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Home My WebLink About184-150ORIGINATED TRANSMITTAL DATE: 3/5/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5237 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 5327 1L-08 50029211750000 Production Profile (PPROF) 4-Mar-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 184-150 T40185 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.05 10:31:07 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 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 7810'feet None feet true vertical 6363' feet None feet Effective Depth measured 7810'feet 7041', 7156', 7403'feet true vertical 6363'feet 5665', 5767', 5988'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) J-55 J-55 7127' 7432' 5741' 6015' Packers and SSSV (type, measured and true vertical depth)7041' 7156' 7403' 5665' 5767' 5988' 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: 2398' 2272' Burst Collapse 7752' Casing 6334'7779' 2367' 110'Conductor Surface Production 16" 9-5/8" 78' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 184-150 50-029-21175-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025659 Kuparuk River Field/ Kuparuk Oil Pool KRU 1L-08 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 110' Well Shut-In 324-379 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 Cy Eller cy.eller@conocophillips.com (907) 265-6049 RWO/CTD Engineer 7306-7362', 7482-7500' 5901-5952', 6060-6077' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 3-1/2" 3-1/2" Packer: SLB BluePack Packer: BAKER FHL Retrievable Packer: Baker FB-1 Permanent SSSV: None By Grace Christianson at 1:12 pm, Oct 16, 2024 Page 1/6 1L-08 Report Printed: 10/15/2024 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) 9/15/2024 00:00 9/15/2024 05:00 5.00 MIRU, MOVE MOB P Pull sub off well. Hang tree in cellar. Shuffle rig mats to `L-08. Clean up around cellar on 1L-10..Spot sub over 1L-08.. 0.0 0.0 9/15/2024 05:00 9/15/2024 08:00 3.00 MIRU, MOVE RURD P Safe out rig, Work acceptance check list, Rig up tanks, FMC here to open up SSV. RIG ACCEPT 08:00 0.0 0.0 9/15/2024 08:00 9/15/2024 10:00 2.00 MIRU, WELCTL RURD P Take fluid on in pits, Build deep clean pill and heat PJSM to PT surface lines 0.0 0.0 9/15/2024 10:00 9/15/2024 10:15 0.25 MIRU, WELCTL SEQP P PT Surface lines to all tanks and manifold to 2500 PSI Bleed off well. Bled tubing down to 55 PSI, IA=0 0.0 0.0 9/15/2024 10:15 9/15/2024 12:00 1.75 MIRU, WELCTL KLWL P Bring pumps online 3 1/2 BPM 191PSI, wide open choke ICP=225 PSI FCP=367, Pumped 6460 STK, Pumped 376 BBl + 35 BBl deep clean pill. Clear 8.5PPG Seawater Coming back On High line 11:00 0.0 0.0 9/15/2024 12:00 9/15/2024 12:30 0.50 MIRU, WELCTL OWFF P OWFF 30 minutes, Blow down surface lines 0.0 0.0 9/15/2024 12:30 9/15/2024 14:00 1.50 MIRU, WELCTL MPSP P Install BPV, R/U Test equipment, PT 1000 PSI/10 Minutes. Good test. Blow down lines. R/D test equipment 0.0 0.0 9/15/2024 14:00 9/15/2024 15:30 1.50 MIRU, WHDBOP NUND P PJSM, ND production tree, Lay down 0.0 0.0 9/15/2024 15:30 9/15/2024 16:00 0.50 MIRU, WHDBOP NUND P Inspect hanger threads - Good 0.0 0.0 9/15/2024 16:00 9/15/2024 21:30 5.50 MIRU, WHDBOP NUND P PJSM on BOPE Nipple up, Set slip over blanking plug, NU DSA, & BOP. Set flow nipple. R/U trip tank hose. 0.0 0.0 9/15/2024 21:30 9/15/2024 23:00 1.50 MIRU, WHDBOP RURD P R/U testing equipment. Grease HCR's. 0.0 0.0 9/15/2024 23:00 9/16/2024 00:00 1.00 MIRU, WHDBOP BOPE T Initial BOPE test, Unable to obtain passing test. Begin troubleshooting. 0.0 9/16/2024 00:00 9/16/2024 02:45 2.75 MIRU, WHDBOP BOPE T Idenified leaking LDS. Call out FMC to change out packing on leaking LDS. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 9/21/2024 Page 2/6 1L-08 Report Printed: 10/15/2024 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) 9/16/2024 02:45 9/16/2024 11:30 8.75 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular, UVBR's, w/ 3 1/2" test joints. Test LPR w/ 7" test joint. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=300 PSI, after closure= PSI, 200 PSI attained =14 sec, full recovery attained =114 sec. UVBR's= 5 sec, LPRs= 5 sec. Annular= 19 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =2000 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Guy Cook. 0.0 0.0 9/16/2024 11:30 9/16/2024 12:00 0.50 MIRU, WHDBOP RURD P R/D test equipment, Blow down choke and kill lines. Pull slip on blanking plug 0.0 0.0 9/16/2024 12:00 9/16/2024 12:30 0.50 MIRU, WHDBOP MPSP P PJSM, Pull BPV 0.0 0.0 9/16/2024 12:30 9/16/2024 13:00 0.50 COMPZN, RPCOMP RURD P R/U 3 1/2" elevators, R/U Echold tongs. 0.0 0.0 9/16/2024 13:00 9/16/2024 13:30 0.50 COMPZN, RPCOMP THGR P P/U 3 1/2" landing joint, M/U to hanger, Set down 10K. BOLDS. Observed tubing jump on last LDS. Pull hanger to floor, PUW=51K 0.0 1,852.0 9/16/2024 13:30 9/16/2024 14:00 0.50 COMPZN, RPCOMP CIRC P Circ BU 3 BPM @84 PSI 1,852.0 1,852.0 9/16/2024 14:00 9/16/2024 14:30 0.50 COMPZN, RPCOMP OWFF P Flow check well, R/U HES control line spooler 1,852.0 1,852.0 9/16/2024 14:30 9/16/2024 16:30 2.00 COMPZN, RPCOMP PULL P Lay down landing joint and hanger. Start pulling 3 1/2' completion, Recover 59 Jts, 2 pups, 1 Cut joint @ 4.45'. Recovered 30 bands out of 31 1,852.0 0.0 9/16/2024 16:30 9/16/2024 18:30 2.00 COMPZN, RPCOMP RURD P Clean and clear rig floor. Load out recovered tubular's, Off load HES spooler, Change out elevators, R/D eckle tongs. R/U spinners 0.0 0.0 9/16/2024 18:30 9/16/2024 19:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #1 Tandum 6" string reamers and bull nose 0.0 9.6 9/16/2024 19:00 9/16/2024 21:00 2.00 COMPZN, RPCOMP TRIP P Trip in well from 9' to 1845 Light tag on 3 1/2 stub. SOW=55K No indication of damaged casing. Consult town. Revise plan forward 9.6 1,845.0 9/16/2024 21:00 9/16/2024 21:30 0.50 COMPZN, RPCOMP TRIP P Trip out 1845 to 1430'. PUW=60K, 1,845.0 1,430.0 9/16/2024 21:30 9/16/2024 23:00 1.50 COMPZN, RPCOMP MPSP P P/U Storm packer, RIH to set packer @ 105' COE, PT 1000 PSI / 10 minutes. Rig up to chart and chart test, Good test. Pull stand 1,430.0 90.0 9/16/2024 23:00 9/16/2024 23:30 0.50 PROD1, CSGRCY BHAH P At surface Lay down running tool 90.0 0.0 9/16/2024 23:30 9/17/2024 00:00 0.50 PROD1, CSGRCY NUND P Nipple down BOPE, 0.0 9/17/2024 00:00 9/17/2024 01:00 1.00 PROD1, CSGRCY NUND P N/D BOP. Rack back on pedistal. