The URL can be used to link to this page

Home My WebLink About191-021ORIGINATED TRANSMITTAL DATE: ALASKA E-LINE SERVICES TRANSMITTAL #: 5592 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 5592 2M-25 50103201520000 Perf Record 3-Aug-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 lorna.c.collins@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 191-021 T40800 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.26 12:39:54 -08'00' 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 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 7445'feet None feet true vertical 6393' feet None feet Effective Depth measured 7116'feet 6841'feet true vertical 6099 feet 5860'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)3-1/2" L-80 6910' 5920' Packers and SSSV (type, measured and true vertical depth)6841' 5860' 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: 3153'2776' Burst Collapse Production 3138' 4225' Casing 2786' 6431' 3165' 7487' 3118' 115'Conductor Surface Production 16" 9-5/8" 76' measured TVD 7" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 191-021 50-103-20152-01-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025586 Kuparuk River Field/ Kuparuk Oil Pool KRU 2M-25 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 115' N/A 325-302 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: HES TNT SSSV: None adam Klem adam.klem@conocophillips.com (907) 263-4529 RWO/CTD Engineer 7088-7100', 7120-7154' 6074-6085, 6103-6133' 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 11:51 am, Aug 05, 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: 2025.08.04 15:26:50-08'00' Foxit PDF Editor Version: 13.1.6 Adam Klem JJL 8/12/25 RBDMS JSB 080825 DSR-9/10/25 Page 1/19 2M-25 Report Printed: 8/4/2025 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) 6/14/2025 12:00 6/15/2025 00:00 12.00 MIRU, MOVE MOB P Moveing F/1C T/2M-25 Spot Camp, Pits, and Shop on 2M-25 0.0 0.0 6/15/2025 00:00 6/15/2025 04:30 4.50 MIRU, MOVE MOB P Cont. to move sub F/ 1C to 2.1 miles from 2M. 0.0 0.0 6/15/2025 04:30 6/15/2025 07:30 3.00 MIRU, MOVE MOB T Sub fell through road 2.1 miles from 2M. Place dunnage under sub wheels and set mats under sub. Repeat until sub out of hole. 0.0 0.0 6/15/2025 07:30 6/15/2025 09:30 2.00 MIRU, MOVE MOB T While backing sub back onto matting boards front of rig fell through road. Place dunage under axles, and compress until front of rig out of the hole. 0.0 0.0 6/15/2025 09:30 6/15/2025 10:30 1.00 MIRU, MOVE MOB T Back sub down rig mats to 4 corners. Spot sub to allow for traffic to pass. 0.0 0.0 6/15/2025 10:30 6/16/2025 00:00 13.50 MIRU, MOVE MOB T Attempt to move rig .5 mile, Leap frog mats to 2M pad. Estamated time to 2M from now, is 36 hrs. 0.0 0.0 6/16/2025 00:00 6/17/2025 00:00 24.00 MIRU, MOVE MOB T Attempt to move rig .5 mile, Leap frog mats to 2M pad. Estamated time to 2M from now, is 30 hrs. 0.0 0.0 6/17/2025 00:00 6/18/2025 00:00 24.00 MIRU, MOVE MOB T Continue to move rig .5 mile, Leap frog mats to 2M pad. Estamated time to 2M from now, is 23.59 hrs. The AOGCC has been notified for the delay on the BOP Testing on 2M-25 W/ no issue Arrived on Location @ 11:59 PM 0.0 0.0 6/18/2025 00:00 6/18/2025 06:00 6.00 MIRU, MOVE RURD P Spread pit liner and plywood around wellhead. Hang tree in cellar. Spot in sub base Get com's up, needed support to get. Spot pits, start working on rig acceptance checklist Place berming around rig. 0.0 0.0 6/18/2025 06:00 6/18/2025 09:00 3.00 MIRU, MOVE RURD P PJSM, raise derrick, hook up inner connects, work on rig acceptance check list, bring on 9.0 PPG brine, rig up lines to kill well 0.0 0.0 6/18/2025 09:00 6/18/2025 11:00 2.00 MIRU, WELCTL RURD P Check TBG/IA and OA pressures 50/400/280 PSI, obtain RKB's, rig up lines to kill well, check line up, finish off loading 9.0 PPG brine to pits G/L = 27.95', LLDS = 26.72', ULDS = 24.80' 0.0 0.0 6/18/2025 11:00 6/18/2025 11:45 0.75 MIRU, WELCTL RURD P Blow air thru lines, flood lines to tiger tank, test lines to 250 low and 2500 high 0.0 0.0 6/18/2025 11:45 6/18/2025 12:30 0.75 MIRU, WELCTL KLWL P PJSM on circulating 9.0 PPG brine ands killing well TBG PSI at 400, IA PSI at 400 Bleed off gas cap IA down to 100 PSI, TBG down to 300 PSI 0.0 0.0 6/18/2025 12:30 6/18/2025 13:30 1.00 MIRU, WELCTL KLWL P Pump 30 BBL deep clean pill, chase with 130 BBLS (2X tubing volume) 9.0 PPG brine, at 3 BPM 1000 PSI, 2.5 BPM 850 PSI, have 80 -100% loss rate Shut down, shut in well TBG and IA PSI at 0 Reduce brine in pits to 8.8 PPG IA climb back to 350 PSI TBG on a vac 0.0 0.0 6/18/2025 13:30 6/18/2025 15:00 1.50 MIRU, WELCTL COND P Reduce 9.0 PPG to 8.8 PPG 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/7/2025 Page 2/19 2M-25 Report Printed: 8/4/2025 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) 6/18/2025 15:00 6/18/2025 17:00 2.00 MIRU, WELCTL KLWL P Pump 8.8 PPG brine at 2 BPM 570 PSI, 8.8 PPG turn corner 788 PSI at 2 BPM, 3 BPM 1180 PSI ICP 1360 PSI FCP, pump 259 BBLS Discuss options, decide to cut brine back to 8.6 PPG 0.0 0.0 6/18/2025 17:00 6/18/2025 22:00 5.00 MIRU, WELCTL KLWL P Montior pressure, tubing at 50 PSI, bleed off pressure come back to 50, increase brine weight to 8.9 - PPG Bull Head 70 BBls Down Tubing W/ no returns on IA w/ 0 Pres on IA Shut Down Monitor well Tubing 30 mins No Flow Fill up tubing take 2 bbls Line up IA and Pump Down IA @ @ 3 BBls min W/ 600 psi W/ returns Throu-Tubing one full circ Returns Back 8.9 Clean fluids 0.0 0.0 6/18/2025 22:00 6/18/2025 23:00 1.00 MIRU, WELCTL OWFF P Flow check, one hour, tubing and IA at zero 0.0 0.0 6/18/2025 23:00 6/19/2025 00:00 1.00 MIRU, WHDBOP PRTS P Set BPV w/ FMC and Test F/ below @ 3 bbls min 500 psi rolling test All Good 0.0 0.0 6/19/2025 00:00 6/19/2025 05:00 5.00 MIRU, WHDBOP NUND P Blow Down All lines and N/D FMC Tree,N/U BOP 0.0 0.0 6/19/2025 05:00 6/19/2025 07:45 2.75 MIRU, WHDBOP RURD P Rig up to test BOP, purge air from system Try to obtain shell test, trouble shoot leak Fill IA with 8.9 PPG brine take 13 BBLS, pressure up on BOP, observe fluid coming out IA, confirm blanking plug leaking by 0.0 0.0 6/19/2025 07:45 6/19/2025 09:00 1.25 MIRU, WHDBOP RURD P Drain BOP stack, pick up LH acme test joint, pull FMC slip over blanking plug, one seal had small cut, and ball seat had trash under it Change out blanking plug Set blanking plug, fill up stack with water, purge air from system obtain good shell test 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/7/2025 Page 3/19 2M-25 Report Printed: 8/4/2025 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) 6/19/2025 09:00 6/19/2025 15:00 6.00 MIRU, WHDBOP BOPE P All test to 250 PSI low 2,500 PSI for 5 minutes each test charted. Test annular preventer with 3 1/2" and 7" test joint.Test 4" Demco kill , choke valves 1 to 14 , 3.5" x 5 1/2" UVBR and lower 7" solid body, blind rams , auto/manual IBOP , HCR kill/choke valve , manual kill/choke valve, HT38 dart/FOSV, 3 1/2" EUE FOSV. Test remote and hydraulic chokes to 1,500 PSI and observed pressure drop when opening. Accumulator drawdown: ISP = 3100 PSI PSI after functioning = 1600 PSI 200 PSI rec = 13 seconds Full system recovery = 187 seconds 4 bottles back up average = 2050 PSI Bottle pre-charge average = 1100 PSI Closing times: Annular = 23 seconds, UPR = 6 seconds, Blind rams = 6 seconds, LPR = 6 seconds, Choke HCR = 1 second, Kill HCR = 1 second Test all gas alarms, PVT gain/loss, Flow paddle Witness waived by AOGCC Sean Sullivan @ 16:00 HRS on 6-18-25 Fill hole with 13 BBLS at 12:30 0.0 0.0 6/19/2025 15:00 6/19/2025 16:30 1.50 MIRU, WHDBOP RURD P Rig down testing equipment, blow down lines Pull blanking plug, pull BPV, change elevators to 3 1/2" DP 0.0 0.0 6/19/2025 16:30 6/19/2025 17:15 0.75 COMPZN, RPCOMP PULL P Make up BHA #1, 2 13/16" spear, stab into hanger, set down 10K, BOLDS, pull hanger to floor, hanger off seat at 75K, pull to 130K on hook, free travel at 110K Fill hole with 13 BBLS 0.0 6,845.0 6/19/2025 17:15 6/19/2025 21:15 4.00 COMPZN, RPCOMP CIRC P Circulate at 2 BPM 660 PSI, establish loss rate at 15 BPH, cicrulate surface to surface Shut Monitor Well 1 Hr Static loss rate 12 bbls hr 6,845.0 6,845.0 6/19/2025 21:15 6/19/2025 22:45 1.50 COMPZN, RPCOMP PULL P POOH L/D 3 1/2" tubing w/ control line L/D 22 jt 6,845.0 6,163.0 6/19/2025 22:45 6/20/2025 00:00 1.25 COMPZN, RPCOMP PULL P M/U Drift Run W/ 6" String Mill RIH t/ 21.5' No Go POOH L/D String Mill R/U to Continue POOH L/D 3 1/2" Tubing W/ Control Line/Attempt To Get SSSV out of Hole. 6,163.0 6,189.0 6/20/2025 00:00 6/20/2025 02:30 2.50 COMPZN, RPCOMP PULL T Continue POOH L/D 3 1/2" Tubing W/ Control Line/AttemptTo Get SSSV out of Hole. No Go SSSV @5' Below Well Head Jts 3 1/2" L/D 55 Tot Jts Free @ Well Head Recover 20 SS bands 6,189.0 5,114.0 6/20/2025 02:30 6/20/2025 06:00 3.50 COMPZN, RPCOMP OTHR T Discuss with town engineer decision was made to run IBP w/ AK E-line Call out AK E line and IBP Static loss rate at 12 BPH 5,114.0 5,114.0 6/20/2025 06:00 6/20/2025 06:45 0.75 COMPZN, RPCOMP RURD T Install 3 1/2" DP elevators, bring up Baker on/off tool to floor Prep rig floor and pipe shed to pick up drill pipe 5,114.0 5,114.0 Rig: NABORS 7ES RIG RELEASE DATE 7/7/2025 Page 4/19 2M-25 Report Printed: 8/4/2025 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) 6/20/2025 06:45 6/20/2025 08:30 1.75 COMPZN, RPCOMP BHAH T Make up BHA #3 Attempt to drift well head with 4 3/4" OD tools Tag up with 4 1/2" OD tubing collar, work past top of 7" , tag up at 29' in with 4 3/4" OD L-10 tool Trip in from 5,114' to 5,142' POOH L/D BHA 5,114.0 5,114.0 6/20/2025 08:30 6/20/2025 09:00 0.50 COMPZN, RPCOMP ELNE T Rig up AK E- line Make up Baker IBP 5,114.0 5,114.0 6/20/2025 09:00 6/20/2025 10:45 1.75 COMPZN, RPCOMP ELNE T Trip in hole with Eline to 5,117' Tag up multi able times unable to make it past Tagging up at tubing cut or tight spot that was just below cut due to pulling seals out of PBR and tubing wasn't cut 5,114.0 5,114.0 6/20/2025 10:45 6/20/2025 12:00 1.25 COMPZN, RPCOMP ELNE T POOH with Eline, rig down and have Eline stand by Start loading shed with 2 7/8" tubing 5,114.0 5,114.0 6/20/2025 12:00 6/20/2025 16:00 4.00 COMPZN, RPCOMP RURD T Load and process 61 of 2 7/8" EUE, releize plan for 2 7/8" would not work, kick out 2 7/8", load and process 60 JTS of 3 1/2" IBT tubing, mobilize BHA tools from Dead Horse, contact and mobilize Well tech cutter from Dead Horse Rig up to run 3 1/2" tubing Static loss rate at 12-14 BPH 5,114.0 5,114.0 6/20/2025 16:00 6/20/2025 19:00 3.00 COMPZN, RPCOMP RURD T Load and process 60 JTS of 3 1/2" IBT tubing, mobilize BHA tools from Dead Horse, contact and mobilize Well tech cutter from Dead Horse 5,114.0 5,114.0 6/20/2025 19:00 6/20/2025 22:00 3.00 COMPZN, RPCOMP PULD T M/U 3 1/2" IBT P/U 56 Jts and Tag up @ 6859' and P/U Space out T/ 6834 . 5,114.0 6,834.0 6/20/2025 22:00 6/21/2025 00:00 2.00 COMPZN, RPCOMP ELOG T R/U Ak-E-line and M/U Well Tech Cutter / RIH Tag @ 6838' POOH T/ 6822' and set tool 6,834.0 6,834.0 6/21/2025 00:00 6/21/2025 02:00 2.00 COMPZN, RPCOMP ELOG P Continue RIH Tag @ 6838' POOH T/ 6822' and set tool Cut 3 1/2" Tubing POOH Well Teck Hand Confirm Cut is Made. 6,834.0 6,834.0 6/21/2025 02:00 6/21/2025 03:00 1.00 COMPZN, RPCOMP PULD T POOH L/D 7 Jts 3 1/2" IBT Bottom Cut @ 6649' 6,834.0 6,649.0 6/21/2025 03:00 6/21/2025 06:00 3.00 COMPZN, RPCOMP ELOG T R/U AK-Eline W/ Baker 2 1/2" IBP RIH, tag up at 6,653' POOH with IBP Stand back Eline, send AK Eline employees to KIC to get some sleep due to being timed out Look at CCL logs from the IBP run yesterday, Well Tech cutter run and IBP runs today, confirm tagging up at same spot as yesterdays IBP run, the 1.80" restriction in tubing above the PBR 6,649.0 6,649.0 6/21/2025 06:00 6/21/2025 07:30 1.50 COMPZN, RPCOMP PULD T Trip in hole F/6,649' T/6,859 with 3 1/2" IBT tubing Tag up at 6,859', set down 5K 95K UP 70K DN Pick up to 6,832' 6,649.0 6,832.0 Rig: NABORS 7ES RIG RELEASE DATE 7/7/2025 Page 5/19 2M-25 Report Printed: 8/4/2025 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) 6/21/2025 07:30 6/21/2025 14:00 6.50 COMPZN, RPCOMP WAIT T Perform rig maintenance on rig equipment Look at suction line in pit 4, service rig, change dies in iron roughneck, general house keeping Static loss rate at 9 BPH Call AK Eline to location at 13:00 HRS 6,832.0 6,832.0 6/21/2025 14:00 6/21/2025 15:00 1.00 COMPZN, RPCOMP ELOG T Rig up AK Eline, make up Well Tech 2 3/8" cutter, test tools 6,832.0 6,832.0 6/21/2025 15:00 6/21/2025 16:30 1.50 COMPZN, RPCOMP ELOG T RIH with Eline to 6,840', tag up same spot in 3 1/2" tubing as before, pick up correlate collar depth at 6,482' CCL Make cut at 6,500', first full joint below GLM #3 6,832.0 6,832.0 6/21/2025 16:30 6/21/2025 17:45 1.25 COMPZN, RPCOMP ELOG T POOH with Eline, lay down cutter, stand Eline back Cutter showed max OD sweep of 3.77" 6,832.0 6,832.0 6/21/2025 17:45 6/21/2025 18:45 1.00 COMPZN, RPCOMP PULD T POOH with 3 1/2" IBT tubing F/6,832' T/6,321' 6,832.0 6,321.0 6/21/2025 18:45 6/22/2025 00:00 5.25 COMPZN, RPCOMP ELOG T Rig up Eline, RIH with CCL and 2 1/8" drift to 6475' w/ no issue ' POOH with Eline M/U Baker 2 1/2" IBP RIH and Set IBP @ 6375' COE w/ WLM, top of fish neck at 6,368' 6,231.0 6,231.0 6/22/2025 00:00 6/22/2025 00:30 0.50 COMPZN, RPCOMP ELOG T POOH L/D Running Tool and R/D AK Eline 6,321.0 6,321.0 6/22/2025 00:30 6/22/2025 01:30 1.00 COMPZN, RPCOMP MPSP T Test 7" IBP T/1000 PSI F/ 10 mins All good L/D 1 Jt to 6,290' 6,321.0 6,290.0 6/22/2025 01:30 6/22/2025 10:15 8.75 COMPZN, RPCOMP OTHR P R/U to dump sand Dump 50' of sand on top of IBP - Dump 23l sacks of sand and 7 busted ones Let sand fall one hour 6,290.0 6,290.0 6/22/2025 10:15 6/22/2025 11:30 1.25 COMPZN, RPCOMP TRIP P POOH stand back IBT tubing F/6,290' T/4,786' 6,290.0 4,786.0 6/22/2025 11:30 6/22/2025 12:15 0.75 COMPZN, RPCOMP BHAH P Make up BHA #5 Baker L10 on/off tool 4.51" OD 4,786.0 4,786.0 6/22/2025 12:15 6/22/2025 14:15 2.00 COMPZN, RPCOMP TRIP P Trip in hole F/4,786' T/6,294' Tag up 25' in with 4.50" OD L10 tool in well head 94K UP 63K DN 4,786.0 6,294.0 6/22/2025 14:15 6/22/2025 14:15 COMPZN, RPCOMP FISH P Slack off F/6,294' T/6308' Tag top of sand with 5K DN, make up top drive Release from L10 tool at 1,518.19' top of 3 1/2" tubing 6,294.0 1,518.0 6/22/2025 14:15 6/22/2025 16:30 2.25 COMPZN, RPCOMP TRIP P POOH F/1,518' to surface L/D 15 joints to pipe shed, stand back 11 stands of 3 1/2" IBT tubing 1,518.0 0.0 6/22/2025 16:30 6/22/2025 18:00 1.50 COMPZN, RPCOMP BHAH P L/D BHA #5, Make up BHA #6 3 3/8" IBP T/78' FIll pipe with fresh water and apply grease cap 0.0 78.0 6/22/2025 18:00 6/22/2025 20:00 2.00 COMPZN, RPCOMP TRIP P Trip in hole F/78' T/1010' 78.0 1,007.0 6/22/2025 20:00 6/22/2025 22:00 2.00 COMPZN, RPCOMP PACK P Set IBP Plug @ 1007' T.O.F.N. 1014.27' COE and Release 1,007.0 1,007.0 Rig: NABORS 7ES RIG RELEASE DATE 7/7/2025 Page 6/19 2M-25 Report Printed: 8/4/2025 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) 6/22/2025 22:00 6/23/2025 00:00 2.00 COMPZN, RPCOMP TRIP P POOH L/D 3 1/2" Tubing and Running tool 1,007.0 0.0 6/23/2025 00:00 6/23/2025 01:00 1.00 COMPZN, RPCOMP MPSP P Test IBP Plug T/2500 PSI 10 mins All good 0.0 0.0 6/23/2025 01:00 6/23/2025 02:30 1.50 COMPZN, RPCOMP NUND P Blow Down Prep T/ N/D BOP and N/D BOP set Stack Back on Stub 0.0 0.0 6/23/2025 02:30 6/23/2025 06:45 4.25 COMPZN, RPCOMP CUTP P Rig up Cameron to grow 7" casing, first grow showed 240K up force Grow 7" casing 2.21' Spear casing pull to 175K on hook, set slips Cut 7" casing off 10.25" above casing head, install pack off 0.0 0.0 6/23/2025 06:45 6/23/2025 09:30 2.75 COMPZN, RPCOMP NUND P Clean ring groove and nipple up 11" 3K x 13 5/8" 5K DSA Nipple up BOP 0.0 0.0 6/23/2025 09:30 6/23/2025 10:45 1.25 COMPZN, RPCOMP SEQP P Pressure test BOP flange break 250/2500 5 minutes each 0.0 0.0 6/23/2025 10:45 6/23/2025 11:15 0.50 COMPZN, RPCOMP BHAH P P/U BHA # 8. 6.125" tandum string reamer to drift first 700' casing 0.0 42.0 6/23/2025 11:15 6/23/2025 11:45 0.50 COMPZN, RPCOMP PULD P Continue in hole on singles to 796', PU45K, SOW-45K. Smooth trip in 42.0 796.0 6/23/2025 11:45 6/23/2025 12:15 0.50 COMPZN, RPCOMP TRIP P Trip out of well BHA #8, drift. PUW=45K 796.0 42.0 6/23/2025 12:15 6/23/2025 13:00 0.75 COMPZN, RPCOMP BHAH P Lay down BHA #8, P/U BHA #9 IBP retrival tool 42.0 8.0 6/23/2025 13:00 6/23/2025 13:30 0.50 COMPZN, RPCOMP SVRG P Grease draw works and iron roughneck 8.0 8.0 6/23/2025 13:30 6/23/2025 14:15 0.75 COMPZN, RPCOMP PULD P Trip in hole BHA #9 to retrieve packer, Unable to locate packer. Concerned might be going along side IBP 8.0 1,014.0 6/23/2025 14:15 6/23/2025 15:30 1.25 COMPZN, RPCOMP FISH P Unable to locate packer. Concerned might be going along side IBP 1,014.0 1,014.0 6/23/2025 15:30 6/23/2025 16:00 0.50 COMPZN, RPCOMP TRIP P Trip out of well to reconfigure BHA, PUW=48K 1,014.0 8.0 6/23/2025 16:00 6/23/2025 16:30 0.50 COMPZN, RPCOMP BHAH P Lay down BHA #9, P/U BHA #10 IBP retrieval tool with centeralizer. 8.0 16.0 6/23/2025 16:30 6/23/2025 17:00 0.50 COMPZN, RPCOMP TRIP P Trip in hole BHA #10 to retrieve IBP, PUW=48K, SOW=48K 16.0 1,014.0 6/23/2025 17:00 6/23/2025 18:00 1.00 COMPZN, RPCOMP FISH P 1014' No firm set down. Single in hole. Ease down to 1504', Set down 4K. PUW=55K, After tag 56 - 57K. Drag 1 - 2K 1,014.0 1,504.0 6/23/2025 18:00 6/23/2025 19:00 1.00 COMPZN, RPCOMP TRIP P Trip out F/1,504' to surface 1,504.0 0.0 6/23/2025 19:00 6/23/2025 19:45 0.75 COMPZN, RPCOMP BHAH P Lay down BHA #10 IBP retriving tool and IBP 0.0 0.0 6/23/2025 19:45 6/23/2025 20:45 1.00 COMPZN, RPCOMP BHAH P Make up BHA #11 L10 Trip in to 1,513', tag up on top of 3 1/2" tubing fish 55K UP 52K DN Set down 10K latch up L10 retriving tool, pick up 102K break over weight 98K up confirm latched up on fish 0.0 6,299.0 6/23/2025 20:45 6/23/2025 21:45 1.00 COMPZN, RPCOMP TRIP P POOH F/6,299' T/4,790' 73K UP 6,299.0 4,790.0 6/23/2025 21:45 6/23/2025 22:30 0.75 COMPZN, RPCOMP RURD P L/D BHA #11 L10 tool Rig up to lay down 3 1/2" tubing 4,790.0 4,790.0 6/23/2025 22:30 6/23/2025 22:45 0.25 COMPZN, RPCOMP PULL P POOH laying down 3 1/2" EUE completion F/4,790' T/4,695' 4,790.0 4,695.0 Rig: NABORS 7ES RIG RELEASE DATE 7/7/2025 Page 7/19 2M-25 Report Printed: 8/4/2025 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) 6/23/2025 22:45 6/23/2025 23:45 1.00 COMPZN, RPCOMP CIRC P Make up top drive, circulate bottoms up due to fluid not draining in tubing Pressure up to 800 PSI, pressure drop off, CBU @ 5 BPM 370 PSI Blow down top drive 4,695.0 4,695.0 6/23/2025 23:45 6/24/2025 00:00 0.25 COMPZN, RPCOMP PULL P POOH laying down 3 1/2" completion F/4,695' T/4,255' 68K UP 4,695.0 4,255.0 6/24/2025 00:00 6/24/2025 05:00 5.00 COMPZN, RPCOMP PULL P POOH laying down 3 1/2" completion F/4,255' to surface Lay down 151 joints, 6 GLM, 1 SSSV, cut JT = 22.00' 4,255.0 0.0 6/24/2025 05:00 6/24/2025 05:30 0.50 COMPZN, RPCOMP RURD P Rig down 3 1/2" TBG equipment 0.0 0.0 6/24/2025 05:30 6/24/2025 06:45 1.25 COMPZN, RPCOMP BHAH P Make up BHA #12 to 235' 0.0 235.0 6/24/2025 06:45 6/24/2025 11:15 4.50 COMPZN, RPCOMP PULD P Trip in the hole from pipe shed F/235' T/5,300' 125K UP 90K DN 235.0 5,300.0 6/24/2025 11:15 6/24/2025 12:45 1.50 COMPZN, RPCOMP SLPC P Slip and cut drilling line, service rig 5,300.0 5,300.0 6/24/2025 12:45 6/24/2025 13:30 0.75 COMPZN, RPCOMP CIRC P CBU @ 210 GPM @ 688 PSI. 5,300.0 5,300.0 6/24/2025 13:30 6/24/2025 16:00 2.50 COMPZN, RPCOMP TRIP P POOH F/ 5300' to 235'. 5,300.0 235.0 6/24/2025 16:00 6/24/2025 16:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA F/ 235' to surface. 235.0 0.0 6/24/2025 16:30 6/24/2025 17:00 0.50 COMPZN, WELLPR CLEN P Clean and clear rig floor. Load next BHA in pipe shed. 0.0 0.0 6/24/2025 17:00 6/24/2025 17:30 0.50 COMPZN, WELLPR SVRG P Service rig grease draw works, iron roughneck and crown. 0.0 0.0 6/24/2025 17:30 6/24/2025 19:00 1.50 COMPZN, WELLPR BHAH P P/U BHA # 13, G-lock BHA F/ surface to 52' 0.0 52.0 6/24/2025 19:00 6/24/2025 19:45 0.75 COMPZN, WELLPR MPSP P TIH F/52' T/928' w/ drill pipe. PUW 48K / SOW 46K Set G-lock per Baler rep @ 928' COE, Set down 25K, Pull 20K over. Release off G-lock plug. 52.0 928.0 6/24/2025 19:45 6/24/2025 20:30 0.75 COMPZN, WELLPR MPSP P TOOH with G-lock retieval tool F/928 T/Surface 928.0 0.0 6/24/2025 20:30 6/24/2025 21:00 0.50 COMPZN, WELLPR MPSP P PT CSG against G-lock plug to 2500 psi for charted 10 minutes. Good solid test. BD lines and pump out stack. 0.0 0.0 6/24/2025 21:00 6/24/2025 23:30 2.50 COMPZN, WELLPR NUND P ND BOP stack and pulled riser. Rack back the stack. Remove the DSA. Install tubing spool and torque bolts. 0.0 0.0 6/24/2025 23:30 6/25/2025 00:00 0.50 COMPZN, WELLPR MPSP P PT void to 3000 psi for 10 minutes: good test. 0.0 0.0 6/25/2025 00:00 6/25/2025 02:00 2.00 COMPZN, WELLPR NUND P NU BOP stack and install DSA. Install riser. 0.0 0.0 6/25/2025 02:00 6/25/2025 03:00 1.00 COMPZN, WELLPR BOPE P PT break on stack to 250psi low/2500 psi high for 5 min charted. Good test. 0.0 0.0 6/25/2025 03:00 6/25/2025 03:30 0.50 COMPZN, WELLPR MPSP P Pull test plug and install 6 3/8" ID wear ring. 0.0 0.0 6/25/2025 03:30 6/25/2025 04:15 0.75 COMPZN, WELLPR TRIP P RIH w/ G-lock retrieval tool, F/ Surface to 900'. 0.0 900.0 6/25/2025 04:15 6/25/2025 04:30 0.25 COMPZN, WELLPR MPSP P Engauge, and release G-lock plug, allow elements to relax for 10 min. 900.0 900.0 Rig: NABORS 7ES RIG RELEASE DATE 7/7/2025 Page 8/19 2M-25 Report Printed: 8/4/2025 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) 6/25/2025 04:30 6/25/2025 06:00 1.50 COMPZN, WELLPR TRIP P RIH w/ G-lock F/ 900' to 3200'. 900.0 3,200.0 6/25/2025 06:00 6/25/2025 06:15 0.25 COMPZN, WELLPR MPSP P Set G-lock @ 3200'. 3,200.0 3,200.0 6/25/2025 06:15 6/25/2025 07:00 0.75 COMPZN, WELLPR TRIP P POOH w/ Drill pipe, and G-lock running tool. 3,200.0 0.0 6/25/2025 07:00 6/25/2025 08:00 1.00 COMPZN, WELLPR PRTS P R/U and attempt to pressure test 7" CSG from surface to 3200' to 3750 PSI. When bringing pressure up to 3750 psi pressure dropped off, pressure increase of 160 PSI observed in OA. Attempt to pressure up 7" to check for pressure response in OA. Observed imediate pressure response in OA @ 200 PSI. 0.0 0.0 6/25/2025 08:00 6/25/2025 09:30 1.50 COMPZN, WELLPR OTHR P Rig up OA to vent pressure. Line up and vent OA to tiger tank. 8 BBLS bled from OA, with 8 BBL drop in 7" (monitoring 7" on trip tank). 0.0 0.0 6/25/2025 09:30 6/25/2025 10:00 0.50 COMPZN, WELLPR BHAH P M/U BHA # 14, TST packer w/ G-lock retrieval head on bottom. 0.0 241.0 6/25/2025 10:00 6/25/2025 10:30 0.50 COMPZN, WELLPR TRIP P RIH F/ 241' to 719', set test packer, and 241.0 719.0 6/25/2025 10:30 6/25/2025 11:00 0.50 COMPZN, WELLPR PRTS P Purge lines, close upper pipe rams and test above test packer to 500 PSI. No response in OA, good test. Release test packer. 719.0 719.0 6/25/2025 11:00 6/25/2025 11:30 0.50 COMPZN, WELLPR TRIP P RIH F/ 719' to 1485' COE. 719.0 1,485.0 6/25/2025 11:30 6/25/2025 13:30 2.00 COMPZN, WELLPR PRTS P Set test packer @ 1485' COE. Attempt to test bellow test packer against RBP set @ 3200'. Observe imediate pressure response on OA. Close upper pipe rams, and line up to test above test packer to 2500 PSI, pressure held. Move Test packer down to 1583'. Attempt to test below test packer instant pressure response in OA. Line up and test above test packer, held pressure. Move test packer down to 1675'. Set test packer, attempt to test below test packer, observe imediate OA response. Line up and test from above test packer. Pressure held above test packer. Release test packer. 1,485.0 1,675.0 6/25/2025 13:30 6/25/2025 14:30 1.00 COMPZN, WELLPR TRIP P RIH F/ 1675' to 3091'. 1,675.0 3,091.0 Rig: NABORS 7ES RIG RELEASE DATE 7/7/2025 Page 9/19 2M-25 Report Printed: 8/4/2025 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) 6/25/2025 14:30 6/25/2025 18:00 3.50 COMPZN, WELLPR PRTS P Circulate string volume. Set test packer @ 3091' COE. Set test packer, and attempt to test below test packer. Observed OA pressure response. Line up and test above test packer to 2500 PSI and hold for 10 min: GOOD. Release test packer, move test packer to 3171' COE, set, and attempt to test below test packer: GOOD. Pull packer up to 3154', and test to 2500 PSI: GOOD. Pull packer up to 3134', set test packer. Attempt to test: Observe OA pressure response. Release test packer and move down 10' to 3,144'. Set test packer and attempt to test below: Observe response in OA. Close pipe rams and pressure up above test packer: GOOD. Move test packer to 3150 and set. Attempt to test from below. Observe flow up annulus. Close pipe rams and attempt to test form above: Observe pressure in OA. 3,091.0 3,150.0 6/25/2025 18:00 6/25/2025 19:00 1.00 COMPZN, WELLPR DISP P Relax test packer. Rack back one stand, and set test packer @ 3120', Open up OA and verify circulation through CSG leak for future freeze protect @ 3 BPM @ 225 PSI. Pumped a total of 18 bbls through hole in casing, taking diesel returns from OA. 3,150.0 3,120.0 6/25/2025 19:00 6/25/2025 19:30 0.50 COMPZN, WELLPR TRIP P TIH from 3120 to 4000' with G-lock plug PUW 98K/ SOW80K 3,120.0 4,000.0 6/25/2025 19:30 6/26/2025 00:00 4.50 COMPZN, WELLPR MPSP P Set G-lock plug at 4000' COE. Stand back 2 stands. Dump 20 sixty pound sacks (50') of sand on top to G-lock plug, one sack per 20 minutes. 