52 5038.55N 3886.02E 0.00 6362.82 533173.73 6013368.81 9423.07 54.70 36.67 6105.00 5315.49N 4092.22E 0.00 6708.08 533378.84 6013646.52 9492.29 54.70 36.67 6145.00 5360.80N 4125.96E 0.00 6764.57 533412.40 6013691.96 9500.00 54.70 36.67 6149.46 5365.85N 4129.72E 0.00 6770.86 533416.14 6013697.02 9596.11 54.70 36.67 6205.00 5428.76N 4176.57E 0.00 6849.30 533462.73 6013760.11 9786.46 54.70 36.67 6315.00 5553.36N 4269.35E 0.00 7004.64 533555.02 6013885.06 5632.27N 4328.10E 0.00 7103.02 533613.46 6013964.19 9907.01 54.70 36.67 6384.66 10000.00 58.38 36.07 6435.92 5694.73N 4374.09E 4.00 7180.58 533659.20 6014026.82 10100.00 62.35 35.48 6485.36 5765.24N 4424.89E 4.00 7267.45 533709.72 6014097.52 10155.13 64.54 35.17 6510.00 5805.48N 4453.39E 4.00 7316.73 533738.07 6014137.86 10200.00 66.32 34.92 6528.66 5838.89N 4476.83E 4.00 7357.52 533761.37 6014171.36 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #24 and TVD from RKB (Parker #245) (75.00 Ft above mean sea level). Bottom hole distance is 9432.37 on azimuth 24.14 degrees from wellhead. Total Dogleg for wellpath is 202.67 degrees. Vertical section is from wellhead on azimuth 37.17 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 3K,24 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 24 Version #7 Last revised : 24-Nov-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 00 R D I N A T E S Deg/100ft Sect Easting Northing 10215.99 66.95 34.84 6535.00 5850.93N 4485.22E 4.00 7372.18 533769.71 6014183.43 10269.42 69.08 34.56 6555.00 5891.66N 4513.42E 4.00 7421.67 533797.75 6014224.27 10283.60 69.64 34.48 6560.00 5902.59N 4520.94E 4.00 7434.93 533805.23 6014235.23 10300.00 70.29 34.40 6565.62 5915.30N 4529.65E 4.00 7450.32 533813.89 6014247.97 10400.00 74.26 33.91 6596.06 5994.11N 4583.12E 4.00 7545.42 533867.04 6014326.98 10455.16 76.45 33.64 6610.00 6038.47N 4612.78E 4.00 7598.70 533896.53 6014371.45 10500.00 78.24 33.43 6619.82 6074.94N 4636.95E 4.00 7642.36 533920.56 6014408.01 10600.00 82.21 32.97 6636.80 6157.39N 4690.90E 4.00 7740.65 533974.17 6014490.66 10633.87 83.56 32.81 6641.00 6185.61N 4709.15E 4.00 7774.16 533992.31 6014518.95 10700.00 86.18 32.51 6646.91 6241.05N 4744.69E 4.00 7839.82 534027.64 6014574.52 10800.00 90.16 32.06 6650.11 6325.53N 4798.07E 4.00 7939.38 534080.68 6014659.20 10813.87 90.71 32.00 6650.00 6337.29N 4805.42E 4.00 7953.20 534087.99 6014670.98 10813.89 90.71 32.00 6650.00 6337.30N 4805.43E 4.00 7953.21 534088.00 6014671.00 11000.00 90.71 32.00 6647.69 6495.12N 4904.05E 0.00 8138.55 534185.99 6014829.19 11300.00 90.71 32.00 6643.98 6749.52N 5063.01E 0.00 8437.31 534343.95 6015084.17 11400.00 90.27 27.02 6643.12 6836.52N 5112.25E 5.00 8536.38 534392.85 6015171.35 11500.00 89.83 22.04 6643.03 6927.46N 5153.75E 5.00 8633.92 534433.99 6015262.45 11600.00 89.39 17.06 6643.70 7021.67N 5187.20E 5.00 8729.20 534467.07 6015356.77 11700.00 88.87 12.08 6645.22 7118.41N 5212.35E 5.00 8821.48 534491.84 6015453.60 11800.00 88.36 7.11 6647.63 7216.95N 5229.01E 5.00 8910.07 534508.11 6015552.20 11900.00 87.86 2.13 6650.93 7316.54N 5237.06E 5.00 8994.28 534515.77 6015651.81 12000.00 87.38 357.15 6655.08 