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 9/21/2024 Page 3/6 1L-08 Report Printed: 10/15/2024 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) 9/17/2024 01:00 9/17/2024 03:00 2.00 PROD1, CSGRCY RURD P Bleed pack off void. Remove ULDS. R/U Cameron tensioning tool. BOLDS on CSG head. 0.0 0.0 9/17/2024 03:00 9/17/2024 04:30 1.50 PROD1, CSGRCY CUTP P Apply pressure T/ tensioning jacks. Break remaining bolts on casing head. Grow 7" CSG. Initial force = 288K. Total growth = 28.5". Allow CSG T/ relax for 30 Min. 0.0 0.0 9/17/2024 04:30 9/17/2024 04:45 0.25 PROD1, CSGRCY RURD P R/D Cameron tensioning tool. Remove TBG head. 0.0 0.0 9/17/2024 04:45 9/17/2024 05:00 0.25 PROD1, CSGRCY BHAH P M/U BHA #3 _7" spear. 0.0 12.0 9/17/2024 05:00 9/17/2024 05:15 0.25 PROD1, CSGRCY CUTP P Engage 7" spear. Pull 100K tension over string weight. Slips stayed in place. Re-land in original slips. 20" of stretch. OAG = 48.5". 32.0 32.0 9/17/2024 05:15 9/17/2024 05:30 0.25 PROD1, CSGRCY BHAH P Release & L/D BHA #3 _7" spear. 32.0 0.0 9/17/2024 05:30 9/17/2024 07:00 1.50 PROD1, CSGRCY CUTP P Pull pack off. Cut escess 7" w/ WHACHS saw. Install new pack off. 0.0 0.0 9/17/2024 07:00 9/17/2024 09:00 2.00 PROD1, CSGRCY NUND P Install new tubing head. Install secondary IA valve. 0.0 0.0 9/17/2024 09:00 9/17/2024 09:15 0.25 PROD1, CSGRCY PRTS P PT pack off T/ 3000 PSI for 15 Min. 0.0 0.0 9/17/2024 09:15 9/17/2024 09:30 0.25 PROD1, CSGRCY MPSP P Set test plug. 0.0 0.0 9/17/2024 09:30 9/17/2024 12:00 2.50 PROD1, CSGRCY NUND P N/U DSA & BOP. Install flow nipple. R/U trip tank line. 0.0 0.0 9/17/2024 12:00 9/17/2024 12:30 0.50 PROD1, CSGRCY RURD P R/U testing equipment. Fill stack w/ fresh water. 0.0 0.0 9/17/2024 12:30 9/17/2024 13:30 1.00 PROD1, CSGRCY PRTS P PT stack breaks 250/3000 PSI. 0.0 0.0 9/17/2024 13:30 9/17/2024 14:00 0.50 PROD1, CSGRCY MPSP P Suck out stack, Pull test plug. Install wear bushing. 6 5/16" ID. 0.0 0.0 9/17/2024 14:00 9/17/2024 14:30 0.50 PROD1, CSGRCY RURD P Install mouse hole. 0.0 0.0 9/17/2024 14:30 9/17/2024 15:45 1.25 PROD1, CSGRCY MPSP P M/U retrievial head. RIH engage storm packer. Equalize. Release packer. POOH L/D BHA #2 storm packer & retrievial head. 0.0 1,430.0 9/17/2024 15:45 9/17/2024 16:30 0.75 PROD1, WELLPR TRIP P POOH F/ 1430' T/ 9'. PUW=50K.. 1,430.0 9.0 9/17/2024 16:30 9/17/2024 17:00 0.50 PROD1, WELLPR BHAH P L/D BHA #1 tandem 6" stiring mills. 9.0 0.0 9/17/2024 17:00 9/17/2024 18:00 1.00 PROD1, WELLPR BHAH P M/U BHA #4 (3 1/2" spear) T/ 120'. 0.0 120.0 9/17/2024 18:00 9/17/2024 19:30 1.50 PROD1, WELLPR PULD P PUDP F/ 120' T/ 700' 120.0 770.0 9/17/2024 19:30 9/17/2024 20:00 0.50 PROD1, WELLPR TRIP P TIH F/ 770' T/ 1,830'. 770.0 1,830.0 9/17/2024 20:00 9/17/2024 20:30 0.50 PROD1, WELLPR FISH P Obtain Parameters. PUW = 62K. SOW = 60K. Pump rate = 3 BPM @ 1160 psi. TIH slowly to locate top of tubing stub. See top @ 1,845'. Cont. TIH to fully located @ 1,849'. Set 5K down. PU to confirm latched. See good overpull. PU to 125K (23K over calculated string weight). Slight weight bobble then jars hit. Cont. PUH dragging at 110K. Fish on. 1,830.0 7,123.0 9/17/2024 20:30 9/17/2024 21:15 0.75 PROD1, WELLPR CIRC P Circ BU @ 3 BPM and 1083 psi. 7,058.0 7,058.0 Rig: NORDIC 3 RIG RELEASE DATE 9/21/2024 Page 4/6 1L-08 Report Printed: 10/15/2024 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) 9/17/2024 21:15 9/17/2024 21:30 0.25 PROD1, WELLPR OWFF P OWFF. Slight flow. 7,058.0 7,058.0 9/17/2024 21:30 9/18/2024 00:00 2.50 PROD1, WELLPR CIRC P Circ STS @ 3 BPM and 1048 psi. Gassy returns coming back. Pump 15 bbl hi vis pill. Circ pill out. Returns cleaned up after pumping pill around. SD Pumps. 7,058.0 7,058.0 9/18/2024 00:00 9/18/2024 00:30 0.50 PROD1, WELLPR OWFF P OWFF for 30-min. 7,058.0 7,058.0 9/18/2024 00:30 9/18/2024 01:45 1.25 PROD1, WELLPR TRIP P TOOH standing back DP in derrick. 7,058.0 5,293.0 9/18/2024 01:45 9/18/2024 02:45 1.00 PROD1, WELLPR BHAH P Reconfigure pipe handling equipment to L/D 3 1/2" Tubing. L/D BHA #4 (3 1/2" spear). 5,293.0 5,173.0 9/18/2024 02:45 9/18/2024 09:45 7.00 PROD1, WELLPR PULL P L/D cut joint, pup joint, and SSSV. Cont. TOOH L/D remaining 3 1/2" Tubing to surface. 15.25' cut joint. Clean cut, slight flare on one side T/ 3.75" 5,173.0 0.0 9/18/2024 09:45 9/18/2024 10:15 0.50 PROD1, WELLPR CLEN P Clean & clear RF & pipe shed. 0.0 0.0 9/18/2024 10:15 9/18/2024 10:45 0.50 PROD1, WELLPR RURD P R/D tubing handling equipment. R/U DP handling equipment. 0.0 0.0 9/18/2024 10:45 9/18/2024 11:30 0.75 PROD1, WELLPR BHAH P M/U BHA #5, dress off shoe w/ pilot mill & 6 1/8" sting mill T/ 150', SOW=40. 0.0 150.0 9/18/2024 11:30 9/18/2024 14:45 3.25 PROD1, WELLPR TRIP P RIH F/ 150' T/ 6994', PUW=135K, SOW=101K 150.0 6,994.0 9/18/2024 14:45 9/18/2024 15:30 0.75 PROD1, WELLPR REAM P Obtain parameters: Pump @ 3 BPM, 430 PSI. @ 5 BPM, 1020 PSI. Rot @ 60 RPM, 3.5K free Tq, ROT=115K. Wash & ream down, back up & down again F/ 6994' T/ 7111' 6,994.0 7,111.0 9/18/2024 15:30 9/18/2024 16:00 0.50 PROD1, WELLPR MILL P Wash & ream down over TGB stub pump @ 3 BPM, 426 PSI. ROT @ 60 RPM, 3.5K free Tq. ROT=115K. @ 7114', saw PSI spike T/ 580 PSI, Tq increase T/ 4-4.2K. Cont in swallow stub T/ 7123', set down 10K. Saw SPI spike T/ 680 PSI . Tq increase T/ 5-5- 5K. Pull up off stub. RIH without rotation. PSI increase @ 7114', took weigh @ 7123'. 7,111.0 7,123.0 9/18/2024 16:00 9/18/2024 17:30 1.50 PROD1, WELLPR CIRC P P/U T/ 7103'. Pump 30 Bbls hi vis sweep around @ 5 BPM, 750 PSI. Clean fluid in returns. SD pump. 7,123.0 7,103.0 9/18/2024 17:30 9/18/2024 19:45 2.25 PROD1, WELLPR PRTS P RU PT equipment. PT 7" casing to 2,500 psi. Chart. Bump back up double blocked at kill HCR/manual and double blocked at Top Drive. Held for 15-min then had slow leak off. Reconfigure PT equipment to eliminate top drive. RU head pin w/ isolation valve. Re-attempt 7" casing test to 2,500 psi. Still showing slow leak off. Monitor OA pressure = 300 psi. OA pressure after 30-min test = 300 psi. No OA build. See slight flow from flowline. Bleed off. 7,103.0 7,103.0 9/18/2024 19:45 9/18/2024 22:00 2.25 PROD1, WELLPR PRTS P Cycle UPR. Purge system. Close UPR. Cycle and close annular (double blocked). Close HCR and Manual Kill (double block). Changed out sensator. Purged air from system. Re-tested to 2,500 psi. Passed. Bleed off. R/D testing equipment. 7,103.0 7,103.0 Rig: NORDIC 3 RIG RELEASE DATE 9/21/2024 Page 5/6 1L-08 Report Printed: 10/15/2024 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) 9/18/2024 22:00 9/19/2024 00:00 2.00 PROD1, WELLPR PULD P Kick out fishing tools. Load last 40 joints of 3 1/2" Tubing. Process 3 1/2" Tubing. TOOH LDDP F/ 7103' to midnight depth of 6,857'. 7,103.0 6,857.0 9/19/2024 00:00 9/19/2024 05:30 5.50 PROD1, WELLPR PULD P TOOH LDDP F/ 6,857' to 150'. 6,857.0 150.0 9/19/2024 05:30 9/19/2024 07:00 1.50 PROD1, WELLPR BHAH P L/D BHA #5 (string mill w/ dress off mill). Inspect. 