4,000.0 3,890.0 6/26/2025 00:00 6/26/2025 04:00 4.00 COMPZN, WELLPR MPSP P Continue dumping 20 sixty pound sacks (50') of sand on top to G-lock plug, one sack per 20 minutes. Let sand settle for 1 hour and tag top of sand. 3,890.0 3,890.0 6/26/2025 04:00 6/26/2025 06:00 2.00 COMPZN, WELLPR TRIP P POOH standing back DP in the derrick. 3,890.0 0.0 6/26/2025 06:00 6/26/2025 06:30 0.50 COMPZN, WELLPR BHAH P L/D BHA, clean and clear the rig floor. 0.0 0.0 6/26/2025 06:30 6/26/2025 07:30 1.00 COMPZN, WELLPR ELOG P R/U AK E-line. AK E-line P/U tools, and function test at surface. 0.0 0.0 6/26/2025 07:30 6/26/2025 11:30 4.00 COMPZN, WELLPR ELOG P AK E-line RIH logging to 3940', POOH logging F/ 3940' to surface. 0.0 0.0 6/26/2025 11:30 6/26/2025 12:00 0.50 COMPZN, WELLPR ELOG P R/D AK E-line. 0.0 0.0 6/26/2025 12:00 6/26/2025 12:30 0.50 COMPZN, WELLPR BOPE P Function test BOPE: Ann close in 25 sec., open 24 sec., blinds close 5 sec., open 5 sec., lower pipe rams close 5 sec., open 5 sec., upper pipe rams close 5 sec., open 5 sec., choke close 1 sec., open 1 sec., kill close 1 sec., open 1 sec. 0.0 0.0 6/26/2025 12:30 6/26/2025 17:00 4.50 COMPZN, WELLPR MPSP P Send town CBL. P/U test packer BHA #15 trip in hole to 3133'. PT casing shoe. Test between test packer and G- plug to 1000 psi for 15 mins. Good test. 0.0 3,133.0 6/26/2025 17:00 6/26/2025 19:00 2.00 COMPZN, WELLPR TRIP P TOOH F/3133' T/ BHA. 3,133.0 0.0 6/26/2025 19:00 6/26/2025 19:30 0.50 COMPZN, WELLPR BHAH P LD test packer BHA #15 and PU Multi string cutter BHA #16. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/7/2025 Page 10/19 2M-25 Report Printed: 8/4/2025 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) 6/26/2025 19:30 6/26/2025 20:45 1.25 COMPZN, WELLPR TRIP P Trip in hole F/39.36' T/3164' 80K PUW/ 70K SOW 0.0 3,164.0 6/26/2025 20:45 6/26/2025 21:30 0.75 COMPZN, WELLPR DISP P Condition fluid in pits, add 4 drums of Hydrahib 3,164.0 3,164.0 6/26/2025 21:30 6/26/2025 22:00 0.50 COMPZN, WELLPR DISP P Displace well over to 35 vis brine w/Hydrahib at 4.5 bpm / 715 psi 3,164.0 3,164.0 6/26/2025 22:00 6/26/2025 22:30 0.50 COMPZN, WELLPR CPBO P Cut 7" casing at 3162'. 60 RPM, 1.8K TQ off, 2.6-3K TQ ON, 5 BPM / 850 psi. Good indication of cut. 3,164.0 3,162.0 6/26/2025 22:30 6/26/2025 23:30 1.00 COMPZN, WELLPR DISP P SI UPR Pump down DP and out OA to Displace fluid in 7x9-5/8 annulus to 35 vis brine w/Hydrahib. Pumped 110 bbls. 3,162.0 3,162.0 6/26/2025 23:30 6/27/2025 00:00 0.50 COMPZN, WELLPR TRIP P TOOH F/3162 T/1700' PUW 78K 3,162.0 1,700.0 6/27/2025 00:00 6/27/2025 00:45 0.75 COMPZN, WELLPR TRIP P TOOH F/1700 T/0' PUW 78K 1,700.0 0.0 6/27/2025 00:45 6/27/2025 01:00 0.25 COMPZN, WELLPR BHAH P LD BHA #16 Multi string cutter. 0.0 0.0 6/27/2025 01:00 6/27/2025 02:15 1.25 COMPZN, WELLPR OWFF P One hour no flow 0.0 0.0 6/27/2025 02:15 6/27/2025 05:15 3.00 COMPZN, WELLPR NUND P ND BOP stack and stand it back. ND tubing spool and remove PO. 0.0 0.0 6/27/2025 05:15 6/27/2025 07:00 1.75 COMPZN, WELLPR NUND P Change out DSA on BOP. Stab BOP on CSG spool. N/U BOPs. Fill stack and hydro test. 0.0 0.0 6/27/2025 07:00 6/27/2025 07:30 0.50 COMPZN, WELLPR RURD P Rig up 7" handling equipment on the rig floor. 0.0 0.0 6/27/2025 07:30 6/27/2025 08:00 0.50 COMPZN, WELLPR PULL P P/U CSG spear w/ pack off. RIH and stab into top of 7". Pull 7" to the floor @ 120 K PUWT. Lost 15K drag after pulling bottom of 7" into 9 5/8" Shoe. 105K PUWT. 0.0 3,136.0 6/27/2025 08:00 6/27/2025 08:45 0.75 COMPZN, WELLPR CIRC P Circulate bottoms up @ 210 GPM @ 75 PSI. 3,136.0 3,136.0 6/27/2025 08:45 6/27/2025 09:30 0.75 COMPZN, WELLPR BHAH P L/D Spear and top cut jont of 7". 3,136.0 3,136.0 6/27/2025 09:30 6/27/2025 12:30 3.00 COMPZN, WELLPR PULL P POOH L/D 7" CSG F/ 3136' to surface. 3,136.0 0.0 6/27/2025 12:30 6/27/2025 14:00 1.50 COMPZN, WELLPR BOPE P Set test plug. Fill stack, R/U test equipment, and purge lines. Test flange break between stack and CSG spool to 250 low/ 2500 PSI high 5 min each. Drain stack, pull test plug. 0.0 0.0 6/27/2025 14:00 6/27/2025 14:30 0.50 COMPZN, WELLPR OTHR P Set wear bushing. 0.0 0.0 6/27/2025 14:30 6/27/2025 15:30 1.00 COMPZN, WELLPR BHAH P Load Drill collars into pipe shed and strap. Bring BHA subs, and pieces to rig floor. Load jars and bumpers in pipe shed. 0.0 0.0 6/27/2025 15:30 6/27/2025 18:00 2.50 COMPZN, WELLPR BHAH P P/U Clean out/ Dress off BHA F/ Surface to 287'. 0.0 287.0 6/27/2025 18:00 6/27/2025 19:00 1.00 COMPZN, WELLPR TRIP P RIH F/ 287' to 374' Tag tight spot and set down 20K, PU clean, Work string mills a little with no success. 287.0 374.0 6/27/2025 19:00 6/27/2025 20:00 1.00 COMPZN, WELLPR TRIP P POOH F/374' T/287' 374.0 287.0 6/27/2025 20:00 6/27/2025 22:00 2.00 COMPZN, WELLPR BHAH P LD BHA #18 w/8.5" sting mill and 8.5" dress off shoe and PU BHA #19 w/8- 3/8" string mill and bull nose. 287.0 263.0 Rig: NABORS 7ES RIG RELEASE DATE 7/7/2025 Page 11/19 2M-25 Report Printed: 8/4/2025 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) 6/27/2025 22:00 6/28/2025 00:00 2.00 COMPZN, WELLPR REAM P TIH with 8-3/8" string mill. Ream tight spots form 370' to 420' three times. Also saw tight spot 1589'-1614' did not rotate, just 3K to 5K to push through it.Continue in the hole to 1680' at midnight. 263.0 1,680.0 6/28/2025 00:00 6/28/2025 01:00 1.00 COMPZN, WELLPR REAM P TIH from 1680 to 3162' Tight spot at 1589'-1614' no rotate, just 3K to 5K to push through it. 1,680.0 3,162.0 6/28/2025 01:00 6/28/2025 02:15 1.25 COMPZN, WELLPR TRIP P TOOH with 8-3/8" string mill to PU 8- 1/2" string mills. 3,162.0 263.0 6/28/2025 02:15 6/28/2025 02:45 0.50 COMPZN, WELLPR BHAH P LD BHA #19 w/8-3/8" string mill and bull nose. 263.0 0.0 6/28/2025 02:45 6/28/2025 03:30 0.75 COMPZN, WELLPR BHAH P PU BHA #20 w/8-1/2" string mill and bull nose. 0.0 278.0 6/28/2025 03:30 6/28/2025 04:00 0.50 COMPZN, WELLPR TRIP P RIH F/ 278' to 370' 278.0 370.0 6/28/2025 04:00 6/28/2025 06:00 2.00 COMPZN, WELLPR REAM P Rotate through tight spot F/ 370' to 420'. ROT 60 RPM @4-5K TQ. Pumping @ 174 GPM @ 75 PSI. Rotated through tight spot 6 times. P/U and drift through tight spots 4 times w/o rotation. 370.0 440.0 6/28/2025 06:00 6/28/2025 07:00 1.00 COMPZN, WELLPR TRIP P Cont. RIH F/ 420' to 3144'. Encountered minot tight spots @ 1570', and from 1607'- 1620'. Drift thorugh each 3 times, no rotation needed. PUWT: 92 K SOWT: 65 K 440.0 3,120.0 6/28/2025 07:00 6/28/2025 07:30 0.50 COMPZN, WELLPR WASH P Wash F/ 3120' to top of 7" stump @ 3162'. Pumping @ 2.5 BBL/ min @ 100 PSI. Observe 50 PSI pressure spike when bullnose entered top of 7" stump. Set down 15K to confirm, P/U and repeat tag one more time. PUWT: 92 K SOWT: 65 K 3,120.0 3,162.0 6/28/2025 07:30 6/28/2025 09:00 1.50 COMPZN, WELLPR CIRC P Pump around 30 BBL High vis sweep @ 440 GPM @ 650 PSI. Once sweep cleared open hole section pull BHA into shoe. Observe formation over the shakers. Circulate one more bottoms up until hole clean. 3,162.0 3,140.0 6/28/2025 09:00 6/28/2025 09:15 0.25 COMPZN, WELLPR OWFF P OWFF 10 min: STATIC. 3,140.0 3,140.0 6/28/2025 09:15 6/28/2025 10:30 1.25 COMPZN, WELLPR TRIP P POOH F/ 3140' to 278'. 3,140.0 278.0 6/28/2025 10:30 6/28/2025 11:00 0.50 COMPZN, WELLPR BHAH P L/D BHA F/ 278' to surface. 278.0 0.0 6/28/2025 11:00 6/28/2025 12:30 1.50 COMPZN, WELLPR BHAH P P/U BHA # 20, dress off BHA. 0.0 287.0 6/28/2025 12:30 6/28/2025 14:00 1.50 COMPZN, WELLPR TRIP P RIH F/ 287' to 3140' PUWT: 97 K SOWT: 75 K 287.0 3,140.0 Rig: NABORS 7ES RIG RELEASE DATE 7/7/2025 Page 12/19 2M-25 Report Printed: 8/4/2025 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) 6/28/2025 14:00 6/28/2025 14:45 0.75 COMPZN, WELLPR MILL P Ream down @ 20 RPM 3 K TQ, pumping 168 GPM @ 180 PSI. Tag top of stump @ 3161.5'. Set down 17K to confirm (15K wt below jars), P/U 3', and dress off top of 7" stump to 3162.8'. 60 RPM @ 4.5K- 6K TQ 168 GPM @ 200 PSI 10-15 K WOB. 3,140.0 3,162.8 6/28/2025 14:45 6/28/2025 15:45 1.00 COMPZN, WELLPR CIRC P Circulate around High vis sweep. Pump swep @ 4 BBL/ MIN @ 200 PSI, once sweep exiting BHA, and back into CSG Pull BHA into CSG and increased to 420 GPM @ 700 PSI. Sweep brought back 50% increase in cuttings over the shakers. Circulate 2x after sweep until well cleaned up. 3,162.8 3,140.0 6/28/2025 15:45 6/28/2025 16:00 0.25 COMPZN, WELLPR OWFF P OWFF 10 MIN: STATIC. Blow down top drive. 3,140.0 3,140.0 6/28/2025 16:00 6/28/2025 17:00 1.00 COMPZN, WELLPR TRIP P POOH F/ 3140' T/287'. 3,140.0 287.0 6/28/2025 17:00 6/28/2025 20:30 3.50 COMPZN, WELLPR BHAH P POOH L/D Dress off BHA #21 F/ 287' T/ surface, L/D drill collars. Clean magnets and boot basket. Clean and clear rig floor. 287.0 0.0 6/28/2025 20:30 6/28/2025 21:00 0.50 COMPZN, WELLPR RURD P Pull wear bushing 0.0 0.0 6/28/2025 21:00 6/28/2025 21:45 0.75 COMPZN, WELLPR RURD P R/U GBR 0.0 0.0 6/28/2025 21:45 6/29/2025 00:00 2.25 COMPZN, WELLPR PUTB P PU and RIH with 7" HYD 563, F/surface T/1645' 0.0 1,645.0 6/29/2025 00:00 6/29/2025 02:00 2.00 COMPZN, WELLPR PUTB P PU and RIH with 7" HYD 563, F/1645' T/3165.7' 120K PUW/ 82K SOW Tag top of stump at 3163' and slide over stump set down 25K at 3165.5' Pull 50K over T/170K 1,645.0 3,165.5 6/29/2025 02:00 6/29/2025 04:30 2.50 COMPZN, WELLPR PRTS P RU headpin and PT CSG patch T/1500 psi for 5 min, increase to 2600 psi/5 min to set packer, bleed to 500 psi for 5 min, bleed off to 0 psi. PT to 2500 psi for 10 min. good test. RD CMT hose and head pin. 3,165.5 0.0 6/29/2025 04:30 6/29/2025 06:00 1.50 COMPZN, WELLPR RURD P R/U HAL CMNT on the rig floor. 0.0 0.0 6/29/2025 06:00 6/29/2025 08:00 2.00 COMPZN, WELLPR CIRC P Line up mud pumps on 7" CSG, and pressure up to open ES Cementer. Stage up pumps to 3100 PSI, observe ES cementer open. CBU x2. PJSM w/ HAL CMNT, and rig crew. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/7/2025 Page 13/19 2M-25 Report Printed: 8/4/2025 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) 6/29/2025 08:00 6/29/2025 10:15 2.25 COMPZN, WELLPR CMNT P HAL CMNT pressure test lines to 4K for 5 min. Line up and pump 10 BBL fresh water spacer w/ red dye. Pump 141 BBLS 15.8 class G cement, CMNT wet @ 0838. Drop plug, and HAL wash up behind plug w/ 10 bbls of fresh water. Line up on rig pumps and chase CMNT. Caught CMNT after 2 BBLS pumped @ 240 PSI ICP @ 3 BBL/MIN. After 848 STKS (48 BBLS pumped) pumped observed diminishing returns. Decrease flow rate to 2 BBL/MIN, after 70 BBLS Pumped observed slight returns. Continue to pump until plug bumped @ 1840 STKS (FCP 1200 PSI). Bump plug and pressure up to 2500 PSI and hold for 5 min. Bleed pressure off of 7", and verify ES Cementer closed by flow checking at CMNT head. Cement in place @ 1015. No cement returned to surface. 0.0 0.0 6/29/2025 10:15 6/29/2025 12:15 2.00 COMPZN, WELLPR RURD T Consult town for plan forward. Flush lines, and clear stack. Blow down lines, and R/D HAL CMNT head. 0.0 0.0 6/29/2025 12:15 6/29/2025 15:00 2.75 COMPZN, WELLPR NUND T N/D BOP and attempt to pull CSG slips. Unable to get slips out. N/U BOP. 0.0 0.0 6/29/2025 15:00 6/29/2025 18:00 3.00 COMPZN, WELLPR ELOG T R/U AK E-line and RIH w/ CBL log to 3060' to surface. Observe drop in amplitude @ 360' w/ Amplitude indicating good CMNT @ 1500'. 0.0 0.0 6/29/2025 18:00 6/29/2025 21:30 3.50 COMPZN, WELLPR OWFF T Open IA and OA and wait for slow stream of red die spacer and dark gray gritty water to stop flowing before splitting the stack. 0.0 0.0 6/29/2025 21:30 6/29/2025 23:30 2.00 COMPZN, WELLPR CLEN T Clean cement off slips in wellhead. Clean cement out of BOP stack up to test spools. Flush with water. NU stack to wait on cement. 0.0 0.0 6/29/2025 23:30 6/30/2025 00:00 0.50 COMPZN, WELLPR WOC P Wait on cement until 06:00am. 0.0 0.0 6/30/2025 00:00 6/30/2025 06:00 6.00 COMPZN, WELLPR WOC P Wait on cement until 06:00am. 0.0 0.0 6/30/2025 06:00 6/30/2025 07:00 1.00 COMPZN, WELLPR NUND P N/D BOP and P/U off of CSG spool 0.0 0.0 6/30/2025 07:00 6/30/2025 08:30 1.50 COMPZN, WELLPR NUND P FMC R/U Wach's cutter, and cut 7" CSG. Pull 7" cut joint 32.24' to the rig floor, and L/D. Rack back BOP on BOP pedestal. 0.0 0.0 6/30/2025 08:30 6/30/2025 10:00 1.50 COMPZN, WELLPR NUND P Clean and inspect casing spool bowl. FMC install pack off. N/U DSA, and tubing spool. Test pack off to 3000 PSI for 10 min: GOOD. 0.0 0.0 6/30/2025 10:00 6/30/2025 11:00 1.00 COMPZN, WELLPR NUND P N/U BOP to tubing spool. Secure stack w/ turnbuckles. Install low pressure riser. 0.0 0.0 6/30/2025 11:00 6/30/2025 14:30 3.50 COMPZN, WELLPR OTHR P Install BOP test plug. P/U stack flushing tool, and Jet BOP. Open lower pipe rams and check for cement. Rotate Kill line. Fill stack. Tighten doors, and kill line connection to swivel block. 0.0 0.0 6/30/2025 14:30 6/30/2025 15:00 0.50 COMPZN, WELLPR BOPE P R/U test equipment, flush stack, and test break between BOP and tubing spool to 250 low 2500 PSI high. 0.0 0.0 6/30/2025 15:00 6/30/2025 16:00 1.00 COMPZN, WELLPR OTHR P Pull test plug, and set wear bushing. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/7/2025 Page 14/19 2M-25 Report Printed: 8/4/2025 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) 6/30/2025 16:00 6/30/2025 17:30 1.50 COMPZN, WELLPR BHAH P P/U BHA # 22 F/ Surface to 261'. 0.0 261.0 6/30/2025 17:30 6/30/2025 19:00 1.50 COMPZN, WELLPR TRIP P RIH F/ 261' to 2973'. Tag stringer @ 2973' set down 10K. PUWT: 75 SOWT: 74 261.0 2,973.0 6/30/2025 19:00 6/30/2025 19:30 0.50 COMPZN, WELLPR REAM P P/U and ream through stringers f/ 2973' to 3038'. Tag top of green CMNT @ 3038'. Tag top of hard CMNT @ 3062 PUWT: 75 K ROTWT: 74 K SOWT: 74 K 210 GPM @ 461 PSI 60 RPM @ 2-4K TQ 5-8 K WOB. 2,973.0 3,062.0 6/30/2025 19:30 6/30/2025 20:00 0.50 COMPZN, WELLPR COCF P Tag firm CMNT @ 3050' Clean out CMNT F/ 3050' to 3091'. PUWT: 75 K ROTWT: 74 K SOWT: 74 K 210 GPM @ 509 PSI 65 RPM @ K TQ WOB: 10 K 3,062.0 3,091.0 6/30/2025 20:00 6/30/2025 20:30 0.50 COMPZN, WELLPR CIRC P Circulate Bottoms up 380 @ GPM @ 1000 PSI. Drilled CMNT, and chunks of ES Cementer plug returned to surface. 3,091.0 3,091.0 6/30/2025 20:30 6/30/2025 22:30 2.00 COMPZN, WELLPR REAM P Cont to wash and ream F/ 3091' to 3947'. Intermittent CMNT stringers. Tag top of sand @ 3947' ROTWT: 74 K 210 GPM @ 560 PSI. WOB 0-5K 3,091.0 3,947.0 6/30/2025 22:30 6/30/2025 23:00 0.50 COMPZN, WELLPR OTHR P Dry drill top of sand 3947 to 3952' 15 RPM @ 500 Ft/lbs TQ 3-5 K WOB 3,947.0 3,952.0 6/30/2025 23:00 7/1/2025 00:00 1.00 COMPZN, WELLPR CIRC P P/U 20' and circulate around high vis sweep. @ 300 GPM @ 1000 PSI. 3,952.0 3,932.0 7/1/2025 00:00 7/1/2025 02:00 2.00 COMPZN, WELLPR TRIP P TOOH w/drill out BHA.#22 3,932.0 261.0 7/1/2025 02:00 7/1/2025 02:30 0.50 COMPZN, WELLPR BHAH P LD Drill Out BHA #22 261.0 0.0 7/1/2025 02:30 7/1/2025 03:00 0.50 COMPZN, WELLPR SVRG P Grease top drive blocks and crown 0.0 0.0 7/1/2025 03:00 7/1/2025 03:30 0.50 COMPZN, WELLPR BHAH P PU RCJB BHA #23 0.0 8.0 Rig: NABORS 7ES RIG RELEASE DATE 7/7/2025 Page 15/19 2M-25 Report Printed: 8/4/2025 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) 7/1/2025 03:30 7/1/2025 05:30 2.00 COMPZN, WELLPR TRIP P TIH F/8 T/3130' PUW 85K / SOW 65K Tagged 10K DN and PUW 15K over Wash down with 10-20K bobbles 8.0 3,948.0 7/1/2025 05:30 7/1/2025 06:00 0.50 COMPZN, WELLPR WASH P Wash down F/3948' T/3961' 4BPM at 1060 psi, 60 rpm, 3K TQ OFF, 4K TQ ON 3,948.0 3,961.0 7/1/2025 06:00 7/1/2025 06:45 0.75 COMPZN, WELLPR CIRC P Circulate 20 bbl high vis sweep all the way around at 5 BPM @ 2050psi. 3,961.0 3,955.0 7/1/2025 06:45 7/1/2025 08:15 1.50 COMPZN, WELLPR TRIP P TOOH F/3955 T/8' UWT 100K / SOW 70K 3,955.0 8.0 7/1/2025 08:15 7/1/2025 08:45 0.50 COMPZN, WELLPR BHAH P LD BHA #8 and clean RCJB 8.0 0.0 7/1/2025 08:45 7/1/2025 09:30 0.75 COMPZN, WELLPR PRTS P PT 7" CSG F/3955' T/surface 2500 psi charted for 30 minutes-Good test 0.0 0.0 7/1/2025 09:30 7/1/2025 10:30 1.00 COMPZN, WELLPR BHAH P PU BHA #24 RCJB with string mills. 0.0 273.0 7/1/2025 10:30 7/1/2025 12:00 1.50 COMPZN, WELLPR TRIP P TIH F/273' T/3955' UWT 110K / SOW 74K 273.0 3,955.0 7/1/2025 12:00 7/1/2025 12:45 0.75 COMPZN, WELLPR CIRC P Circulate and condition mud. unable to pump down DP. 3,955.0 3,955.0 7/1/2025 12:45 7/1/2025 13:15 0.50 COMPZN, WELLPR WASH P Washing while RIH tag top of sand at 3961'. Dry mioll to 3964'. TQ OFF = 3.9K TQ ON = 4.5K UWT 110K/ SOW 74K 3,955.0 3,961.0 7/1/2025 13:15 7/1/2025 14:45 1.50 COMPZN, WELLPR TRIP P TOOH F/3964' T/273' UWT 110K 3,961.0 273.0 7/1/2025 14:45 7/1/2025 16:00 1.25 COMPZN, WELLPR BHAH P LD BHA #24 Clean magnets and remove sand blockage from RCJB. 273.0 0.0 7/1/2025 16:00 7/1/2025 16:45 0.75 COMPZN, WELLPR BHAH P PU BHA #25 RCJB 0.0 275.0 7/1/2025 16:45 7/1/2025 18:30 1.75 COMPZN, WELLPR TRIP P TIH w/ BHA #25 F/275 T/3947' drpop ball activate RCJB. PUW=95K SOW=80K 275.0 3,974.0 7/1/2025 18:30 7/1/2025 19:00 0.50 COMPZN, WELLPR WASH P Wash down F/3974' T/3980' 3,974.0 3,980.0 7/1/2025 19:00 7/1/2025 19:30 0.50 COMPZN, WELLPR CIRC P Pumped 20 BBL sweep chased W/8.9# 5 BPM at 1800 PSI. 3,980.0 3,980.0 7/1/2025 19:30 7/1/2025 21:30 2.00 COMPZN, WELLPR TRIP P TOOH F/3980' T/275' 3,980.0 275.0 7/1/2025 21:30 7/1/2025 22:00 0.50 COMPZN, WELLPR BHAH P Break out BHA and rack collars break out BHA. inspect RCJB nominal returns. less than 1/4 cup of metal in basket. 275.0 0.0 7/1/2025 22:00 7/1/2025 22:30 0.50 COMPZN, WELLPR RURD P Unload and Load BHA in pipe shed. to MU retrieving head for G-Lock. 0.0 7/1/2025 22:30 7/1/2025 23:00 0.50 COMPZN, WELLPR BHAH P MU G-plug retrieving head 0.0 12.0 7/1/2025 23:00 7/2/2025 00:00 1.00 COMPZN, WELLPR TRIP P TIH F/12' T/3977' KU and establish circulation. washed down to 3999' 12.0 3,999.0 7/2/2025 00:00 7/2/2025 00:30 0.50 COMPZN, WELLPR CIRC P Circulate sweep SxS @ 7 BPM 830 PSI 3,999.0 3,999.0 7/2/2025 00:30 7/2/2025 01:15 0.75 COMPZN, WELLPR MPSP P Latch G-plug at 3999' pulled 20K over, equalized plug. observed well for flow for 10 minutes. released G-Plug. verified plug was released. 3,999.0 3,999.0 7/2/2025 01:15 7/2/2025 03:00 1.75 COMPZN, WELLPR TRIP P TOOH F/3999' PUW=104K T/12' 3,999.0 12.0 7/2/2025 03:00 7/2/2025 03:30 0.50 COMPZN, WELLPR BHAH P LD retrieving head and G-Plug. 12.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/7/2025 Page 16/19 2M-25 Report Printed: 8/4/2025 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) 7/2/2025 03:30 7/2/2025 03:45 0.25 COMPZN, WELLPR BHAH P MU IBP pulling tool 0.0 8.0 7/2/2025 03:45 7/2/2025 06:00 2.25 COMPZN, WELLPR TRIP P TIH F/8.04' T/6235' PUW=150K SOW=85K. Kelly up and wash down to 6328' top of IBP at 6363' 8.0 6,363.0 7/2/2025 06:00 7/2/2025 07:45 1.75 COMPZN, WELLPR CIRC P Circulate 20 bbl 300 vis sweep SxS at 7 BPM at 1040 psi UWT 150K/SOW 85K 6,363.0 6,299.0 7/2/2025 07:45 7/2/2025 08:30 0.75 COMPZN, WELLPR MPSP P Set down 10K on top of IBP, PU 8K to release IBP. Space out tool joint and close annular and let IBP relax. 6,299.0 6,299.0 7/2/2025 08:30 7/2/2025 11:00 2.50 COMPZN, WELLPR OWFF P Circulate and contion mud at 3 BPM down DP and through gas buster. Loss rate at 3BPM = 11.5 BPM. OWFF for 30 minutes. 6,299.0 6,299.0 7/2/2025 11:00 7/2/2025 14:00 3.00 COMPZN, WELLPR TRIP P TOOH F/6299' T/8' UWT 150K / SOW 85K 6,363.0 8.0 7/2/2025 14:00 7/2/2025 15:00 1.00 COMPZN, WELLPR BHAH P LD BHA #27 IBP assembly. 8.0 0.0 7/2/2025 15:00 7/2/2025 15:30 0.50 COMPZN, WELLPR SVRG P Service rig. 0.0 0.0 7/2/2025 15:30 7/2/2025 17:00 1.50 COMPZN, WELLPR RGRP T Remove upper/lower jaws on iron roughneck to C/O HYD hose. Repair retaining pin for lower jaw assmebly. 0.0 0.0 7/2/2025 17:00 7/2/2025 18:00 1.00 COMPZN, WELLPR BHAH P PU BHA #28 Overshot 0.0 226.0 7/2/2025 18:00 7/2/2025 20:00 2.00 COMPZN, WELLPR TRIP P TIH w/BHA F/226.73' T/6450' PUW=162K SOW=92K 226.0 6,450.0 7/2/2025 20:00 7/2/2025 20:15 0.25 COMPZN, WELLPR FISH P Establish fishing parameters 2 BPM 230 PSI PUW=162K SOW=92K Engage TOF at 6523' Set down 15K PU PUW=165K 6,450.0 6,523.0 7/2/2025 20:15 7/2/2025 20:30 0.25 COMPZN, WELLPR CIRC P Circulate DP vol. 5 BPM at 350 PSI. 6,515.0 6,515.0 7/2/2025 20:30 7/2/2025 23:30 3.00 COMPZN, WELLPR TRIP P TOOH W/fish F/6515' T/226.73' 6,515.0 226.7 7/2/2025 23:30 7/3/2025 00:00 0.50 COMPZN, WELLPR BHAH P Rack back collars and LD BHA, fish recovered. Start laying down fish. 226.7 7/3/2025 00:00 7/3/2025 01:00 1.00 COMPZN, WELLPR PULL P Continue laying down fish. recovered in order9.25' cut joint, 6 full joints, pup, GLM, pup 2 full joints, pup, GLM, pup and cut joint 8.95' OAL. Cut joint had hole punch indications along teh length of joint, cut was flaired with protruding piece of metal. 323.09' New TOF at 6844.09' (7ES RKB) 7/3/2025 01:00 7/3/2025 01:15 0.25 COMPZN, WELLPR RURD P RD from laying down tiubing get floor set up to run DP. clean floor and establish loss rate. 0.0 0.0 7/3/2025 01:15 7/3/2025 01:45 0.50 COMPZN, WELLPR SVRG P Service top drive greased blak jak 0.0 0.0 7/3/2025 01:45 7/3/2025 02:15 0.50 COMPZN, WELLPR BHAH P MU BHA to recover remaining tubing 0.0 226.7 7/3/2025 02:15 7/3/2025 04:30 2.25 COMPZN, WELLPR TRIP P TIH F/226.73' T/6843.69' PUW=170K SOW=95K 226.7 6,843.7 7/3/2025 04:30 7/3/2025 05:00 0.50 COMPZN, WELLPR FISH P Establish fishing parameters. PR2 BPM at 220 PSI 30 RPM 7.8K ROT WT=125K rotate over stump to 6846' Set down 15K push down 11' to 6858' set down 15K. Lost down weight. PUH weight broke back at 195K New PUW=175K PUH to 6828' 6,843.7 6,828.0 Rig: NABORS 7ES RIG RELEASE DATE 7/7/2025 Page 17/19 2M-25 Report Printed: 8/4/2025 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) 7/3/2025 05:00 7/3/2025 06:45 1.75 COMPZN, WELLPR CIRC P Circ SxS 2BPM 200 PSI. 6,828.0 6,828.0 7/3/2025 06:45 7/3/2025 09:30 2.75 COMPZN, WELLPR TRIP P TOOH With BHA #29 and fish from cut down to seal assembly. 6,828.0 0.0 7/3/2025 09:30 7/3/2025 10:15 0.75 COMPZN, WELLPR BHAH P LD BHA #29 0.0 0.0 7/3/2025 10:15 7/3/2025 10:30 0.25 COMPZN, WELLPR RURD P Pull wear ring. 0.0 0.0 7/3/2025 10:30 7/3/2025 11:30 1.00 COMPZN, WELLPR RURD P PU test tools for BOPE test 0.0 0.0 7/3/2025 11:30 7/3/2025 16:00 4.50 COMPZN, WELLPR BOPE P All test to 250 PSI low 2,500 PSI for 5 minutes each test charted. Test annular preventer with 3 1/2" test joint.Test 4" Demco kill , choke valves 1 to 16 , 3.5" x 5 1/2" UVBR, blind rams , auto/manual IBOP , HCR kill/choke valve , manual kill/choke valve, HT38 dart/FOSV, 3 1/2" EUE FOSV. Test remote and hydraulic chokes to 1,500 PSI and observed pressure drop when opening. Accumulator drawdown: ISP = 3000 PSI PSI after functioning = 1500 PSI 200 PSI rec = 14 seconds Full system recovery = 173 seconds 5 bottles back up average = 2090 PSI Closing times: Annular = 22 seconds, UPR = 6 seconds, Blind rams = 6 seconds, LPR = 6 seconds, Choke HCR = 1 second, Kill HCR = 1 second Test all gas alarms, PVT gain/loss, Flow paddle Witness waived by AOGCC Guy Cook @ 13:27 HRS on 7-2-25 0.0 0.0 7/3/2025 16:00 7/3/2025 16:45 0.75 COMPZN, WELLPR RURD P RD from testing and RU to MU BHA. Blow down lines Pull test plug and set wear ring. 0.0 0.0 7/3/2025 16:45 7/3/2025 17:30 0.75 COMPZN, WELLPR SLPC P Slip and cut drilling line. 0.0 0.0 7/3/2025 17:30 7/3/2025 18:00 0.50 COMPZN, WELLPR SVRG P Service rig. 0.0 0.0 7/3/2025 18:00 7/3/2025 19:00 1.00 COMPZN, WELLPR BHAH P MU packer pulling BHA. 0.0 231.4 7/3/2025 19:00 7/3/2025 21:45 2.75 COMPZN, WELLPR TRIP P TIH F/231.42' T/6836' PUW=172K SOW=95K KU Establish fishing parameters 2BPM=260 PSI RIH to tag at 6889' 231.4 6,889.0 7/3/2025 21:45 7/4/2025 00:00 2.25 COMPZN, WELLPR FISH P Engage top of fish at 6889' set down 20K. PU to 225K Start jarring on packer. working up to 350K Cycled jars 50 times no movement Performed derrick inspection, Cycled jars 275K pulled 205K 30K over. Worked 13K RH TQ down to packer. Worked torque to packer 15 rotations. 6,889.0 6,890.0 7/4/2025 00:00 7/4/2025 00:15 0.25 COMPZN, WELLPR FISH P Continue to work torque to packer. Pulled 250K lost torque Pulled 350K TIH to 6897' packer moving down hole. PUW=175K-210K PUH to 6864' 6,864.0 6,850.0 Rig: NABORS 7ES RIG RELEASE DATE 7/7/2025 Page 18/19 2M-25 Report Printed: 8/4/2025 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) 7/4/2025 00:15 7/4/2025 02:00 1.75 COMPZN, WELLPR CIRC P Closed in pipe rams circulate SxS through gas buster 2 BPM 300 PSI. 6,850.0 6,850.0 7/4/2025 02:00 7/4/2025 02:30 0.50 COMPZN, WELLPR OWFF P OWFF for 30 minutes well static 6,850.0 6,850.0 7/4/2025 02:30 7/4/2025 04:00 1.50 COMPZN, WELLPR TRIP P RIH to 6900' PU to 6850' TOOH F/6850' T/5396' PUW=177K to 210K off bottom. Well not taking proper diplacement. 50% displacement for 5 stands 1.6-1.7 BBL's 6,900.0 6,523.0 7/4/2025 04:00 7/4/2025 04:30 0.50 COMPZN, WELLPR CIRC P Circulate BUS at 3BPM 450 psi OWFF static 6,523.0 6,523.0 7/4/2025 04:30 7/4/2025 08:00 3.50 COMPZN, WELLPR TRIP P TOOH F/6823' T/231' PUW 140K packer catching collars with 15K overpulls then dropping off. 6,823.0 231.0 7/4/2025 08:00 7/4/2025 08:45 0.75 COMPZN, WELLPR BHAH P LD BHA #30 spear assembly. Packer and tail pipe section. Fish length 41.71' 231.0 0.0 7/4/2025 08:45 7/4/2025 09:30 0.75 COMPZN, WELLPR BHAH P PU BHA #31 clean out assy. PUW 42K 0.0 291.0 7/4/2025 09:30 7/4/2025 12:00 2.50 COMPZN, WELLPR TRIP P TIH F/291 T/6800' UWT 170K/ SOW 90K 291.0 6,800.0 7/4/2025 12:00 7/4/2025 13:30 1.50 COMPZN, WELLPR REAM P Reaming in hole F/6800' T/6896' at 6 bpm/ 900 psi, 30 RPM, RWT 122K, FREE TQ 8.2K, 1-5K WOB, Make two passes at packer setting depth. RIH to 7113' and set down 10K on top of perfs. 6,800.0 7,113.0 7/4/2025 13:30 7/4/2025 14:00 0.50 COMPZN, WELLPR CIRC P Circ BUS at 6BPM/900psi. OWFF static 7,113.0 7,081.0 7/4/2025 14:00 7/4/2025 16:15 2.25 COMPZN, WELLPR TRIP P TOOH F/7081' T/290' UWT 175K 7,081.0 290.0 7/4/2025 16:15 7/4/2025 17:00 0.75 COMPZN, WELLPR BHAH P LD BHA #31 6.125" junk mill and string reamers. 