7416.42N 5236.43E 5.00 9073.49 534514.76 6015751.67 12100.00 87.91 352.17 6659.18 7515.87N 5227.14E 5.00 9147.12 534505.08 6015851.08 12200.00 88.46 347.20 6662.35 7614.17N 5209.25E 5.00 9214.65 534486.82 6015949.30 12300.00 89.02 342.23 6664.55 7710.58N 5182.91E 5.00 9275.55 534460.10 6016045.60 12400.00 89.59 337.26 6665.77 7804.36N 5148.31E 5.00 9329.37 534425.14 6016139.23 12500.00 89.94 332.28 6666.19 7894.79N 5105.69E 5.00 9375.68 534382.18 6016229.49 12518.00 90.00 331.38 6666.20 7910.66N 5097.20E 5.00 9383.19 534373.62 6016245.32 12600.00 90.00 327.28 6666.20 7981.17N 5055.38E 5.00 9414.11 534331.53 6016315.67 12700.00 90.00 322.28 6666.20 8062.84N 4997.72E 5.00 9444.34 534273.56 6016397.10 12718.00 90.00 321.38 6666.20 8076.99N 4986.60E 5.00 9448.90 534262.38 6016411.21 12800.00 90.36 317.29 6665.95 8139.18N 4933.17E 5.00 9466.17 534208.73 6016473.18 12868.00 90.65 313.91 6665.35 8187.75N 4885.61E 5.00 9476.14 534160.97 6016521.56 12900.00 91.78 312.77 6664.67 8209.71N 4862.34E 5.00 9479.57. 534137.62 6016543.43 12918.00 92.42 312.14 6664.01 8221.85N 4849.07E 5.00 9481.23 534124.31 6016555.52 13000.00 92.14 308.04 6660.75 8274.61N 4786.40E 5.00 9485.40 534061.44 6016608.02 13100.00 91.79 303.05 6657.31 8332.69N 4705.11E 5.00 9482.57 533979.93 6016665.79 13200.00 91.43 298.06 6654.50 8383.50N 4619.06E 5.00 9471.06 533893.69 6016716.25 13300.00 91.06 293.08 6652.33 8426.63N 4528.90E 5.00 9450.96 533803.38 6016759.03 13400.00 90.67 288.09 6650.82 8461.78N 4435.33E 5.00 9422.42 533709.68 6016793.81 13485.27 90.34 283.84 6650.06 8485.22N 4353.37E 5.00 9391.58 533627.64 6016816.93 13500.00 90.34 283.84 6649.97 8488.75N 4339.07E 0.00 9385.75 533613.32 6016820.40 13995.29 90.34 283.84 6647.00 8607.22N 3858.16E 0.00 9189.59 533132.01 6016937.00 13995.30 90.34 283.84 6647.00 8607.23N 3858.15E 0.00 9189.58 533132.00 6016937.00 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #24 and TVD from RKB (Parker #245) (75.00 Ft above mean sea level). Bottom hole distance is 9432.37 on azimuth 24.14 degrees from wellhead. Total Dogleg for wellpath is 202.67 degrees. Vertical section is from wellhead on azimuth 37.17 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 3K,24 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 24 Version #7 Last revised : 24-Nov-98 Comments in wellpath MD TVD Rectangular Coords. Comment 300.00 300.00 0.00N 0.00E KOP / Start of Nudge 633.33 1763.47 2204.50 5590.10 5936.19 9423.07 9492.29 9596 11 9786 46 9907 01 10155 13 10215 99 10269 42 10283 60 10455 16 10633 87 10813 87 10813 89 11300 00 13485 27 13995 29 13995 30 631 1640 1933 3890 4090 6105 6145 6205 6315 6384 6510 6535 6555 6560 6610 6641 6650 6650 6643 6650 6647 6647 .64 .00 .53 .00 .00 .00 .00 .00 .00 .66 .00 .00 00 00 00 00 00 00 98 06 00 00 7.51N 331.85N 590.29N 2806.47N 3033.02N 5315.49N 5360.80N 5428.76N 5553.36N 5632.27N 5805.48N 5850.93N 5891 66N 5902 59N 6038 47N 6185 61N 6337 29N 6337 30N 6749 52N 8485 22N 8607 22N 8607 23N 28 03E 372 10E 573 83E 2224 00E 2392 69E 4092 22E 4125 96E 4176 57E 4269 35E 4328 10E 4453 39E 4485 22E 4513.42E 4520.94E 4612.78E 4709.15E 4805.42E 4805.43E 