150.0 0.0 9/19/2024 07:00 9/19/2024 07:15 0.25 PROD1, WELLPR RURD P Pull wear ring. 0.0 0.0 9/19/2024 07:15 9/19/2024 07:45 0.50 PROD1, WELLPR CLEN P Kick out fishing tools from RF & pipe shed. 0.0 0.0 9/19/2024 07:45 9/19/2024 09:45 2.00 PROD1, WELLPR SLPC P Slip and Cut 66' Drill Line. 0.0 0.0 9/19/2024 09:45 9/19/2024 10:15 0.50 PROD1, WELLPR RURD P Prep rig floor to run 3 1/2" completions. Load 3 1/2" completions equipment. 0.0 0.0 9/19/2024 10:15 9/19/2024 11:00 0.75 PROD1, WELLPR CLEN P Clean RF. Verify jewelry and run order. 0.0 0.0 9/19/2024 11:00 9/19/2024 11:30 0.50 PROD1, WELLPR SFTY P PJSM w/ SLB & rig crew on running 3 1/2" EUE completion. 0.0 0.0 9/19/2024 11:30 9/19/2024 21:00 9.50 COMPZN, RPCOMP PUTB P Run 3 1/2", 9.3#, L-80, EUE-M completions as per Tally to 7,105' 0.0 7,105.0 9/19/2024 21:00 9/19/2024 21:45 0.75 COMPZN, RPCOMP WASH P Screw TD into Joint #224. Obtain Parameters. PUW = 90 K. SOW = 70K. Pump Rate = 2 BPM @ 105 psi. Wash down to tubing stub @ 7,116 N3 RKB (see slight wt bobble). See pressure indicator @ 7,118' (245 psi) See shear indicator @ 7,119' (3' below top). Fully locate @ 7,122' (6.6' swallow). Set 10K down. Repeat set down. Set 3K down. Mark pipe. 7,105.0 7,122.0 9/19/2024 21:45 9/20/2024 00:00 2.25 COMPZN, RPCOMP HOSO P Mark Pipe. Pull partial joint #224 (12.62'). Pull full joint #223 (31.42'). Total Pulled = 44.04'. Total Needed = 32.76'. L/D full joint #222. Calc space out pups required. Delta Pulled vs Needed = 11.28'. MU space out pups (8.17', 2.08'), full joint #222, hanger + pup, and landing joint (w/ head pin, chicksan, circ hose). Results in 3' space out. RU circ hose to choke. Line up to take returns to open top tank. 7,122.0 7,086.0 9/20/2024 00:00 9/20/2024 01:30 1.50 COMPZN, RPCOMP CIRC P Close UPR. Reverse Circulate 190 bbls 8.6# CI SW down annular taking returns up tubing and out to open top tank. 2 BPM @ 155 psi. Choke Pressure = 60 psi. Chase w/ 10 bbls SW to clear rig lines. SD pumps. B/D lines. Open UPR. Drain stack. 7,086.0 7,086.0 9/20/2024 01:30 9/20/2024 02:00 0.50 COMPZN, RPCOMP THGR P Land Hanger. RILDS. Drop Ball and Rod. 7,086.0 7,119.0 9/20/2024 02:00 9/20/2024 03:15 1.25 COMPZN, RPCOMP RURD P RU pressure testing equipment to Tubing and IA. Sensator on both with green isolation valves. 7,119.0 7,119.0 9/20/2024 03:15 9/20/2024 04:00 0.75 COMPZN, RPCOMP PACK T Attempt to pressure up to set SLB Packer. Unable to pressure up. Ball not on seat. Ramp rate from 0.5-2.5 BPM to attempt to flush ball on seat. Unable. Surged rate to 2.5 BPM a few times to get ball moving. Unable to push ball on seat. Called out Slick line unit. 7,119.0 7,119.0 9/20/2024 04:00 9/20/2024 05:30 1.50 COMPZN, RPCOMP WAIT T Wait on Slick line unit to arrive. On location @ 05:30 Hrs. 7,119.0 7,119.0 Rig: NORDIC 3 RIG RELEASE DATE 9/21/2024 Page 6/6 1L-08 Report Printed: 10/15/2024 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) 9/20/2024 05:30 9/20/2024 06:45 1.25 COMPZN, RPCOMP RURD T PJSM. Spot & R/U slick line. 7,119.0 7,119.0 9/20/2024 06:45 9/20/2024 08:15 1.50 COMPZN, RPCOMP SLKL T RIH, tap ball & rod out of station #2, SOV @ 4500'. Push down to RHC plug. POOH. Stand back slick line. 7,119.0 7,119.0 9/20/2024 08:15 9/20/2024 08:45 0.50 COMPZN, RPCOMP RURD T R/U testing equipment. 7,119.0 7,119.0 9/20/2024 08:45 9/20/2024 09:00 0.25 COMPZN, RPCOMP PRTS T Pressure up on TBG confirm ball & rod on seat T/ 500 PSI. m 7,119.0 7,119.0 9/20/2024 09:00 9/20/2024 09:30 0.50 COMPZN, RPCOMP PRTS T R/D & release slick line. Call out SLB for packer set. 7,119.0 7,119.0 9/20/2024 09:30 9/20/2024 10:30 1.00 COMPZN, RPCOMP PACK P Pressure up to set packer in 500 PSI increments holding for 1 min up T/ 2500 PSI. Continue pressure up T/ 3700 PSI hold for 30 Min. Passing MIT on TBG 7,119.0 7,119.0 9/20/2024 10:30 9/20/2024 11:30 1.00 COMPZN, RPCOMP PRTS P Bleed TBG T/ 1500 PSI. PT IA T/ 2500 PSI for 30 Min. Dump TBG pressure, shear out SOV. Pump down IA @ 2 BPM, 220 PSI. 7,119.0 7,119.0 9/20/2024 11:30 9/20/2024 12:00 0.50 COMPZN, RPCOMP RURD P B/D, R/D TBG side testing equipment. Pull landing joint. 7,119.0 7,119.0 9/20/2024 12:00 9/20/2024 12:30 0.50 COMPZN, RPCOMP MPSP P Set HP BPV 7,119.0 7,119.0 9/20/2024 12:30 9/20/2024 13:00 0.50 COMPZN, RPCOMP PRTS P PT BPV T/ 1000 PSI for 10 Min. 7,119.0 0.0 9/20/2024 13:00 9/20/2024 14:00 1.00 COMPZN, WHDBOP RURD P B/D, R/D testing equipment. B/D surface lines. Suck out stack. 0.0 0.0 9/20/2024 14:00 9/21/2024 00:00 10.00 COMPZN, WHDBOP OTHR P Perform BWM. Identified bad annular element. C/O element. Clean out LPR cavities. Swap 7" fixed rams out to 2 7/8" x 5 1/2" VBR's. 0.0 0.0 9/21/2024 00:00 9/21/2024 03:45 3.75 COMPZN, WHDBOP OTHR P Continue BWM. Clean out UPR cavities and inspect VBR's. Rubbers worn out. Replaced. Pull and inspect blinds. 0.0 0.0 9/21/2024 03:45 9/21/2024 05:45 2.00 COMPZN, WHDBOP NUND P ND BOP's. Install test dart. NU Tubing head adapter and new tree. 0.0 0.0 9/21/2024 05:45 9/21/2024 09:00 3.25 COMPZN, WHDBOP NUND P Install test dart. NU Tubing head adapter and new tree. Install companion flange on production valve. 0.0 0.0 9/21/2024 09:00 9/21/2024 09:30 0.50 COMPZN, WHDBOP PRTS P PT hanger void to 5,000 psi for 15-min. 0.0 0.0 9/21/2024 09:30 9/21/2024 10:30 1.00 COMPZN, WHDBOP RURD P R/U LRS & circ manifold. 0.0 0.0 9/21/2024 10:30 9/21/2024 11:15 0.75 COMPZN, WHDBOP PRTS P PT new tree to 5,000 psi. 0.0 0.0 9/21/2024 11:15 9/21/2024 11:45 0.50 COMPZN, WHDBOP MPSP P Pull BPV and test dart. 0.0 0.0 9/21/2024 11:45 9/21/2024 13:30 1.75 COMPZN, WHDBOP FRZP P LRS Pump 72 BBLS of diesel freeze protect down IA, taking returns up tubing @ 2 BPM ICP=500, FCP=700. U-Tube for 1 Hour. Start building dance floor for pulling of well. 0.0 0.0 9/21/2024 13:30 9/21/2024 14:30 1.00 COMPZN, WHDBOP RURD P Gather Final Pressures (T/IA/OA) = 10 / 40 / 0 psi. Secure tree & cellar. Spread herculite & lay mats for 1L-28. 0.0 0.0 9/21/2024 14:30 9/21/2024 18:00 3.50 DEMOB, MOVE DMOB P Prep for rig move over to 1L-28. Rig release @ 18:00 Hrs 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 9/21/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,506.0 1L-08 10/5/2024 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Installed Post RWO GLD design. Pulled B&R, RHC. Pulled HEX plug. 1L-08 10/5/2024 fergusp 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 32.0 110.0 110.