290.0 0.0 7/4/2025 17:00 7/4/2025 18:30 1.50 COMPZN, WELLPR BHAH P MU 5-5/8" Clean out BHA 0.0 250.9 7/4/2025 18:30 7/4/2025 21:30 3.00 COMPZN, WELLPR TRIP P TIH W/BHA F/250.85' T/7054' KU PUW =180K SOW=97K secure well for proactive safety meeting. 250.9 7,054.0 7/4/2025 21:30 7/4/2025 22:00 0.50 COMPZN, WELLPR SFTY P Refocus safety on the holiday and getting close to going home. Crew hasn't worked together prior to this last few days and has reduced size. Stay focused on safety while at work, work as a team and we all go home as a team! 7,054.0 7,054.0 7/4/2025 22:00 7/4/2025 23:45 1.75 COMPZN, WELLPR REAM P Establish clean out parameters. 5 BPM 660 Wash and ream F/7054' to 7119' Rot at 60 RPM free tq.=8.2K 125K rot wt. Rotate down F/7100' T/7325' 7,054.0 7,325.0 7/4/2025 23:45 7/5/2025 00:00 0.25 COMPZN, WELLPR CIRC P Circulate sweep off bottom chase SxS 5 BPM reciprocate from 7325' to 7240'. Large amount of sand in returns. 7,325.0 7,325.0 7/5/2025 00:00 7/5/2025 00:30 0.50 COMPZN, WELLPR CIRC P Circulate sweep off bottom chase SxS 5 BPM reciprocate from 7325' to 7240'. Large amount of sand in returns. Increase PR to 7BPM at 1275 PSI 7,325.0 7,325.0 7/5/2025 00:30 7/5/2025 01:00 0.50 COMPZN, WELLPR OWFF P OWFF for 30 minutes. 7,325.0 7,325.0 7/5/2025 01:00 7/5/2025 04:00 3.00 COMPZN, WELLPR TRIP P TOOH F/7325' T/250.9' PUW=180K off bottom. 7,325.0 250.9 7/5/2025 04:00 7/5/2025 05:30 1.50 COMPZN, WELLPR BHAH P LD collars and BHA. 250.9 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/7/2025 Page 19/19 2M-25 Report Printed: 8/4/2025 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) 7/5/2025 05:30 7/5/2025 06:00 0.50 COMPZN, WELLPR BHAH P MU G-plug and test packer BHA #33. 0.0 34.2 7/5/2025 06:00 7/5/2025 08:30 2.50 COMPZN, WELLPR TRIP P TIH F/34' T/6900' UWT 165K/SOW 90K 34.2 6,900.0 7/5/2025 08:30 7/5/2025 10:15 1.75 COMPZN, WELLPR MPSP P PT casing. Atempt to set G-plug at 6900'. Just kept moving. Set G-plug at 6887 COE and test casing to 2500 for 5 min then ramp up to 3000 psi for 10 min. Good test. Release G-plug. 6,900.0 6,900.0 7/5/2025 10:15 7/5/2025 18:00 7.75 COMPZN, WELLPR PULD P LD DP F/6887 T/Surface. UWT 165K/SOW 90K 6,900.0 0.0 7/5/2025 18:00 7/5/2025 19:00 1.00 COMPZN, WELLPR RURD P Clear floor after laying down completion. RU to run tubing. load pipe shed with completion equipment. Verify tally and running order. 0.0 0.0 7/5/2025 19:00 7/5/2025 19:30 0.50 COMPZN, WELLPR SFTY P PJSM to run completion. Halliburton GBR Nabors and CPAI. 0.0 0.0 7/5/2025 19:30 7/6/2025 00:00 4.50 COMPZN, WELLPR PUTB P Start RIH with 3.5" HYD 563 completion per tally. F/surface to 4800' 0.0 7/6/2025 00:00 7/6/2025 02:00 2.00 COMPZN, WELLPR PUTB P Continue RIH with 3.5" Hyd 563 Completion F/4800 T/6909 PUW=98K SOW=68K 4,800.0 6,910.0 7/6/2025 02:00 7/6/2025 02:45 0.75 COMPZN, WELLPR THGR P Pump out BOP stack. MU TBG HGR and landing joint to string. Land hanger and RILDS. 6,909.0 6,910.0 7/6/2025 02:45 7/6/2025 03:00 0.25 COMPZN, WELLPR RURD P RU to circulate CI brine down IA taking returns up the tubing 0.0 0.0 7/6/2025 03:00 7/6/2025 04:00 1.00 COMPZN, WELLPR CIRC P Circulate down IA at 3.5 BPM 600 PSI taking returns up the tubing to the cuttings box. 0.0 0.0 7/6/2025 04:00 7/6/2025 10:00 6.00 COMPZN, WELLPR RURD P Bleed fluid off tubing RD hardline from landing joint. Open well for flow. 0.0 0.0 7/6/2025 10:00 7/6/2025 11:00 1.00 COMPZN, WELLPR CIRC P Circulate 60 bbls 9.1 ppg brine down tubing at 2.5 BPM 280 psi taking returns to tiger tank. 0.0 0.0 7/6/2025 11:00 7/6/2025 13:00 2.00 COMPZN, WELLPR PRTS P Drop ball and rod. press up tubing to 3600 psi to set the Packer per Halliburton rep. Charted test for 30 minutes Good test. Bled tubing to 1500 psi and Pressure test IA to 3000 psi for 30 minutes. test good. Dump tubing pressure and shear SOV. 0.0 0.0 7/6/2025 13:00 7/6/2025 13:30 0.50 COMPZN, WELLPR MPSP P Install BPV and PT from below to 1000 psi for 10 min. Good test. 0.0 0.0 7/6/2025 13:30 7/6/2025 18:30 5.00 COMPZN, WELLPR RURD P Between wells maintenance. 0.0 0.0 7/6/2025 18:30 7/6/2025 20:30 2.00 COMPZN, WHDBOP NUND P ND BOP's NU tree and adapter. Install BPV test dart. Test adapter to 5000 PSI for 10 minutes 0.0 0.0 7/6/2025 20:30 7/6/2025 23:00 2.50 DEMOB, MOVE FRZP P RU to freeze protect. Freeze protected to 2000' in tubing and IA. 3BPM FCP=750PSI. U-tube well for 1 hour. 0.0 0.0 7/6/2025 23:00 7/7/2025 00:00 1.00 DEMOB, MOVE DMOB P Demobilize from 2M-25. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/7/2025 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,340.0 2M-25 7/19/2025 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added perforations 2M-25 8/3/2025 Jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: Prod CSG tally has calculation errors; corrected shows set depth 7487', questionable depth ?? 7/23/2012 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 39.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.76 35.0 3,152.6 2,775.7 36.00 J-55 BTC Production 7 6.28 26.7 3,165.0 2,785.9 26.00 L-80 HYD 563 PRODUCTION 7 6.28 3,162.0 7,487.1 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.2 Set Depth … 6,910.0 String Max No… 3 1/2 Set Depth … 5,919.7 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection HYD563 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) 33.2 33.2 0.10 Hanger 7.000 FMC hanger GEN IV hanger H BPV profile, 3 1/2" EUE lift threads FMC FMC Gen 4 2.900 2,971.5 2,626.2 34.16 Mandrel – GAS LIFT 5.972 3 1/2" x 1.5" Camco MMG GLM SN 25489-08 Target 2975' SLB MMG 2.992 5,191.1 4,465.1 32.54 Mandrel – GAS LIFT 5.972 3 1/2" x 1.5" Camco MMG GLM SN 25489-07 Target 5175' SLB MMG 2.992 6,108.8 5,242.3 32.44 Mandrel – GAS LIFT 5.972 3 1/2" x 1.5" Camco MMG GLM SN 25584-02 Target 6100' SLB MMG 2.992 6,782.4 5,810.2 31.88 Mandrel – GAS LIFT 5.972 3 1/2" x 1.5" Camco MMG GLM SN 25584-01 SLB MMG 2.992 6,840.8 5,860.0 31.03 PACKER 7.000 HES TNT packer SN 0005072351-2 Target 6829' HES TNT 2.992 6,898.7 5,909.9 30.07 Nipple - XN 4.250 XN nipple SN 0005217403 Target 6882' HES 2.81" XN 2.750 6,909.5 5,919.2 30.02 Wireline Guide 4.509 WLEG HES WLEG 2.992 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) 2,971.5 2,626.2 34.16 1 GAS LIFT DMY RK 1 1/2 7/18/2025 SLB 5,191.1 4,465.1 32.54 2 DMY RK 1 1/2 7/5/2025 SLB 6,108.8 5,242.3 32.44 3 DMY RK 1 1/2 7/5/2025 SLB 6,782.4 5,810.2 31.88 4 DMY RK 1 1/2 7/5/2025 SLB Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,088.0 7,100.0 6,074.4 6,084.9 A-4, 2M-25 8/3/2025 6.0 APERF 2.5" GEO GUN LOADED 12' W/ 11.5 GRAM RAZOR XDP CHARGES, 6 SPF, 60° PHASE 7,120.0 7,134.0 6,102.5 6,114.8 A-3, 2M-25 9/23/1991 4.0 IPERF SWS 4 1/2" Csg Gun;180 deg. phasing; Oriented 64 deg. CCW 7,134.0 7,154.0 6,114.8 6,132.5 A-3, 2M-25 9/23/1991 4.0 IPERF SWS 4 1/2" Csg Gun; 180 deg. phasing; Oriented 68 deg. CCW Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 341.0 3,152.0 341.0 2,775.1 Primary – Full Bore Lead 191 bbl 12.1 ppg Arctic Set IIITail 146 bbl ... Circ. 2 csg. Volumes @ 9.5 BPM. Drop btm plug pump 10 bbls. Test lines to 3500 psi. Pump 70 bbls H2O. 191 bbl Lead- AS III 12.1 ppg. Dropbtm plug #2 mix & pump 146 bbls tail slurry. Drop top plug, pump 10 bbls w/ Dowell, switch to rig pup, pump 19 bbls mud. Pressure went to 1000 and locked up. Pressure up to 2000. Switch to Dowell pump. Pressure up to 3270 psi. Cemnet would not move assume flash set in csg. Cement pumped out of casing 122 bbls. 69 bbls Lead in casing plus 146 bbls tail. **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=9.625 35.0 150.0 35.0 150.0 Grouting / Top -Up Top Job 20 bbl Arctic Set I ... R.U. & do Top Job. Pump 10 bbls water followed by 20 bbls Class G AS I. Good cement. Returns to surface. **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=9.625 6,350.0 7,427.0 5,445.7 6,376.9 Primary – Full Bore Tail 41 bbl 15.8 ppg Class G ... Test lins to 3500 psi, pump 10 bbls preflush 35 bbls 11.5 ARCO spacer. Drop bt plug, mix & pump 41 bbls Class G cmt @ 15.8 ppg. Flush lines. ^^Csg OD=7 26.7 3,096.5 26.7 2,729.2 Production String 2 Cement 6/29/2025 2M-25, 8/4/2025 2:26:12 PM Vertical schematic (actual) PRODUCTION; 3,162.0-7,487.1 IPERF; 7,134.0-7,154.0 IPERF; 7,120.0-7,134.0 APERF; 7,088.0-7,100.0 Nipple - XN; 6,898.7 Primary – Full Bore; 6,350.0 ftKB PACKER; 6,840.8 Mandrel – GAS LIFT; 6,782.3 Mandrel – GAS LIFT; 6,108.8 Mandrel – GAS LIFT; 5,191.1 Production; 26.7-3,165.0 SURFACE; 35.0-3,152.6 Mandrel – GAS LIFT; 2,971.5 Primary – Full Bore; 341.0 ftKB Production String 2 Cement; 26.7 ftKB CONDUCTOR; 39.0-115.0 Grouting / Top-Up; 35.0 ftKB Hanger; 33.2 KUP PROD KB-Grd (ft) 35.01 RR Date 4/1/1991 Other Elev… 2M-25 ... TD Act Btm (ftKB) 7,445.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032015200 Wellbore Status PROD Max Angle & MD Incl (°) 39.86 MD (ftKB) 2,100.00 WELLNAME WELLBORE2M-25 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP ($8 8/14/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.14 09:51:32 -08'00' RBDMS JSB 081825 1 Dewhurst, Andrew D (OGC) From:Dewhurst, Andrew D (OGC) Sent:Monday, 11 August, 2025 10:00 To:Klem, Adam Cc:Guhl, Meredith D (OGC); Loepp, Victoria T (OGC); Wallace, Chris D (OGC) Subject:RE: [EXTERNAL]KRU 2M-25 Frac Sundry (325-459): Questions Adam, Thanks for the schematic. With regards to the AOR, the KRU 2M-23 is a shallow well that TDs in the Ugnu. It is within the ½-mile radius in a map view, but doesn’t need to be included as it isn’t within the fracturing zone. In any case, this is just an FYI; no reply or update needed. I have no other questions. Thanks, Andy From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Monday, 11 August, 2025 07:46 To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL]KRU 2M-25 Frac Sundry (325-459): Questions My apologies on the missing schematic. Here it is. The info I was provided from our tech shows the following: Well Name Status Symbology Well in Frac Port 1/2 mi Buffer Open Interval in Frac Port 1/ mi Buffer 2H-15 ACTIVE Injector Miscible Water Alternating Gas Yes Yes 2M-20 ACTIVE Oil Yes Yes 2M-23 PA Plugged and Abandoned Yes - P&A Yes - P&A From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Thursday, August 7, 2025 4:05 PM To: Klem, Adam <Adam.Klem@conocophillips.com> Cc: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: [EXTERNAL]KRU 2M-25 Frac Sundry (325-459): Questions Adam, I am completing my review of the KRU 2M-25 frac sundry and have a couple questions: 2 The request for logs was from me. I noticed that there are some signiƱcant gaps in the log coverage for this well and wanted to see if our record was incomplete. I suspect that there are no additional data as the digital coverage matches our paper log records – just wanted to conƱrm. I check this as part of the frac checklist conƱrming that any other signiƱcant hydrocarbons in the well are properly isolated. It appears that the application is missing the wellbore schematic. Would you please send a copy? Regarding the AOR, it looks like the KRU 2H-15, 1M-20, and 2M-23 wells do not intersect the fracturing zone within the ½-mile radius. Would you please conƱrm? Thanks, Andy From: Klem, Adam <Adam.Klem@conocophillips.com > Sent: Thursday, 7 August, 2025 09:59 To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Ambatipudi, Anu <Anu.Ambatipudi@conocophillips.com >; Collins, Lorna G <Lorna.C.Collins@conocophillips.com> Cc: Gluyas, Gavin R (OGC) <gavin.gluyas@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL]PTD 191-021: KRU 2M-25: openhole logs between 3650' and 6650' Meredith, This well was drilled and frac’d in the 1990s. We just worked this well over and looking to re-frac it for uplift. Can you explain why logs are required for this frac sundry? Adam From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Thursday, August 7, 2025 9:42 AM To: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Ambatipudi, Anu <Anu.Ambatipudi@conocophillips.com >; Klem, Adam <Adam.Klem@conocophillips.com>; Collins, Lorna G <Lorna.C.Collins@conocophillips.com> Cc: Gluyas, Gavin R (OGC) <gavin.gluyas@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL]PTD 191-021: KRU 2M-25: openhole logs between 3650' and 6650' I did a quick look yesterday at the well Ʊles and came up empty- I will research drilling records and see what I can Ʊnd with Lorna- Greg From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Sent: Wednesday, August 6, 2025 4:00 PM To: Ambatipudi, Anu <Anu.Ambatipudi@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Klem, Adam <Adam.Klem@conocophillips.com> Cc: Gluyas, Gavin R (OGC) <gavin.gluyas@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL]PTD 191-021: KRU 2M-25: openhole logs between 3650' and 6650' 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. 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. 3 Hi Anu, We’re trying to track down any open hole log data for KRU 2M-25 between 3650’ and 6650’. The digital data in the AOGCC archive does not cover this interval. Does ConocoPhillips have any open hole logging data in that interval, and if so, could ConocoPhillips please provide the data in an LAS Ʊle. A composited LAS Ʊle for the entire wellbore would also be very welcome. This request is made in support of a frac sundry for KRU 2M-25 with an estimated ops date of 8/11/2025, please prioritize this request to assist the AOGCC in review of the sundry application. Thank you, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 20 AAC 25.283 Hydraulic Fracturing Application – Checklist KRU 2M-25 (PTD No. 191-021; Sundry No. 325-459) Paragraph Sub-Paragraph Section Complete? AOGCC Page 1 August 7, 2025 (a) Application for Sundry Approval (a)(1) Affidavit Provided with application. A.Dewhurst 06AUG25 (a)(2) Plat Provided with application. A.Dewhurst 06AUG25 (a)(2)(A) Well location Provided with application.A.Dewhurst 06AUG25 (a)(2)(B) Each water well within ½ mile None: According to the Water Estate map available through DNR’s Alaska Mapper application (accessed online June 8, 2025), there are no wells are used for drinking water purposes are known to lie within ½ mile of the surface location of KRU 2M-25. There are no subsurface water rights or temporary subsurface water rights within 15 miles of the surface location of KRU 2M-25. A.Dewhurst 06AUG25 (a)(2)(C) Identify all well types within ½ mile Provided with application. A.Dewhurst 06AUG25 (a)(3) Freshwater aquifers: geological name; measured and true vertical depth None. This well lies within the Kuparuk River Unit (KRU). 40 CFR 147.102(b)(3) exempts aquifers within the KRU as follows: “That portions of the aquifers on the North Slope described by a ¼ mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field”. A.Dewhurst 06AUG25 (a)(4) Baseline water sampling plan None required. A.Dewhurst 06AUG25 (a)(5) Casing and cementing information Provided with application. No schematic attachedCDW 08/05/2025 (a)(6) Casing and cementing operation assessment 9-5/8” surface casing cemented with a top job completed. 7” casing cemented with losses reported. TOC (log) as 6350 ft MD. No issues with cement for the upcoming stimulation. CDW 08/05/2025 20 AAC 25.283 Hydraulic Fracturing Application – Checklist KRU 2M-25 (PTD No. 191-021; Sundry No. 325-459) Paragraph Sub-Paragraph Section Complete? AOGCC Page 2 August 7, 2025 (a)(6)(A) Casing cemented below lowermost freshwater aquifer and conforms to 20 AAC 25.030 Only exempt freshwater aquifers present. (See Section (a)(3), above.) A.Dewhurst 06AUG25 (a)(6)( B) Each hydrocarbon zone is isolated The Kuparuk is isolated by the 7” production casing cement. TOC from CBL is 6,350’ MD. A.Dewhurst 07AUG25 (a)(7) Pressure test: information and pressure-test plans for casing and tubing installed in well Provided with application. 2970 psi MITIA planned, 4400 psi MITT plan. CDW 08/05/2025 (a)(8) Pressure ratings and schematics: wellbore, wellhead, BOPE, treating head Provided with application. 10K psi tree saver. Max. frac. Pressure simulated as 6600 psi. MAWP 8000 psi. Pump shut downs 7100 psi and PRV’s ePRV 7600 psi, Annulus PRV 2800 psi, tree saver test 10K psi, lines test 9000 psi. Max allowed working pressure of 8000 psi., tubing ePRV 7600 psi. CDW 08/05/2025 (a)(9)(A) Fracturing and confining zones: lithologic description for each zone (a)(9)(B) Geological name of each zone (a)(9)(C) and (a)(9)(D) Measured and true vertical depths (a)(9)(E) Fracture pressure for each zone Upper confining zones: HRZ and Kalubik mudstones that have an aggregate thickness of about 280’ true vertical thickness (TVT). Fracture gradient expected to range from about 15 ppg EMW. Fracturing Zone: Fracturing zone is the Kuparuk A sand at 7,036’ MD (-5,889’ TVDSS) consisting of fine-grained sandstone separated by laterally continuous shales. Fracture gradient expected to be about 12.5 ppg EMW. Lower confining zone: Miluveach Shale that has an aggregate TVT of about 550’ in this area. Fracture gradient expected to be about 15.5 ppg EMW. A.Dewhurst 06AUG25 (a)(10) Location, orientation, report on mechanical condition of each well that may transect the confining zones and sufficient information to determine wells will not interfere with containment of It is highly unlikely that any of the wells or wellbores within a ½-mile radius will interfere with hydraulic fracturing fluids from this operation because of cement isolation and / or separation distance from proposed fracture interval. CDW 08/05/2025 A.Dewhurst 07AUG25 20 AAC 25.283 Hydraulic Fracturing Application – Checklist KRU 2M-25 (PTD No. 191-021; Sundry No. 325-459) Paragraph Sub-Paragraph Section Complete? AOGCC Page 3 August 7, 2025 hydraulic fracturing fluid within ½ mile of the proposed wellbore trajectory There are 3 wells within ½ mile of KRU 2M-25 that penetrate the confining intervals within ½ mile. CPAI has evaluated each well. (a)(11) Faults and fractures, Sufficient information to determine no interference with containment of the hydraulic fracturing fluid within ½ mile of the proposed wellbore trajectory Four faults: Though this area is extensively faulted, with many sub-seismic faults present, the operator has identified four faults within a ½-mile radius of KRU 2M-25. The closest fault lies approximately 800’ from the proposed fracturing interval, and the modeled half-length of the induced fracture is 340’. It is unlikely that this fault will interfere with containment of the injected fracturing fluids; however, if there are indications that a fracture has intersected a fault or natural-fracture interval during frac operations, the operator will go to flush and terminate the stage immediately. A.Dewhurst 07AUG25 (a)(12) Proposed program for fracturing operation Provided with application. CDW 08/05/2025 (a)(12)(A) Estimated volume Provided with application. 2503 bbl total dirty vol. 128K lb total proppant CDW 08/05/2025 (a)(12)(B) Additives: names, purposes, concentrations Provided with application. CDW 08/05/2025 (a)(12)(C) Chemical name and CAS number of each Provided with application. Halliburton disclosure provided. Proprietary chemicals on file at AOGCC CDW 08/05/2025 (a)(12)(D) Inert substances, weight or volume of each Provided with application. CDW 08/05/2025 (a)(12)(E) Maximum treating pressure with supporting info to determine appropriateness for program Simulation shows max surface pressure 6600 psi. Max. 8000 psi allowable treating pressure. With 2700 psi back pressure IA (IA popoff set 2800 psi), max tubing differential should be 3900 psi. ePRV 3750 psi, Annulus PRV 2800 psi, tubing ePRV 7600 psi. CDW 08/05/2025 20 AAC 25.283 Hydraulic Fracturing Application – Checklist KRU 2M-25 (PTD No. 191-021; Sundry No. 325-459) Paragraph Sub-Paragraph Section Complete? AOGCC Page 4 August 7, 2025 (a)(12)(F) Fractures – height, length, MD and TVD to top, description of fracturing model Provided with application. The anticipated half-lengths of the induced fractures are 340’ according to the Operator’s computer simulation. Computer simulation indicates the anticipated height of the induced fractures will be 95’. See the application for detailed depths. A.Dewhurst 07AUG25 (a)(13) Proposed program for post-fracturing well cleanup and fluid recovery Basic well cleanout and flowback procedure provided with application. No disposal identified. CDW 08/05/2025 (b)Testing of casing or intermediate casing Tested >110% of max anticipated pressure 2700 psi back pressure, plan to test to 2970 psi, popoff set as 2800 psi. CDW 08/05/2025 (c) Fracturing string (c)(1) Packer >100’ below TOC of production or intermediate casing 3.5” tubing will be anchored with a packer set at approx. 6841 ft with perforations of 7120-7154 ft. TOC in 7” casing at 6350 ft so packer set >100 ft below TOC. CDW 08/05/2025 (c)(2) Tested >110% of max anticipated pressure differential Tubing test of 4400 psi. Max pressure differential is estimated as 3900 psi (6600 psi with 2700 psi backpressure) so test of 4400 psi satisfies 110% CDW 08/05/2025 (d) Pressure relief valve Line pressure <= test pressure, remotely controlled shut-in device 9000 psi line pressure test, max est frac pressure 6600 psi, ePRV 7600 psi. IA PRV set as 2800 psi. CDW 08/05/2025 (e) Confinement Frac fluids confined to approved formations Provided with application. CDW 08/05/2025 (f) Surface casing pressures Monitored with gauge and pressure relief device IA PRV set at 2800 psi. Surface annulus open. Frac pressures continuously monitored. CDW 08/05/2025 (g) Annulus pressure monitoring & notification 500 psi criteria During hydraulic fracturing operations, all annulus pressures must be continuously monitored and recorded. If at any time during hydraulic fracturing operations the annulus pressure increases more than 500 psig above those anticipated increases caused by pressure or thermal transfer, the operator shall: CDW 08/05/2025 (g)(1) Notify AOGCC within 24 hours (g)(2) Corrective action or surveillance 20 AAC 25.283 Hydraulic Fracturing Application – Checklist KRU 2M-25 (PTD No. 191-021; Sundry No. 325-459) Paragraph Sub-Paragraph Section Complete? AOGCC Page 5 August 7, 2025 (g)(3) Sundry to AOGCC (h) Sundry Report (i) Reporting (i)(1) FracFocus Reporting (i)(2) AOGCC Reporting: printed & electronic (j) Post-frac water sampling plan Not required (see Section (a)(3), above). A.Dewhurst 07AUG25 (k) Confidential information Clearly marked and specific facts supporting nondisclosure Non-confidential well. A.Dewhurst 07AUG25 (l) Variances requested Modifications of deadlines, requests for variances or waivers No plan for post fracture water well analysis. Commission may require this depending on the performance of the fracturing operation. TRANSMITTAL DATE: 7/30/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5533 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 5533 2M-25 50103201520000 Cement Bond Log 25-Jun-2025 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 191-021 T40725 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.30 15:08:47 -08'00' 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: 7/30/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5539 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 5539 2M-25 50103201520000 Cement Bond Log 29-Jun-2025 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 191-021 T40725 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.30 15:08:30 -08'00' 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: 6/25/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5505 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 5505 2M-25 50103201520000 Tubing Puncher Record 12-Jun-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 lorna.c.collins@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 191-021 T40610 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.25 08:12:20 -08'00' 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: Delivered to:18-Jun-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 TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2B-02A 50-029-21154-01 910106459 Kuparuk River Multi Finger Caliper Field & Processed 14-Jun-25 0 12 2B-03B 50-029-21151-02 n/a Kuparuk River Radial Bond Record Field- Final 8-Mar-25 0 13 2F-09 50-029-21090-00 910080198 Kuparuk River Plug Setting Record Field- Final 23-May-25 0 14 2F-09 50-029-21090-00 910010602 Kuparuk River Radial Bond Record Field- Final 2-May-25 0 15 2G-17 50-029-23134-00 910106461 Kuparuk River Plug Setting Record Field- Final 9-Jun-25 0 16 2K-23 50-103-20125-00 910099510 Kuparuk River Multi Finger Caliper Field & Processed 2-Jun-25 0 17 2K-34 50-103-20688-00 910096425 Kuparuk River Multi Finger Caliper Field & Processed 15-Jun-25 0 18 2M-08 50-103-20184-00 910027001 Kuparuk River Multi Finger Caliper Field & Processed 9-May-25 0 19 2M-25 50-103-20152-00 910106929 Kuparuk River Plug Setting Record Field- Final 12-Jun-25 0 110 2M-25 50-103-20152-00 910106929 Kuparuk River Tubing Cut Record Field- Final 13-Jun-25 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:216-087223-080184-036202-243190-014214-026192-101191-021T40589T40590T40591T40591T40592T40593T40594T40595T40596T405966/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.20 08:42:29 -08'00'191-0212M-2550-103-20152-00 910106929Kuparuk RiverPlug Setting RecordField- Final12-Jun-250110 2M-2550-103-20152-00 910106929Kuparuk RiverTubing Cut RecordField- Final13-Jun-2501 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? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7445'None Casing Collapse Conductor Surface Production 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: 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: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Adam Klem adam.klem@conocophillips.com (907) 263-4529 CTD/RWO Engineer Tubing Grade:Tubing MD (ft): Packer: 6915'MD/5924'TVD SSSV: 1804'MD/1673'TVD Perforation Depth TVD (ft):Tubing Size: J-55 6944' 7/2/2025 Packer: Baker HB SSSV: CAMCO TRDP-4A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL025586 191-021 P.O. Box 100360, Anchorage, AK 99510 50-103-20152-00-00 ConocoPhillips Alaska, Inc. KRU 2M-25 Kuparuk River Oil PoolKuparuk River Oil PoolKuparuk River Field N/A Length Size Proposed Pools: 115'115' TVD Burst PRESENT WELL CONDITION SUMMARY 76'16" 6393'7116'6099'2116'None MD 2776'3153'9-5/8"3118' Perforation Depth MD (ft): 7120-7154'MD 7" 6103-6133'TVD 7487'7452' 3-1/2" 6431' P s 66 t Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:27 pm, May 14, 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: 2025.05.14 10:49:04-08'00' Foxit PDF Editor Version: 13.1.6 Adam Klem 325-302 10-404 DSR-6/3/25 AOGCC Witnessed BOP and Annular Test to 2500 psi. Subsequent Form: A.Dewhurst 10JUN25JJL 6/2/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.10 11:58:27 -08'00'06/10/25 RBDMS JSB 061025 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 13, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Adam Klem Staff RWO/CTD Engineer ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Producer 2M-25 (PTD# 191-021). 2M-25 is a producer drilled in 1991 completed with 3.5" tubing and 7" casing. It is estimated to have high subsidence and a gyro indicates damage at 500'. Therefore a workover to fix the subsidence is required. Furthermore, the A4 was never perf'd or frac'd and appears to have good potential, so perfs and a frac will be included in the scope of this workover. The plan is to pre rig cut the tubing and pull the tubing on rig. The the 7" will be cut based on log evalaution with a goal depth of around 2500' and a subsidence style repair of running new 7" with a sealing overshot onto the 7" stub and cementing the 7" to surface will be performed. Then the reaminaing tubing stub and the packer will be removed. The A4 will be perforated and then a new packer and tubing will be ran. Post rig the A3 and A4 will be frac'd (Frac sundry to be submitted at a later date). If you have any questions or require any further information, please contact me at 907-263-4529 Digitally signed by Adam Klem DN: CN=Adam Klem, E= adam.klem@ conocophillips.com, C=US Reason: I am approving this documentLocation: Date: 2025.05.14 10:49:14 -08'00' Foxit PDF Editor Version: 13.1.6 Adam Klem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ast Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,116.0 2M-25 4/11/2021 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Changed out OV 2M-25 1/31/2025 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: Prod CSG tally has calculation errors; corrected shows set depth 7487', questionable depth ?? 7/23/2012 osborl NOTE: View Schematic w/ Alaska Schematic9.0 11/16/2010 ninam NOTE: SUSPECT BUCKLED TUBING 10/6/2005 WV5.3 Conversio n NOTE: 1.5" tool string needed for TAG; SUSPECT TUBING BUCKLED @6880' SLM 10/8/1995 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 39.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.76 35.0 3,152.6 2,775.7 36.00 J-55 BTC PRODUCTION 7 6.28 35.0 7,487.1 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 33.0 Set Depth … 6,944.0 Set Depth … 5,949.1 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-ABM 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) 33.0 33.0 0.10 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 1,804.1 1,672.9 37.63 SAFETY VLV 5.250 CAMCO TRDP-4A SSSV CAMCO TRDP- 4A 2.812 2,880.3 2,550.0 32.66 GAS LIFT 5.560 MACCO SPM-1A MACCO SPM-1A 2.867 4,566.2 3,940.2 34.61 GAS LIFT 5.560 MACCO SPM-1A MACCO SPM-1A 2.867 5,477.5 4,707.0 32.02 GAS LIFT 5.560 MACCO SPM-1A MACCO SPM-1A 2.867 5,827.6 5,004.3 31.99 GAS LIFT 5.560 MACCO SPM-1A MACCO SPM-1A 2.992 6,173.4 5,296.7 32.45 GAS LIFT 5.560 MACCO SPM-1A MACCO SPM-1A 2.867 6,520.2 5,589.1 32.67 GAS LIFT 5.560 MACCO SPM-1A MACCO SPM-1A 2.867 6,756.4 5,788.1 32.13 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.920 6,844.5 5,863.2 30.97 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.920 6,900.5 5,911.5 30.05 PBR 5.125 BAKER 10' STROKE PBR, 4" SEAL BORE BAKER 10' STROK E 3.000 6,915.3 5,924.3 30.01 PACKER 6.025 BAKER HB PACKER BAKER HB 2.890 6,931.7 5,938.5 29.96 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 6,943.3 5,948.5 29.93 SOS 3.500 BAKER SHEAR OUT BAKER 2.992 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) 6,856.0 5,873.1 30.78 TIGHT SPOT TUBING IMPINGEMENT (POSSIBLE BUCKLING) STARTING @ 6856'. Could not drift w/1.80" plug 6/11/21 4/11/2021 1.750 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) 2,880.3 2,550.0 32.66 1 GAS LIFT GLV BK 1 1,284.0 2/21/2022 0.188 4,566.2 3,940.2 34.61 2 GAS LIFT GLV BTM 1 1,291.0 2/20/2022 0.188 5,477.5 4,707.0 32.02 3 GAS LIFT OV BK 1 1/30/2025 0.188 5,827.6 5,004.3 31.99 4 GAS LIFT DMY BK 1 0.0 6/10/2020 0.000 6,173.4 5,296.7 32.45 5 GAS LIFT DMY BK2 1 0.0 2/21/2020 0.000 6,520.2 5,589.1 32.67 6 GAS LIFT DMY BK2 1 0.0 9/30/2010 0.000 6,756.4 5,788.1 32.13 7 GAS LIFT DMY RK 1 1/2 0.0 9/23/1991 0.000 6,844.5 5,863.2 30.97 8 GAS LIFT DMY RK 1 1/2 0.0 2/20/2020 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,120.0 7,134.0 6,102.5 6,114.8 A-3, 2M-25 9/23/1991 4.0 IPERF SWS 4 1/2" Csg Gun;180 deg. phasing; Oriented 64 deg. CCW 7,134.0 7,154.0 6,114.8 6,132.5 A-3, 2M-25 9/23/1991 4.0 IPERF SWS 4 1/2" Csg Gun; 180 deg. phasing; Oriented 68 deg. CCW 2M-25, 1/31/2025 3:30:33 PM Vertical schematic (actual) PRODUCTION; 35.0-7,487.1 IPERF; 7,134.0-7,154.0 IPERF; 7,120.0-7,134.0 PACKER; 6,915.3 TIGHT SPOT; 6,856.0 GAS LIFT; 6,844.5 GAS LIFT; 6,756.4 GAS LIFT; 6,520.2 GAS LIFT; 6,173.4 GAS LIFT; 5,827.6 GAS LIFT; 5,477.5 GAS LIFT; 4,566.2 SURFACE; 35.0-3,152.6 GAS LIFT; 2,880.3 SAFETY VLV; 1,804.1 CONDUCTOR; 39.0-115.0 KUP PROD KB-Grd (ft) 35.01 RR Date 4/1/1991 Other Elev… 2M-25 ... TD Act Btm (ftKB) 7,445.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032015200 Wellbore Status PROD Max Angle & MD Incl (°) 39.86 MD (ftKB) 2,100.00 WELLNAME WELLBORE2M-25 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP 2M-25 Proposed RWO Completion PROPOSED COMPLETION 3-1/2" Hyd563 Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ TBD 3-1/2" by 7" Packer (TNT High Pressure) @ ~7,110' RKB 3-1/2" X landing nipple (2.313" min ID) 3-1/2" WLEG TOC: 6350' No arctic pack Originated: Delivered to:13-Aug-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1Q-22 50-029-22595-00 909470221 Kuparuk River Leak Detect Log Field- Final 1-Aug-24 0 1 2 1Q-22 50-029-22595-00 909470221 Kuparuk River Multi Finger Caliper Field & Processed 1-Aug-24 0 1 3 2A-11 50-103-20057-00 909443804 Kuparuk River Multi Finger Caliper Field & Processed 13-Jul-24 0 1 4 2C-12 50-029-21222-00 909469468 Kuparuk River Packer Setting Record Field- Final 23-Jul-24 0 1 5 2M-25 50-103-20152-00 909509189 Kuparuk River Multi Finger Caliper Field & Processed 10-Aug-24 0 1 6 2X-05 50-029-20985-00 909469473 Kuparuk River Leak Detect Log Field- Final 26-Jul-24 0 1 7 2X-05 50-029-20985-00 909469473 Kuparuk River Packer Setting Record Field- Final 28-Jul-24 0 1 8 2Z-06 50-029-20957-00 909460858 Kuparuk River Multi Finger Caliper Field & Processed 15-Jul-24 0 1 9 WSW-05 50-029-20838-00 909490893 Kuparuk River Multi Finger Caliper Field & Processed 2-Aug-24 0 1 10 PLEASE 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 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T39442 T39442 T39443 T39444 T39445 T39446 T39446 T39447 T39448 195-140 186-003 184-206 191-021 183-107 183-077 182-164 8-14-2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.14 08:42:09 -08'00' 52M-25 50-103-20152-00 909509189 Kuparuk River Multi Finger Caliper Field & Processed 10-Aug-24 0 1 191-021 0 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 9, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Down Hole Video: 2M -25 Run Date: 9/7/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Minton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2M -25 Digital Video File (AVI) 1 DVD Rom 50 -103- 20152 -00 NG�' �tL PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 l Office: 907 - 273 -3527 Fax: 907-273-3535 �� klinton.wood@halliburton.com Date: Signed: C 05/12/09 ~~~~~ Schlumberger -DCS ~, ~''~~ '~~"~' ~,~~.V> 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~i MAY ~ ~ 2009 ~9~s~~ C~ii ~ has ~Ons. ~®I~r~issi0~a ~I~~h~r~g~ Log Description NO. 5228 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 3A-18 AYS400069 PERF/SBHP SURVEY 6 04/26/09 1 1 3C-08 6148-00033 GLS $ = / 04/21/09 1 1 2M-25 B14B-00034 GR/TEMP LOG l9 (- 04/22/09 1 1 1R-19A AYS4-00065 SBHP SURVEY -rG ` `'- 3Co 04/23/09 1 1 3G-13 AYS4-00067 SBHP SURVEY - ( 04/24/09 1 1 3G-05 AYS4-00066 SBHP SURVEY 04/24/09 1 1 3F-07 B14B-00038 SBHP SURVEY _ 04/24/09 1 1 3F-08 B14B-00037 SBHP SURVEY _ 04/24/09 1 1 3M-25A B146-00040 SBHP SURVEY 04/25/09 1 1 3K-08 B14B-00039 SBHP SURVEY C/ 04/25/09 1 1 2N-318A AWJI-00026 MEM BHP SURVEY -® 04/27/09 1 1 22-07 8146-00045 SBHP SURVEY L 04/29/09 1 1 2Z-01A B14B-00044 SBHP SURVEY ~-_ ~ 04/29/09 1 1 3K-102 ANHY-00080 GLS 04/30/09 1 1 2W-06 604C-00036 PRODUCTION PROFILE 05/02/09 1 1 2W-12 604C-00037 PRODUCTION PROFILE - p_~ 05/03/09 1 1 3C-02 B04C-00045 POWERCUTTER W/SBHP SURVEY ~ 05/09/09 1 1 1J-120 B04C-00043 GLS ~ Q Q 05/08/09 1 1 31-11 604C-00044 SMALL TBG PUNCH W/SBHP 05/08/09 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. ~~ 1 • y' . . ConocoPh~ll~ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 6, 2008 RECEIVED JAN ~ 8 ~00~ Alaska Oil & Gaa Cony. Comrnl~,tion Anchorage Mr. Tom Maunder Alaska Oil & Gas Commission ~,~Q 333 West 7`" Avenue, Suite 100 Anchorage, AK 99501 ~~~~~ ~~~ ~ ~~~~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRL)7. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of 12". The remaining volume of annulaz void respectively was filled with a corrosion inhibiter, RG2401, engineered to prevent water from entering the annulaz space. Asper previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on Dec 25, 2007. We mixed 15.7 ppg Class G cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor/sealant was pumped in a similaz manner Jan 6, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Sincerely, Perry ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404j Kuparuk Field r)afn "~ STATE OF ALASKA '~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations PerfOrmed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate _ Repair well O t h e r 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 99510 Type of Well: Development X Exploratory · _ · Stratigraphic _ SerVice _ 114' FSL, 579' FWL, SEC 27, T11N, R8E, UM At top of productive interVal 957' FSL, 1300' FEL, SEC 27, T11N, R8E, UM At effective depth 1004' FSL, 1250' FEL, SEC 27, T11N, R8E, UM At total depth 1020' FSL, 1205' FEL, SEC 27, T11N, R8E, UM. 12. Present well condition summary Total Depth: measured trUe vertical 6. Datum elevation (DF or KB) RKB 140 7. ~Unit or Property name Kuparuk River Unit 8. Well number 2M-25 9. Permit number/approval number 91-21 10. APl number 5o-103-20152-00 11. Field/Pool Kuparuk River Oil Pool 744 5 feet Plugs (measured). None 6393 feet Effective depth: measured 7 3 3 7' feet Junk (measured) None true vertical 6 2 9 6' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 220 SX AS II I 1 5' 115' Surface · 3152' 9 5/8" 554 Sx AS III & 3175' 2794' Intermediate 200 Sx Class G Production 7427' 7" 200 Sx Ciass G 7445 6393' Liner Perforation depth: measured 7120' 7154' true vertical 6102' - 6131' RECEIV. E';D Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 EUE, @ 6944' Packers and SSSV (type and measured depth) PKR: Baker HB @ 6915'; SSSV: Camco TRDP-4A @ 1804' 13. Stimulation or cement squeeze summary Refracture 'A' sands on 8/20/96. Intervals treated (measured) ORIGINAl_ 7120' 7154' Treatment description including volumes used and final pressure Pumped 271.4 M lbs 20/40~ 12/1'8, & 10/1.4 ceramic proppant intO .f0rmation~ fp was 4166 psi. 14. Reoresentative Daily Average Production or In_iection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1 5 1997 0il & 6as .Cons. Prior to well operation 863 455 80 850 237 Subsequent to operation 1 1 6 0 1063 95 875 240 15. Attachments Copi_es of Logs and Surveys run Daily Report of Well Operations X 16. Status of Well classification as: Oil ~ Gas Suspended m Service 17. I hereby certify that the foregoing is true-and correct to the best of my knowledge. · Signed ~~ ~ ~1~ Form 10~404 ~ev 06/15/~8 Title Wells Superintendent , ,, Date '4-9-97 SUBMIT IN DUPLICATE ARCO AlaSka, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT '~ K1(2M-25(W4-6)) WELL JOB SCOPE JOB NUMBER 2M-25 FRAC, FRAC SUPPORT 0815960916.4 DATE DAILY WORK UNIT NUMBER 08/20/96 'A' SAND REFRAC ,'~ ../ DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR ' /'/:' 1 (~) Yes ~'~ NoI ~ Yes O No DS-GALLEGOS PENROSE ,, /~' FIELD AFC# CC# DAILY COST ACCUM COST Signed ",. ~? '/~'.~' ESTIMATE KM1340 230DS28ML $1 67,1 32 $167,132 ',: "'-~'"?'"' "~"' "- Initial Tb.cl Press Final Tbcl Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final' Outer Ann 55 PSI 1937 PSI 1375 PSI 500 PSII 255 PSII 331 PSI DAILY SUMMARY RE-FRAC'D 'A' SAND AS DESIGNED. PLACED 271,437 LBS SAND BEHIND PIPE, LEFT 2,871 LBS IN WELLBORE. TOP 3,300' OF TBG IS DIESEL-FILLED. USED 32,439 LBS OF 20140, 222,700 LBS OF 12/18 AND 19,169 LBS OF 10/14 PROPPANT. TIME LOG ENTRY 07:00 MIRU DOWELL PUMPING EQUIP AND APC/LRS SUPPORT EQUIP. 08:30 WORK UP AND QC FLUIDS, HOLD PRE-JOB SAFETY MEETING. 09:05 PRIME UP PUMPING EQUIP, SET TREE SAVER, PRESSURE TEST TO 9,400 PSI, PRESSURE UP BACKSIDE TO 2,500 PSI. 09:45 START PUMPING BREAKDOWN/CONDITIONING STAGE. PUMP 250 BBLS 50# DELAYED XL GW @ 25 BPM, 4,220 PSI. BRING BACKSIDE PRESSURE UP TO 3,500 PSI WHILE PUMPING. 09:55 SLOW RATE TO 15 BPM AND ADD 1 PPA 20/40 PROPPANT, PUMP 75 BEES. 10:00 CUT PROPPANT, PUMP ADD'L 50 BBLS@ 15 BPM. 10:05 ADD 2 PPA 20/40 PROPPANT, PUMP 50 BBLS@ 15 BPM. 10:08 CUT PROPPANT, PUMP ADD'L 25 BBLS FOLLOWED BY 65 BBLS STRAIGHT WATER FLUSH. 10:15 FINISH BREAKDOWN/CONDITIONING STAGE, S/D. FFP = 2,513 PSI, ISIP --- 1,497 PSI. PERFORM PULSE TESTING AND MONITOR WHP. 11:08 START PUMPING DATAFRAC. DISPLACE W/67 BBLS OF 50# DELAYED XL GW @ 5 BPM. 11:20 INCREASE RATE TO 15 BPM, PUMP ADD'L 85 BEES. 11:25 SWITCH TO STRAIGHT WATER, PUMP 65 BBLS@ 15 BPM. 11:30 FINISH PUMPING DATAFRAC, S/D. FFP = 2,550 PSI, ISIP - 1,460 PSI. MONITOR WHP AND CALC PAD VOLUME. 12:45 START PUMPING FRAC. PUMP 67 BBLS 50# DELAYED XL GW PAD @ 5 BPM. 13:00 INCREASE RATE TO 15 BPM, PUMP ADD'L 183 BBLS PAD. 13:13 START ADDING 2 PPA 20/40 PROPPANT, PUMP 150 BBLS@ 15 BPM. 13:22 START RAMPING PROP CONC UP FROM 2 PPA TO 10 PPA. CONTINUE PUMPING @ 15 BPM. 13:32 SWITCH TO 12/18 PROPPANT WITH PROP CONC @ 4.1 PPA. 13:55 14:20 14:25 14:30 14:35 14:50 16:30 END RAMP, PUMP ADD'L 400 BBLS ~OF 12/18 @ 10 PPA, 15 BPM. RAMP 12/18 PROP CONC UP--~R~'20 I~PA to 12 PPA. PUMP 65 BEES @ 15 BPM. ~- ! r, ~ i SWITCH TO 10/14 PROPPANT, RAMP UP FROM 12 PPATO 14 PPA. PUMP 86 BBLS@ 15 BPM. SWITCH TO FLUSH: 13 BBLS DELAYED XL GW FOLLOWED BY 8 BBLS NON-XL GW FOLLOWED BY 36 BBLS SLICK DIESEL (7 BBLS DIESEL LEFT IN SURF LINES, 29 BBLS DOWNHOLE). FINISH PUMPING, S/D. FFP = 4,166 PSI, ISIP = 2,481 PSI. MONITOR WHP. SIWHP = 1,937 PSI. BLEED BACKSIDE PRESSURE TO 500 PSI. RDMO DOWELL AND APC/LRS. WELL SECURE AND EVERYBODY OFF LOCATION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $2,200.00 $2,200.00 ARCO $242.00 $242.00 DOWELL $162,650.00 $162,650.00 LIq-I'LE RED $2t040.00 $2,040.00 TOTAL FIELD ESTIMATE $167,132.00 $;167,132.00 ARCO Alaska, Inc.~ Post Office .~.~' .~,!~ 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 16, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, Alaska 99501 AR3B-6003-93 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. · WELL ACTION WELL ACTION Stimulate .--~ 2M-18 Stimulate Stimulate ~-~ I~-~ 2M-19 Stimulate Stimulate 9 ~.._ ~ ~ 2M-20 Stimulate Stimulate ~ ~z.~ 2M-21 Stimulate Stimulate q~_qc~ 2M-22 Stimulate Stimulate ~.~.~ 5o 2M-24 Stimulate Stimulate o1~.~;~,, 2M-25 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (atch only) FTR051696 (w/o atch) 242-2603 1. Operations Performed: Pull tubing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 114' FSL, 579' FWL, SEC 27, T11N, R8E, UM At top of productive interval 957' FSL, 1300' FEL, SEC 27, T11N, R8E, UM At effective depth STATE OF ALASKA ~ ALASKA OIL AND C-~,S CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown__ Stimulate X Plugging Alter casing Repair well 5. Type of Well: Development X Exploratory _ Stratigraphic _ At total depth 1020' FSL, 1205' FEL, SEC 27, T1 12. Present well condition summary Total Depth: measured true vertical Service 1N, R8E, UM 7445' feet 6393' 'feet Plugs (measured) Perforate Other 6. Datum elevation (DF or KB) RKB 140' feet ' 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-25 9. Permit number/approval number 10. APl number so-103-20152 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 3 3 7' feet Junk (measured) true vertical 6296' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 1 1 5' 1 6" 220 SX AS II 3152' 9 5/8" 554 SX ASIII 200 SX CLASS G 7 4 2 7' 7" 200 SX CLASS G measured 7120' - 7154' true vertical 6102' - 6131' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 EUE, @ 6944' Packers and SSSV (type and measured depth) Measured depth True vertical depth RECEIVED MAY 20 1994 Alaska Oil & Gas Cons. Commission Anchorage CAMCO TRDP-4A-RO @ 1804', BAKER PBR @ 6901', BAKER HB KPR @ 6915'r SSSV @ 1804' 13. Stimulation or cement squeeze summary Intervals treated (measured) 7120' - 7154' Treatment description including volumes used and final pressure See Attached Summary 14. Re_oresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 5/21/92 None 3376 3926 17 1125 2O2 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~~, ~ Title Senior En.qineer Form 10-404 Rev 06/15/88 Date 5 '" / 7- q5/ SUBMIT IN DUPLICATE ® 05/05/92 GSW FRAC W/DS YF140D. PUMP 170 BBL PREPAD @ 25 BPM, LAST WHTP=4118 PSI, ISIP=1515 PSi, FG=0.69 PSI/FT, PERF/XS FRIC= 1390 PSI. PUMPED 650 BBL PAD AT 25 BPM, LAST WHTP = 4907 PSI. PUMPED 15.5 MLBS 16/20 & 157.67MLBS 12/lS CL IN 2 TO 12 PPA STAGES. PUMPED 64 BBL FLUSH AT 25 BPM AND 4742 PSI. TOT PROP: DESiGN=179.9 MLBS, IN FORM 170.2 & 12.1PPA @ PERFS. FLUID IN PCM WAS OVER X-LINKED. ELECTED TO PUMP PRE-PAD NON X-LINKED TO UNLOAD PCM. RE-CHECKED FLUIDS FOR PAD, LOOKED GOOD, MAY HAVE STILL HAD MORE X-LINKER THAN NECESSARY. (ANGLEN/PALISCH) RECEIVED MAY 20 1994 Alaska Oil & Gas Cons. Commission 1 Status of Well Cla~lltcatlon of Service Well OIL r~l GAS ["-! SUSPENDED r--! ABANDONED I-"1 SERVICE r-"l ,"2 Name of Operator 7 Permit Number ARCO Alaska, Inc 91-21 3 Address 8 APl I~lm13~ P.O. Box 100360, Anchorage, AK 99510-0360 50-103~20152 4 Location of well at surface -- Cu .~-.TI0~ [OCATI~ 9 Unit or ~ Name ~ATE/ 114' FSL, 579' FWL, SEC 27, T11 N, R8E, UM ~.//~.~/~,/_ VEE1FIF..I) KUPARUK RIVER At Top prOducing Interval - wel, Numm 957' FSL, 1300'FEL, SEC 27, T11N, R8E, UM /[~/e/,...~ . _ ~ I. H~' tl~_ 2M-25 At Total Depth ..Z _ -: , ..... : - ,,',, ~ .~." : 11 Field end Peel 1020; FSL, 1205' FEL, SEC 27, T11N, R8E, UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, eto.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 140', PAD 105' GLI ADL 25.586, ALK 2672 12 Date Spudded 13 Date T.D. Reached 14 Date Comp,, Susp. or Aband. I 15 Water Depth, if offehore IlS No. of Completions . .03/24/91. 03/31/91. 09/23/91. -! NA . feet MSLI 1 17 Total Deplh (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Direc~onal Survey 20 DePth where SSSV set 21 Thlckne~ of permafrost 7445' MD, 6393' TVD 7337' MD, 6296' TVD YES _1"~1 NO D 1804. feet MD 1400' APPROX 22 Type Electric ~. Other Logs Run D IL/SP/GR/LDT/CNI/CET/CBI.JGCT i 23 cASING, LINER AND CEMENTING RECORD i SETTI~'DE~H MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RFC ,O,RD AMOUNT PULLED 16" ' 62.5# H-40 ~ SURF 9-5/8" 36# J-55 ' SURF 3152' 12-1/4' 554 SX ASlII, 200 $X CLASS G 7' 26# J-55 SURF 7427. 8-1/2" 200 SX CLASS G ,ri , , 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD , , , interval, size and number) -- ~IZE DE .PTH SET (MD) . PACKER SET (MD) 3~1/2" 6944' 6915' 7120'-7154' W/4-1/2" CSG GUN @ 4 SPF MD 6102'-6131' TVD i' '26 'ACID, FRACTURE; CEMENT ~:3UEEZE, FTC DEPTH INTERVAL (MD) . , AMOUNT & KIND OF MATERIAL USED , ,, i ~ r i ii i r ,, ~1 ,,i , , , ' ' ; ' , , ,'~ '~',~, , ,i i1' , i ~,,, 27 PRO,ION:TEST . Date First Production.JMeth°d~°f Operation (Flowing, gas lift. etc.) I I Date of Test IH ours Tested .... ~ ....... I PRODUC~ FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS:01L'RATIO TESTPER,3D .. I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVlTY-API (corr) Press. 24-HOUR RATE ~ , , i 28 ~ ':" " ":C~RE DATA Brief deSCription of lithology, porosity, fractures, apparent dips and Presence of oil, gas or water. Submit core chil~. ' : R'ECEIVED dAN 4 tggE STATE OFALASKA C~ISSION ~A OIL AND GAS CONSERVATION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GECLOGIC M,~I(ERS FORIVlA'~ TESTS N.NVlE Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 7036' 6029' NA KUPARUK C BO'I-rOM 7048' 6039' KUPARUK A TOP 706~ 6054' KUPARUK A BO'I'rOM 7220' 16191' 31. LISTOF ATTACHMENTS GYRO, REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. , Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of~the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "nOne''. Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 2M-25 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 25586 ALK 2672 50-103-20152 91-21 ACCEPT: 03/24/91 SPUD: 03/24/91 RELEASE: 04/01/91 OPERATION: DRILLING RIG: DOYON 14 AFE: AK5768 WI: 55.252072 03/'25/91 ( 1) TD:-1912' (1912) SUPV:PDW 03/26/91 (2) TD: 3175' (1263) SUPV:PDW 03/27/91 (3) TD: 3175'( SUPV:PDW 0) 03/28/91 (4) TD: 4178' (1003) SUPV:PDW 03/29/91 (5) TD: 6130'(1952) SUPV:PDW 03/30/91 (6) TD: 6756' ( 626) SUPV:PDW 03/31/91 (7) TD: 7412' ( 656) SUPV:PDW DRILLING AT 1912' MW: 9.1 VIS: 62 ACCEPT RIG AT 06:00 HRS 3/24/91. RU GLOBAL CUTTINGS PROCESSING UNIT, RU DIVER TER AND TEST SAME. SPUD AT 11:00 HRS 3/24/91. DRILL TO 1912' MD. DAILY:S280,933 CUM:$280,933 ETD:S280,933 EFC:$1,570,000 CIRC FOR 9-5/8" CASING MW: 9.7 VIS: 51 DRILL TO 3175', CBU, SHORT TRIP TO 1000', HOLE TIGHT AT 1500'. POOH FOR LOGS. HLS LOG WITH TRIPLE COMBO, RD LOGGERS RIH TO TD, CIRC FOR CASING, POOH. DAILY:$59,951 CUM:$340,884 ETD:S340,884 EFC:$1,570,000 DRILLING CEMENT 9-5/8"@ 3153' MW: 9.9 VIS: 40 POOH, RUN 72 JTS OF 9-5/8" CASING. CIRC 2 CASING VOLUMES, PUMP 80 BBL FRESH WATER SPACER, 191 BBL ASIII LEAD SLURRY, 146. BBL TAIL SLURRY. DISPLACED ONLY 22 BBL WITH MUD AT WHICH POINT CEMENT FLASH SET. PRESSURED UP TO 3270 PSI. 122 BBL LEAD OUT OF CASING, 69 BBL LEAD STILL IN CASING. ND BIT AND TURBINE AND START DRILLING CEMENT AT 360'- DAILY:S210,348 CUM:$551,232 ETD:S551,232EFC:$1,570,000 DRILLING AT 4178' 9-5/8"@ 3153' MW: 9.5 VIS: 35 DRILL CEMENT AND FLOAT COLLAR. CHANGE TO 9.5 PPG MUD SYSTEM. DRILL FLOAT SHOE AND 10' OF NEW FORMATION. FORMATION TEST TO 12.5 PPG EMW, OK. DRILL TO 4178' . DAILY:S65,927 CUM:$6~7,159 ETD:S617,159 EFC:$1,570,000 DRILLING AT 6130' 9-5/8"@ 3153' MW: 9.5 VIS: 38 DRILL FROM 4178' TO 6130'. DAILY:S65,597 CUM:$682,756 ETD:S682,756 EFC:$1,570,000 CHANGE BHA 9-5/8"@ 3153' MW: 9.5 VIS: 39 DRILL FROM 6130' TO 6756'. POOH, RUN FORMATION INTEGRITY TEST TO 11.1 PPG EMW OK. PU SPERRY REAL TIME LOGGING TOOLS, MAKE MAD PASS ACROSS COLVILLE, NO OIL BEARING COLVILLE PRESENT. COLVILLE LOG FROM 3369' TO 3597' RIH, TIGHT SPOT AT 3620' POOH TO REMOVE DRILLING MOTOR AN~ FULL GAUGE STABILIZERS. DAILY:S62,249 CUM:$745,005 ETD:S745,005 EFC:$1,570,000 DRILLING AT 7412' 9-5/8"@ 3153' MW: 10.4 VIS: 38 CHANGE TO .ROTARY BHA. RIH, WORK THROUGH TIGHT AREAS. DRILL FROM 6756' TO 7412'. DAILY: $78,601 CUM: $823,606 ETD: $823,606 EFC: $1,570,000 WELL: 2M-25 OPERATION: DRILLING RIG: DOYON 14. © PAGE: 2 04/01/91 (8) TD: '7445'( 33) SUPV:PDW 04/02/91 (9) TD: 7445'( SUPV:PDW 0) CIRC CASING 7"@ 7427' MW:10.4 VIS: 38 DRILL TO TD AT 7445'. SHORT TRIP AND POOH LDDP. RUN 180 JTS 7" CASING. CIRC CASING AT REPORT TIME. DAILY:S145,627 CUM:$969,233 ETD:S969,233 EFC:$1,570,000 RIG RELEASED 7"@ 7427' MW: 0.0 VIS: 0 CIRC CASING, PUMP 10 BBL PREFLUSH, 35 BBL SPACER AT 11.5 PPG 41 BBL CLASS G CEMENT AT 15.8 PPG. DISPLACE WITH 282 BBL 10.4 PPG BRINE, BUMP PLUG TO 3000 PSI. FLOATS OK, ND BOPE, NU TREE AND TEST TO 3000 PSI. INJECT 180 BBL MUD DOWN ANNULUS FOLLOWED BY 80 BBL DIESEL. RELEASE RIG AT 16:30 HRS 4/1/91. MOVE RIG TO 2M-23. DAILY:S106,888 CUM:$1,076,121 ETD:S1,076,121 EFC:$1,570,000 SIGNATURE: DRILLING sUpERIN ,,! ARCO ALASKA INC. WELL: 2M-25 BOROUGH: NORTH SLOPE UNIT: KUPARUK RIVER UNIT FIELD: KUPARUK RIVER FIELD LEASE: ADL 25586 ALK 2672 API: 50-103-20152 PERMIT 91-21 AP P ROVAL: DAILY OPERATIONS ~--~ ACCEPT: 09/20/91 SPUD: RELEASE: 09/23/91 OPERATION: COMPLETION RIG: NORDIC AFE: AK5768 WI: 55.252072 PAGE: 1 09/21/91 (10) TD: 7445 PB: 7337 SUPV:GB/SW 09/22/91 (11) TD: 7445 PB: 7337 SUPV:GB/SW 09/23/91 ( 12) TD: 7445 PB: 7337 SUPV:GB/SW PU DP/RIH WITH BIT 7"@ 7427' MW:10.3 NaBr BEGIN RIG MOVE TO 2M-25 FROM 1B-03 AT 04:30 19-SEP-91,RIG BOGGED DOWN IN ROAD APPROX. 