5063.01E 4353.37E 3858.16E 3858.15E Begin Turn to Target Base Permafrost EOC Base West Sak (WS10) 9 5/8" Casing Pt C30 (K-2) C20 (HRZ Mid Point) Base HRZ K-1 Marker Begin Build/Turn to Target Top C4 Top C3 Top C1 Top B Shale 7" Casing Point Top A(3) Target I / EOC 3K-24 T1 Rvsd 05-Nov-98 Begin Directional Thru Formation EOC Target 8 / TD 3K-24 T8 Rvsd 17-Nov-98 Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 5936.19 4090.00 3033.02N 2392.69E 9 5/8" Casing 0.00 0.00 0.00N 0.00E 10455.16 6610.00 6038.47N 4612.78E 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 3K-24 T1 Rvsd 05-Nov 534088.000,6014671.000,0.0000 3K-24 T8 Rvsd 17-Nov 533132.000,6016937.000,0.0000 3K-24 T2 Rvsd 17-Nov 534497.000,6015365.000,0.0000 3K-24 T3 Rvsd 17-Nov 534715.000,6015813.000,0.0000 3K-24 T4 Rvsd 17-Nov 534570.000,6016132.000,0.0000 3K-24 T5 Rvsd 17-Nov 534458.000,6016272.000,0.0000 3K-24 T6 Rvsd 17-Nov 534094.000,6016491.000,0.0000 3K-24 T7 Rvsd 05-Nov 533679.000,6016794.000,0.0000 6650.00 6337.30N 4805.43E 5-Nov-98 6647.00 8607.23N 3858.15E 5-Nov-98 6640.00 7029.78N 5217.17E 5-Nov-98 6633.00 7476.97N 5436.93E 5-Nov-98 6657.00 7796.56N 5293.16E 5-Nov-98 6665.00 7937.01N 5181.69E 5-Nov-98 6664.99 8157.45N 4818.51E 5-Nov-98 6648.00 8462.09N 4404.65E 5-Nov-98 ~laska, Inc. ' AK 99510-2776 "~ ALASKA DEPT OF REVENUE ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE EXACTLY *********** 100 al Bank of Chicago-0710 cago, Illinois Through Republic Bank /ville, Kentucky NUMBER: 205086720 6720 NOVEMBER 19, 1998 73-426 839 0997579 VOID AFTER 90 DAYS *** AND O0 CENTS ~*********** 100.00 Oqg ? S 7 q,' :o WELL PERMIT CHECKLIST COMPANY _WELL NAME /'~,,~./' ,~,~' ".2_/-72 PROGRAM: exp [] dev'~redrll [] serv [] wellbore segll ann. disposal para req~:~ i - · - · - FIELD & POOL ADMINISTRATION INIT CLASS /~z../...-- .//-~;;,/' 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unil boundary .... 6. Well Iocaled proper distance from other wells .......... 7. Sufficienl acreage available in drilling unit ............ 8. If deviated, is we,bore plat included ............... 9. Operator only affected party .................. 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING A_~_P.,~ DAI'E 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CM[ vol adequate to tie-in long string to surf csg ........ 18. CMl will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ,,~'OOO psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY D/YTE / 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones. ' 33. Seabed condition survey (if off-shore) ............. 34. Contact nam. e/phone for weekly progress reports ....... [exploratory only] ANNULAR DISPOSAL 35. APPR DATE ....... Wilh proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... lo surface; (C) will nol impair mechanical integrity of the well used for disposal; (D) will nol damage producing formation or i~npair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOL Y N Y ~ AREA ~::~ ,,c',,..