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 31.3 2,397.8 2,271.7 36.00 J-55 BTC PRODUCTION 7 6.28 27.2 7,778.7 6,333.6 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 27.2 Set Depth 7,126.7 String Max No 3 1/2 Set Depth 5,740.7 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L80 Top Connection EUE-M 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) 27.2 27.2 0.06 Hanger 6.980 3.5" x 7" FMC Gen 4 Tubing Hanger - 3 1/2" EUE top FMC Gen4 2.920 2,657.5 2,462.9 44.59 Mandrel GAS LIFT 5.927 3.5" x 1.5" MMG, GLM SLB MMG 2.990 4,505.8 3,695.3 46.80 Mandrel GAS LIFT 5.924 3.5" x 1.5" MMG, GLM SLB MMG 2.990 6,980.6 5,612.9 30.28 Mandrel GAS LIFT 5.928 3.5" x 1.5" MMG, GLM SLB MMG 2.920 7,040.8 5,665.2 29.26 Packer 6.280 3.5" x 7" BluePack RH Max VAM TOP B/P SLB BluePac k 2.894 7,098.5 5,715.8 28.30 Nipple - X 4.545 3.5" x 2.813" X-Nipple Halliburt on X 2.813 7,119.7 5,734.5 27.96 Overshot 6.000 3 1/2" x 7" Poorboy Overshot w/ 6.6' of swallow (3' space out off no-go) Inno Poorboy Oversho t 3.625 Top (ftKB) 7,123.0 Set Depth 7,431.8 String Max No 3 1/2 Set Depth 6,014.6 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade J-55 Top Connection FL4S 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) 7,142.2 5,754.3 27.60 PBR 4.500 BAKER PBR 3.000 7,155.8 5,766.5 27.38 PACKER 6.156 BAKER FHL RETRIEVABLE PACKER 3.000 7,191.1 5,797.8 26.82 PRODUCTION 5.312 MMH FMHO 2.867 7,255.4 5,855.4 26.10 PRODUCTION 5.312 MMH FMHO 2.867 7,290.1 5,886.6 25.73 BLAST RINGS 3.500 BLAST RINGS (3) 4.5" OD 2.992 7,385.5 5,972.7 25.46 PRODUCTION 5.312 MMH FMHO 2.867 7,402.1 5,987.7 25.40 LOCATOR 4.500 BAKER LOCATOR SUB 3.000 7,402.9 5,988.4 25.39 PACKER 6.156 BAKER FB-1 PERMANENT PACKER 4.000 7,405.4 5,990.7 25.36 SBE 4.500 BAKER SEAL BORE EXTENSION 3.000 7,425.6 6,009.0 25.11 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750 7,431.2 6,014.0 25.04 SOS 4.500 BAKER SHEAR OUT SUB 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) 2,657.5 2,462.9 44.59 1 GAS LIFT GLV RK 1 1/2 1,215.0 10/2/2024 SLB MMG 0.313 4,505.8 3,695.3 46.80 2 GAS LIFT OV RK 1 1/2 0.0 10/2/2024 SLB MMG 0.313 6,980.6 5,612.9 30.28 3 GAS LIFT DMY RK 1 1/2 9/20/2024 SLB MMG Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,306.0 7,362.0 5,901.0 5,951.5 C-4, UNIT B, 1L- 08 9/29/1984 12.0 IPERF 5" DA Csg Gun; 120 deg. ph 7,482.0 7,500.0 6,060.2 6,076.6 A-5, 1L-08 9/29/1984 4.0 IPERF 4" DA Csg Gun; 120 deg. ph 1L-08, 10/16/2024 10:50:03 AM Vertical schematic (actual) PRODUCTION; 27.2-7,778.7 IPERF; 7,482.0-7,500.0 PACKER; 7,402.9 PRODUCTION; 7,385.5 IPERF; 7,306.0-7,362.0 PRODUCTION; 7,255.4 PRODUCTION; 7,191.1 PACKER; 7,155.8 Nipple - X; 7,098.5 Packer; 7,040.8 Mandrel GAS LIFT; 6,980.6 Mandrel GAS LIFT; 4,505.8 Mandrel GAS LIFT; 2,657.5 SURFACE; 31.3-2,397.8 CONDUCTOR; 32.0-110.0 Hanger; 27.2 KUP PROD KB-Grd (ft) 35.59 RR Date 9/6/1984 Other Elev 1L-08 ... TD Act Btm (ftKB) 7,810.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292117500 Wellbore Status PROD Max Angle & MD Incl (°) 50.13 MD (ftKB) 3,000.00 WELLNAME WELLBORE1L-08 Annotation Last WO: End Date 9/20/2024 H2S (ppm) DateComment SSSV: LOCKED OPEN ORIGINATED TRANSMITTAL DATE: 8/13/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4991 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 4991 1L-08 500292117500 Tubing Cut Record 9-Aug-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 184-150 T39450 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.14 10:01:19 -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 0 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7810 2547 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: 907-265-6049 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Baker FHL Retrievable Baker FB-1 Permenant SSSV: Baker FVL 6363'8514'6088'7177' KRU 1L-08 7306-7362' 7482'-7500' 7752' 5901-5952' 6060-6077' 2367' 7779' Perforation Depth MD (ft): 8/20/2024 3-1/2" 110' 2398' 6334'7" 16" 9-5/8" 78' Burst 7432' MD 110' 2272' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025659 184-150 P.O. Box 100360, Anchorage, AK 99510 50-029-21175-00-00 ConocoPhillips Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 7156'MD/5767'TVD 7403'MD/5988'TVD 1863'MD/1827'TVD Perforation Depth TVD (ft): Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field Cy Eller cy.eller@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: J-55 TVD m n P s 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 324-379 By Grace Christianson at 12:04 pm, Jul 01, 2024 BOP test to 3000 psig Annular preventer test to 3000 psig X X SFD 7/15/2024 10-404 DSR-7/8/24VTL 8/5/2024*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.05 15:24:25 -08'00'08/05/24 RBDMS JSB 080624 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 19, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 1L-08 (PTD# 184-150). Well 1L-08 was drilled in September of 1984 by Parker 141 and completed by Westward #1 as a Producer in the Kuparuk A and C sands. The well has the original selective completion and has had a healthy life until restrictions in the tubing were observed while performing a SBHP survey from 270’ RKB to 450’ RKB in 2023. A workover is planned to replace the 3-1/2” completion above the selective and repair any subsidence damage found in the 7” casing. The 3-1/2” upper completion will be pulled from a pre-rig cut above the SSSV. The 7” casing will be grown and stretched, and drift will be verified. If drift is not possible, the damaged 7” casing will be cut above SSSV, then new 7” casing will be run and the OA will be cemented to surface. Once the subsidence damage is repaired, a 3- 1/2” completion including a new gas lift design, a non-sealing overshot and a stacked packer will be installed. If you have any questions or require any further information, please contact me at 907-265-6049. Cy Eller Rig Workover Engineer CPAI Drilling and Wells 1L-08 Kuparuk Producer Tubing Swap with Subsidence Repair PTD: 184-150 Page 1 of 3 PPre-Rig Work 1. SBHP – Completed on 8/6/2023 2. Set HEX plug at 7,176’ RKB – Completed on 1/11/2024 3. CMIT-TxIA to 2,500 psi – Passed on 1/17/2024 4. T-PPPOT and T-POT tests 5. CMIT/DDT-TxIA 6. MIT-OA 7. Install DVs in GLMs 8. Tubing cut at ~1,860’ RKB above the SSSV and at ~7,124’ RKB above the upper packer. 9. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nordic 3 on 1L-08. No BPV will be set for MIRU due to Nordic 3 internal risk assessment. 2. Record shut-in pressures on the T & IA. If pressure is observed, bleed off pressure and complete 30-minute NFT. Circulate KWF as needed. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND tree, NU BOPE and test to 250/3,000 psi. Test annular 250/3,000 psi. Retrieve 3-1/2” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to the pre-rig cut at ~1,860’ RKB. 6. Attempt to drift 7” casing with mill prior to attempting to pull tubing section from ~1,860’ - ~7,124’ RKB. a. If drift is achieved, RIH and engage tubing stub and pull remaining tubing down to pre- rig cut at ~7,124’ RKB. b. If drift is not achieved, proceed with 7” Casing Subsidence Repair section. 