1/2 MILE FROM 2M PAD,USE SILLS TO CRIB UP RIG AND DRIVE OUT OF RUTS, USED ROLLAGON TO FERRY PLYWOOD AROUND RIG, MOVE RIG OVER WELL AND ACCEPT RIG AT 19:30 20-SEP-91,ND TREE,NU BOPE, INSTALL TEST PLUG, KILL AND CHOKE.LINES,FLOW NIPPLE, LOAD PIPE SHED W/3-1/2" DP, STRAP AND TALLY SAME, TAKE ON 147 BBLS 10.3 PPG BRINE, TEST BOPE TO 3000 PSI,OK, SET WEAR RING, CONT. TO RACK AND TALLY DP,MU BHA PU AND RIH W/BIT ON DP DAILY:$108,185 CUM:$1,184,306 ETD:S1,184,306 EFC:$1,570,000 RIG UP TO CIRC. 7"@ 7427' MW:10.3 NaBr SERVICE RIG, CHECK CROWN-O-MATIC, FUNCTION BOPS,CONT PU DP AND RIH,TAG CMT AT 6664',PU KELLY, TEST SAME TO 3000 PSI,OK, DRLG CMT F/6664'-7145' (EZSV),CIRC HOLE CLEAN @ 4 BPM/800 PSI,WORK PIPE AND ROTATE DURING CIRC, TEST CSG TO 2000 PSI, LOST 100 PSI IN 30 MIN, NOTED SMALL LEAK IN SWIVEL PACKING, TEST GOOD DRILL UP EZSV, PUSH JUNK TO BTM @ 7332',CIRC HOLE CLEAN @ 4BPM/800 PSI,WORK PIPE AND ROTATE SLOW, USE MI SOLIDS VAN TO REMOVE CMT FROM BRINE, BLOW DN KELLY, POH, CLEAN PIT#3 FOR BRINE FILTRATION WHILE TRIPPING OUT OF HOLE, BREAK OUT BIT,MU 7" CSG SCRAPER AND BIT, RIH TO BTM, RU FILTRATION UNIT, START CIRCULATING AND FILTERING BRINE DAILY:S31,267 CUM:$1,215,573 ETD:S1,215,573 EFC:$1,570,000 PERFORATING 7"@ 7427' MW:10.4 NaBr SERVICE RIG, CHECK CROWN-O-MATIC, FUNCTION BOPS,CIRC WELL WHILE FILTERING 100BBL BRINE INTO PITS,BRING WT UP TO 10.4 PPG, REV CIRC WELL W/FILTERED 10.4 PPG BRINE, FLUSH CHOKE MANIFOLD/BOPE STACK W/CLEAN BRINE, RU FLOOR TO POH, POH LAYING DN DP,RU SWS,TEST LUBRICATOR TO 750 PSI,MU PERF GUN#1 4SPF/180 DEGREE PHASING, RIH, POSITION AND ORIENT 65 DEG CCW PERF F/7133'-7153'USING ALTERNATING 21 GM 34BJJ2 AND 24 GM 43CUP CHARGES,POH,MU PERF GUN #2,SAME CONFIGURATION AS GUN#1 REBUILD BTM ROLLER, RIH WITH GUN#2 DAILY:S47,138 CUM:$1,262,711 ETD:S1,262,711 EFC:$1,570,00 RECEIVED JAN .0~1 & Cas Cons. Commi~ion WELL: 2M-25 Q' OPERATION: COMPLETION RIG: NORDIC PAGE: 2 09/24/91 ( 13) TD: 7445 PB: 7337 SUPV:GB/SW RIG RELEASED 7"@ 7427' MW:10.4 NaBr RIH W/PERF GUN #2,POSITION/ORIENT AND SHOOT PERFS F/7119'-7133',POH, RD SWS, PULL WEAR RING, RIG FLOOR TO RUN 3-1/2" COMPLETION, RIH W/COMPLETION AS PER PROCEDURE, TEST C-LINE TO 5000 PSI,MU HGR AND LANDING JT, DROP BALL, TEST C-LINE TO 5000 PSI,LAND TUBING, RILDS,PREsSURE UP TBG TO 2500 PSI TO SET PKR, HOLD PRES F/10 MIN, PRES ANNULUS TO 1000 PSI WHILE HOLDING PRES ON TBG F/10 MIN, BLEED OFF ANNULUS PRES BOLDS PU/SHR PBR @ 101K# W/1300 PSI LEFT ON TBG, BLEED OFF ALL PRES,RELAND TBG, RILDS,PRES TBG/ANNULUS TO 1000 PSI,CLOSE SSSV, BLEED TBG TO 450 PSI TO TEST SSSV, OK, EQUALIZE PRES,OPEN SSSV, PRESS CSG TO 2580 PSI F/15 MIN, LOST 25 PSI,HOLD ANNULUS PRES AND SHEAR BALL W/4400 PSI ON TBG, BLEED OFF ALL PRES, SET BPV, ND BOPE,NU TREE, TEST TREE TO 250/5000 PSI DISPLACE ANNULUS WITH 12 BBLS DIESEL, BULLHEAD DOWN TBG W/4 BBLS DIESEL, BLOW DOWN LINES,SECURE WELL, SICP-0,SITP-250 RELEASE RIG AND MOVE TO 2M-16 AT 2300 HRS 9-23-91 DAILY:S175,455 CUM:$1,438,166 ETD:S1,438,166 EFC:$1,570,000 SIGNATURE: ~ DRILLING SUPERI~ND~:N'T' DATE: RECEIVED JAN 4 t99 . Oil & Giis Con;. (;ommis;ion Anchorage eeeeeeeeeeeee eeeee eeeeeeee N.T.~. t. BASIS OF 40Q.4rlON AND E'L~'¥,4TION 3.. O00~OtNa~$ SHOWN &NE 4 5,94a, 90~.9 I 4~?, NO. Y ~ 5, 940~ 905.9~ S 5~ ~Aa, 000. ~$ I0 J, 940,00~.04 II 5~Q40, 985. 9~ 400, /4 5, 940,000.~ 400, t$ ~,940,~059~ 400,/69.~ I$ ~,940~ 90~94 /? ~4~,~0~.00 !0 ~,940,905~ 400, · ~ 5,940, O0~?~ 40O, L ONe. 1~,'~ L. /$0~0S'$1~. S~'X " //,l ' / / / ' ~.0' /~0e00'0~.$$~" 1t4 ' 0~' I01.0' /50~O$'$g. a09" 1t4' ~/' I~.0' /iOeOS'8i.~ " / / ~' ~' I01.0' /~0e 0~' E~5~ ~ / / ~ ' / / ' I~.0' /~Oe Oi'i].~30 " / / ~ ' /~ ' I~.~' IOOeOO'O~. 17~" /i4 ' $4' I00.8' /~OeO~'~/.~$O'' //4' ~' /~OeO~'$O,~aO" //~' //4 ' ~0.~' /SOeOS'~.~4' //4 ~ /~' I00.~' t 00e 00'$~.~04 " t14 ~ i ~0~ 00,4~5;4 , 1f4' I 0~' I~.~' 150~0~.~1~ ~ i /~' ~' ~00.~' I~0~00'40.108" t14' $~' ~.~' / O0~ 0~'4~. 7~ ~ I t · ' ~84' I~.t' I$0~'00'4/.S$4" / 14 ' 4R$' 99.9' IO~e O~'~ /~ " 114' OP~' 99.4' PAD 104.9 104.9 104.9 105.0 105.0 108, I 105.2 105.3 105.4 108.~ '108.~ 105,8 I0~. ~ I0.~ .~1 105,6 105.e log. ? 105.? 105.6' ~ 108,4' ~0~ .0' ~o4,~ AND THAT THIS PLAT RE~E$ENT$ ARCO AI,.A~KA, lNG, OWO W~ H,,~)K' tMOO'¢ EA'DRMX, 6E I3 D ? Or/Il SUe ~' M Con#u G! ors /- ~$ As-Built & ASS()CIAI[S. ~:(., l~ ,~f~[ U~., ..(?. ~ .. :. 5~ / o~ i Ol lGl l. S J, ~" '," 8 y ARCO ALASKA .'.'NC, f,¢~F¢T~ SLOPE =n:,~i~ ', *~',,',' Date Run: OB-APR-9i 12:14:22 Job N,.imbm': Af<049182i7 Surveym': TOM STODDARD Azi~mtfi;hs are Relative to TRUE [~OF:TH Ciosu~'m Calculated from Weii Head Location RECEIVED JAN ~ 4 t~g~ Alaslm 011 & 6es Coos. Commie`sion ., Anchorage A Gyrodata Di rec t iona i Fi~.e NEA8 !NCL AZIMUTH ?ERT 290;0 300:0 400~ 0 500,0 600:0 700,0 800:0 900,0 !000,0 !200:0 1300,0 !40{),0 1500:0 1600.0 i800:0 ] 900, 0 2000,0 2i00:0 2200.0 2500:0 2400,0 ~4.07 14,91 i7~82 20,00 30.64 39.86 36:69 · _, ; =., : : 00 77 f)~ ~o 98 84~48 84., 94 82.84. 80,00 79, i2 79,48 77 ~i 76.27 78,05 79,54 ~n v6 83,40 62.92 77.68 7i:86 DEPTHS !00,0 200:0 300:0 399,9 499,3 695,2 792. i 982, 6 1075, 8 ii68,0 1546,0 i430,2 i5ii.1 15%5 1669,7 !749,o 1827,4 !9o4,4 1982,9 2i46,8 feet 00 h) OQ P' .c."-FXm-h, ~- TO F:: },','. B, .i6 N .21 E .50 N i.54 E 75.07 ~i 4:2.47: 85, 46 N 472, 38 E 93, ~9 N 532, % E 111,66 N 654,46 E 125,;7 N 716,8! E !40:97 N 776,71E ~q~ ~ ~: 832,4! E 175,8~ N 885,8~ E VERT SECTION iv ,2 .9 1,6 !5,5 79,5 107, 2 i39,.5. 175,; 215.9 256, 3 304,5 358, 4 4!6,8 477.2 537,7 597, 7 A59, 7. 723.0 784.9 843, 2 899. ,I SEVERITY 4-- .'! ,'q*. ' .1,0 .10 4.37 2.96 '? 9f 2,46 ~ ~'i ~ ~7 l.a2 2, 04 ARCO ALASKA iNC. F-.' o~.u.,.~,.'.,' m'r:.,'~., '..'.~,? ...... NO, NORTH SLOPE ~-n:'O~,~' ALASKA Job Number: AK04:7i8217 Directional Survey MEAS i NCL AZ i P;UTH VERT ft deq ~ ¢-'- ~,.?.,v, 0 33141 7!, 71 2230. '::"<'":'" 0 ":'..-r 27 '72 ~i? .'?.-:-: .',' 2700~ 0 32.67 73,92 2397. 3000.0 34.69 78.82 2649.7 3200.0 33.48 78.84 28i5. i 3400.0 34.08 78.40 298 i. 2 5500, 0 34.23 78,77 ...064, 0 · '5600, 0 .:,4.27 78.85 3146, 6 3700, 0 34,25 78:48 3229.3 3800.0 ::4,, 47 .':'/8 ~.':] ........ :..-'- i i. 8 3900.0 34.51 78, 29 3594.3 4,nnn..,..,...,, n.. 34.6! 77.84 ~' ' ~i00.,'..':' --r.a ~ '7~ ?'. 3558.8 .:%-,,:-n 35,06 ?~ Az :fin o ....... ~, !9 , ,.: ..,~ <.: =.,...:, 44--,:"..,-~'~ 0 :'=' ":"-'=: ..... ; 3804,3 4500, 0 35.24 77:70 ,]';,886: 0 :Ann ;: 34 z: 78,, 64 3968, 2 4900.0 x? P.A o:; ¢:= 4220.0 HORIZONTAL COORDINATES feet 209.91N 990.53 E 225.67 N I042.61E 240.75 N 109;.95 E 2= .... I~= 54 ~.~ N i',~. E 267.65 N 1199.68 E 278.28 N i255.;5 E 288.76 N i510.16 E ~i0.76 N !4!9.~5 E ~,~?~, 87 N 1474.58 ...... ;~ N 1529,58 34;:85 N !584.78 555.16 N i640.08 366~60 ~ .,m~ ~ ~o0 ~: N ~806 6~ ~ 402:!0 N i862,64 E 426,84 N ~975, i6 E 438:99 N 2r~]i ~* 450:68 N 208%38 E ~6e ~8 N ~,..~ ~,-~ .... £,¥.:/u S SECTION ft 954.5 1009:4 1063.8 1117..5 i !70.9 !282.8 1558.5 '~9Z 6 1449.5 i56!.2 !6!7.5 !67L5 !786.5 !900.~ !957.7 2015.2 2072, 7 '"]., i OO & 2i84.3 229!. 5 DOS-LE~ SEVERITY dee'!On' !. 09 2, 02 ,09 ARCO a~ a:'Fa !NC, k'ii.E'&'.F.,i!k." ~(~.VFR iiNTT i4ELL "~ '?' ,""- - '-.' ~ NORTH SLOPE mnRnLinm~ ALASKA ,~d. mber: AK04918217 A By.no-4 Dirmctional S u p ;./ 8 y F'ag~ !flEAS iNCL A7 ~:,'".~u DEPTH ft deg · 5 ! 00, 0 32, S5 77, 48 4~88, 4 5200,0 32.53 77, 91 4472, 6 5300, 0 ;2, .4 ~ 77,82 4557, 0 5400,0 ..:? 4a 76,85 4641,4 5700.0 ..., ~ ,'~ .~ o,,~6'~,, 53 4896, 0 -' ~ 6q-',,":'-' 4980,8 5900.0 32, 03 68,80 506,5.6 ~.~ 7,' .... 5572. 31:7'-" 30.05 6% 51 59! ). HOR : ZONTAL ,-'OnRD i NARES 488,71 N 2701,0& 5i i~ 86 N 2406, 27 523,15 N 2458,75 , "'~ 1 Q7 548,74 N 2562,46 E 565,49 N 2612,46 E 58¥,76 N 266!,95 E 602,38 N 27!1,48 E ~, ~a N 2760,98 E 73% 80 N 5060, 09 E 7A.a 28 ~: 'r~,-,c, r..-., r 780,77 N 3i59,74 E 800, 92 N 3209, 0~ E 8i%57 N 3256, B7 E 869.20 N 3393.53 E 884,53 N 34X~,~,',; ·. - ~,.~ ~ VERT SECTION ft 2345,5 2399,0 2452,7 2506, T 2559,8 26!5,0 27i8,~ 2771.i 2876, 9 2930,2 2o8-~ :<).T7, i 3090,7 3251,5 · 7..405, 4 5454,2 350.0, 8 5565.5 1,63 ,26 Directional S urvey p. - MEAS iNCL AZIMUTH VERT D~T~ - ..... DEPTH ¢~,, deg deg ft HOR i ZgNTAL ~nnRDiN~TE~ feet VERT S~rTTO~ ft DO6-LEB SEVEEITY dpt, l !FW] ' Final Station n~ ...... p, ~= ~ feet 75.~s~ degrees i <KB> 560' 7200 '1! i ARCO' 'ALASKA', TNC,. ', i i ii -!"~ ~' -i :,' ,-;-~ ...... ~: !-i, ~:.- Section at: N73.55 E ;'"'~" ' ........ TYD Scale ~ ~nch = 800 feet ...... :.- BeD Scale · ~ ~nch - 800 fee~ ..... ; ~ ' : ' '"';-' Harken Zdenttf~cak~on ~ TVD SECTH INCH ~:;'' ~' ':''~ BJ 9 5/6' CAS3N6 3S5a 2775 i3S~ 3a.90 ~.~' ',j~'.[ C) ~ 7337 6296 ~6S aG,aO ......... ~--'~ ............. ~ D) 7' CASIN6 . 7~7 ~77 3605 a6.a5 ~ ' ~ .... ~ , %; ....... I ' f ' ' ' , . I ~.. . ~ - ,. , ', . 1~. :. '- !~-- ~ X~ '--~ ..... ~600 a400 aaoo 4000 Sect ~on Departure i i /V Harkm' Zden~lfic.tlon ND N/S E/id A! KB 0 ON o1~ BJ 9 5/8"' CASZNG 3i52 2B4 N i284 E C) PBTD 7337 890 N 345! E DJ 7"' CASZNG 7427 903 N 348B E E} EXTRAPOLATED 'rD 7445 906 N 3496 E ® ARCO ,AL'A,..SKA , INC. ii 2M-25 API50-t03-20152 PLAN VIE ~CLOSURE ..... · 36i! ft N 75.46 E DECLZNATZON.: 0.00 E SCALE. · ! inch = 700 feet DRANN ...... : 05/07/9~ i400 2iOI I . ,, ,, ,,,-~.~:,!- ~. ~ ... , : .- ~.;: .... ~ : ..... ' "'-+--' 'f ; ' ' ' i · : t [ ! : : ~ ~ i ::::!:i : i:;: ::;: :. 'I' ' ,, ... ._~ ..... :.: .... , .... , ;,:. I:..: t. i . : :- : --- i--.::. ~. : : ~ ' ' ' ~ . ~ · J~r, : ~ . ; :;~: '-. 'j, ,: ~ · :::.' ., : . -. :, : .' , ._~_.~.: . .' . . ~ , . . ~ - . J : ; , _ , ..... i _,] , , , . . =. - ' ....... ~ ~ ~ ' '~ .................. h ........................... i ........................... ; ............... 7'- 0 700 1,400 2J, O0 2600 3500 <- #EST: F/ST -> i i ii i i i i i by GREAT LAND DIRECTIONAL DRILLING, INC. for GyroData Incorporated 05/07/91 Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT Well ...... : 2M-25 API50-103-20152- Section at: N,73.55,E Engineer..: TOM STODDARD Computation...: RADIUS OF CURVATURE Survey Date...: 04/08/91 RKB Elevation.: 140.00 ft Reference ..... : 0491G217 INTERPOLATED MARKERS REPORT Surface Location: 114 FSL 579 FWL S27 T11N RSE MARKER IDENTIFICATION 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUKA BASE KUPARUKA PBTD 7" CASING EXTRAPOLATED TD MEAS INCLN VERT-DEPTHS SECT DEPTH ANGLE BKB SUB-S DIST 0 0.00 3152 33.90 7036 29.39 7048 29.27 7065 29.09 7220 26.69 7337 26.20 7427 26.25 7445 26.25 DIRECTION REL-COORDINATES BEARING FROM-WELLHEAD 0 -140 2775 2635 6029 5889 6039 5899 6054 5914 6191 6051 6296 6156 6377 6237 6393 6253 0 N- 0.00 E 1312 N 79.16 E 3423 N 70.17 E 3429 N70.18 E 3437 N 70.19 E 3510 N 69.93 E 3561 N 70.23 E 3601 N 70.32 E 3609 N 70.32 E ON 0 E 284 N 1284 E 843 N 3321 E 845 N 3326 E 848 N 3334 E 872 N 3402 E 890 N '3451 E 903 N 3488 E 906 N 3496 E ~REAT LAND DIRECTIONAL DRILLING, INC. ~lient .... : ARCO ALASKA, INC. ~ield. .... : KUPARUK RIVER UNIT ~ell ...... : 2M-25 API50-103-20152 ~ection at: N,73.55,E ~ngineer..: TOM STODDARD 05/07/91 Computation...: RADIUS OF CURVATURE Survey Date...: 04/08/91 RKB Elevation.: 140.00 ft Reference ..... : 0491G217 MEAS INCLN DEPTH ANGLE 100 0.30 200 0.45 300 0.41 400 3.82 500 8.19 ' 600- 11.85 ' 700 I4.07 ' 800 14.91 ' 900 17.82 ' 1000 20.00 RECORD OF SURVEY VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD 100.0 - -40.0 0.2 N 52.37 E 0.2 N 0.2 E 200.0 60.0 0.9' N 77.05 E 0.4 N 0.8 E 300.0 160.0 1.6 N 88.98 E 0.5 N 1.5 E 399..9 259.9 5.2 N 84.48 E 0.7 N 5.2 E 499 . 3 3'59.3 15.5 N 84.94 E 1.7 N 15.6 E 597.8 457.8 32.5 N 84.61 E 3.3 N 33.0 E 695.2 555.2 54.6 N 83.12 E 5.7 N 55.3 E 792.1 652.1 79.3 N 82.84 E 8.7 N 80.1 E 888.0 748.0 107.2 N 80.99 E 12.7 N 108.0 E 982.6 842.6 139.3 N 80.00 E 18.1 N 139.9 E CLOSURE DL DISTNCE BEARING '/190 0.3 N 52.36 E 0.30 0.9 N 61.17 E 0.15 1.6~ N 71.03 E 0.04 5.3 N 81.94 E 3.41 15.7 N 83.77 E 4.37 33.1 N 84.29 E 3.66 55.5 N 84.12 E 2.22 80.6 N 83.76 E 0.84 108.7 N 83.28 E 2.91 141.1 'N 82.64 E 2.18 1100 22.44 1200 23.18 1300 27.18 1400 30.64 1500 34.70 1075.8 935.8 175.3 N 79.12 E 24.6 N 175.5 E 1168.0 1028.0 -213.9 N 79.48 E 31.8 N 213.6 E 1258.5 1118.5 256.3 N'77.21 E 40.4 N 255.3 E 13'46.0 1206.0 304.5 N 76.27 E 51.5 N 302.3 E 1430.2 1290.2 358.4 N 78.05 E 63.5 N 354.9 E 177.3 N 82.01 E 2.44 216.0 N 81.52 E 0.74 258.5 N 81.00 E 4.03 306.7 N 80.33 E 3.47 360.6 N 79.85 E 4.10 1600 37.19 1700 37.71 '1800 37.64 1900 37.31 2000 39.48 1511.1 1371.1 416.9 N 79.54 E 74.9 N 412.5 E 1590.5 1450'.5 477.3 N 80.76 E 85.3 N 472.4 E 1669.6 1529.6 537.7 N 83.40 E 93.7 N 533.0 E 1749.0 1609.0 597.7 N 82.92 E 101.0 N 593.4 E 1827.4 1687.4 659.3 N 77.68 E 111.4 N 654.6 E 419.3 N 79.70 E 2.55 480.1 N 79.76 E 0.69 541.1 N 80.02 E 0.99 601.9 N 80.34 E 0.37 664.0 N 80.33 E 3.03 2100 39.86 1904.3 1764.3 723.0 N 77.53 E 125.1 N 716.9 E 727.8 N 80.09 E 0.38 Survey Codes:' 7/GYRO 2M25 B1.21) 2M-25 API50-103-20152 RECORD OF SURVEY MEAS INCLN DEPTH ANGLE 2200 36.69 2300 34.79 2400 33.54 2500 33.41 2600 33.27 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD 1982.8 1842.8 784.9 N 73.13 E 140.8 N 776.8 E 2064.0 1924.0 843.3 N 71.86 E 158.4 N 832.5 E 2146.7 2006.7 899.4 N 72.13 E 175.7 N 885.9 E 2230.2 2090.2 954.6 N 71.71 E 192.8 N 938.4 E 2313.7 2173.7 1009.5 N 72.42 E 209.8 N 990.7 E ? 2700 32.67 2397.6 2257.6 ? 2800 32.01 2482.1. 2342.1 ? 2900 32.82 2566.5 2426.5 7 3000 34.69 2649.6 2509.6 7 3100 34.36 2732.0 2592.0 1063.9 N 73.92 E 1117.4 N 73.31 E 1171.0 N 75.31 E 1226.5 N 78.82 E 1282.9 N 79.51 E 225.5 N 1042.7 E 240.6 N 1094.1 E 255.1 N 1145.7 E 267.5 N' 1199.8 E 278.2 N 1255.5 E 3200 33.48 2815.0 2675.0 1338.4 N 78.84 E 288.7 N 1310.3 E 3300 33.91 2898.2 2758.2 1393.7 N 78.61 E 299.5 N 1364.7 E 3400 34.08 2981.1 2841.1 1449.4 N 78.40 E 310.7 N 1419.5 E 3500 34.23 3063.9 2923.9 1505.3 N 78..77 E 321.8 N 1474.5 E 3600 34.27 3146.5 3006.5 1561.3 N 78.85 E 332.7 N 1529.7 E 3700 34.25 3229.2 '3089.2 1617.4 N 78.48 E 343.8 N 1584.9 3800 34.47 3311.7 3171.7 .1673.6 N 78.40 E 355.1 N 1640.2 3900 34.51 3394.2 3254.2 1730.1 N 78.29 E 366.5 N 1695.7 4000 34.61 3476.5 3336.5 1786.6 N 77.84 E 378.2 N 1751.2 4100 34.74 3558.7 3418.7 1843.3 N 78.21 E 390.1 N 1806.8 4200 35.06 3640.8 3500.8 1900.4 N 77.63 E 402.0 N 1862.8 4300 35.19 3722.6 3582.6 1957.8 N 77.38 E 414.5 N 1918.9 4400 35.25 3804.2 3664.2 2015.3 N 78.00 E 426.8 N 1975.3 4500 35.24 3885.9 3745.9 2072.8 N 77.70 E 438.9 N 2031.7 4600 34.29 3968.1 3828.1 2129.7 N 78.64 E 450.6 N 2087.5 4700 32.56 4051.5 3911.5 2184.5 N 80.54 E 460.6 N 2141.7 E 'Survey Codes: O/UNKNOWN 7/GYRO Page 2 05/07/91 . CLOSURE DL DiSTNCE BEARING / 100 789.5 N 79.72 E 3.54 847.4 N 79.22 E 1.94 903.2 N 78.77 E 1.25~ 958.0 N 78.38 E 0.18 1012.6 N 78.04 E 0.26 1066.8 N 77.79 E 0.74 1120.2 N 77.59 E 0.68 1173.7 N 77.44 E 1.00 1229.3 N'77.42 E 2.19 1285.9 N 77.50 E 0.40 1341.7 N 77.57 E 0.90 1397.2 N 77.61 E 0.44 1453.1 N 77.65 E 0.18 1509.2 N 77.68 E 0.19 1565.5 N 77.72 E 0.05 1621.8 N 77.75 E 0.12 1678.2 N 77'. 78 E 0.22 1734.8 N 77.79 E 0 05 1791.6 1848.4 N 77.81 E 0.18 1905.7 N 77.81 E 0.37 1963.2 N 77.80 E 0.15 2020.9 N 77.80 E 0.22 2078.6 N 77.80 E 0.10 2135.6 N 77.81 E 1.00 2190.6 N 77.85 E 1.82 ~M-25 API50-103-20152 RECORD OF SURVEY MEAS INCLN DEPTH ANGLE 4800 32.64 4900 32.86 5000 32.52 5100 32.65 5200 32.53 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD 4135.8 3995.8 2237.9 N 80.59 E 469.4 N 2194.8 E 4219.9 4079.9 2291.6 N 80.45 E 478.3 N 2248.2 E 4304.0 4164.0 2345.4 N 77.50 E 488.6 N 2301.2 E 4388.3 4248.3 2399.1 N 77.48 E 500.3 N 2353.8 E 4472.5 4332.5 2452.8 N 77.91 E 511.8 N 2406.4 E 5300 32.41 5400 32.44 5500 31.90 5600 31.78 5700 31.91 4556.9 4416.9 2506.4 N 77.82 E 523.1 N 2458.9 E 4641.3 4501.3 2559.9 N 76.85 E 534.8 N 2511.2 E 4726.0 4586.0 2613.1 N 72.99 E 548.7 N 2562.6 E 4810.9 4670.9 2665.8 N 69.96 E 565.4 N 2612.6 E 4895.9 4755.9 2718.5 N 69.53 E 583.7 N 2662.1 E 5800 31.98 5900 32.03 6000 32.23 6100 32.44 6200 32.46 4980.7 4840.7 2771.2 N 69.27 E 602.3 N 2711.6 E 5065.5 4925.5 2824.1 N 68.80 E 621.3 N 2761.1 E 5150.2 5010.2 2877.1 N 68.56 E ' 640.6 N 2810.7 E 5234.7 5094.7 2930.3 N 68.57 E 660.2 N 2860.5 E 5319.1 5179.1 2983.8 N 68.55 E 679.8 N 2910.4 E 6300 32.48 6400 32.58 6500 32.71 6600 32.50 6700 ,32.68 5403.5 5263.5 3037.3 N 68.39 E 699.5 N 2960.4 5487.8 5347.8 3090.8 N 68.03 E 719.4 N 3010.3 5572.0 5432.0 3144.5 N 67.73 E 739.7 N 3060.3 5656.2 5516.2 3198.1 N 67.59 E 760.2 N 3110.1 5740.5 5600.5 3251.7 N 67.68 E 780.7 N 3159.9 6800 31.71 6900 30.05 7000 29.77 7100 28.73 7200 26.91 5825.1 5685.1 3304.7 N 67.90 E 800.9 N 3209.2 E 5910.9 5770.9 3355.8 N 69.51 E 819.5 N 3257.1 E 5997.6 5857.6 3405.6 N 70.15 E 836.7 N 3303.9 E 6084.8 5944.8 3454.3 N 70.22 E 853.3 N 3349.8 E 6173.3 6033.3 3500.9 N 70.02 E 869.1 N 3393.7 E ' 7300 25.81 6262.9 6122.9 3545.2 N 69.58 E 884.5 N 3435.4 E 'Survey Codes: 7/GYRO Page 3 05/07/91 CLOSURE DL DiSTNCE BEARING / 100 2244.5 N 77.92 E 0.08 2298.5 N 77.98 E 0.22 2352.5 N 78.00 E 0.92~ 2406.4 N 77.99 E 0'13 2460.2 N 77.98 E 0.17 2513.9 N 77.98 E 0.~2 2567.5 N 77.97 E 0.28 2620.7 N 77.91 E 1.21 2673.1 N 77.78 E 0.85 2725.4 N 77.62 E 0.18 2777.7 N 77.47 E 0.10 2830.2 N 77.31 E 0.14 2882.8 N 77.15 E 0.21 2935.7 N 77.00 E 0.21 2988.7 N 76.84 E 0.02 3041.9 N 76.70 E 0.05 3095.1 N 76.55 E 0.14 3148.4 N 76.40 E 0.16 3201.7 N 76.26 E 0.21 3254.9 N 76.11 E 0.18 3307.7 N 75.98 E 0.97 3358.6 N 75.87 E 1.71 3408.2 N 75.78 E 0.32 3456.8 N 75.70 E 1.04 3503.2 N 75.63 E 1.82 3547.4 N 75.55 E 1.10 ~M-25 API50-103-20152 Page 4 o5/o7/91 RECORD OF SURVEY MEAS INCLN VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES DEPTH ANGLE BKB SUB-SEA DISTNCE BEARING 7342 26.25 6300.6 6160.6 3563.6 N 70.32 E 7445 26.25 6393.0 6253.0 3609.1 N 70.32 E 'Survey Codes.: 7/GYRO X/EXTP3LPOLATED CLOSURE DL FROM-WELL-HEAD DISTNCE BEARING / 100 890.8 N 3452.7' E 3565.7- N 75.53 E 1o10 906.1 N 3495.6. E 3611.1 N 7S.46 E o'.oo !M-25 API50-103-20152 Page 5 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL o5/o7/91 IUBSEA MEAS INCLN TVD )EPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 100 240 0.43 240 0 0 N 81.82 E 0.49 N 1.10 E 200 340 1.77 340 0 0 N 87.17 E 0.5'5 N 2.30 E 300 440 5.58 440 0 0 N 84.66 E 1.05 N 8..50 E 400 541 9.70 540 1' i N 84.80 E 2.28 N 22.01 E 500 643 12.81 640 3 2 N 83.96 E 4.21 N 42.14 E 600 746 14.46 740 6 3 N 82..99 E 7.06 N 66.55 E 700 850 16.36 840 10 4 N 81.91 E 10.52 N 93.39 E 800 955' 19.01 940 15 5 N 80.44 E 15.50 N 125.07 E 900 1061 21.50 1040 21 7 N 79.46 E 21.93 N 161.34 E 1000 1170 22.95 1140 30 8 N 79.37 E 29.62 N 201.91 E 1100 1279 26.35 1240 39 10 N 77~68 E 38.39 N 1200 1393 30.40 1340 53 14 N 76.33 E 50.66 N 1300 1512 35'00 1440 72 19 N 78.22 E 64.89 N 1400 1636 37.38 1540 96 24 N 79.98 E 78.80 N 1500 1763 37.66 1640 123 26 N 82.41 E 90.89 N 1600 1889 37.35 1740 149 26 N 82.97 E 100.11 N 1700 2016 39.54 1840 176 28 N 77.65 E 113.64 N 1800 2146 38.40 1940 206 30 N 75.50 E 131.88 N 1900 2271 35.35 2040 231 25 N 72.23 E 153.17 N 2000 2392 33.64 .2140 252 21 N 72.10 E 174.35 N 2100 2512 33.39 2240 272 20 N 71.79 E 194.88 N 2200 2631 33.08 2340 291 20 N 72.89 E 214.90 N 2300 2750 32.34 2440 310 19 N 73.61 E 233.08 N 2400 2869 32.56 2540 329 18 N 74.68 E 250.71 N 2500 2988 34.47 2640 348 20 N 78.40 E 266.23 N 2600 3110 34.27 2740 246.19 E 298.90 E 361.66 E 434.17 E 510.27 E 586.56 E 664.74 E 745.12 E 816.49 E 881.66 E 944.52 E 1007.06 E 1068.68 E 1129.23 E 1193.29 E 370 21 N 79.44 E 279.19 N 1260.82 E !M-25 API50-103-20152 Page DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL o5/o?/91 ~UBSEA MEAS INCLN )EPTH DEPTH ANGLE BKB 2700 3230 33.61 2840 390 20 N 78.77 E 291.90 N 2800 3350 33.99 2940 410 20 N 78.50 E 305.11 N 2900 3471- 34..18 3040 431 21 N 78.66 E 318.61 N 3000 3592 34.26 3140 452 21 N 78.84 E 331.84 N 3100 3713 34.28 3240 473 21 N 78.47 E 345.24 N MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 3200 3834 34.48 3340 494 3300 3956 34.56 3440 5'16 3400 4077 34.71 3540 537 3500 4199 35.06 3640 ,559 3600 4321 35.20 3740 581 3700 4444 35.24 3840 604 3800 4566 34.61 3940 626 3900 4686 32.79 4040 646 4000 4805 32.65 4140 665 4100 4924 32.78 4240 684 4200 5043 32.57 4340 703 4300 5161 32.57 4440 721 4400 5280 32.43 4540 740 4500 5398 32.44 4640 758 4600 5517 31.88 4740 777 4700 5634 31.82 4840 794 4800 5752 31.94 4940 812 4900 5870 32.01 5040 830 5000 5988 32.20 5140 848 5100 6106 32.44 5240 866 5200 6225 32.46 5340 1326.53 .E 1392.'27 E 1458.60 E 1525.36 E 1592.14 E 21 N 78.36 E 21 N 78.04 E 22 N 7'8.12 E 22 N 77.63E 22 N 77.51 E 358.99 N . 1659.23 E 372.99 N 1726-55 E 387.39 N 1794.11 E. 401.91 N 1862.25 E 417.15 N 1930.96 E 22 N 77.86 E 22 N 78.32 E 2O N 80.28 E 19 N 80'. 58 E 19 N 79.74 E 432.05 N 446,. 76 N 459.33 N 469.83 N 480.53 N 2000.00 E 2068.65 E 2134.40 E 219'7.51 E 2260.98 E 19 N 77.49 E 19 N 77.74 E 19 N 77..83 E 18 N 76.86 E 18 N 72.49 E 493.60 N 507.39 N 520.79 N 534.62 N 551.. 25 N 2323.61 E 2386.10 E 2448.39 E 2510.39 E 2570.94 E 18 N 69.81 E 18 N 69.39 E 18 N 68.94 E 18 N 68.59 E 18 N 68.56 E 571.62 N 593.34 N 615.51 N 638.25 N 661.38 N 2629.55 E 2687.87 E 2746.25 E 2804.69 E 2863.60 E 885 19 N 68.51 E 684.63 N 2922.79 E 2M-25 API50-103-20152 Page 7 05/07/91 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB 5300 6343 32.52 5440 5400 6462 32.66 5540 5500 6581 32.54 5640 5600 6699 32.68 5740 5700 6818 31.42 5840 5800 6934 29.95 5940 5900 7049 29.26 6040 6000 7163 27.59 6140 6100 7275 26.09 6240 6200 7386 26.25 6340 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 903 19 N 68.23'E 708.07 N 2981.99 E 922 19 N 67.84 E 731.99 N 3041.27 E 94I 19 N 67.61 E 756.28 N 3100.54 E 959 19 N 67.68 E 780.60 N 3159.63 E 978 18 N 68.18 E 804.28 N 3217.73 E 994 16 N 69.72 E 825.34 N 3272.80 E 1009 15 N 70.18 E 844.83 N 31326.44 E 1023 14 N 70.09 E 863.27 N 3377.60 E 1035 12 N 69.69 E 880.58 N 3424.94 E 1046 11 N 70.32 E 897.31 N 3470.98 E ~-25 API50-103-20152 Page 8 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 05/07/'91 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING 1000 20.00 983 843 139 N 80.00 E 2000 39.48 1827 1687 659 N 77.68 E 3000 34.69 2650 2510 1226 N 78.82 E 4000 34.61 3477 3337 1787 N 77.84 E 5000 32.52 4304 4164 2345 N 77.50 E DL/ 100 18 N 111 N 268 N 378 N 489 N mmm mmmmmm mmm 140 E 141 N 82.64 E 2.2 .655 E 664 N 80.33 E 3.0 1200 E 1229 N 77.42 E 2.2 1751 E 1792 N 77.80 E 0.2 2301 E 2353~'N 78.00 E 0.9 6000 32.23 5150 5010 2877 N 68.56 E 7000 29.77 5998 5858 3406 N 70..15 E 641 N 837 N 2811 E 2883 N 77.15 E 0.2 3304 E 3408 N 75.78 E 0.3 AOGCC GEOLOGICpL MATERIALS INVENTORY LIST PERMIT # C~ ~ -. ,~, ~ WELL NAME ~, ~-.iX. ~ ~- ~ COMPLETION DATE ~ t 2'~ ! ~1 CO, CONTACT check off or list data as it is received;list received date for 407. if not required list as NR 407 t'* ]J?_kl J~[" r, drJllJnQ~ histoly / surVey]~ J weilteSts 0 I core descriPtlodN~ Co[cd int~wa~s core analysis U~ d~ ditch intCwals digital 'data. ..... ~~ %~~ ~C~o.~ LOG TYPE ' RUN ' INTERVALS 'SCALE NO. (to, the nearest foot] lin,chi1 O0~l i i 7) Ce.-~ Iprc, I .su.t¢,u. - 5tc~ :~ ,, ii i i i i i 141 ... i i ARCO Alaska, Inc. Date: September 13, 1991 Transmittal #: 8223 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of this transmittal. ~[ {~ ---1A-23~ 1A-23< 1A-23x' Receipt Tracerscan Pulsed Spectral Gamma Log Pulsed Spectral Gamma Log Cased Hole Extra Long Spaced Fullwave Log Cased Hole Spectra Gamma Log Cased Hole Fullwave Acoustic Log Tracercheck Log Tracercheck Log Cement 'Bond Log Cement Evaluation Log Cement Evaluation Log Cement Bond Log 7-1 5-1 5-1 5-1 5-1 5-1 7-1 7-1 5-1 5-1 8-2 8-2 8-2 8-2 Cement Evaluation Log 8- 2 Cement Bond Log i 8 - 2 Acknowledge- - .......... Please acknowledge receipt and 6-91 5-91 5-91 5-91 5-91 5-91 6-91 9-91 5-91 5-91 7-91 7-91 7-91 7-91 8-91 8-91 ...... Date: 6900-7300 6800-7350 6800-7350 6800-7350 6800-7350 6800-7350 6900-7300 6900:7300 6900-7300 6900-7300 '8500-10092 8500-10113 10000-11198 10000-11178 5990-7334 5990-7314 Drilling State of Alaska(+sepla) NSK RECEIVED $£P 1 61991 Alaska O# & Gas Cons. Commiss~o. Anchorage ARCO Alaska, Inc. Date: June 7, 1991 Transmittal#: 8126 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of this transmittal. qO-tSt 1A-17 Acoustic Cement Bond Log Acoustic Cement Bond Log Acoustic Cement Bond Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Pulse Echo. Cement Evaluation Log After Squeeze 4-8-91 4-5-91 1-19-91 4-6-91 4-8-91 1-19-91 4-24-91 Please acknowledge receipt and 4529-7334 72-3430 5700-8140 27-3431 4424-7333 5700-8116 7000-8375 Receipt Drilling Acknowledge' St~Pia) ARCO Alaska, Inc. .~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 SAMPLE TRANSMITTAL TO: State of Alaska Oil & Gas Conservation Comm. 3001 Porcupine Dr. Anchorage, Ak. 99501 Attn: John Boyle OPERATOR: Arco DATE: 5-31-91 AIRBILL fl: AL510109 AFTfl: 01-05-3 1-36 CHARGE CODEfl 18511 NAME: PBU 2-29A SAMPLE TYP SAMPLES SENT: NUMBER OF BOXES: 3 9595'-9631' Box #1 9632'-9672' Box /t2 9673'-9686' Box #3 SENT BY: Dan Przywojski UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ArcoAlaska, Inc. P. O. Box 100360 Anchorage, AK. 99510 Attn: ABV-100 RECEIVED BY: ,DATE: ARCO Alalke, Inc. ita Subsidiary of AllanllcRichlleldCompany AR3B-6003-C ARCO Alaska, Inc. Date: April 19, 1991 RETURN TO: Transmittal #: 8072 ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Cle~_ ATO-1119 __ P~OTBb~(~-00360 Anchorage, AK.' 99510-0360 Transmitted here with are the following items. Please acknowledge 'receipt and return one signed copy of this transmittal. 