~ UNIT# ON/OFF SHORE Y N GEOLOGY: ENGINEERING: UIC/Annular JDH ~ COMMISSION: DWJ_~=~ ......... -~X RNC -~_, ~ co ~~,l~ Comments/Instructions: Mcheklisl mv ('}512919~{ dll (; ~nlq(l{h( i~\w()ldir, l\dl;ilt;ib h,, I,h, I Well Flisto -rY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Wed Apr 21 08:23:01 1999 Reel Header Service name ............. LISTPE Date ..................... 99/04/21 Origin ................... STS Reel Name ................ UNK/~OWN Continuation Number ...... 01 Previous Reel Name ....... UNK/~OWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/04/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KTJPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NIIMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPEP~ATOR WITNESS: MWD RUN 1 AK-MM-90057 T.MCGUIRE GUY WHITLOCK RECE!V API ? 1999 Oil & Gas Cons. _Commi.' on 3K-24 500292293500 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 21-APR-99 MWD RUN 2 AK-MM-90057 TOM MCGUIRE DON BREEDEN MWD RUN 4 AK-MM-90057 S. BURKHARDT D. BREEDEN JOB NUMBER: LOGGING ENGINEER: OPER3ATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: MWD RUN 5 AK-MM-90057 K. FERGUSON D. BREEDEN MWD RUN 6 AK-MM-90057 S. BURKHARDT G. WHITLOCK 35 13N 09E MWD RUN 6 AK-MM-90057 S. BURKHA_RDT G. WHITLOCK FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1322 317 .00 75.30 34.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.630 5937.0 8.500 7.000 10522.0 6.750 14073.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 3. MWD RUN 2 IS DIRECTIONAL WITH DGR AND PRESSURE WHILE DRILLING (PWD). 4. MWD RUN 3 MADE NO FOOTAGE AND IS NOT PRESENTED. 5. MWD RUNS 4-6 ARE DIRECTIONAL WITH DGR, PWD, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND DYNAMIC DRILLSTRING SENSOR (DDS) . 6. A MEASUREMENT AFTER DRILLING (MAD) PASS FROM l1950'MD, 6644'TVD TO 10520'MD 6633'TVD WAS PERFORMED FOLLOWING MWD RUN 6. 7. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL FROM D. SCHWARTZ OF ARCO ALASKA, INC. ON 02/12/99. THIS DATA IS CONSIDERED PDC. 8. EWR4 DATA FROM RUNS 4-6 IS FILTERED WITH A WEIGHTED AVERAGE, 3 FT WINDOW. THIS DATA IS PRESENTED DIGITALLY AS THE MERGED MWD PASS AND ON THE LOGS. ORIGINAL, UNFILTERED EWR DATA IS RETAINED IN THE INDIVIDUAL MWD RUNS AND AS A SEPARATE ASCII FILE AVAILABLE FROM THE OPEP=ATOR. 9. MWD RUNS 1-6 REPERSENT WELL 3K-24 WITH API#: 50-029-22935-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14073'MD, 6696'TV-D. SROP = SMOOTHED P~ATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED EXPOSURE TIME. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. CURVES WITH SUFFIX 'M' DENOTE MAD PASS DATA. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 121.0 ROP 121 0 FET 5904 5 RPD 5904 5 RPM 5904 5 RPS 5904 5 RPX 5904 5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 14029.5 14073 0 14036 5 14036 5 14036 5 14036 5 14036 5 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined BIT RUN NO MERGE TOP MERGE BASE 1 121.0 5947.0 2 5947.0 10536.0 4 10536.0 11299.0 5 11299.0 11912.0 6 11912.0 14073.0 Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 DEPT GR ROP FET RPD RPM RPS RPX Name Service Order Units Size Nsam FT 4 1 MWD API 4 1 MWD FT/H 4 1 MWD HOUR 4 1 MWD OHMM 4 1 MWD OHMM 4 1 MWD OHMM 4 1 MWD OHMM 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max