7” Casing Subsidence Repair 7. Set storm packer or plug above SSSV. PT to confirm plug is set. Dump sand on top of plug. 8. ND BOPE. ND old tubing head. Grow casing as needed using Hydratight. Pull casing in tension and land in slips. NU BOPE to casing head. a. Test break as soon as practical once test plug can be installed. b. Attempt to drift 7” casing with mill after grow/stretch. If enough drift is obtained to pull SSSV, RIH and engage tubing stub and pull remaining tubing down to lower pre-rig cut. 9. RU E-Line and log 7” casing from tubing stub to surface to verify free pipe. a. Estimated top of cement is 1,825’ RKB. 10. RIH and cut 7” casing. Circulate out Arctic Pack diesel/slurry. 11. Pull 7” casing from cut. a. Make additional cuts in 7” casing to remove in sections if necessary. 12. RIH with mills to ensure drift for overshot casing patch and ES cementer. a. Bore out 9-5/8” casing to create drift as necessary. 1L-08 Kuparuk Producer Tubing Swap with Subsidence Repair PTD: 184-150 Page 2 of 3 13. MU and RIH with overshot casing patch, ES cementer, and new 7” casing. Engage overshot and PT casing to 2500 psi. 14. Cement 7” x 9-5/8” annulus to surface. 15. ND BOPE, set casing slips, cut excess 7” casing and install packoffs. NU new tubing head and BOPE. Test breaks to 250/3000 psi. 16. RIH and mill up cement and plugs in cementer. Perform additional cleanout runs if necessary. 17. RIH and wash sand from top of RBP. Retrieve RBP. 18. Pull remaining completion. Install 3-1/2” Completion with Stacked Packer 19. RIH to tubing stub and dress off stub as needed. Perform casing cleanout runs as needed. 20. MU new 3-1/2” completion with non-sealing overshot, packer, nipple profile, and GLMs. RIH to tubing stub. 21. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 22. Land tubing hanger, RILDS, PT packoffs and set packer. 23. Pressure test tubing to 3,000 PSI. 24. Pressure test IA to 2,500 PSI. ND BOP, NU Tree 25. Shear out SOV with pressure differential. 26. Install BPV and test. ND BOPE. NU tree. 27. Pull BPV and freeze protect well. 28. RDMO. PPost-Rig Work 1. Run GLD. 2. Pull any plugs and ball/rod used for setting packer. General Well Information: Estimated Start Date: 8/20/2024 Current Operations: Shut-In, secured with plug below upper packer Well Type: Producer Wellhead Type: FMC Gen III, 11” 3M casing head top flange. 7-1/16” 5M tubing head top flange. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Static BHP: 3,146 psi / 5,986’ TVD measured on 8/6/2023 MPSP: 2,547 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 3-1/2” completion to a pre-rig cut above the SSSV, run a CBL, cut and pull 7” casing, replace casing with overshot casing patch and cement up OA. Install a new 3-1/2” completion and stacked packer. 1L-08 Kuparuk Producer Tubing Swap with Subsidence Repair PTD: 184-150 Page 3 of 3 PPersonnel: Workover Engineer: Cy Eller (907-265-6049 / Cy.Eller@conocophillips.com) Reservoir Surveillance Engineer: Cody Keith Production Engineer: Banabas Dogah Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,513.0 1L-08 10/21/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled OV, pocket open 1L-08 1/15/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: Unable to drift with 2.72" RBP or 2.60 ME RBP deeper than 80' RKB 12/26/2023 rogerba NOTE: Suspected buckled tubing at 350'-450' RKB 10/12/2023 rmoore22 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 32.0 110.0 110.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 31.3 2,397.8 2,271.7 36.00 J-55 BTC PRODUCTION 7 6.28 27.2 7,778.7 6,333.6 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 27.1 Set Depth … 7,431.8 String Max No… 3 1/2 Set Depth … 6,014.6 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8RDMOD 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) 27.1 27.1 0.06 HANGER 8.000 FMC GEN III 5M TUBING HANGER 3.500 1,862.5 1,827.3 27.13 SAFETY VLV 5.937 BAKER FVL SAFETY VALVE (LOCKED OPEN 4/5/93) 2.810 2,035.0 1,977.8 31.26 GAS LIFT 5.312 MMH FMHO 2.867 4,199.8 3,487.9 47.83 GAS LIFT 5.312 MMH FMHO 2.867 5,866.6 4,720.6 39.10 GAS LIFT 5.312 MMH FMHO 2.867 6,640.1 5,327.2 35.40 GAS LIFT 5.312 MMH FMHO 2.867 7,102.4 5,719.2 28.23 GAS LIFT 5.312 MMH FMHO 2.867 7,142.2 5,754.3 27.60 PBR 4.500 BAKER PBR 3.000 7,155.8 5,766.5 27.38 PACKER 6.156 BAKER FHL RETRIEVABLE PACKER 3.000 7,191.1 5,797.9 26.82 PRODUCTION 5.312 MMH FMHO 2.867 7,255.4 5,855.4 26.10 PRODUCTION 5.312 MMH FMHO 2.867 7,290.1 5,886.7 25.73 BLAST RINGS 4.500 BLAST RINGS (3) 2.992 7,385.5 5,972.7 25.46 PRODUCTION 5.312 MMH FMHO 2.867 7,402.1 5,987.7 25.40 LOCATOR 4.500 BAKER LOCATOR SUB 3.000 7,402.9 5,988.4 25.39 PACKER 6.156 BAKER FB-1 PERMANENT PACKER 4.000 7,405.4 5,990.7 25.36 SBE 4.500 BAKER SEAL BORE EXTENSION 3.000 7,425.7 6,009.0 25.11 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750 7,431.2 6,014.0 25.04 SOS 4.500 BAKER SHEAR OUT SUB 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) 350.0 350.0 0.23 TIGHT SPOT Suspected buckled tubing 350- 450' RKB. See CTU WSR 10/11/23. 10/11/2023 2.700 7,176.8 5,785.1 27.05 PLUG 180-350 INTERWELL HEX PLUG MID-ELEMENT AT 7180' RKB, MAX OD 1.80", OAL 5.83', OAW 34 LBS, FISHNECK 1.5" GS INTERW ELL 180-350 HEX 23440 5 1/11/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,035.0 1,977.8 31.26 1 GAS LIFT GLV BK 1 1,305.0 1/16/2009 0.188 4,199.8 3,487.9 47.83 2 GAS LIFT GLV BK 1 1,295.0 12/6/1994 0.188 5,866.6 4,720.6 39.10 3 GAS LIFT GLV BK 1 1,400.0 12/6/1994 0.250 6,640.1 5,327.2 35.40 4 GAS LIFT DMY BK 1 0.0 4/25/1994 0.000 7,102.4 5,719.2 28.23 5 GAS LIFT Open 1 1/15/2024 7,191.1 5,797.9 26.82 6 PROD DMY BK 1 0.0 4/12/2022 0.000 7,255.4 5,855.4 26.10 7 PROD DMY BK 1 0.0 4/12/2022 0.000 7,385.5 5,972.7 25.46 8 PROD DMY BK 1 0.0 4/12/2022 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,306.0 7,362.0 5,901.0 5,951.5 C-4, UNIT B, 1L- 08 9/29/1984 12.0 IPERF 5" DA Csg Gun; 120 deg. ph 7,482.0 7,500.0 6,060.2 6,076.6 A-5, 1L-08 9/29/1984 4.0 IPERF 4" DA Csg Gun; 120 deg. ph 1L-08, 6/20/2024 9:00:26 AM Vertical schematic (actual) PRODUCTION; 27.2-7,778.7 IPERF; 7,482.0-7,500.0 PACKER; 7,402.9 PRODUCTION; 7,385.5 IPERF; 7,306.0-7,362.0 PRODUCTION; 7,255.4 PRODUCTION; 7,191.1 PLUG; 7,176.8 PACKER; 7,155.8 GAS LIFT; 7,102.4 GAS LIFT; 6,640.1 GAS LIFT; 5,866.6 GAS LIFT; 4,199.8 SURFACE; 31.3-2,397.8 GAS LIFT; 2,035.0 SAFETY VLV; 1,862.5 TIGHT SPOT; 350.0 CONDUCTOR; 32.0-110.0 KUP PROD KB-Grd (ft) 35.59 RR Date 9/6/1984 Other Elev… 1L-08 ... TD Act Btm (ftKB) 7,810.