2M-25 LIS Tape and Listing(Colville) 4- 1 0- 91 AKMM910310 2M-25 LIS Tape and Llsting(Kuparuk) 4-8- 9 1 AKMM910310 Receipt Acknowledged: ~ .... Date: .......... DISTRIBUTION: Lynn Goettinger State of Alaska R£CEIV£D APR 2 2 ~ ~ , ~aska Oil & C~as C-~ ,~ ARCO Alaska, Inc. Date: April 19, 1991 Transmittal #: 8070 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 2 M - 1 6 Compensated Neutron-Litho- 4 - 9 - 91 1 1 4- 2 9 0 0 Densily Raw Data 2 M - 1 6 Compensated Neutron-Litho- 4 - 9 - 9 1 1 1 4- 2 9 0 0 Density Porosity 2 M - 1 6 Dual Induction-SFL 5" Phasor 4 - 9 - 91 1 1 4- 2 9 2 8 2 M - 1 6 Dual Induction-SFL 2" Phasor 4 - 9 - 91 1 1 4- 2 9 2 8. 2 M - 1 6 Array Sonic with Waveforms 4 - 9 - 9 1 1 1 4- 2 91 0 2 M - 2 5 Dual Gamma Ray Electromagnetic 3 - 31 - 91 3 $ 7 0- 7 4 4 5 Wave Resistivity 2 M - 2 5 Compensated Neutron Porosity 3 - 31 - 91 3 3 7 0- 7 4 4 5 Simullaneous Formation Density 2 M - 2 5 Dual Gamma Ray Electromagnetic 3 - 31 - 91 2 9 5 9- 6 4 0 2 Wave Resistivity 2 M - 2 5 Dual Gamma Ray Electromagnetic 3 - 31 - 91 2 9 5 9- 6 4 0 2 Simultaneous Formation Density Receipt Acknowledged: ,~~-'~~ ..... Date: DISTRIBUTION: ~ D&M Drilling NSK Franzen ~,tate o(&!aska(~Sepla) Vendor Package(Johnston) ARCO Alaska, Inc. Date: April 5, 1991 Transmittal #: 8059 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 2M-25 3-25-91 0-3163 2 M - 2 5 High Resolution DSL Log 5" 3 - 2 5 - 91 0 - 31 6 3 2 M - 2 5 High Resolution DFL Log 2" 3 - 2 5 - 91 0 - 31 6 3 2 M - 2 5 Spectral Density Dual Spaced 3 - 2 5 - 91 0- 31 6 3 Neutron Raw Data Log Spectral Density Dual Spaced Neutron Porosity Log 2 M - 2 5 Spectral Density Dual Spaced 3 - 2 5 - 91 0 - 31 6 3 Neutron High Resolution Pass Receipt Acknowledged' ~-~ Date' - ......... DISTRIBUTION: D&M NSK Drilling Franzen State of Alaska~Pia) Vendor Package(Johnston) ARCO Alaska, Inc. Date: April 5, 1991 Transmittal #: 8060 RETURN TO: T0t~ran~\smitted here with are the following items. one signed copy of this transmittal. ~~ 1L-14 LIS Tape and Usting ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Please acknowledge receipt and return Receipt 3-12-91 3-12-91 LIS Tape and Usting 3- 2 5- 91 LIS Tape and Listing Acknowledged' ~~ Lynn Goettinger O_iSTRIBUTION: 3536.5-6475 920-6482 92-3185.5 Date: .......... State RECEIVED APR 9 1991 Alaska 0il & 8as Cons. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION March 27, 1991 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-14,33 TELECOPY: (907) 276.7542 Re: Kuparuk River Unit 2M-25 Revised ARCO Alaska, Inc. Permit No. 91-21 Sur. Loc. ll4'FSL, 579'FWL, Sec. 27, TllN, R8E, UM Btmhole Loc. 1155'FSL, 1177'FEL, Sec. 27, TllN, R8E, UM Dear Mr. McBride: Enclosed is the approved revised appliCation for permit to drill the above referenced well. The provisions of the cOver letter dated February 20, 1991 accompanying the original approved permit are in effect for this revision. Alaska Oil an Gas Conservation Commission dlf Enclosures Department of Fish & Game, Habitat Section w/o encl. Department of. Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office B~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 27, 1991 Mr. Lonnie Smith Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith' SUBJECT: RevisedApplication for Permit to Drill KRU Field Well 2M-25 Attached is a revised application for a Permit to Drill for well 2M-25. Prior approval was for drilling only the surface hole on 2M-25 and completing the well as a temporary disposal well. However, a problem was encountered while pumping the surface cement job on 2M-25 which resulted in the higher compressive strength tail cement not covering the proposed injection interval. Therefore, ARCO Alaska, Inc. requests permission to continue drilling 2M-25 as a normal Kuparuk producing well and not attempt to complete 2M-25 as a temporary disposal well. Another 2M well will be proposed for use as the temporary disposal well for 2M pad. Thank you for your assistance in this matter. Sincerely, A. W. McBride Area Drilling Engineer RECEIVED 41aska Oil.& Gas ~a1~,. ~.~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill -- I lb. Type of Well Exploratory__ Slratigrophto Test _ Development 011 x Re-Entry Deepen,I Service Development G~ Single Zone X Multiple Zone 2. Name of Operator $.Dalum EleVation (DF or KB) 10. Field and Pool ,ARCO. Alaska. Inc. RKB 140'. Pad 105' GL f. Qt Kuparuk River Field 3. Address 6. Properly Designation Kuparuk River Oil Pool P. O. Box i00360r Anchorager AK'. 99510-0360 ADL 255.86 ALK 2672 4. Locet~n of well at surface 7. Unit or properly Name 11. Type Bond (ese 20 AAC 25.025) 114' FSL, 579' FWL, Sec. 27, T11N, R8E, UM Kuoaruk River I,Ipit Statewide . At top of productive intarvel (TARGET) S. Well number' Number 1095' FNL, 1380' FEL, Sec. 27, T11N, R8E, UM 2M'25 ;Ravisioni #U630610 At totes depth g. Amroximme spud date Amount 1155' FSL~ 1177' FEL, Sec 27~ T11Nr R8E~ UM 24-MAR-91 $200r000 12. Distance to nearest 13. Distance to nearest Well 14. Number a~ agree in property 15. Proposed depth (MD ami TVD) property line 2M-24 (proposed) 7422' MD 1177' ~ TD feet 25' at -surface feet 2560 6334' TVD feet '16. To be completed f~ deviated wells ..... 17. Anticipated Pressure (ese 20 AAO 28.03~is)(2)) kickoff depth 300' feet Maximum hoe ancjie 34° Max;mum ,umme 1660 ~ At fetal d,pth (I'VD) 3690sig (~ 6334 18. Casing program Setting Depth size Specification Top Bottom Qua,ntit~ of cement Hole ' Casing Weight Grade CouPling Length M) TVD M), "TVD (ino!ude stage data) ' 24 16" :62..5# H-40 Weld 80.. 35' 35' 115' 115' :1:200 Cu. Ft. 12.25 9.625 36.0# J-55 BTC 3274' 35' 35' 3309' 2804' 685 Cu. Ft. AS III i i i i i ii i i HF-ERW '2 :0# J-SS' BTC' ' 35' 35' 74 2'' 334. TOp 500' a ov. Kuparuk 19. To be completed for Redrill, Re-entry, and'Deepen ~rations. " Present well condition summary Total deplh: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true verticaltrue vertical feet . Casing Length Size. Cemented Measured depth True Vertical depth Structural co. uc,o, cu.,. r ,;iV:ED cu.,. Intermediate Production L,,o, 2 7 1991 Perforation depth: measured -' ' true ve,ioal ~iaska 0il & Gas Cons, , Anch0r;~, '~"'"' 20. AttaChments Filing fee ..2;,, ProPerty pial _. BOP Sketch ~ Diverter Sketch ~ Drilling program ~ Drilling fluid program .2[. Time ye doplh plot _. Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I 'hereby certify that the 'lamgoing is true and correct to the b~t c~ my knowledge Sign. //~,~ ~ ~~ Title Area Drilling Engineer Dm. 'NUmber ' APl number '' 'Approv~J dale ' See covm' letter for I~ermic/,,t.L / _ ~ ~ 50- /~ ,~' - .~ ~/.~ ~ 0 2 / 2. 0 / 0 ~,, other recluirements Conditions. of approval Samples required ~Y e s ~ N o Mud log required__ Ye s o ' Hydrogen sulfide measures _.. Yes ~ N o ~l;)ireclional survey required ~2~'/. Yes ._ N o Required working pressure for BOPE ~2M; ~. 3M; ~ SM; ~ 10,.,, ~ I 5M by ord.' of Approv, e~~..~, .~/:~~.._//_ ~--~-~ r , Commissioner the commt_--_!on Date /')"),,~ .,q~'/ Form 10-401 Rev. 7-24-89. ~, ;plicate DRILLING FLUID PROGRAM (2M-25) Spud to 9-5/8" Drill out to Weight up surface casing weight uo toTD Density 8.6-10.0 8.6-9.6 10.6 PV 15-35 5-15 10-18 YP 15-35 5-8 8-12 Viscosity 50-1 00' 30-40 35-50 Initial Gel 5-1 5 2- 4 2 - 4 10 Minute Gel 1 5-4 0 4 - 8 4 - 8 APl Filtrate 1 0-1 2 8-1 0 4- 5 pH 9-10 8.5-9 9.0-9.5 % Solids 10 +/- 4- 7 1 0-1 2 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes' .. RECEIVED - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 1660 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 2M-25 will be 2M-24 (proposed). As designed, the minimum distance, between the two wells would be 25' at surface. The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. - The annulus will be sealed with 175 sx of'cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. [ARCO ALASKA, Inc.I Structure: Pod 2M Well: 25 Field: Kuparuk River Unit Location: North Slope, Alaska IrureOted by i jones FOR: 'r BILLINGSLEY ate plotted .' 27-Mar-91 lot Reference Is 2M-25 Version 1~4-Feb-9! oo~dinales ore In feet reference slot 125. e Vertical Depths ore reference wellhead. r-JIJ1EASTMAN I/_/JICHRISTE NSEN & ~ ~ SURFACE LOCATION; 114' FSL, 579' FWLI SiC. 27, TtlN. RK N 73 DEG 33 MINE 3463' (TO TARGET) oO. o O o (/) 120o ~ U ' - >. I 4400- . East --> 0 400 800 1200 1600 2000 2400 2800 3200 3000 I, ! ! I I I I I ! I I I I I I I I I I t I'AROET LOCATION: IOOS' ~L, t380' FELl SCC. 27. TtlN. RSE TO LOC~ON: I lt55' FSI., 1177' FELl SEC. 27, TI IN, RS[ J TARGET 'IVD-6020 11AD-7044 OEP-34.83 NORTH 981 I RKB L'UEVATION: 140' FU~'T ~321 ! ~:: KOP '~4)=300 TUO-500 ils.aa Btm. O 3 0~0/IOO FT EOC "lVD=I.,T68 'TMD=1435 DEP=326 ~ B/ PERMAFROST WD-Isgo TldO=1460 DEP=341 T/ UONU $NDS 1vo-1460 1MD-1544 DEP-589 %~X T/ W SAK SNDS WD-2025 TMD-2226 DEP-?6g · ~. B/ W SAK SANDS 1~D=2§95 TMD,,2915 D£P-115¢ g 5/8'CSG PT T~-2795 TMD-51$¢ DEP-1289 K-lO WO-2870 x, AVERAGE ANGLE 33 OEO 59 MIN -4360 TM?=50¢2 0EP=2344 · . ?A~¢~ - T/ ZONE C B/ KUP $N05 TVD=6168 TMD=7222 OEP-,3563 TO / LOGGING PT 1¥T)~6334 TMD-7¢22 DEP,,3674 I ! I J i I I I I I I ~ I I 0 400 800 12OO ICaO 2000 2400 2800 3200 3~ 4800 ~COIe I : 200.00 Verflcol Secfle~ on 73.54 ezlmMh with reference O.O0 N, O,OO E from sim ~125 PAR K RIVER UNI 20" DIVERTER SCHEMATIC ! I 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 1(7' HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 2(7' - 2000 PSI ANNULAR PREVENTER SRE 2/6/90 7 I ' ,i II a 13 "50 TA K ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUEC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PS! DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNIT~ SIMULTANEOUSLY AND RECORD THE TIME AND PRE~S(JRE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLI~DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEATAND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCRE~E PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3(XX) PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BoTroM PIPE RAMS. TEST BO]rOM RAMS TO 250 PSI AND 30(X) PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILUNG SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11' - 3(X)0 PSI CASING HEAD 3. 11" - 3(XX) PSI X 13-5/8" - 5(XX) PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8' - 5(X)O PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8'-5(X)0 PSI ANNULAR SRE 8/22/89 DOYON 14 I . . . . . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. © GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 2M PAD Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10° of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run. open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-14,33 TELECOPY: (907) 276-7542 March 21, 1991 A Wayne McBride. Area Drlg Engineer ARCO Alaska, Inc P O Box 100360 Anchorage AK 99510-0360 Re: Alternative cementing procedure for some Kuparuk River Field wells on Drill Site 2M. Dear Mr McBride: This is in reply to the meeting with the Commission on March 8, and your letter of request dated March 11, 1991. The Commission'has reviewed the conditions expected to exist on Drill Site 2M, and approves isolation of Colville sands by down squeezing cement into the annular space between Surface and production casing. This will occur after the primary cement job is completed, and applies to those wells which encounter significant hydrocarbon zones within 200' TVD of the surface casing shoe. If you have any questiOns, please feel free to call me. Sincerely, ~, Lonnie C Smith Commiss ioner LCS/jo ARCO Alaska, Inc. ~ Post Office B~+i.~'0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 19, 1991 Mr. Lonnie C. Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Subject: Transmittal of RequeSted Cross Sections Dear Mr. Smith: Enclosed please find one copy of the cross section presented to you, Chairman Johnston, and Mr. Minder during our meeting on February 13, 1991, as per your request. Also enclosed for your files is a cross section showing the correlation of the "Authorized Injection Strata for Disposal" as defined in the ARCO West Sak River State No. 1 well in Area Injection Order No. 2, dated June 6, 1986, with the equivalent zone in the ARCO 2K-11 well offset from the KRU 2M drill site; again, as per your request. Sincerely, Geologist Enclosures (2) M.L. Prestridge R.G. Jackson T.L. Hudson ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED FEB 2 o 1991 AR3B-6003-C A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 WALTER Jo HICKEL, GiOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1~ TELECOPY: (907) 276-7542 Re: Kuparuk River Unit 2M-25 ARCO Alaska' Inc. Permit No. 91-21 Sur. Loc. ll4'FSL, 579'FWL, Sec. 27, TllN, RSE, UM Btmhole Loc. 444'FSL, 2076'FWL, Sec. 27, TllN, RSE, UM Dear Mr. McBride: Enclosed is" the approved application for permit to drill the above referenced-well. The permit to drill does not exempt you from obtaining additional permits reqUired by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The mechanical integrity of the injection wells must be demonstrated under 20 AAC 25.412 before operation. Please contact the cOmmiSsion at least 24 hours before pressure testing so that a representative of the commission may witness the test. Sinc'erely, C' '-'% t/~nnie C ( ~~, ' Commissioner Alaska Oil and Gas Conservation commission BY ORDER OF THE COMMISSION dlf/Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907.276-1215 January 31, 1991 Mr. Lonnie Smith Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: SUBJECT: Application for Permit to Drill KRU Field Well 2M-25 (Temporary Disposal) Attached is an application for Permit to Drill for the above referenced well. The surface casing portion of this well will be used for temporary disposal of drilling fluids and other fluids incidental to the drilling of wells on Drill Site 2M in the Kuparuk River Field. The plan for handling these fluids utilizes a solids processing module to eliminate the need for a reserve pit at Drill Site 2M. Most, if not all, of the drilling fluid waste would be pumped down this well instead of the annulus of the previously drilled well. The exact injection interval will be selected from open hole logs of the well. After log analysis of the well, the 9-5/8" casing would be run to 3309' MD or 2804' TVD. A CBL would be run to ensure cement integrity, the well perforated, and a packer and tubing run for the completion assembly. After all of the other wells on the pad have been drilled, the injection interval in this well would be squeezed off and this surface casing utilized to complete the drilling of 2M-25 as a normal producing oil well. We have reviewed the likelihood of formations in this well having recoverable hydrocarbons, and anticipate that the Ugnu is water wet in this area of the Kuparuk River Field. The final decision will have to be made after review of the open hole logs. RECEIVED FEB 1 lggl Oil .& oommi881on ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 If for any reason that this method of disposal is impractical, ARCO would utilize annular pumping that has been standard procedure in the past. Mark Prestridge of this office has had general conversations with Blair Wondzell of your office about this concept. Either Mark or myself would be happy to visit with you further if you need more information regarding the project. Thank you for your assistance in this matter. Sincerely, Area Drilling Engineer AWM/MLP/mac attachment RECEIVED FEB 1 ~ 1991 Alaska Oil & 6a8 Cons. Comml#lon Afx:hol~ PERMIT TO DRILL 20 AAC 25.O05 la. Type of Work Drill . X Redrill ~ lb. Type of Well Exploratory_._ Stratigraphio Test _ Development Oil .. I Re-En, try_ Deepen _ Service ~-~ Development Gas .._ , Single Zone ~ Multiple Zone . ~.. Name of Operator ' 5.Datum Elevation (DF or KB) 10. Field and Pool . AR(;;O Alaska, lnc, RKB 130. Pad 105' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchora~le, AK 99510:0360 . ADL 25586. ALK 2672 4. Location of Well at sudace 7.' Unit or property Name 11. Type Bond (see 20 AAC 25.025) 114' FSL, 579' FWL, Sec. 27, T11N, R8E, UM Kuoaruk River Unit At top of productive interval 8. Well number Number ~M-25 #U 630610 Al lolai depth 9. Approximate spud dale Amount 444' FSL, 2076' FWL~ ,Sec. 27 ,. T11N, R8E, UM 2-18-91 $200r000 , 12. Distance to nearest 13~ DiStance to nearest well 14. NUmber cd ~oras in prOpertY 15. Proposed depth (MD and 3'VD) properly line 2M-24 (proposed) 3,309' MD 3204' @ TD fee. t 25'at SURFACE fee,t ,,,256,0 , 2r8,04' TVD feet ~6. To be comPleted for deviated wells 17. Anticipated pressure (see 20 AA¢ kick,off d, epth 300 feet Maximum hole an~l!e 40° , Maximum, suN,o.,, 1150 p~ At total depth ~I'VD} 2804' 1450 psi; 18. Casing program Setting Depth size specificatio,n, Top , Bptlom Quantity of cement "Hole casing weight Grade, Couplin~ Length lye TVD bi:) ' ,TVD (includ® sta~e data} 24 16.0" 62.5# H-40 Weld 80' 35' 35' 115' 115' :f.2.00 Cu. Ft. 12.25 9.625" 36.0# J-55' amc . 3,274' :~'5' 35' ' 3,309' ,2~804' 1130 Cu. Ft ASIII & HF-ERW ' 590 Sx Class G r i i 19. To be completed l(~r Redrill, Re-entry, and Deepen Operations. ' ' ' Present well condition summary Total depth: measured feet Plugs (measured) true vertical leer Effective depth: measured feet Junk (measured true vertical leer Casing Length Size Cemented Measured depth True Vertical depth Structural R E C E I V E D Intermediate Production Liner FEB 1 31991 Perforation depth:true measuredvertical ~ 0il & 20. Attachments Filing lee _X_ Property plat ~ BOP Sketch _. Diverter Sketch ~ Drilling program X Drilling flUid program ~ Time vs depth plot ~ Refraction analysis ._ Seabed rep?ri ...20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~/~~'t-,w~'~-... Title Area Drilling Engineer D ate//~:~/~'/ COmmisSion USe Only Permit Number- /~ APl numberI ApprOval.date- I See cover letter for e -zl I s0-to - I 02/20/91 I _ other recluiremenls Conditions of approval Samples required ~ e s .~N o Mud Icg required ~'~ Ye s ~ N o Hydrogen sulfide measures ~ Y e s ~/'N o Directional survey required .~f'as~ N o Required working pressure for BOPE ~ ~:~ ~_5j~M' __10M; __ 15M Other: A, pproved b~, , "" Commissioner the commission Date 2~ Z 43-~/' Form 10-401 Rev. 7-24-89 / Submit in triplicate ARCO ALASKA, Structure ''Pad 2M. Well 25 Field · Kuparuk River Unit' Location · North Slope, Alaska 0 400 0 · 0 200 U") 200 400 (D. ¢) ' I - V - lCreated by : jon~srot: T IDate plotted ' 2g-Jan-g1 I~ot Reference is 25 Version ICoordinote$ ore in feet reference slot ~25. [True VerUcal Depths are reference wellhead. I IIE:ASTMAN I ' IZJ~C'HRISTE:NS£N Surlace Location** I 114' FSI., 579' FWLI Sec. 27, TllN, ReEI RKB Elevation.' 14g' KOP Tvd=300 Tmd--300 Dep=o 3.00 oo East --> 200 0 200 400 600 800 I0~0 1200 1400 1~0 1800 IIIIIIIIIIIllllllllll 444' FSL) AOTt,, 'F~. A ~ '1 I . -2oo :2:: N '77 DEG 33 MIN E 1533' (To TD) ~ 1§.00 Build 5 D~g/IOOFt - AVERAGE ANGLE 2~.oo · 40 DEG 23 MIN ' 27.00 . . 'XS"O0 El/ ~,r~;fnr~StsndTsVd;:d~9194;;dT~r~d4=7:5:;P;e3p,~8400 , ~£C£1 ' .' N~g'O0 £00 Tvd=1538 Tmd=1646 Dep=455 yED '.. i '~ ' . ~or~e '~r~/~lon NXx, NB/ W Sak Snd$ Tvd=2604 Trod=5047 Dep~ g 5/8" ¢SG'Pt Tvd=2804 Tmd=3309 Dep=1533 ""~000 ' I i I I I i I I I I I ' I i I I I I I I I I I I _1 I 400 . 200 0 200 400 600 ~00 1000 "1200 '1400 '1~00 .'18~0 2000 Scale 1 ' 100.00 Vertical Section on 77.56 azimuth with reference 0.00 N, 0.00 £ from slot 1l~25 10. 11. 12. 13. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2M-25 (Temporary Disposal) 1. Move in and rig up Doyon Rig 14. 2. Install diverter system. 3. Drill 12-1/4" straight hole to 9-5/8" surface casing point (3309' MD, 2804' TVD') 4. Log well with open hole wireline logs from TD to surface. 5. Run and cement 9-5/8" casing. Pressure test to 2,800 psi. 6. 'ND diverter and install 11" 3,000 psi casing head. 7. Run cased hole cement evaluation logs. 8. Install and test BOPE. 9. Run CIBP to just below designated injection zone. Displace hole with diesel. Perforate and run completion assembly, set and test packer. ND BOPE and install injection tree. Shut in, secure well and release rig. DRILLING FLUID PROGRAM (2M-25 Disposal) Spud to 9-5/8" surface casin~l Density 8,6-10.0 ' PV 15-35 YP 15-35 Viscosity 50-100' Initial Gel 5-15 10 Minute Gel 15-40 APl Fluid Loss 10-12 pH 9-10 % Solids 10% + Drillin(] Fluid System: T~.ndem B~:andt Shale Shakers Tandem Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuge,Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Drilling fluid practices Will'be in aCcOrdance' With the appropriate regulations stated in 20 AAC 25.033. The nearest well to 2M-25 is 2M-24 (proposed). As designed, the minimum distance between the two wells Would be 25' at sudace. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be hauled to the nearest Kuparuk Field disposal well. *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds. .UPARUK RIVER 20" DIVERTER SCHEMATIC 3 DO HOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THATAN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUES'PS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIA~E FROM ~20AAC25.035(B)~ 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16'- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DNERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI~,NNULAR PREVENTER SRE 2/6/9O CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) Loc (-2' tWr. (S) - (10 and 13) 12. 13. (l~ th~ 22) 15. (23 thru 28) .Company 1. Is the permit fee attached ........................................... 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4.'Is well located proper distance fr°m other veils .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is vellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the veli have a unique name.and number ......................... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or 'production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse., tension and burst.. Is this well to be kicked off from an existing wellbore ............. ,, Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ..s......................... Is a diverter system required . .... ~ · ...... 41,.. i....... ~.......~l.~l.... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of ~ ~ BOPE attached. Does BOPE have sufficient pressure rating - Test to 5000 psig .. Does the choke manifold Comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. 0 ,G. eology: . Eng'~nee~ing: DWJ~LCS ~BEW d ; ......... :.v: 11/30/90 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. ,,, Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. ~ ,, , Additional Remarks .... INITIAL ' GEo. ' UNIT ON/'OFF ' · POOL CLASS STATUS AREA NO. SHORE nS .... ~ ~W~ 1 ~s the pe~it fee attached ~ -- (1) Fee ........................................... (2 thru 8)' (8) (9 thru 13) (lO and (14 th~-a 22) " (23 thru 28) 2. Is well to be located in a defined pool ............................. __ ~._ 3. Is well located proper distance from property line .................. 4. is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ Z~_ . 7. Is operator the only affected party ................................. 8 Can permit be approved before fifteen-daY wait · . 12. 13. 9. Does operator have a bond in force .................................. ~ 10. Is a conservation order needed ...................................... ~ 11. Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... ,f~ . Will cement tie in surface and intermediate or production strings ... ,, Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. .. Is old wellbore abandonment procedure included on 10-403 ............ _ Is adequate wellbore separationproposed ®..®,,®,e.,e.®,®.®®e®.®,.®,e .. ... Isa diverter system required e®e·,,.~,~,.®,.,®,ee®,,,,®~,.®®~®®ee®®® Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to .~6)~ .... psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (2-9 tbru 31) ' (6) Add: Geology ~;.. DWJ ~ RPC ~,,,,, En gi~ er lng: Lcs"LC 11/30/90 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. J Are seismic analysis data presented on shallow gas zones ............ ~/ . ... ...... If an offshore loc., are survey results of seabed conditions present·dj ..... .. · Additional requirements ~,_ . eee . e e e e e e e e . . . . e . . . .... · · · e · · · · e · · · · · · · · · · · , , Additional Remarks: ' ')1 ,. ' / ' w,: ~;,9~ ~,,,, ,,,,,, ........ . ................ ....... INITIAL ..... oEO·' uNIT oN/oFF POOL CLASS STATUS AREA NO. SHORE .......... W~'P L .................... Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the histOry file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ .. No special'effort has been made to chronologically organize this category of information. /' DIRECT DIGITAL LOGGING · IIIIIllIII $$$$$$$S DDDDDDDDD UU UU MM MM PPPPPPPPPPI . IIIIIIIIII ~~$~S~ DDDDDDDDDD UU UU MMH MMM PPPPPPPPPPi . ' ' II ~ ~S DD DD UU UU MMMM MMMM PP , II ~8 DD DD UU UU MM HH MM MM PP · II SS DD DD UU UU MM MMMM MM PP i ,. II $SSSSSSS$ DD DD UU UU MM MM MM PPPPPPPPPPI · II ~S~S$S DD DD UU UU MM MH PPPPPPPPPPI · II $~ DD DD UU UU MM MM PP . Ii ~ DD DD UU UU MM MM PP II ~ ~ DD DD UU UU MM MM PP ~LLLLLLLLLL IIIIIIIIIl S$~S~SSS~ DDDDDDDDDD UUUUUUUUUUUU MM MM PP .LLLLLLLLLL IIIIIIIIII $~~99 DDDDDDDDD UUUUUUUUUU MM MM PP 1l Il 777777777777 PPPPPPPPPPP MM 11! tll 7777777??7? PPPPPPPPPPPP MHH Mi 1111 ::: llli 77 77 PP PP HMMH 11 ::~ It 77 PP PP MM MM MM il 11 77 PP PP MM MMHM ll 11 77 PPPPPPPPPPPP MM HH 11 11 77 PPPPPPPPPPPP MM 11 1! 