DEPT 121 14073 GR 9.91 533.31 ROP 0 2570.5 FET 0.1 86.3 RPD 0.13 2000 RPM 0.19 2000 RPS 0.06 2000 RPX 0.05 2000 Mean Nsam 7097 27905 95.48 27818 191.183 27905 2.07158 16222 52.1128 16222 47.778 16222 47.9522 16222 18.0768 16222 First Reading 121 121 121 5904.5 5904.5 5904.5 5904.5 5904.5 Last Reading 14073 14029.5 14073 14036.5 14036.5 14036.5 14036.5 14036.5 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 14073 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEA/DER FILE NUMBER: EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR RAT $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: .5000 START DEPTH 10506 5 10506 5 10506 5 10506 5 10506 5 10507 0 10525 5 STOP DEPTH 11957 5 11957 5 11957 5 11957 5 11957 5 11957 5 12026 5 MAD RUN NO. M_AD PASS NO. MERGE TOP 6 10507.0 MERGED MAD PASS. $ MERGE BASE 12027.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 10506.5 12026.5 11266.5 3041 10506.5 RAT 20.27 3304.69 413.906 3003 10525.5 GR 43.52 168.25 95.8399 2902 10507 RPX 0.05 430.84 8.49836 2903 10506.5 RPS 0.05 2000 31.1173 2903 10506.5 RPM 1.89 2000 82.5464 2903 10506.5 RPD 2.87 2000 73.1231 2903 10506.5 Last Reading 12026 5 12026 5 11957 5 11957 5 11957 5 11957 5 11957 5 FET 16.58 228.85 101.099 2903 10506.5 11957.5 First Reading For Entire File .......... 10506.5 Last Reading For Entire File ........... 12026.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMM3LRY VENDOR TOOL CODE ST~tRT DEPTH STOP DEPTH GR 121.0 5911.5 ROP 121.0 5947.0 $ LOG HEADER DATA DATE LOGGED: 06-JAiq-99 SOFTWARE SURFACE SOFTWARE VERSION: 5.06 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 5947.0 TOP LOG INTERVAL (FT) : 121.0 BOTTOM LOG INTERVAL (FT) : 5947.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .4 MAXIMUM ANGLE: 57.3 INSITE 3.2 (UP3) / ISC TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD MT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER P1206CG8 12.250 12.3 SPUD MUD 9.50 140.0 8.5 350 6.4 .000 .000 .000 .000 32.5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 121 5947 3034 11653 121 GR 9.91 240.83 80.7345 11582 121 Last Reading 5947 5911.5 ROP 0.04 944.71 263.641 11653 121 5947 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 5947 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 R3kW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 5904.5 10490 0 RPD 5904.5 10490 0 RPM 5904.5 10490 0 RPM 5904.5 10490 0 RPX 5904.5 10490 0 GR 5912.0 10480 5 ROP 5949.0 10535 0 $ LOG HEADER DATA DATE LOGGED: 12-JAN-99 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2 (UP3) 5.06 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10536.0 TOP LOG INTERVAL (FT) : 5947.0 / ISC BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPER3~TURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPEP~ATURE: MUD FILTP~ATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 10536.0 53.7 78.7 TOOL NUMBER Pl209CWGVR6 P1209CWGVR6 8.500 8.5 LSND 9.30 45.0 9.0 400 6.2 3.700 2.090 4.800 3.100 52.1 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHMM 4 1 68 12 4 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOLrR 4 1 68 16 20 24 28 Name Min Max Mean Nsam DEPT 5904.5 10535 8219.75 9262 GR 39.01 533.31 119.42 9138 RPX 0.52 2000 3.85125 9172 RPS 0.38 2000 3.96177 9172 RPM 0.19 236.58 3.644 9172 RPD 0.13 2000 10.0816 9172 ROP 1 862 190.393 9173 FET 0.1 65.26 1.34495 9172 First Reading 5904.5 5912 5904.5 5904.5 5904.5 5904.5 5949 5904.5 Last Reading 10535 10480.5 10490 10490 10490 10490 10535 10490 First Reading For Entire File .......... 