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292117500 Wellbore Status PROD Max Angle & MD Incl (°) 50.13 MD (ftKB) 3,000.00 WELLNAME WELLBORE1L-08 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OPEN 1L-08 Proposed RWO Completion 7" Subsidence Repair 7" L-80 Casing to Surface 7" HES Cementer Baker 7" Overshot Casing Patch Proposed Completion 3-1/2" L-80 9.3# EUE-8rd Tubing to surface Camco 3-1/2" x 1-1/2" MMG GLMs 3-1/2" x 7" Packer 3-1/2" X Nipple 3-1/2" Non-sealing Overshot Baker PBR @ 7142' RKB Baker FHL Retrievable Packer @ 7155' RKB McMurry-Hughes FMHO Production Mandrel @ 7191' RKB McMurry-Hughes FMHO Production Mandrel @ 7255' RKB Carbide Blast Rings @ 7290' RKB McMurry-Hughes FMHO Production Mandrel @ 7385' RKB Baker Locator Seal Assembly @ 7402' RKB Baker FB-1 Permanent Packer @ 7402' RKB Baker Seal Bore Extension @ 7405' RKB 3-1/2" Camco D Nipple No Go @ 7426' RKB (2.75" Min ID) Baker Shear Out Sub @ 7431' RKB 9-5/8" 36# J-55 shoe @ 2398' MD 7" 26# J-55 shoe @ 7779' MD A-sand perfs 7482' - 7500' MD C-sand perfs 7306' - 7362' MD 16" 62.5# H-40 shoe @ 110' MD 17 bbls Arctic Pack pumped. Est. TOC:1825' RKB 184-150 T38885 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.11 14:59:29 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-10-21_22571_KRU_1L-08_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22571 KRU 1L-08 50-029-21175-00 Caliper Survey w/ Log Data 21-Oct-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 10/27/2023 PTD: 184-150 T38105 Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.27 13:24:24 -08'00' ge Project Well History File' CI Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 1 L 5-_0_ RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [3 Maps: [] Grayscale items: [] Other, No/Type [3 Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: NOTES: ?~ : Logs of various kinds [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl_ DATE: /SI Scanning Preparation o~._x 30 = ~ ~ + l,_~-" = TOTALPAGES 7~r'' BY: BEVERLY BREN VINCENT SHERYL,~LOWELL Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: ~'7 BY: Stage 2 BY: (SCANNING IS COMPLETE AT THIS POINT UNLES~ SPECIAL ATTENTION IS REQUIRED ON AN INDNIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES NO ~BREN VINCENT SHERYL MARIA LOWELL DATE: I/,/~'.~'~,S, ~ IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO III Illllllllll II III RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd • ~. ~ ConocaPhillps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360---- -- February 1, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 ~tE~EIVED ~aR o ~ zo~~ Alaska Od F~ fins Cans. Coirmtission Anchorage Dear Mr. Dan Seamount: ~~-~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped December 5~', 2009. The corrosion inhibitor/sealant was pumped December 22"d, 25~`, 26~' & 28~`, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, r Kle1~i ~~~-~sa ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/1/2010 1 G. 1 L 8< 1 R Pad Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1G-17 50029229450000 1990620 SF n/a 17" Na 7.65 12/26/2009 1 L-01 50029211960000 1841730 52' 7.7 31" 12/5/2009 10.15 12/22/2009 1 L-02 50029211930000 1841700 45' 5.7 35" 12/5/2009 10.15 12/22/2009 1 L-04 50029211790000 1841540 40' 3.9 24" 12/5/2009 5.8 12/22/2009 1 L-06 50029211640000 1841330 2'5" n/a 2'5" - Na 7.22 12/26/2009 1 L-08 50029211750000 1841500 34' 3.7 40" 12/5/2009 10.2 12/26/2009 1L-09 50029220250000 1900340 11" n/a 11" n/a 1.27 12/26/2009 1L-11 50029220340000 1900450 16" n/a 17" n/a 2.25 12/25/2009 1 L-12 50029220330000 1900440 7" n/a 15" n/a 3.4 12/25/2009 1 L-13 50029221500000 1910420 13' 2.2 27" 12/5/2009 5.52 12/26/2009 1 L-17 50029221510000 1910430 26' 4.0 18" 12/5/2009 9.35 12/26/2009 1 L-19 50029220490000 1900610 9' 2.5 19" 12/5/2009 4.25 12/25/2009 1 L-23 50029221670000 1910620 SF n/a 17" n/a 2.12 12/26/2009 1 L-26A 50029221730100 2000150 SF n/a 17" Na 2.97 12/25/2009 1 R-14 50029213860000 1851510 SF n/a 29" Na 5.95 12/28/2009 1 R-31 50029225380000 1941680 6" n/a 24" n/a 7.22 12/28/2009 1 R-32 50029225230000 1941460 SF n/a 24" n/a 5.95 12!28/2009 1 R-33 50029225290000 1941560 SF n/a 24" n/a 4.67 12/28/2009 04/08/08 ~~~~~ i i' ! NO.4650 Schlumberger -DCS 2525 Gambelf Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth ~~~ ~,~~ .~'. `/~ ~~~~ Anchoraget AKv99501te 100 Field: Kuparuk ~~~~ ~~ O~ 1 Imo" Well Job # Log Description Date BL Color CD 1A-19 12031469 LEE TOOL PROD PROFILE 03/21/08 1 1 F-07 12031470 PROD PROFILE I ~ ~-'~ 03/22/08 1 3A-09 11980648 PROD PROFILE /~9 03/22/08 1 2A-22 11970645 MULTI-FINGER CALIPER 03/20/08 1 1F-15 11970659 INJECTION PROFILE 04/02/08 1 1 C-11 11994642 LDL 04/03/08 1 1 G-09 11996613 INJECTION PROFILE U = - 04/05/08 1 iJ-159 11994646 GLS (o- 04/06/08 1 2W-15 11996615 PRODUCTION PROFILE 04/07/08 1 1 L-08 11996616 PRODUCTION PROFILE L - 04/08/08 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • / r1D ARCO Alaska, Inc. Post Office Box ]u0360 Anchorage, Alaska 99510-0360 Telephone 907 27,3 1215 February 1, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 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 · 2,-~-- ol 1B-05 % ~--~ ~8 1 E-28 %4-)~01 L-02 $~..-t~ 1 L-08 ~t -:z~l 1Q-05 Cq. ~,¢ 1 Q-06 Other (SSSV) Other (SSSV) Other (SSSV) Other (SSSV) Other (SSSV) Other (SSSV) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECEIVED FEB - 7 1994 Alaska OJJ & Gas Cogs. Commission Anchorage AR3B-6003-93 242-2603 Report of Well Sund~"-'~erations Page 2 bxc: V. L. Ferguson P. A. Billingsley Well Files FTR020196 ATO-1228 ATO-1431 (w/o attachments) (w/o attachments) (Form 10-404 only) (w/o attachments) Subject' Report of Sundry Well Operations, 1B-05(sssv), 1E-28(sssv), 1L-02,08(sssv), 1Q-05,06(sssv) Original + one copy to AOGCC (one -sided copy) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 224' FSL, 216' FWL, Sec 29, T11N, R10E, UM _ At top of productive interval 1091' FSL, 1400' FEL, Sec 29, T11N, R10E, At effective depth . 1136' FSL, 1246' FEL, Sec 29, T11N, R10E, UM At total depth 1148' FSL, 1205' FEL, Sec 29, T11N, R10E, UM 12. Present well condition summary Total Depth: 6. Datum elevation (DF or KB) RKB 118 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1L-08 9. Permit number/approval number 84-1 50/93-351 10. APl number 50-029-2117~ 11. Field/Pool Kuparuk River Oil Field/Pool measured 7 81 0 feet true vertical 6361 feet Plugs (measured) None Effective depth: measured 76 9 8 feet true vertical 6258 feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 110' 16" 2367' 9-5/8" 7748' 7" measured 7306'-7362', true vertical 5942'-5960', Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7420' Packers and SSSV (type and measured depth) Cemented 275 SX CS II 855 SX AS III & 250 SX Class G 775 SX Class G & 17 Bbls AS I 7482'-7500' 6055'-6068' Measured depth 110' 2398' 7779' True vertical depth 110' 2272' 6333' RECEIVED FEB - 7 1994 Aiaska UiI & Gas Cons. Commission Anchorage Pkr: Baker FHL @ 7144' & Baker FB-1 @ 7391'; SSSV: Baker FVL @ 1851', Otis 'K' valve 13. Stimulation or cement squeeze summary Installed sub-surface, spring controlled safety valve in production well. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 649 1326 575 950 166 Subsequent to operation 649 1326 575 950 166 15. Attachments Well Schematic Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby rtify that th oregoing is true and correct to the best of my knowledge. Si~ned ~~ ~,~ Title Senior Engineer Form 10-404 Rev 06/15/88 Date Z"'/-' ? L~ SUBMIT IN DUPLICATE Well: I L-08 Spud Date: Completion Date: Maximum Hole Angle: 5 0 Original Rig RKB: 27.15' ARL_. ALASKA INC. - KUPARUK FIEL~ APl# 50-029-21175-00 C Sand: OPEN A Sand: ~ deg. @ 3000' MD All depth are RKB MD to top of equipment. Well Type: OIL Tree Type: FMC GEN 3 5000# Tree Cap Type: Otis Q.U. Tree Cap Size: 3.5" Tree Cap O-ring ASN: 302-7856 Last Workover Date: J J J J J J I: × X 5 6,7 Jewelry I SSSV: BAKER FVL 2.81" ID @ 1851' LOCKED OPEN BR LOCK/K-VALVE 2 SBR: BAKER PBR-10 3.0" ID @ 7130' 3 PKR: BAKER FHL @ 7144' 4 PKR: BAKER FB-1 @ 7391' 5 NOGO: CAMCO "D" NIPPLE 2.75" ID @ 7414' 6 SHEAR OUT: BAKER @ 7419' 7 TUBING TAIL: @ 7420' Minimum ID: 2.75" J Casing and Tubing Size Weight Grade ToD Bottom I 6" 62.5# H-40 0 11 0' 9.625" 36# J-55 0 2398' 7" 26# J-55 0 7779' 3.5" 9.3# J-55 0 7420' Description CASING CASING CASING TUBING Gas Lift Information Deoth Stn# Valve Type 2023' I FLOPE GL 1" BK 4188' 2 FLOPE GL 1" BK 5855' 3 FLOPE GL 1" BK 6628' FLOPE GL I" BK 7091 ' 5 FLOPE OV 1" BK Sz. Latch Port Sz. Date Run 10/64 09/1 0/85 10/64 09/1 0/85 I2/64 09/1 0/85 20/64 09/1 0/85 20/64 03/1 8/93 71 79' I CV 1" BK 7244' 2 CV 1 " BK 7374' 3 CV 1" BK 02/1 5/93 02/1 5/93 02/1 5/93 Perforation Data Interval SPF Date 7306-7362' 1 2 C 7482-7500' 4 A Zone Comments RECEIVED Comments: FEB - 7 1994 0il & Gas Cons. Commission Anchorage LAST TD:7554' ON 04/11/88 PBTD:7683' PBTDSS: LAST REVISION · 12/23/93 JKH:Irl ARCO Alaska, Inc..:~-, Post Office B 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 15, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission '3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in triplicate are multiple Applications for Sundry Approval on the following Kuparuk wells. Well Action T/'--ot 1 B-05 Bi., I~-~ 1E-28 9~f-' l"~o 1 L-02 ~q'"/5~ 1 L-08 9~-- Ct~/' 1Q-05 ¢~f--- zz~8 1Q-06 Variance Variance Variance Variance Variance Variance Anticipated Start Date If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments DE.C '2_ ] 199~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ~ OIL AND ~ ~SERVATION COMMISo,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: · . Abandon Suspend Alter casing _ Repair well Change approved program _ Operation Shutdown_ Re-enter suspended well_ Plugging _ Time extension Stimulate Pull tubing _ Variance ;~ Perforate _ Other 2. Name of Operator AR(~O Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 224' FSL, 216' FWL, Sec. 29, T11N, R10E, UM At top of productive interval 1091' FSL, 1400' FEL, Sec. 29, T11N, At effective depth 1136' FSL, 1246' FEL, Sec. 29, T11N, At total depth 1148' FSL, 1205' FEL, Sec. 29, T11N, R10E, UM R10E, UM R10E, UM 12. Present well condition summary Total Depth: measured 7 81 0 true vertical 6 3 61 feet feet 6. Datum elevation (DF or KB) RKB 11~ 7, Unit or Property name Kuparuk River Unit 8. Well number · 1 L-08 9. Permit number 84-150 10, APl number 50-029-21 1 75 11. Field/Pool feet Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth: measured 7 6 9 8 true vertical 6 2 5 8 feet feet Junk (measured) None Casing Length Size Structural Conductor I 1 0' 1 6" Surface 2367' 9-5/8" Intermediate Production 774 8' 7" Liner Perforation depth: measured 7306'-7362', true vertical 5942'-5960', Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7420' Packers and SSSV (type and measured depth) Cemented 275 SX CS II 855 SX AS III & 250 SX Class G 775 SX Class G & 17 bbls AS I 7482'-7500' 6055'-6068' Measured depth 110' 2398' 7779' True vertical depth 110' 2272' 6333' RECEIVED DEC 2 1 1993 A.i~ska Oil & Gas Cons. Commission Anchorage Pkr: Baker FB-1 @ 7391', Baker FHL @ 7144'; SSSV: Camco TRDP-1A @ 1851' 13. 14. Attachments Description summary of proposal ~ Detailed operation program _ Install sub-surface, sprincj controlled safet), valve in production well Estimated date for commencing operation 15. Status of well classification as: Oil X Gas _ Service 16. If proposal was verbally approved Name of Date approved a~oprover 17. I hereby/c~rtify th~t~e ~s true and correct to the best of my knowledge. Si~ned "~t~'/~''~~'-" '"'{~/~ Title Sr. Engineer FOR COMMISSION USE ONLY BOP sketch -- Suspended _ Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 Original Signed By David W. Johnston Commissioner Date /,//~,//~ ~ SUI~MIT IN TRIPLICATE -Approved Copy Returned Attachment 1 Request for Variance Kuparuk Well 1L-08 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests Commission approval for a variance to install a subsurface, ambient-type safety valve in Well 1L-08. This valve replaces the original subsurface safety valve which has failed. The replacement valve operates by remaining open until flowing well pressure falls below a predetermined limit. Should such an event occur, the valve automatically closes, thus preventing uncontrolled flow. This valve, refered to as a storm choke, does not require a hydraulic control line from the surface to the subsurface valve. Its fail-safe design as normally-closed provides the same level of protection. Attached is a schematic of the "K" valve, an Otis Engineering storm choke. RECEIVED DEC 2 1 199} 0~t & Gas Cons. Commission Anchorage Attachment 2 Storm Choke Schematic OPEN [] 'WELL PRESSURE CLOSED [] INTERNAL CHAMBER PRESSURE HOUSING PIN HEAD TEFLON RING O-RING VALVE PISTON SPRING ROD SPACER BODY SPRING DETENT RING BALL GASKET SET SCREW CAP SCRE1N GASKET RECEIVED r~C 2 ~l 199,~ Gas Cons. Commission Anchorage Figure 1 - Otis "K" Valve ARCO Alaska, Inc. Date: March 24, 1989 Transmittal #: 7447 RETURN TO: ARCO Alaska. Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage. AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 30-16 Kuparuk Well Pressure Report 1-3-1 89 3 O- 10 Kuparuk Well Pressure Report 2 - 04 - 8 9 3 O- 13 Kuparuk Well Pressure Report 2 o 0 8 - 8 9 30-03 Kuparuk Well Pressure Report 1 - 0 9- 8 9 3 O- 15 Kuparuk Well Pressure Report 3 - 04 - 8 9 2G- 14 Kuparuk Fluid Level Report 3-11-89 2G- 13 Kuparuk Fluid Level Report 3 - 1 I - 8 9 2G-09 Kuparuk Fluid Level Report 3 - 1 1 - 8 9 1 E-03 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 1 E-05 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 3 O- 18 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 3 H - 1 0 Kuparuk Fluid Level Report 3 - 09 - 8 9 3 A- 03 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 3 H - 04 Kuparuk Fluid Level Report 3 - 04 - 8 9 '~-2 B - 14 Kuparuk Fluid Level Report . 