77 PP MN 11 :~: 11 77 PP MM 11 :~ 11 77 PP NM iIlIlllIll Illlllllll 77 PP MM 1111111111 1111111111 77 PP NH 11 RA PPPPPPPPPPP RRRRRRRRRRR 9999999999 I1 111 RAAA PPPPPPPPPPPP RRRRRRRRRRRR 999999999999 llll AA RA PP PP ER RR 99 99 1111 11 AR AA PP PP RR RR 99 99 11 il RA AR PP PP RR ER 99 ~9 II 11 AA AA PPPPPPPPPPPP RRRRRRRRRRRR 999999999999 11 11 AARRAAAAAAAA PPPPPPPPPPPP RRRRRRRRRRR 999999999999 11 11 AAAAARRRAAAR PP RR RE 99 11 11 AR RR PP RR RE 99 II 11 AA AA. PP RR RR 99 99 11 1111111111 R~ AA PP RR RR ,,, 999999999999 111111111 1111111111 AA AA PP RR ER ,., 9999999999 111111111 *********************** :*** REEL.HE~DER Service name: &G5F01 Previous. re¢l~ HEADER RECORDS Page Date: 91/04/01 Origin: Reel name: 666061 Comments: Continuation #: 01 *********************** TAPE'HEADER ~ervice name: &G5F01 Pp~viou~ tape: FILE, HEADER File name: ,001 91/04/01 Origin: Tape name: ~GGOGI Comments: Version #: Data: Continuation #: Ol Maximum,length: 1024 File type: LO Previous ~ile: INFORMATION RECORDS Page NNEN ~ONTENTS UNIT TYPE CATG SIZE CODE ERROR CN WN FN COUN 8TAT CTRY APIH LATI LONG SECT TOWN RANG EDF EGL PD LNF DHF HUH TINE DATE LCC LUN LUL ENGI WITH CBD! CBL! TLI BLI TC8 TLAB BHT HRT DFD N¥IS OFPH DFL RM NFST NFSS RNC ARCO ALASKA INC. 2H-25 KUPARUK NORTH SLOPE ............. flLASKA ............. USA ............. 20152,000 ........................ O.Deg . , Sec 11N .............. , ............... 0SE .............................. 130,000 .......................... t29,000 .......................... 105 000 ltlll'ellllliitlllmlill'Jlll.l'l, 2200,'OOO ......................... 25/ 379t ......................... 666061 ....................... ...................... NORTH 8LOP~ ............. NORTH SLOPE ............. YARBRO ............. GILSTRAP ............. 3175.000 ......................... 3174,000 ......................... 115.000 .......................... 114.000 .......................... 92,000 ........................... 3.163.000 ......................... 1900.000 ......................... 2200.000 ......................... 90:000 ............... , ........... 90.000 ........................ .,,, GEL/BEHEX ............. CIRCUALTED ............. 9.600 ............................ 45.000 .................... , ...... 9.000 ............................ 8.400 ............................ 8,050 ............................ 9.230 ............................ 7! .000 ........................... NEAS ...................... 4.350 ............................ API NUN, 50-I 03-20152 .............. DATE LOGGED: 03-25-91 ................ illlll..lllml, milmtllllllli I111111,iiiii ,,11,,1111.,i 1111.1141tlti i,ii1.111.11, 1111111,114., I.I,i. IIIllll ill,l.llll,l. Illllllllll,, II1,1,,ii1,Ii Ii1,Iit1114,1 Illl,llllll,i iIiilll.ll.ii t'lllllllilll IIIIIIIII1,1. '.111.1,1111. II1'1'1111111 II1''.111111. I,IIIIIIII1.1 Illllltll,lll 0 0 40 65 0 0 40 65 0 0 40 65 ........ 0 0 20 65 ........ 0 0 20 65 ........ 0 0 20 65 ........ 0 0 4 68 ........ 0 0 34 65 ........ 0 0 34 65 ........ 0 0 2 65 ........ 0 0 3 65 ........ 0 0 3 65 ........ FT 0 3 4 68 ........ FT O. 3 4 68 ........ FT .0 3 4 68 ........ 0 3 2 65 ........ 0 3 2 65 ........ 0 3 2 65 ........ 0 0 2 29 ........ 0 0 4 68 ........ 0 0 8 65 ........ 0 0 2 79 ........ 0 0 10 65 ........ 0 0 10 65 ........ 0 0 20 65 ........ 0 0 20 65 ........ 0 0 20 65 ........ 0 0 20 65 ........ FT 0 3 4 68 ........ FT 0 3 4 68 ........ FT 0 3 4 68 ........ FT 0 3 4 68 ........ FT 0 3 4 68 ........ FT 0 3 4 68 ........ HR 0 2 4 68 ........ HR 0 4 4 68 ........ DEGF 0 I 4 68 ........ DEGF 0 1 4 68 ........ 0 2 20 65 ........ 0 2 20 65 ........ LB/G 0 2 4 68 ........ CP 0 2 4 68 ........ 0 2 4 68 ........ 0 2 4 68 ........ OHMN 0 2 4 68 ........ OHNN 0 2 4 68 ........ DEGF 0 2 4 68 ........ 0 2 12 65 ........ OHHH 0 2 4 68 INFORMATION RECORDS Pag~ ~ MNEM CONTENTS UNIT TYPE CATG $I2E CODE ERROR MCST 8~ , 000 .............. , ................................... OEGF 0 2 MCBB MEA9 ............. , ................ . ............... 0 ~ CB I~. 000, ~ ...... , ......................................... 0 3 BB 1 ~, ~§ 0 .................................................. 0 ::;3 COMMENT RECORDS Well Location Comment 1: SURFACE: Well Location Comment 2: Well Location Comment 3~ Well Location Comment 4: Well File.Comment 1: HRI-SDL-,DSN RUN Well File Comment 2: "SP FISH" Well File.Comment 3: We 1t4' FSL & 579' FWL IN COMBINATION. DSM RAN DECENTRALIZED, USED IN PACE OF I'SP" DUE TO FL'OATIflG "SP ELECTRODE", 11 File Comment ******************************************************************************** LIS tape written bv: ANCHORAGE COMPUTING CENTER All..curYe and tool mnemonics used ar~ those which most closely match Halliburton.curve and tool mnemonics, ******************************************************************************** ******************************************************************************** HALLIBURTON TO SCHLUMBERGER TOP BOTTOH MNEM SERVICE UNIT MHEM SERVICE UNIT DEPTH DEPTH mmmmmm- mmm mmmm mmmm DEPTH FT DEPT FT ?5.00 4000.00 GR SDL GAPI GR SDL GAPI 92,00 3185,00 FDSN DSM2 CPS FDSN DSM2 CPS 92,00 3185.00 NDSN DSM2 CPS NDSN DSM2 CPS 92,00 3185.00 NPHI DSM2 DECP NPHI DSN2 DECP 92,00 3185.00 HRAT DSM2 C/C NRAT OSH2 C/C 92.00 3185,00 DPHI SDL DECP DPHI SDL DECP 92.00 3185.00 DRHO SDL G/C3 DRHO SDL G/C3 92.00 3105.00 FSDL SDL CPS FSDL SDL CPS 92.00 3185.00 NSDL SDL CPS NSDL SDL CPS 92.00 3185,00 Page 4 P£ 8~L P£ 8DL 92.00 PELC 8DL PELC 8DL 9~.00 ~85.00 QL 8DL QL SOL 9~.00 3t85.00 OS SDL QS SDL 92.00 3185,00 RHOB SDL G?C3 RHOB SDL G%C3 92.00 3185,00 CALI SDL 'IN CALI SDL IH 92,00 3185,'100 HDR NRI HDR HRI 92.00 3185.00 HDg HRI HDg HRI 92,00 HNR HRI HNR HRI 92,00 3185,0'0 HNX HRI HHX NRI' 92,00 3185,00 HDR$ NRI ONNH NDRS HRI OHNN 92,00 HHRS HRI OHHH HHR8 NRI OHNH 92.00 3185.00 HDCN HRI NHHO HDCN HRI MHNO 92,00 3185,00 HHCN HRI 'HNHO HNCN HRI MNHO 92,00 DFL HRI ONHN DFL HRI OHHH 92,00' TENS 8DL LB TEN8 SDL LB 92.00 FISH HRI NY FISH HRI NV 92,00 3185,00 ENTRY DATA FORHAT SPECIFICATIONS TYPE SIZE CODE Page '= 16 I 66 0 1 66 .mm. ENTRY,BLOCK LEGEHD TYPE DESCRIPTION 16 Datum specification block sub:type 0 Terminator ( no more entries ~ DATA FORMAT' DATUM SPEOIFICATION BLOCKS SPECIFICATIONS Page 6 MNEM SERVI~E SERVICE AP1 AP1 APl APl FILE ID ORDER # UNIT LO~ TYPE OLA8g MOD # PRO # SIZE LVL gMPL RC PROCESS INDICATOR9 DEPT GR SDL FDSN DSM2 NDSN DSM2 NPHI DSH2 NRAT DSM2 DPNI ~DL DRHO SDL FSDL SOL HSDL SDL PE SDL PELC SDL. QL SDL QS ~DL RHOB SDL CALI SDL HDR HRI HDX HRI HMR HRI HM~ HRI' HDRS HRI. HMRS HRI- HDCH HRI HMCN HRI DFL HRI TENS ~DL FISH HRI 666'061 FT 0 0 0 0 666 061 GAPI 94 0 0 1 0 666'061 CPS 94 0 0 1 0 666'061 CPS 94 0 0 I 0 666'06~ DEeP 94 0 0 I 0 666061 CFC 94 0 0 1 0 666'061 DECP 94 0 0 1 0 666.061 G~C3 94 0 0 1 0 666'061 CPS 94 0 0 1 0 666061 CPS 94 0 O I 0 666061 94 0 0 1 O 666061 94 0 0 1 0 666061 94 0 0 I 0 666061 94 0 0 1 0 666061 G?C3 94 0 0 'I 0 666061 IN 94 0 0 'l 0 666061 94 0 0 '1 0 666061 94 0 0 1 0 666061 94 0 O' 1 0 666061 94 0 0 I 0 666.061 OHMM .94 0 0 i 0 666061 OHMH 94 0 0 t 0 666,061 MHHO 94 0 0 1 0 666061 MMHO 94 0 0 1 0 666 061 OHMM 94 0 0 I 0 666061 LB 94 0 0 I 0 666061 NV 94 0 0 1 0 000000 000000 000000 000000'000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000. 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DATA RECORDS DEPT GR FDSN HDSN HPHI HEAT DPHI DRHO FSDL HSDL PE PELC GL ~.S RHOB GAL I HDR HD~4 HMR HHX HDRS HHRS HDCH HHCH DFL TENS FISH ........: - .. ~ : --: : -: .::. ~ ....:.-. _ ::~ _., . .... 3185. 000 91 ,225 1233. 779 13266.613 ,539 1'1 ,676 .245 , ! 12 I O118,615 16985. 031 2.838 2.906 -.600 ,200 2,246 12. 044 41 . 706 365 50.394 .755 17.857 17,602 56. 000 56.813 31 00. 000 86,580 1476.542 13833,131 .442 1 0.. 17'3 .276 . 043 9820.416 16078,604 2,731 2,874 -.026 -.028 2.195 12.499 137,629 14,716 158,718 8.251 5.740 5,450 174,2! ! 183.492 3.62? 3545. 392 546,262 3000,000 73.162 1425.832 13855,742 ,463 10,552 .303 .040 0556.416 16272,604 2.533 2.550 -,005 ,047 2. 150 12.829 90,782 9. 248 96,037 4,348 9,555 9,544 I 04,654 1 04. 776 6,843 2959. 259 537,791 2900.000 76.364 1363.238 13454,295 .477 10.716 ,308 ,048 10847,816 16440,461 2,671 2.747 -.034 -,014 2,142 12,507 95.019 2,485 125,129 4,346 7.845 7,098 127,477 140.888 5.192 3002.146 539.935 ' 2800,000 86.858 1459.427 13793,658 .449 10,262 .284 ,044 10045,016 16141.748 2.747 3,060 ,036 -,,027 2.181 12.774 94.874 '1,215 99.955 7.248 9.069 8.663 110.268 115.434 7,231 2944,963 530.t05 2700. 000 69.368 1400,9019 13739,266 .471 I 0.649 .259 . 061 9614,416 1621;3.461 3,146 3.219 -.021 -.012 2.223 12.834 75. 459 18. 194 79. 431 28. 550 12. I 02 I 1 , 634 82. 628 85.954 9,082 2844. 891 532, .094 2600,000 69.155 1338.347 13684.346 ,495 11.102 .300 ,051 10650.016 16406.031 2,762 2.837 -.074 ,067 2,155 12.816 55.238 4,126 58,044 11,445 16.094 15.322 62.135 65.266 11.090 2830,595 530,905 2500,000 IS9,255 1261 ,902 13234,672 .518 11 .388 ,286 . 076 I 0772.217 16758.605 2.990 2.812 .032 -.023 2.177 12,940 83.49! 8,519 92,535 17,872 I 0.543 1 0.544 94. 846 94. 841 6,944 2687,636 527,734 Page 7 DATA DEPT GE FDSN NDSN F~DL H~DL PE PELC HDR HDX HMR HMX DFL TENS FISH 2400. OOO 37,334 1506,071 14734,508 13348,816 1-7033,891 2, !37 1 ,850 42. 233 -4. 029 30. 350 -. 1 t 9 79. 040 2816.299 519.821 2300. 000 66.9! 6 1332. 383 13596. 883 12130.615 1655.0. 176 2.473 2.6t 1 57,745 t .971 64,180 1 , 032 11 , 087 2744.820 517,607 2200.000 40.473 1532.6?5 14668.861 12590.2t? 16594.316 2.342 2.364 43.358 2.212 44.852 -1.072 18.162 2444.605 492,465 2100.000 67.679 1309.563 13342.625 10949.416 16328.461 2.627 2.642 69,780 2,086 75,981 -,104 e.e20 2558.973 523.685 2000,000 34.165 13'01.547 13579.494 12392.217 16626.461 2.448 2.592 39,3t9 2,333 42,883 .412 14.627 2330.238 511.635 1900.000 57.222 1350.688 13593.521 10234.215 16319.605 2.651 2.855 59.46! 2.530 68.265 -.145 9.878 2558.973 523.580 1800. 000 78,418 1428.716 13830.635 0188.615 16286.604 2.837 3. 139 43. t54 I .548 46. 929 -.517 1 5. 433 2373. !25 497. 308 1700,000 62. t76 1474,892 14197.385 I1752.217 17032.461 2.026 2.276 35. 967 I .351 37. 409 -2. 765 27. 657 3045,034 491 ·602 RECORDS NPHI NEAT DPHI DRHO QL QS RHOB C~LI HDES HHES HDCN HMCN Page , 463 1 O. 617 , 3,.0,5 . 038 -, 009 , 072 2,0t4 13.511 54,980 99,634 18. 189 1 O. 037 .500 11 . 081 . 362 . 025 . 027 -. 049 2. 053 12. 457 15.632 15. 029 63. 970 66. 538 .457 1 O. 392 .378 . 021 -. 063 -..009 2. 026 i2.371 24. !57 22. 686 41 . 395 ~ 44. 081 ,494 11 , 063 , 313 , 037 -, 050 -,023 2, 1 2 · 554 12.3 02 79 . 656 81 . 288 ,515 11,329 ,371 ,028 ,013 ,033 2,.038 12,384 22.302 21,206 44.839 47,156 .487 1 0.928 . 287 . 051 -. 058 -. 045 2..177 12.562 15.856 14,423 63. 067 69,334 ,461 10.511 .286 .049 · 011 .011 2.179 12.454 21.061 20.038 47.481 49.904 .455 10.452 .319 .039 ,02! 2,t24 12.904 33.541 30.836 29.815 32.430 DA TA' RECORDS DEPT GR FDSN NDSN NPHI NRAT DPHI DRHO FSDL NSDL PE PELC QL QS RHOB CALI HDR HDg HHR HMX HDR9 HHRS HDCN HHCN DFL TENS FISH Page 1600.000 63,95? 1606.654 15476,639 ,464 10',459 .342 ,, 88@. 4,6 1-675,.746 2,6,0 2.667 .030 .045 9,0,96 26.6,4 .302 29.774 -1 .247 33.601 31.178 29.761 .514 2,5~.687 53,9.633 21 1500. 000 45. 046 13101 .416 16740. 176 1 0.31 t -1 . 372 1.41 ,694 2l Ol ,503 1400,000 3?, 406 ! 3397,6!7 16795,605 1 !. 378 2. 263 92,36.0 2.1'58,687 1300, 000 6e,660 -999. 250 -999,250 40.~13 -,14l 13. 878 1887,064 1200,000 40,692 -999,250 -999,250 12,239 -1 ,734 116,004 2030,'023 1 ! 00. 000 42 -999,250 -999,250 9,290 -1,460 196,618 2030,023 1 000,000 41 .275 -999. 258 -999,250 13.44'8 -1 ,63! 397. 964 1872. 768 900. 000 4?'.468 -999. 250 -999,250 8,049 -, 954 ! 90. 482 1,987,064 .048 11 .614 32. 074 1206.698 13136,500 ,533 11..82! .399 ,023 2,197 2,194 -,026 -.01,9 2,009 14,899 9.,916 -2.487 124.333 116.337 8,043 ,9.596 53,9.361 1302,369 13397.340 ,466 11.170 ,396 ,020 2,124 2,292 ,052 -,068 1.997 19,000 10.113 7.103 105,713 101.523 9,460 9.850 509,565 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999,250 -999.250 17,372 49.423 .606 18.741 17.015 53.360 58,772 533.595 -999.250 -999.250 -999.250 -999,250 -999,250 -999.250 -999,250 -999,250 -999,25.0 -999,250 -999.250 23.760 11.174 ,332 122.881 135.286 8.138 7.392 549,041 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 21,742 7,547 -,118 224,414 172,963 4,456 5.782 559,694 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999,250 -999.250 -999,250 -999,250 23.t43 12,612 -1,404 194.447 185,506 5,143 5.391 548.084 -999.250 -999.250 -999,250 -999.250 -999,250 -999.250 -999.250 -999,250 -999.250 -999.250 7,032 -.687 153,072 168,818 6.533 586,584 -999.250 21.845 5.924 DATA RECORDS DEPT GR FDSH NDSN NPHI NRAT DPHI DRHO F~DL N~DL PE PELC QL QS RHOB CALI HDR HDX HMR HH~< HDRS HHRS HDCN HHCN DFL TENS FISH 800.000 22.525 -999,250 -999.250 -999.250 -999,250 -999,250 -999,250 8.959 -,771 8,764 -,649 259,036 1829,88t 577,462 Page 't 0 -999,250 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 16,728 92.957 90.600 10.758 11.038 700. 000 26.926 -999,250 -999,250 -999,250 -999. 250 -999. 250 -999. 250 4,.041 -,504 4,256 -, 753 484,860 1629,738 542,216 600.000 ?3,725 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 16,088 ,438 24,216 1,126 28,213 1515,37:0 546,839 500,000 55,467 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 12,820 13,531 16,611 18,070 65,638 1515,37:0 570.139 400,000 58,079 -999,250 -999,250 -999.250 -999,250 -999.250 -999,250 36.146 -2.625 48.345 -2,382 33.463 1601.146 527,251 300.000 51,013 -999,250 -999.250 -999.250 -999,250 -999.250 -999,250 18.979 -.2~2 32.337 -1.2.00 36.334 1372.410 494.679 200.000 32,778 -999.250 -999,250 -999,250 -999,250 -999,250 -999.250 8.614 -1,478 14,639 -1.896 120,970 1358,115 464,490 100.000 23.733 -999.250 -999.250 -999,250 -999,250 -999,250 -999,250 13.879 3.020 22.254 -2.067 -12345,000 1343.819 463.278 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 23,440 20000,000 2269.417 ,050 .441 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 16,238 44,047 36,420 22,703 27. 457 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999.25'0 22,560 57. 285 49,672 17,457 20,132 -999,250 -999,250 -999.250 -999.250 -999.250 -999,250 -999.250 ~9.745 37.689 24.079 26.533 41.530 -999,250 -999.250 -999,250 -999.250 -999,250 -999,250 -999.250 11.486 67,595 31.613 14,794 31,633 -999,250 -999,250 -999.250 -999.250 -999,250 -999,250 -999,250 18.104 182.857 72.050 5.469 13.879 -999.250 -999,250 -12345. 000 -999.250 -999,250 -12345,000 -999,250 -999,250 -12345. 000 -999.25 0 15.903 -!2345. 000 DATA RECORDS DEPT GR FDSH NDSN NPHI NRAT DPHI DRHO FSDL HSDL PE PELC QL QS RHOB CALI NDR HD~ HMR HH~ HDR~ HHRS HDCN HMCN DFL TENS FISH Page 11 FILE TRAILER File name= &GSF'01.0.01 Haximum lengt'h: 1024 TRAILER RECORDS Service name: Verzion #: File t~pe= LO N¢×t ¢ile: Data: Page 12 *********************** .*** FILE,.HE~DER ************************ File name: .0.02 Service name: Ver.~ion #: Date: Maximum.l~ngth: 1:024 File t~pe: LO Previous ¢ile: INFORMATION RECORDS Page MNEM CONTENTS UNIT TYPE CATG SIZE CODE~ ERROR CH WN FN COUN STAT CTRY APIN .LATI LONG SECT TOWN RANG EKB EDF EGL PD LHF DHF RUN TIHE DATE LCC SON LUN FL LUL EN~I WITN DD DL CBD! CBL! TLI BLI TLAB BNT MAT MT M¥IS DFPH DFL RM RHF HFST HFSS AMC ARCO ALASKA INC. . 2H-25 API HUM: 50-103-20152. KUPARUK DATE LOGGED: 03-25-91. NORTH SLOPE ..................... ALASKA ..................... USA ..................... 20152.000 ................................ 0 ~eg. .0 Hin, .0. 0 Sec. N ......... O.ueg. 0 Min', O, 0 Sec. W ......... 2?,.,,mi,m,. ,,i.,m~,...,,,,,m,,,,,..,,., 11N ......... 0SE .... , .... 130.000 ..... 129.000, .... 105..000 .... , 22'0'0.000 .... 25/ 3/91 .... 666'061 .. 51:939 . NORTH SLOP~ NORTH SLOPE YARBRO G]LSTRAP .................................... 3175.000... .............................................. 3174.000 ................................................ 115.000.. .... , ........................................... 114.000 ........... ' ................. , .................... 92.000 .............. , ................................... 3.1'63.000 ................................ 1900.000 ................................ 2200,000 ................................ 90.000 .................................. 90.000 .................................. GEL?BENEX .................... ClRCUALTED .................... 9.600 ............ , ............... , ...... 45.000 .................................. 9. 000,.,. ............................... 8.400 ................................... e o5o ........ 71.000 .................................. MEAS ............................. 4.350 ................................... IIIilllllllllll IIll$tlllllllll IIIIIIIit111111 IIIIIitliiiiiii I1~IIIIIIIIIItl IIII1~111111111 II1111111111111 illtlllllllll ! lllllllllltlltl ItJllllllellellllltlllllltll IIIllllllllllltlllllllllllll It111111tlittlti111111111tll IIIIIit1111111111111tt11111t : ...... : ............ : ........ I!III! IIit11111111 IIIIlllllllllltllllltlltllll Illllllllllllltllllllttlllll llllllllllllllllllllllllllll IIIIIIIIIIIIII1111111 t11111111111111111111 Illlllllllllllll Illllllllllllll! $lllll·tllllllll tlllllllltllllll IIIIIllltlllllll III1111111111111 IIIIIIIIIIIIIIII IIIIIIIIII111111 IIIIIIIIIIIIIIII 1111111111111111 II!11111111111tl llllllllllllllll IIIIIIIIIIIIIIII t1111111111·IIII 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 4 68 0 0 34 65 0 0 34 65 0 0 2 65 0 .0 3 65 0 0 3 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 0 3 2 65 0 3 2 65 0 3 2 65 0 0 2 79 0 0 4 68 0 0 8 65 0 0 2 79 .0 0 10 65 0 0 10 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 65 FT 0 3 4 68 FT 0 3 4 6~ FT 0 3 4 68 FT 0 3 4 6~ FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF 0 1 4 68 DEGF 0 I 4 68 0 2 20 65 0 2 20 65 LB/G 0 2 4 68 CP 0 2 4 68 0 2 4 68 0 2 4 68 OHMM 0 2 4 68 OHHH 0 2 4 68 DEGF 0 2 4 68 0 2 12 65 OHMH 0 2 4 68 INFORMATION RECORDS Page 14 MNEM CON?ENTS MCST 81,00'0 .............................. ' ................... MEA8 .................................. ' .......... 16,000 ............ , ................ ' .................... 12,25'0 .................................................. UNIT TYPE CATG SIZE CODE ERROR DEGF .O 2 4 ' 68 O ,2 12 65 0 3 4 68 0 3 4 68 COMMENT RECORDS Page tS Well Location Comment 1: Well Location Comment 2: Well Location Comment 3: Well Location Comment 4: Well File Comment I: Well File Comment 2: Well File Comment 3: Well File Comment 4: SURFACE: 114' FSL & 579' FWL HRI-SDL-DSN RUN IN COMBINATION, DSM RAN DECENTRALIZED, USED "BP FISH" IH PACE OF "BP" DUE TO FLOATING "BP ELECTRODE". LIS.tape written b~: ANCHORAGE COMPUTIHG CENTER All curve and tool mnemonics used are those which most closel~ match Halliburton curve and tool mnemonicz. HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEH SERVICE UNIT NHEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 75.00 4000.00 GRI ~DL GAPI GR SOL GAPI 2390.75 3185.00 FDSHI DSH2 CPS FDSH DSH2 CPS 2390.75 3185,00 NDSN1 DSH2 CPS HDSN DSN2 CPS 2390.75 3185,00 NPHII DSH2 DECP HPHI DSH2 DECP 2390.75 3185.00 HRAT1 DSN2 C/C HRAT DSH2 C/C 2390.75 3185,00 DPHI1 SDL DECP DPHI SDL DECP 2390.75 3185.00 DRHOI SDL G/C3 DRHO SDL G/C3 2390.75 3185.00 FSDL1 SDL CPS FSDL SDL CPS 2390.75 3185.00 HSDLI SDL CPS HSDL SDL CPS 2390.75 3185.00 PE1 SDL PE SDL 2390,75 PELC1 SDL PELC SDL 2390,?5 3195,00 GL! SOL QL SDL 2390,75 Q$1 SDL QS SDL 2390,75 3185,:00 RHOB! 8DL G/C3 RHOB SDL G?C3 2390.75 3185.00 CALI1 SDL .~N CALl SDL IN 2390,75 3185,00 HDR1 HRI HDR HRI 2390,75 3S85,'00 HDX.S HRI HDX HRI 2390.75 3185.Q0 HMR! HR! HHR HR! 2390.75 3185,00 HHXl HRI HHX HRI 2390.75 3185,00 HDR$1 HRI OHHM HDRS HRI OHHH 2390.75 3~85,'00' HNRSI HRI OHHM HHRS HRI OHHH 2390,75 3'185,00 HDCNJ HRI HHHO HDCH HRI HHHO 2390,75 3185,00 HHCN1 HRI HHHO HHCH HRI HHHO 2390,?5 3185,00 DFL1 HRI OHHH DFL HRI OHHH 2390.75 3185,00 TENS! SDL LB TENS SDL LB 2390.75 3185,00 FISH! HRI NV FISH HRI HV 2390.75~ 3185,00 DATA ENTRY BLOCKS EHTRY FORNAT SPECIFICATIONS Page TYPE 0 SIZE CODE 66 ****************************** ENTRY BLOCK LEGEND TYPE ~ESCRIPTIOH 16 Oatum zpeci?ication block zub-%~,pe 0 Terminator ( no mor~ entries ) DATA FORMAT DATUM SPECIFICATION BLOCKS ************************************** SPECIFICATIONS Page MNEM SERVICE SERVICE APl APl APl APl FILE ID ORDER # UNIT LOG TYPE CLASS MOD # PRO # SIZE LVL SMPL RC m~m PROCES~ INDICATOR8 DEPT GR SDL FDSN DSN2 NDSN DgN2 NPNI DSN2 NEAT DSN2 DPHI SDL DRHO SDL FSDL NSDL PE SDL PELC 8DL aL 8DL QB ~DL RNOB gDL C~LI BDL HDR HRI HDX HRI' HMR HRI HM~ HRI HDRB HRI HMRS HRI HDCN HRI HMCN HRI DFL HRI* TENS SDL FISH HRI 666061 FT 0 0 0 0 666 061 GAPI 94 0 0 3 ! 666061 CPS 94 0 0 3 666061 CPS 94 0 0 3 666.061 DECP 94 0 0 3 666'061 C?C 94 0 0 3 666061 DECP 94 0 0 3 666061 G/C3 94 0 0 3 666061 CPS 94 0 0 3 666061 CPS 94 0 0 3 666061 94 .0 0 3 666 061 94 0 0 3 666 061 94 0 0 3 t 666061 94 0 '0 3 666061 G~'C3 94 0 0 3 666'061 I H 94 0 0 3 1 666.061 94 0 0 3 666 061 94 0 '0 3 1 666061 94 0 0 3 666061 94 0 0 3 1 666061 OHHM 94 0 0 3 1 666 061 OHHM 94 0 0 3 666061 MMHO 94 0 0 3 666061 NMHO 94 0 0 3 1 666'061 OHMM 94 0 0 3 666061 LB 94 0 0 3 666061 HV 94 0 0 3 I 4 0 I 68 4 0 t 68 4 0 ! 68 4 0 . I 68 4 0 I 68 4 0 t 68 4 0 t 68 4 0 1 68 4 0 ~ 4 0 I 68 4 0 t 68 4 0 i 68 4 0 '1 68 4 O 1 68 4 0 1 68 4 0 1 68 4 0 t 68 4 0 i 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 I 68 4 0 '1 68 4 0 I 68 4 0 1 68 4 0 I 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 0'00000 000000 000000 000000 000000 000000 000000 000000 000000 ~00000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DATA RECORDS DEPT GR FDSH HDSN NPHI NEAT DPHI DEHO FSDL HSDL PE PELC QL QS RHOB OALI HDR HDX NME HHX HDRS HMR~ HDON HHON DFL TEN~ FISH 3185.000 96.09! 1243.014 13096.965 ,531 11,441 .283 .062 ~0326,615 1-6454.031 2,778 2,769 -,152 -,083 2.183 11.164 147,010 8.112 174.541 -8.373 -12345.000 -12345.00'0 -12345,000 -12345.000 -12345.000 3187,994 123450000, 3100,000 95,.088 1408,528 13720,367 ,475 10.,577 ,269 ,064 9957.016 16367,89! 2,8?4 2,921 ,'063 -,006 2,206 11,843 137,756 15,126 158,942 8,327 5.790 5,453 173.025 193.375 3,705 3316,657 556,170 3000,000 69.39? 1373.116 13850,455 ,486 10,952 ,302 ,046 10656,416 16357,749 2,484 2,633 -,027 ,001 2,151 12,733 9,0,313 9,263 95,687 4,408 9,600 9,716 I04,171 102,923 6.985 2959,259 548,847 2900,000 76,378 1367,765 13425.008 ,475 10.658 ,305 ,042 10591,416 16291,033 2,588 2,656 -,046 ,022 2,147 t2,484 95.110 4,832 125.503 9,497 7,620 6,921 131.227 144.479 4,766 30t6,442 549.253 2800,000 93,6.08 1452,623 13777,965 .446 10,299 ,269 ,057 9836,217 16254.176 2,758 2,887 ,OO6 -,OO4 2.206 12.806 94.765 ,437 99.567 6,965 9,065 8,711 110,312 114,803 7,337 2987.851 545.701 2700,000 71 ,264 1406,674 13557,732 ,462 1 0.465 ,276 , 044 9799,615 16081,604 2,912 3,250 , 012 -, 000 2,195 12,809 74,907 16,922 78,026 29,292 12,258 11 .920 8t ,630 83.893 9. :329 2659,044 552,44! 2600. 000 72,198 1334,439 13765,355 .502 1 I .20! ,300 . 045 10520.016 1630{I,318 2,780 3,056 ,051 ,026 2.156 12.814 55, t37 16.04? 57,042 26. 434 16. 279 15.569 61 ,431 64. 230 11 , 547 2730,524 543,56? 2500.000 79,255 1309.768 13356,299 .494 11,073 ,305 .049 I0819,816 16462,605 2,790 2,756 -,025 ,022 2,146 12.862 81,903 6.3.07 90,852 14,643 10.960 10.904 91.237 91,710 7.323 2659,044 556,082 Page 18 DA'TA RECORDS DEPT GR FDSH NDSH NPHI NRAT DPHI DRHO F~DL H~DL PE PELC QL QS RHOB C~Li HDR HD~ HMR HH~ HDR~ HMRS HDCN HHCH DFL TENS FISH 2400. 000 44. '1 92 ! 472,4! :7 14562,059 ,465 10. 7'39 ,392 , 033 '13408.416 16951 ,461 2,006 1 ,992 024 -. 020 2,003 13.400 42,066 -4.064 31 ,045 -.030 5~;906 108,254 17.269 9.238 75,917 2744.8:20 544,270 Pag~ 19 FILE TRAILER File name: &GSF'01.002 Haximum length: 1024 TRAILER RECORDS Service name: File %ppe: LO Version Next file: Date: Page 20 ~*** FILEiHEADER **** *********************** File name: ,003 Version Date: Haximum length: I024 File t~pe: LO Previous file: INFORMATION RECORDS Page 21 HNEH CONTENTS UNIT TYPE CATG SIZE CODE ERROR .CH WN FN COUN STAT CTRY APIH LRTI LONG SECT TOWN RANG EKB EDF EGL PD LMF DMF RUN TIME DATE L¢C SON LUH FL LUL ENGI WITH DD DL CBD1 CBLI TLI BLI TCS TLAB BHT MRT MT MSS DFO HVIS DFPH DFL RH RHF MFST HFSS AMC ARCO ALASKA IHt ................. 2H-25 APl HUM: 50-103-20152 ................ KUPARUK bATE LOGGED: 03.25-91 ................ NORTH-SLOPE .................................... ALASKA .................................... USA .................................... 20152°00.0 ............................................... 0 Deg 0 Hin 0 0 Sec N · ° t I 0 Deg. 0 Min. 0. 0 Sec. W ........................ llN ......... OeE ........ . 130,000 ..... t29,-000 ..... 105.00'0 .... , KB .......... KB .......... 2200.000,.,, 25/ 3791.... 666061 ,, 51.939 , NORTH SLOPE YARBRO GILSTRAP 3175.000 ................................................ zi74.ooo ................................................ ~..o~o ................................................. ~' °°°;;;;:' i''' i" i' i ":' ;' i'" ii'i" i' '~ i' i'i: 'i ...... ~=.~oo ............................ 31.63.000 ................................................ t900.000 ................................................ 2200.000 ..... . ............... *°'°°°"iii"i'iiiii"'i"i'i'"iii"i'iii:"i"iii'ii'i ¢0.000 ........ , ............... ~EL?8£NER .................... , ............... ¢.600 ................................................... 45.000 .................................................. 9.000 ................................................... 0.400 ................................................... 8,050 ................................................... ¢. ~0 ................................................... 