5904.5 Last Reading For Entire File ........... 10535 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NTJMBER: 5 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10481.0 11254.5 FET 10512.0 11261.5 RPD 10512.0 RPM 10512.0 RPS 10512.0 RPX 10512.0 ROP 10535.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 5.06 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 11261.5 11261.5 11261.5 11261.5 11299.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPER3kTURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL FLATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record 17-JA1~-99 INSITE 3.2 5.46 MEMORY 11299.0 10536.0 11299.0 82.7 89.5 TOOL N-UMBER P1217GRV4 P1217GRV4 6.130 6.1 BAR3kDR I L -N 10.40 56.0 9.5 3.7 .050 .029 .050 .100 .0 (uP3) 52 .2 / ISC Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 4 API 4 1 RPX MWD 4 OHMM 4 1 RPS MWD 4 OHMM 4 1 RPM MWD 4 OHMM 4 1 RPD MWD 4 OHMM 4 1 ROP MWD 4 FT/H 4 1 FET MWD 4 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 10481 11299 10890 GR 49.14 171.91 104.348 RPX 0.05 1936.29 32.104 RPS 0.06 2000 100.93 RPM 1.93 2000 78.6342 RPD 2.8 1660.61 68.7571 ROP 1 1605 88.8711 FET 0.42 86.3 4.41339 First Last Nsam Reading Reading 1637 10481 11299 1548 10481 11254.5 1500 10512 11261.5 1500 10512 11261.5 1500 10512 11261.5 1500 10512 11261.5 1528 10535.5 11299 1500 10512 11261.5 First Reading For Entire File .......... 10481 Last Reading For Entire File ........... 11299 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE ST~LRT DEPTH GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 11255.0 11262 0 11262 0 11262 0 11262 0 11262 0 11299 5 5.06 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR RE~LL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~AY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): STOP DEPTH 11867 5 11874 5 11874 5 11874 5 11874 5 11874 5 11912 0 19-JAN-99 INSITE 3.2 (UP3) / ISC 5.46 MEMORY 11912.0 11299.0 11912.0 88.9 94.8 TOOL NUMBER P1217GRV4 P1217GRV4 6.130 6.1 BAi~ADRI L 10.50 58.0 9.3 3.2 .O5O MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .031 .050 .040 .0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 5 API 4 1 RPX MWD 5 OHMM 4 1 RPS MWD 5 OHMM 4 1 RPM MWD 5 OHMM 4 1 RPD MWD 5 OHMM 4 1 ROP MWD 5 FT/H 4 1 FET MWD 5 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 51.1 Name Min Max Mean DEPT 11255 11912 11583.5 GR 50.37 124.6 79.3218 RPX 3.44 1767.87 48.7061 RPS 4.48 2000 188.13 RPM 5.14 2000 167.482 RPD 6.68 2000 222.562 ROP 1 1925 84.3589 FET 0.88 23.41 3.47763 First Last Nsam Reading Reading 1315 11255 11912 1226 11255 11867.5 1226 11262 11874.5 1226 11262 11874.5 1226 11262 11874.5 1226 11262 11874.5 1226 11299.5 11912 1226 11262 11874.5 First Reading For Entire File .......... 