71 .000 .................................................. ~EflS ............................................. 4.350 ................................................... tllll/lllllllllll$llltlllllll$1111lllllllll lllllllllllllllllllllllllllll°illlllllltlll Illllltlllllllltllllllllllllll$111111111lll ;i: ....... :: ................. : ....... i ..... ~ltl~ll Illlllllllllltlll IIIllll 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 4 68 0 0 34 65 0 0 34 65 O 0 2 65 0 0 3 65 0 0 3 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 0 3 2 65 0 3 2 65 0 3 2 65 0 0 2 79 0 0 4 68 · 0 0 8 65 0 0 2 29 0 0 10 65 0 0 10 65 0 0 20 65 O 0 20 65 0 0 20 65 0 0 20 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 HR .0 2 4 68 HR 0 4 4 68 DEGF 0 1 4 68 ~EGF 0 1 4 68 0 2 20 65 0 2 20 65 LB/G 0 2 4 68 CP 0 2 4 68 0 2 4 68 0 2 4 68 OHHM 0 2 4 68 OHMM 0 2 4 68 DEGF 0 2 4 68 0 2 12 65 OHMM 0 2 4 68 INFORMATION RECORDS P~ge 22 MNEM CONTENTS UNIT TYPE CATQ SIZE CODE ERROR HOST g~ OO'O . DEaF 0 ~ 4 68 .......... ::'": ................................... o l ~t t Sli lei Iltllell$1Stll$11lllllletlllllllllt OS 1~.000 ........................... . ...................... 0 ~ ~ BS J~ ~'0 0 3 4 t IlelllltlllllSellllllllllellltllllllllelllllllllll COMMENT RECORDS Well Locat Well Locat Well Locat Well Loc~t Well File. Wel 1 File Well File Well File ion Comment l: SURFACE: 114' FSL & 579' FWL ion Comment 2: ion Comment 3: ion Comment 4: Comment 'l: HRI-SDL-DSN RUN IN COMBINATION. Commen%.2: Comment 3: Comment 4: DSN RAN DECENTRALIZED, USED "SP FISH" IN PACE OF "SP" DUE TO FLOATING "SP ELECTRODE", LIS.tape wri:tten bv: ANCHORAGE COMPUTING CENTER All curve and tool mnemonics used are those which most closel~ match Halliburton curve and tool mnemonics, HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MHEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT ?5.00 4000.00 GR2 SDL GAP.I GR SDL GAPI 1333,50 3J85,00 FDSN2 DSH2 CPS FDSH DSN2 CPS ~333,50 3185,00 HDSH2 DSH2 CPS HDSN DSN2 CPS t333,50 3~B5,00 HPHI2 DSN2 DECP HPHI DSN2 DECP 1333.50 3185.00 HRAT2 DSH2 C/C NRAT DSH2 C/C 1333,50 3185,00 DPHI2 SDL DECP DPHI SDL DECP ~333,50 3~5,00 DRH02 SDL G/C3 DRHO SDL G/C3 1333,50 3185,00 FSDL2 SDL CPS FSDL SDL CPS t333.50 3~85,00 NSDL2 SDL CPS NSDL SOL CPS 1333,50 3185,00 Page 23 PE2 SDL PE SDL 1333.50 3185,00 · PELC2 SDL PELC SDL 1333.50 3185,00 QL2 SDL QL SDL 1333.50 31~5.00 QS2 SDL QS SDL 1333,50 3185,00 RHOB2 SDL G?C3 RHOB SDL G?C3 1333.50 3155,00 CALI2 SDL IN CALI SDL IN 1333.50 3185.00 HDR2 HRI HDR HRI 1333.50 3185,00 HDX2 HRI HDX HRI 1333.50 3185..00 HHR2 HRI HHR HRI 1333.50 3165.00 HHX2 HRI HHX HRI 1333.50 3185.00 HDRS2 HRI OHNN HDR$ HRI OHHN 1333,50' 3185,00. HHRS2 HR! OHHH HHRS HR! ' OHHH 1333,50 31S5,00 HDCH2 HR! HNHO HDCH HR! NNHO 1333,50 3185,00 HHCN2 HR[ HNHO HNCH HR! HHHO 1333,50 3185,00 DFL2 HR! OHNH DFL HR! OHHN 1333,50 3185,00 TEH.S'2 SDL LB TEHS SDL LB 1333,50 3185,00 FZSH2 HR! HV FZSH HR! NV 1333,50 3185,00 d ENTRY DA~TA FORHAT SPEC I F I CAT I'ONS TYPE SIZE CODE Page 24 0 1 66 TYPE DESCRIPTION Datum specification block zubT%~pe Terminator ( no mope entpies ~ DATA FORMAT SPECIFICATIONS DATUM SPECIFICATION' BLOCKS MNEM SERVICE SERVICE API API API API FILE ID ORDER # UNIT LO~ TYPE CLASS MOD # PRC # SIZE LVL SMPL RC II PROCESS INDICATORS DEPT GR SDL FDSN DSN2 NDSN DSN2 HPNI DSN2 NRAT DSN2 DPHI SDL DRHO SDL FSDL SDL HSDL ~DL PE SDL PELC SDL ~L SDL QS SDL RNOB SDL CALI SDL HDRS HRI HMRS HRI HDCN HRI NMCN HRI DFL HRI TENS SDL FISH NRI 66606! FT 0 0 0 0 .'3 66606i GAPI ':34 0 0 4 2 66606i CPS 94 0 0 4 2 66606l CPS 94 0 '0 4 2 66606l DECP 94 0 0 4 2 666061 C/C 94 .0 0 4 2 666061 DECP 94 0 0 4 2 666061 G/C3 94 0 0 4 2 666061 CPS 94 0 0 4 2 666061 CPS 94 0 0 4 2 666061 94 0 0 4 2 666061 94 0 0 4 2 666061 94 0 0 4 2 666 06 J 94 0 0 4 2 666061 G/C3 94 0 0 4 2 666061 IH 94 0 0 4 2 666 06 ! 94 0 0 4 ;2 666 06 1 94 0 .0 4 2 66606! 94 0 0 4 2. 666061 94 0 0 4 2 66606~ OHNH 94 0 0 4 2 666,06 1 OHNM 94 0 0 4 2 666:061 MMHO 94 0 0 4 2 .666061 MNHO 94 0 0 4 2 666061 OHHM 94 0 0 4 2 666061 LB 94 0 0 4 2 666'061 NV 94 0 0 4 2. 4 0 1 613 4 0 1 68 4 0 1 68 4 0 1 60 4 0 I 60 4 0 1 69 4 0 1 68 4 0 1 60 4 0 ! 68 4 0 I 68 4 0 1 68 4 0 I 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 t 68 4 0 1 68 4 0 1 68 4 0 1 60 4 0 1 68 4 0 I 68 4 0 1 68 4 0 I 68 4 0 1 68 4 0 1 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000,000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 0'00000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 Page 25 DATA RECORDS D£PT ~;R FDSN NDSN NPH I NRAT DPH I DRHO FSDL NSDL PE PELC QL QS RHOB C~aL I HDR HDX HMR HMX HDRS HMRS HDCN HHCN DFL TENS FISH 2900.000 71.100 1366,530 13532.475 ,478 10.753 .303 .048 10661..016 16384,605 2,633 2.761 -,077 .043 2,151 12.396 94.419 ,568 123.731 1,334 8,007 7.323 124.886 136.556 5.195 2944,963 555.798 2800,000 86.754 1402.349 13662.686 ,465 10.579 .275 .055 9985.416 16282.461 2.767 2.869 -,001 ,043 2.196 12.709 95.152 .860 99.648 8.071 9.059 8.680 110.391 115.209 2,296 2982,851 546.630 2700.000 69. 050 1410.793 1366:9.469 ,465 10.536 .275 .040 9715.416 J5999,605 2,933 3.186 -.012 -,001 2.196 12,811 75. 255 t?. 076 79. 556 28. 595 12,182 11 . 729 :82. 086 :85. 256 9. 127 2673.340 545.382 2608. 000 67,235 1'338,552 13637.670 .495 11 . 063 .300 . 049 06 0:8.215 16376,461 2. 825 2.99:8 -,064 . 045 2. 154 !2.:811 55. 585 6,24Q 57,651 13.521 15,996 15,475 62.515 64. 620 I I , OOl 2816,299 540,923 2500.000 ?9.544 1297.438 13311,219 ,500 11.140 .289 11477,016 17377,316 3,069 3,077 -.021 -.042 2.173 12.665 :83.252 8.077 92.23:8 17.989 10.571 10.584 94,59:8 94.4:86 7,055 2716.22:8 550.556 3000.000 66,504 1396,5:84 13770,633 ,468 I 0,?06 ,303 , 039 10552.215 1'6257,033 2,515 2,601 -,055 .003 2,150 13.033 :89. 707 9. 273 95. 421 5. 372 9,603 9.69:8 1 04. 137 1 03, 119 6,98;4 2944,963 553. 748 3100,000 93,317 1390.201 1366:8.539 ,474 10.676 ,263 ,060 9728.617 16241 .:891 2, :830 2,929 -, 035 -. 005 2.21 ? 12.527 137. 132 1.4,526 158.790 :8,237 5. 786 5.48:6 172.:840 1:82,296 3.692 323-0.8:81 564.444 Page 26 31:85.000 83.927 1262.517 13486.662 ,533 11.599 ,314 .016 10378.615 15945,033 3,147 3.0:87 ,333 .200 2.132 12.107 59.328 4.61:8 56,201 ,320 16.742 17.45:8 59.729 57.279 -9.626 3202.290 123450000. DATA RECORDS DEPT GR FDSN NDSN NPHI NRAT DPHI DRHO FSDL NSDL PE PELC QL QS RHO8 CALI HDR HDX HHR HHX HDRS HHRS HDCN HHCN DFL TENS FISH 2400. 000 43. 768 1518. 016 14698.691 ,454 1 0.5i 4 .389 3245.41 6 i6877.605 2. 020 1 .870 .i 08 -. 028 2. 009 42,1 08 -4,228 30,517 .647 55,502 I Ol , i3i t8,018 81 , 353 2759. I i 6 534. 281 2300,000 60,27.0 1335.262 13514,961 ,492 10.990 ,357 t2038,4t6 16564,746 2,518 2.533 ,037 -.012 2,06i 57,766 i,670 64,053 1,329 15,683 15,034 63.763 1.0.988 2544.677 533.153 2200,000 47,823 1502,124 14593,1;'0 ,467 1 0.549 ,377 12374,217 16433,031 2,238 2,313 -,027 ,007 2., 028 44,125 . 2,582 44. 549 -, 785 23,683 22. 883 42,224 Ie,213 .2444,6.05 518,066 21.00, O01D 71 ,616 1295,794 132419,027 .495 11 ,101 ,31.0 1.0;:'90.41 6 16321 . 176 2. 753 2. 720 -. 023 . 052 2. i39 69,656 2,,222 75,540 -, 098 12,595 12,416 79.397 8,91 2 2330.238 54! , 728 2000.000 42,155 1279,358 13561,674 ,524 11,510 ,384 12468,016 16419,891 2,471 2,701 -,033 -.002 2,017 39,183 1,961 42,947 .201 22,286 21,070 44,871 14.981 2458,901 535,755 1900,000 66,579 1357,065 1354'0,939 ,482 1 0,834 ,282 i0231,016 16403,891 2.686 2.855 -,011 -,'062 2.185 59,436 2,524 68,380 ', 'I75 15.780 14,294 63,370 9,886 2487,493 546,858 1800,000 70.546 1325.392 13786.031 ,509 11.294 .269 10009,016 16442,.031 3,037 3,061 ,109 .049 2.206 43,304 1,674 46.342 .024 21,087 20.198 47.423 1'5,508 2315,942 532,117 1700.000 62.955 1490,157 14'I78.176 ,447 10,331 ,326 11814,416 16926,031 2,039 2,264 -.008 ,Ol? 2,112 36.751 .512 38.328 -3.410 32.277 29.044 30.981 26.978 2773,412 529.541 Page 27 .028 13.410 9.888 ,030 i2.429 66.517 .011 12.303 43.700 ,041 12,696 80.540 .009 12.253 47,461 ,060 12,525 69.958 .067 12,338 49,5 09 ,066 12,854 34.430 DATA R£CORDS D~PT ~R FD~H ND~N NPHI F~DL NSDL PE PELC QL HDR HD~ HMR HMX HDRS DFL TENS FISH 1600. OOO 68,435 127.0,321 1358! . 1 02 ,529 12022,41 6 16702.746 2. 648 2. 824 , 003 26. 364 . -,496 28. 707 -.482 34,389 23,973 22 01 .574 551.727 1500,000 42. 096 1169. 384 12914.873 ,537 13049.615 -165t7,6,05 2,037 2.352 -,069 1 O. 2618 -I . 567 10. 007 -1 .9.01 ! 16,371 141 ,939 2.072,91 I 545.8'11 1400,000 44,480 1273,196 131 03.625 .467 13428.2t5 1691.0,746 2.229 2.268 -,OOi I 1 , 286 2,408 t 0.218 7,336 1 08. 700 93. 749 2201 ,574 5:38,401 NRAT DPHI DRHO QS RHOB CALI HHRS HDCH HHCN 11.609 033 992 022 14.28i 11 ,175 -. 033 03. 045 Page .349 2,075 29. 079 ,042 12,595 31. 167 ,399 I .992 8,593 ,005 iS. 133 8.750 ,390 2. OO& 9,200 .029 18.85g 9.704 FILE TRAILER ************************ File name~ &G5FOl,003 Maximum, length: 1024 TRAILER RECORDS Page 29 Service name: Film type: LO Version #: Next tile: Date: ********************** ~** TAPE..HEADER ********************** $~,rvice name: &G5F01 Previous tape: Date: 91/04/01 Comments: Origin: Tape name: Continuation #: 01 ********************** FILE HEADER File name: ,001 Maximum, length: 1.024 Service name: File type: LO Version #: Date: Previous INFORMATION RECORDS Pag~ 30 MNEH CONTENTS UNIT TYPE CATG SIZE CODE ERROR CH ARCO ALASKA INC ................. 0 0 40 65 WN 2M-25 API HUM: 50-103-20152 ................ 0 0 40 65 FN KUPARUK DATE LOGGED: 03-25-9! ..... ~ ........... O 0 40 65 COUH NORTH SLOPE .................................... 0 0 20 65 8TROT ALASKa .................................... 0 0 20 65 CTRY USA ......... , .......................... 0 0 20 65 APIN 20152,00'0.., .......... , , ...................... , ......... 0 0 4 68 LATI 0 Deg. .0 Min. O. 0 Sec. N ........................ 0 0 34 65 .o ..,.?. .o..o ,. .......... . ..... : ..... :.. o o SECT ..... ..................................... 0 0 2 65 TOWN tIN ..,. .................................. ........... 0 0 3 65 RANG 0SE: .......... : ................................. :,,',:,,. 0 0 3 65 EK8 130.'000 ................................................. FT 0 3 4 68 EDF 129. 000 ............... , ................................. FT 0 3 4 68 PD Hu, : ....... , ..... ', ................ ;: ...... 0 3 2 65 LMF KB .. ................. , ...................... 0 3 2 65 C>.F~ .... , ,, .............. ,,, ......... , ........... o ~ '~ e~ ..... , .......... , ................ , ..... 0 0 ~, ?~ TIME .......................... . ............. 0 0 4 68 DATE 25/' 3/'91., . ,, ,, , ......... ...... .......... ........... 0 0 8 65 LCC ~o ............................................ '" "' :': : : o 0 ~ ?e so. ~eeo~ ...... , ....................................... o o ~ oe~ LUH 51939 . , ........................................... 0 0 ! 0 65 FL NORTH SLOPi'-' .................................... 0 0 20 65 LUL NORTH SLOPE .................................... 0 0 20 65; £.~ VA~o .................................... 0 o 20 eS WITN G:ILSTRAP ................... . ................. 0 0 20 e5 DD 3175.000 ............ , ........... , ....................... FT 0 3 4 68 DL 3~ 7'4. 000 ............. ,. ..................... . ........... FT 0 3 4 68 CBD! 1 !5.000 .... ............................................. FT O 3 4 68 CBLI 114. 000 .......................... , ................. . .... FT 0 3 4 68 TLI 92,000 ........ , .......... , .............................. FT 0 3 4 68 BLI 3163.000 ................................ ....... , ........ FT 0 3 4 68 TCS 1900. 000 .................. . ............................. HR 0 2 4 68 TLAB 2200. 000 ...... , ............. ..... . ....................... HR 0 4 4 68 BHT 90. 000 ..... , ............. , .... ,, ..., ..................... DEGF 0 I 4 &8 NRT r 90,000 .................................................. DECF 0 1 4 68 liT GEL/BENEX .................................... 0 2 20 65 HSS CIRCULATED ........ 0 2 20 65 DFD 9,6'00 ............... :,,::::::::::::::::,.::::::::.:..:,: LB/'C 0 2 4 68 avis 45.000 .................................................. cP o 2 4 ee DFPH 9.0 O O ................................................... 0 2 4 68 DFL 8 400 . ......... 0 2 4 68 RMF 9. 230 ......... OHMM 0 2 4 68 HFST 71 .O00 ................. , ................................ DEGF 0 2 4 68 HFSS HERS. 0 2 12 65 e,c 4.38o...,...:: :::'.:::::::::'.::::::::::::::::::::::::'.: :'. oH~ o .~ 4 es INFORMATION RECORDS Pag~ 31 MNEM CONTENTS I ~I IlII ME~aS., ......... ' ......................... 16 'O00 · ~ i I i, I i ! I I I I, ii ! ii t I ii I $ i I ii $ i ii I i ii i ~ I I d I * I i ii ii 'I ii I I I I i I i I I 12 1250.......................... ' UNIT OEGF TYPE CATG III~ 2 2 3 3 SIZE 4 12 4 4 CODE 65 ERROR COMMENT Wel W~I Wel I Location Comment I Location Comment I Location Comment SURFACE: FSL & 579' FWL RECORDS I Location Comment 4: I File Comment I: THIS SECTION CONTAINS HIGH RESOLUTION SDL/DSN DATA ONLY, 1 File Comment 2: DSM RAN DECENTRALIZED, 1File..Comment 3: Well File Comment 4: ** LIS tape wriitten by: ANCHORAGE COMPUTING CENTER *m All curve and tool mnemonics used ape those which most closely match ** Halliburton curve.and tool mnemonics. ******************************************************************************** HALLIBURTON TO SCHLUMBERGER TOP BOTTOH MNEH SERVICE UNIT NNEM SERVICE UNIT -DEPTH DEPTH DEPTH FT DEPT FT 1300,00 400'0,00 GR3 SDL GAPI GR SDL GAPI 1350.50 3185.00 FDSN3 DSH2 CPS FDSH DSH2 CPS 1350,50 3185.00 NDSH3 DSH2 CPS HDSH DSH2 CPS 1350,50 3185,00 NPHI3 DSH2 DECP NPHI. DSH2 DECP 1350,50 3185,00 HRAT3 DSH2 C/C HRAT DSH2 C/C 1350.50 3185.00 DPHI3 SDL DECP DPHI SDL DECP 1350.50 3185.00 DRH03 SDL G/C3 DRHO SDL G/C3 1350,50 3185,00 FSDL3 SDL CPS FSDL SDL CPS 1350,50 3185,~0 NSDL3 SDL CPS HSDL SDL CPS 1350.50 31B5.00 Pag~ 32 PE3 . SOL PE SDL 1350.50 3185.~0 PELC3 SDL PELC SDL 1350.50 3185.00 QL3 80L QL 8DL 1350.50 3~85.00 RHOB3 SOL G?C3 RHOB SDL G/C3 i350.50 3185.00 CALI3 SDL IN CALI SDL IN 1350.50 3185.:00 TENS3 SOL LB TENS SDL LB 1350,50 3185.00 ,** ENTRY BLOCK9 **** *********************** DATA FORHAT SPEC I F I CA T I'OHS Page 33 ENTRY TYPE SIZE CODE 1 6 1 66 0 1 66 ***************************** ENTRY BLOCK LEGEND ***************************** TYPE DESCRIPTIOH 16 Datum specification block sub-tvpe 0 Terminator ( no more entriez ) DATA FORMAT DATUM SPECIFICATION BLOCKS SPECIFICATIONS MNEM SERVICE SERVICE APl API API API FILE PRC # ID ORDER # UNIT LOG TYPE CLASS MOD # SIZE LYL SHPL RO PROCESS INDICATORS DEPT GR SDL .FDSH bSN2 NDSH DSN2 NPHI DSH2 NEAT DSH2 DPHI SDL DRHO SDL FSDL ~DL NSDL SDL PE SDL PELC SDL aL SDL RHOB SDL CALI SDL TENS SDL ~66 061 P I 94 0 0 ~ ~ 4 0 t 68 666106 ! CPS 94 0 0 666061 CPS 94 0 0 S 3 4 0 1 68 666061 DECP 94 0 0 5 3 4 0 1 68 666061 CYC 94 0 0 5 666061 DECP 94 0 0 5 3 4 0 1 68 666061 ~C3 94 0 0 5 3 4 0 1 68 666061 CP~ 94 0 0 5 3 4 0 i 68 666'06t CPS 94 0 0 5 3 4 0 ~ 68 66606 t 94 0 0 5 3 4 0 66606~ 94 0 0 5 3 4 0 t 666 061 94 0 0 5 3 4 0 t 68 66606 t 94 0 0 5 3 4 0 1 68 66606~ GYC3 94 0 0 5 3 4 0 t 68 66606 t I N 94 0 0 5 3 4 0 1 68 666 061 LB 94 ,0 0 5 3 4 0 000000 00000 0000 0000000 0 0 O00OO0 000000 000000 000000 000000 000000 000000 000000 000000 '000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000.000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DATA RECORDS DEPT GR FDSN FSDL N~DL PE TENS 3185 t0118 3473 3100 9826 3545 3000 1 05 05 2959 ;2900 t 1 024 3002 2800 9956 2944 2700 9398 2844 2600 '10954 2830 NDSH NPHI NRRT DPHI DRHO PELC gL QS RHOB CALi ,000 9't ,225 J233.77'9 13266.613 ,61 5 16985,031 2,838 2.906 ,912 , 000 86,580 1396,1 ?2 1 3845,932 ,61 ? 15990,36? 2,698 2,894 ,392 , 000 73,162 1429,128 13820,037 ,61 5' t6285,365 2,532 2,639 ,259 ,000 7'6,364 1315,935 13560,740 ,61 5 16285,033 2,576 2,723 .146 .000 86,858 1510.585 .615 15977.033 2. 789 3,163 ,000 69,360 1453,860 13587,295 ,617 16287,.033 3,353 3,173 ,891' ,000 69,155 1333,411 13527,891 ,6t5 16426,36? 2,800 2.727 .595 2500. 000 I004.615 2607. 636 2400 13462,615' 2816,299 69.255 1209,159 13322,850 169.00,699 3,123 2,968 . 000 37. 334 1526.068 14739,256 17249. 031 2. 063 I .753 ,539 I 1 .676 ,245 ,112 -~600 .200 2,246 12,044 .465 10. ?68 .27? .039 -,049 ,08i 2,192 12,499 ,464 1 0.500 .301 .041 ,018 , 154 2,154 12,829 ,497 11 . 189 ..3!9 , 037 -, 098 -, 034 2,124 12.507 .435 9,855 . 285 . 035 , 120 -, 034 2,180 12,774 ,449 10. 148 ,247 , 070 -, 096 . 056 2. 243 12,834 .491 11 . 016 , 309 , 04? -.002 . 110 2. 141 12.816 . 544 11 . 964 . 288 . 082 -. 083 -, 021 2. 174 12.940 .454 10. 487 .36:1 . 052 -. 028 . 049 2. 021 13.511 Page 35 DEPT GR FDSN FSDL NSDL PE TENS :_..-- : :: :- : :7:~-- : __ ._:::_. - ~ .::t_ t '- -t- .: . 2300,00'0 66. 916 13e?.936 12100,6t5 16481 ,699 2,4;92 2744.82.0 22'00,000 40,4:73 1592,180 12464.615' 16573.367 2,354 2444,605 21.00,000 67,679 1196.854 I 0972.61 5' 16313. 367 2,65.9 2558. 973 ;2000,000 34. 165 t369.411 12270,615 16771 . 031 2,657 233'0. 238 1900,000 57. 222 1349. 665 'I 0062.615 !628i . 033 2, ;;42 2558,9?3 1800,000 .28.418 1443,554 I 0320.615 16193.699 2.753 2323.125 1700.000 '11640.615 3045,034 1600,000 11710,615 2158,687 15.00,000 12804,615 21 O1,503 62,126 1544,653 17.064,367 I .995 63,957 1610,291 16844, .031 2,685 45,~46 1224,545 16746.031 2,231 DATA RECORDS NOSH NPHI NRAT DPHI DRHO PELC QL QS RHOB CALI 3527. 891 ·484 1 0,583 . 36? ,.017 2. 628 -,017 -. i 40 2. 044 i2.457 'I 4590. 043 ,442 9. 950 , 376 , 020 2,440 -, 122 , 009 2,030 12,371 13270,535 ,535 12,039 , 312 , 03<) 2,590 -, 174 . 007 2. 135 12.721 13529. ?29 .490 t O. ?28 .. 359 , 041 2.617 -. 047 -. 050 2.05::3 12.384 13529. 467 ,494 1 0,883 .2;81 . 055 2.935 -, 151 -. 024 2.18;; 12,562 '1 386.0. 734 . 460 10. 426 . 289 . 044 3. 090 -, 049 -. 015 2,172 !2.454 14342,986 ,439 1 O, 082 . 313 , 082 2,249 , 141 ,845 2,134 12,904 15497,045 , 4?0 10, 446 , 335 , 057 2,789 -,'025 . 071 2,097' 11 .614 13249. 102 ,534 11 . 248 .383 ,026 2,146 ,068 ,044 2. 018 14,899 Page 36 DATA R£CORDS DEPT GR FDSN NDSN NPHI NRAT DPHI DRHO FSDL NSDL PE PELC QL QS RHOB CNLI TENS 400,000 3498.6 t 5' 2158,687 37.406 t289.219 13246,488 .466 ~1.157 ,40t ,019 t6854,367 2. 133 2.233 . 125 -. 083 I ,989 19. OOO Page 37 File name,.' &GSF01.'O01 Page 38 Service name: Version Maximum length: !024 File t~pe: LO Next ¢ile: REEL TRAILER :Service name: &GSFO! Next reel: Date~ 91/04/01 · om. mo.s*~ .mt, me .o Comments: Origin: Reel name: 666061 Continuation #: O! (NOTE: **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # i SERVICE NAME: SSDS DATE: 91/04/03 ORIGIN OF DATA: 2M25 REEL NAME: ARCO CONTINUATION #: O1 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: MPT DATE: 91/04/03 ORIGIN OF DATA: 2M25 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING' INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** RECEIVED 2 2 ** FILE HEADER ** FILE NAME: 2M25.DAT SERVICE NAME: MPT VERSION #: V 3.26 DATE: 91/04/03 MAX. RECORD LENGTH: FILE TYPE: EO PREVIOUS FILE NAME: ** COMMENTS ** FILE SEQUENCE 1024 COMPANY: ARCO ALASKA INC./ WELL: 2M-25/ API#: 50-103-20152/ DATE: 31-MAR-91 LOCATION: LAT. 70°16'18.586" LONG. 150°05'37.186", 114' FSL & 579' FWL, SEC 27 TWP. llN, RANGE SE, NORTH SLOPE BOROUGH, ALASKA, USA/ RIG: DOYON 14 - P. WHITE COMMENTS >> TVD CALCULATED FROM MWD DIRECTIONAL SURVEYS. NUCLEAR LOGS ARE CALIPER CORRECTED. NO TOOL WEAR FACTORS APPLIED. NEUTRON PROCESSING ASSUMES A SANDSTONE MATRIX & FORMATION WATER SALINITY OF 14,545 PPM CL. DENSITY ASSUMES A MATRIX OF 2.65 G/C3 & FLUID DENSITY OF 1.0 G/C3. TOOL STRING #DH099RND6S ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT ROP CALC TVD CALC NPSC 99RND6 RHOB 99RND6 CAL 99RND6 FXD CALC DDD CALC NDIS DWD EDIS DWD FXN CALC DDN CALC NF0 99RND6 NFl 99RND6 NN0 99RND6 NN1 99RND6 FXE CALC DDE CALC EWR 99RND6 GRC 99RND6 DEVI DWD ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 PPF 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 PPF 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 PPF 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 DEG 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE 4 1 66 0 1 66 ENTRY 255 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT ROP CALC TVD CALC NPSC 99RND6 RHOB 99RND6 CAL 99RND6 FXD CALC DDD CALC NDIS DWD EDIS DWD FXN CALC DDN CALC NF0 99RND6 NFl 99RND6 NN0 99RND6 NN1 99RND6 FXE CALC DDE CALC EWR 99RND6 GRC 99RND6 DEVI DWD ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 i 4 0 I 68 FT/H 0 0 0 0 I 4 0 i 68 FT 0 0 0 0 i 4 0 i 68 P.U. 0 0 0 0 I 4 0 i 68 G/C3 0 0 0 0 1 4 0 i 68 INCH 0 0 0 0 i 4 0 i 68 HOUR 0 0 0 0 1 4 0 i 68 PPF 0 0 0 0 i 4 0 i 68 FT 0 0 0 0 1 4 0 I 68 FT 0 0 0 0 1 4 0 I 68 HOUR 0 0 0 0 i 4 0 1 68 PPF 0 0 0 0 1 4 0 i 68 CTS 0 0 0 0 i 4 0 i 68 CTS 0 0 0 0 i 4 0 i 68 CTS 0 0 0 0 1 4 0 I 68 CTS 0 0 0 0 i 4 0 i 68 HOUR 0 0 0 0 1 4 0 i 68 PPF 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 I 68 API 0 0 0 0 1 4 0 1 68 DEG 0 0 0 0 1 4 0 1 68 :H~N HqI& OH :H~A~ H~I~ :H~ON~I GHOOHH 'X~ ~0/~0/t6 9E'£ A :# NOISHHA · ~N :H~fN HDIAHHS · ~G'~ :H~fN H~I& ~ 00'00~L O~ 00'0~99 ~OH~ ~ SGHODHH ~G ~I ~ 096'~ 0~'666- 0~E'666- 0~'666- 0gE'666- 0~E'666- 0~E'666- 0~E'666- 0~'666- 0~'666- 0~E'666- 6Lg'CLE 9~L'0EI 0~E'666- 0~E'666- 0~'666- 0~'666- 0~E'666- 0~6'Ig99 0~E'666- 000'00~£ 096'~' AI8'~6 0~'666- 0gE'666- 0~'666- 000'899E 000'E~9E 000'A9~ 000'L9~ ~'~ 0~'666- I96'I~ I88'9ti 0~E'9 0~E'666- ~9A'8 68Z'~ 996'6~ 090'E9~9 68L'SE 000'009£ 699'9g 9~'00I 6gg'~ ZEE'8 699'I 000'gggE 000'E£~E 000'ES~ 000'6~9 L99'9 0g~'666- 990'06E 8~8'EOI 0~E'9 0~E'666- 8~A'8 6L~'~ LIE'S9 6~'ELE9 ILI'~9 000'00~£ 08g'£~ I98'96 018'~ &99'9 6~E'I 000'969E 000'899E 000'IE9 000'IA9 L9I'9 0~'666- 0ES'99E E~E'88 ~9E'~ 0~E'666- ~9'8 96E'~ 9~9'LE ~'~819 9EL'0~ 000'00Et 969'8~ 099'0£ 890'II 000'~ 69&' 000'896E 000'9~8E 000'I6~ 000'6~9 ZE6'I 0~E'666- 68E'~0E LgE'Z& 8~8'I 0gE'666- 999'8 8I~'~ ~9~'~ 690'~609 6Z~'98 000'00I£ 0~E'6~ 86S'I~I A6S'I £9I'A 86S'I 000'EZEE 000'EI~E 000'I~ 000'L9~ 98~'~I 0~E'666- 66g'9~I CZA'L~ 0~E'666- 89A'8 09Z'~ 909'£9 669'L009 I00'I~ 000'000£ ~00'0~ ~6'~I 69~'~ 000'~ EII'I 000'889E 000'~0GE 000'~9 000'IA9 ~I'~ 0~E'666- ~6'60I ~L~'I9 89~'~ 0§E'666- ~'8 ~99'~ 98~'I9 EL~'0~6~ E9I'6C 000'0069 588'0~ L90'gEE 09~'I £9~'~ I90'I 000'099E 000'099E 000'6~8 000'A88 IL~'~ 0~'666- E~'~9 LEI'gE 0~E'666- 0~E'666- ~89'8 ~6E'~ £66'~£ L~'9£8~ 906'I~ 000'0089 9~8'IE 0~E'666- 0~'666- 0~E'666- 0~E'666- 0~'666- 0gE'666- 0~E'666- 0~'666- 0~'666- 0~'666- ELL'~I 989'~ 0~E'666- 0~E'666- 0~'666- 0g~'666- 0~E'666- Z96'89£~ 0~E'666- 000'00£9 00I'EE 0g~'666- 0~'666- 0~E'666- 0~'666- '0~E'666- 0~E'666- 0GE'666- 0~E'666- 0~E'666- 0~E'666- 698'0I- £~C'9- 0gE'666- 0§E'666- 0~'666- 0~'666- 0~'666- ~'90L~ 0~E'666- 000'0~99 IAHG DHD HMH HGG HX~ INN 0NN IMN 0~N NGG NX& SIGH SIGH GGG GX~ ~D ~OHH DS~N GA~ ~OH ~HG ~ (~& 00I A/sAS) NOI~DI~IHHA ~G ~ ~k'HO~ SI~ -'DNI DNI~OD H~H~OH~H~ :SANH~OD :Hk~fN ~HHH ~XHN I0 :# NOI~f~NI~NOD ODH~ :H~V~N ~HHH Z0/~0/~6 SGSS :H~N HDIAHHS ~{HO& SIq -'DNI DNI~d~OD W/1H~OH~H~ :S~NH~40D :H~N H4~ ~XHN I0 :# NOI~flNI~NOD gEnE :~G &O NIDIHO ~ :H~fN HDIAHHS (NOTE: MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 91/04/10 ORIGIN OF DATA: MPT REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: MPT DATE: 91/04/10 ORIGIN OF DATA: 2M25 TAPE NAME: KUPARUK CONTINUATION #: 01 PP~VIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** RECEIVED APR 2. 2 7991 Alaska Oil & Gas Cons. COl~miSSion Anchorage SHDO~ HOI~DI~IDH6S ~~G (SHIH~NH HHON 0H) H0~NI~H~ N~OG 'HOI~DHHIG O0~ NOI~IHDEH0 99 I 0 gg~ 99 I ~ XH~NH HGOD ~HH HZIS H6X~ SHDO~ XH~HH 89 T 0 89 T 0 89' T 0 89 I 0 ~ I 0 0 0 0 HDNI 89 T 0 ~ I 0 0 O' 0 ~NHO 89 I 0 ~ I 0 0 0 0 I6k~f 89 T 0 t I 0 0 0 0 H/~ 89 I 0 HGOD ~J~ 'ON ~ON ~D ~X~ DO~ #HHGHO H6HH ~6S DOH6 HZ~ H~I& I~ Ia-q Ia'q Ia-q ,l. IHfl HDiAHHS HDIAHHS HWqN SHD0~[~ HOI.I,~fDI.~IDH6S N.rI.,T,~(I (SHIH~HH HHON OH) H0~HI~/H~ N~40G 'HOI~DHHIQ OO~ NOI~6IHDSHG 99 I 0 gg~ 99 I ~ XH~NH H~OD 6HH HZIg H6X~ SHDO~ XH~HH 'GH~DHHHOD HH6ITqD XIH~¥~ HNO~SGN%fS X~ISOHO6 NOH~flHN = DS6N X~I~NHG H~fl~ = 50HH R-qH~D~N 'HH6IT~D = ~'D HOI~HHH~-~O-H~%fH = 60H I~ O~ ~H~DHHHOD X~H ~D = DHD 'NOI~DHS H~IA~OD HO~ 'q~G ** DATA VERIFICATION (every 25 FT) DEPT NPSC ROP GR EWR CAL GRC RHOB 3250.000 -999.250 -999.250 .-999.250 -999.250 -999.250 -999.250 -999.250 3275.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3300.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3325.000 43.026 -999.250 -999.250 4.019 9.168 -999.250 2.226 3350.000 44-.647 -999.250 89.671 3.482 9.669 98.639 2.406 3375.000 33.191 2873.584 67.757 7.133 9.172 74.532 2.583 3400.000 36.978 144.614 61.204 13.164 8.989 67.324 2.564 3425.000 38.862 110.613 79.830 5.062 9.033 87.813 2.436 3450.000 40.889 171.429 90.980 4.105 9.208 100.078 2.464 3475.000 41.641 128.571 88.818 4.335 9.434 97.700 2.414 3500.000 41.296 107.198 98.910 3.948 9.982 108.801 2.413 3525.000 46.896 3550.000 -999.250 127.017 71.966 2.751 9.691 79.163 2.270 141. 673 -999. 250 -999. 250 -999. 250 -999. 250 -999. 250 3575.000 -999.250 150.586 -999.250 -999.250 -999.250 -999.250 -999.250 3600.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3625.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3650.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** 26 DATA RECORDS ** ** FILE TRAILER** FILE NAME: COLVIL.DAT FROM 3250.00 TO 3650.00 FT ** TAPE TRAILER** SERVICE NAME: MPT DATE: 91/04/10 ORIGIN OF DATA: 2M25 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL T~AILER ** SERVICE NAME: SSDS DATE: 91/'04/10 ORIGIN OF DATA: MPT REEL NAME: ARCO CONTINUATION #: 01' NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** TAPE TERMINATED BY REEL TRAILER **********