11255 Last Reading For Entire File ........... 11912 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMNLARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 11868 0 11875 0 11875 0 11875 0 11875 0 11875 0 11912 5 5.06 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY STOP DEPTH 14029 5 14036 5 14036 5 14036 5 14036 5 14036 5 14073 0 26-JAN-99 INSITE 3.2 (UP3) / ISC 5.46 MEMORY 14073.0 11912 . 0 14073.0 82.5 94.0 TOOL NUMBER P1202GRV4 EWR4 $ ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPEP~ATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 P1202GRV4 6.130 6.1 BA_RADRIL-N 10.50 56.0 9.0 13781 2.8 .05O .030 .040 .060 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 API 4 1 68 4 2 RPX MWD 6 OHMM 4 1 68 8 3 RPS MWD 6 OHMM 4 1 68 12 4 RPM MWD 6 OHMM 4 1 68 16 5 RPD MWD 6 OHMM 4 1 68 20 6 ROP MWD 6 FT/H 4 1 68 24 7 FET MWD 6 HOUR 4 1 68 28 8 62.3 First Name Min Max Mean Nsam Reading Last Reading DEPT 11868 14073 12970.5 4411 GR 44.89 198.89 85.789 4324 RPX 1.71 1828.57 34.9157 4324 RPS 3.1 1922.87 90.3168 4324 RPM 4 2000 97.1121 4324 RPD 5.09 2000 87.9979 4324 ROP 2.04 2570.5 64.0364 4322 FET 0.41 32.35 2.40186 4324 11868 11868 11875 11875 11875 11875 11912.5 11875 14073 14029.5 14036.5 14036.5 14036.5 14036.5 14073 14036.5 First Reading For Entire File .......... 11868 Last Reading For Entire File ........... 14073 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NTJMBER: 8 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: FILE SUMMARY .5000 6 VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX GR RAT $ 10506 5 10506 5 10506 5 10506 5 10506 5 10507 0 10525 5 STOP DEPTH 11957 5 11957 5 11957 5 11957 5 11957 5 11957 5 12026 5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 5.06 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA tLAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEILATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined 26-JAN-99 INSITE 3.2 (UP3) / ISC 5.46 MEMORY 14073 . 0 11912.0 14073.0 82.5 94.0 TOOL NUMBER P1202GRV4 P1202GRV4 6.130 6.1 BAR_ADRIL-N 10.50 56.0 9.0 13781 2.8 .O5O .030 .040 .060 62.3 .0 Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD 6 FT/H 4 1 68 4 2 GR MAD 6 API 4 1 68 8 3 RPX MAD 6 OHMM 4 1 68 12 4 RPS MAD 6 OHMM 4 1 68 16 5 RPM MAD 6 OHMM 4 1 68 20 6 RPD MAD 6 OHMM 4 1 68 24 7 FET MAD 6 HOUR 4 1 68 28 8 Name DEPT RAT GR RPX RPS RPM RPD FET Min 10506.5 20 27 43 52 0 O5 0 05 1 89 2 87 16 58 First Max Mean Nsam Reading 12026.5 11266.5 3041 10506.5 3304.69 413.906 3003 10525.5 168.25 95.8399 2902 10507 430.84 8.49836 2903 10506.5 2000 31.1173 2903 10506.5 2000 82.5464 2903 10506.5 2000 73.1231 2903 10506.5 228.85 101.099 2903 10506.5 Last Reading 12026 5 12026 5 11957 5 11957 5 11957 5 11957 5 11957 5 11957 5 First Reading For Entire File .......... 10506.5 Last Reading For Entire File ........... 12026.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/04/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 99/04/21 Origin ................... STS Reel Name ................ IINK~OWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File