3 - 1 3 - 89 30-13 Sub-Surface Pressure Survey · 2 - 0 8 - 8 9 em-30-10 Sub-Surface Pressure Survey 2-04-89 ~ 30 o 16 Sub-Surface Pressure Survey I - 31 - 8 9 '~'1 B - 07 Kuparuk Fluid Level Report 3 - 31 - 8 8 '"'~1 B - 03 Kuparuk Fluid Level Report 1 - 2 7- 8 8 ~ 1 B - 05 Kuparuk Fluid Level Report 1 - 2 7 - 8 8 ""'"'~1 B - 07 Kuparuk Fluid Level Report 4 - 2 7 - 8 8 ~1 B - 07 Kuparuk Fluid Level Report 1 - 2 7- 8 8 ~ 1 L- 08 Kuparuk Fluid Level Report 2 - 1 2 - 8 8 ~,,,-1 L- 04 Kuparuk Fluid Level Report 2 - 1 2 - 8 8 "'3H-10 ""-- 3 M- 01 Sand 'A' Sand 'A' Sand 'A' Sand 'A' Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing #72665 #72655 #72655 Casing Tubing Tubing Tubing Tubing Tubing Tubing Kuparuk Fluid Level Report 3- 1 7 Kuparuk Fluid Level Report 3-1[~ .-~ ~ ,,~_.1~~ ..,~" Anch0rag~ ~ O- 09 Kuparuk Fluid Level Report 3 - 1 8 - 89 Casing '~'"~30-18 Kuparuk Fluid Level Report 3 - 1 8 - 89 Casing ~ O- 18 Kuparuk Fluid Level Report 3 - 1 7- 89 Casing "~~OB- 09 Kuparuk Fluid Level Report 3- 1 7- 89 Casing - 13 Kuparuk Fluid Level Report 3 - 1 7- 89 Casing Receipt Acknowledged: ........................... Date' - ........... DISTRIBUTION: D&M State of Alaska SAPC Chevron Unocal Mobil ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: October 20, 1987 Transmittal #6088 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. lA-8 Static BHP Bottom-Hole Pressure Survey 9-29-87 ~3A-4 Kuparuk Well Pressure Report (Otis) 9-27-87 . 2B-4 Pressure Build Up Test 10-13-87 'lL-2 Kuparuk Well Pressure Report(Otis) 9-6-87 ~-lL-15 Kuparuk Well Pressure Report(Camco) 6-9-87 ~lL-8 Kuparuk Well Pressure Report(Camco) 6-9-87 50-029-20313 'A' Sand Static 'C' Sand 02157 Static Static 'C' Sand 'C' Sand Receipt Acknowledged: DISTRIBUTION: DAlae~ 0ii & Gas Cons. C0mmisslotl D&M State of Alaska BPAE Chevron Mobil SAPC Unocal .......... ~'-'~-;~;~ ,',f Atl~,nticRichfieldCompany ARCO Alaska, Inc. Post Office' ~x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/30/85 Transmittal No: --o 5013 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B ~/a~sAnm. O. Box 100360 chorage, AK 99510 itted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. BHP REPORTS & .SEQUENCE DF EVENTS 1G-4.- 9/30/84 9/04/84 "BHP" 1G-i~ 11/24/8~ 11/24/84 "SBHP" 1~.-8 10/05/8.~ 1L-7 10/19/8'4 1L-6 10/18/84 - 1L-5 10/18/84 1L-4 10/19/84 2W-7'J= 1/07/85 2W-6 -'~ 1/07/85 2W-5~-~ 1/07/85 2w-8 :~' 1/08/85 1E-5 11/~5/84 .1/o7/84 1/o7/84 1/o7/84 1/o8/84 11/26/84 "SBHP" "Initial" "SBHP" "Initial" "SBHP" "Initial" "SBF~" "Initial" ,,sBHP,, /cat Receipt Acknowledged: DISTRIBUTION ,=~,i,:~.;,~:~.~i~ B. Currier Drilling W, Pasher State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D & M NSK Ops. J. Rathmell Well Files ARCO Aiesk&. Inc. is e lubsi0iary of AllanticRichfieldCompany ARCO Alaska, Inc Post Office =ox 360 Anchorage, Ala,~ka 99510 Telephone 907 277 5637 RETURN TO: Date:l/29/85 Transmittal No: 5009 PAGE 1 of 2 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH FINALS Schlumberger ~/ 2C~ 2"/5" FDC-CNL/GR "Poro" 9/30/84 Run 1 7300 - 7889 ~' " 2"/5" " "Raw" 9/30/84 " 7300 - 7889 " 2"-/5" DIL-SFL/OR 9/30/84 " 2847 - 6914 " CPL Cyberlook 9/30/84 " 7300 - 7874 ~ 1L-il6 2"/5" FDC-CNL/OR '.'Moro" 2"/5" " "Raw" 2"/5" .DIL.-.SFL/GR . CPL Cyberl°°k 10/17/84 Run 1 7100 - 7780 10/17f84 " 7100 - 7780 10/17/84 _ " 4012 - 7820 10/17/84 " 7100 - 7780 1L-8 2"/5" FDC-CNL/GR "Poro" 2"/5" " "Raw" 2"/5" DIL-SFL/GR CPL Cyberlook 9/04/84 9/04/84' 9/04/84 9/04/84 Run 1 2392 - 7742 " 2392 - 7742 " 2392 - 7782 ./cat Receipt Acknowledged: B. Currier BPAE Chevron D & M DISTRIBUTION · Drilling Geology Mobil NSK Ops. 7100 - 7742 W, Pasher G. Phillips. Phillips Oil J. Rathmell State of AK ~ Sohio Union Well Files ARCO Alaska, Inc. Post Office~ ~( 360 Anchorage, ~aska 99510 Telephone 907 277 5637 RETURN TO: --. --o Date: lf29./85 Transmittal No: 5009 PAGE 2 of 2 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2"/5" FDc-cNL/oR "Poro" _ ._ 2"/5" " "Raw" " 2"/5" DIL-SFL CPL Cyberlook 9/20/84 Run 1 3600 - 8452 · · 9/20/84 !! 3600 - 8452 9/20/84 " 2074 - 8452 9/19/84 " 3600 - 8150 2"/5" Density Neutron/GR "Poro" · 2" " " "Raw" 5" "' " "Raw" .2"/5" DIL, SFL/GR -o CPL' Cyberlook 9/23/84 Run 1 9/23/84 " 9/23/84 " 9/23/84 " 9/23/84 " 7290 - 8i25 7290 - 8125 2884 -'8125 2884 - 8148 7~50 - 7750 /cat Receipt Acknowledged: B. Currier BPAE Chevron D&M -. Drilling .. Geology DISTRIBUTION W. Pasher G. Phillips State of AK Sohio Mobil Phillips Oil Union NSK Ops. J. Rathmell Well Files ARCO Alaska. Inc. is a Subsidiary of AllanticRichfieldComl=any ARCO Alaska, Inc. Post Offic('--"')x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/03/85 Transmittal No: 4943 RETURN TO: ARCO ALASKA, INC. ATTN: Records Cler~ ATO-1115B P.~'; Box 100360 chorage, AK 99510 i ~l~ransmitted herewith are the following items. Please acknowledge receipt ~mnd rm~'and return one signed copy of this transmittal. OH LIS SChlumberger oo. . . #6979.8 2E-14 11/26/84 4015 - 8691.5 Run 1 #69895 2H-14 7/16/84 2808 - 8898.5 'Run 1 (Recomputed 12/26/84) #69887 1L-8 9/04/84 2383.5-7825 Run 1 (Recomputed 12/26/84) /cat :: Receipt Acknowledged: Da~e: DISTRIBUTION B. Currier BPAE Chevron Drilling · _ Geology· Mobil W. Pasher G. Phillips Phillips 0il State of AK Sohio Union D&M NSK Ops. J. RatHmell Well Files " ARCO Alzska. Inc. is ,3 subsidiary ol AtlanticRichfieldCompany ARCO Alaska, I' Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 12/11/84 Transmittal No: 4906 RETLSLN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O..Box 100360 . _~orage, AK-99510 - . . ///Transmitted here%%th are the fOllowing items. Please acknowledge receipt ~ and return one signed copy of this transmittal. .,/1L-7 ./1L-8 1L-5 / 1L-6 CBL' s FINALS/Schlumberger Variable Density "GCT/JB/G. Ring" ~'C~OR~E CT~n"~Q 9/13/84 " " "GCT/G. Ring" " " "GCT/JB/G. Ring" NOTE: Ref. Transmittal #4871, 11/27/84 Run 1 5191 - 6517 9/13/84 Run 2 9/14/84 PME 9/15/84 .Run 1 3256 - 7678 4025 - 7678 5855 - 8298 /cat Receipt Acknowledged: Date: DISTRIBUTION B. Currier BPAE Chevron Drilling Mobil W. Pasher G. Phillips Phillips Oil State of AK Sohio Union D & M NSK Ops. J. Rathmeil Well Files ARCO Alaska, inc,~--, Post Office..x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 12/11/84 Transmittal No: 4906 . RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 horage, AK 99510 '. . ~. T~nsmitted herewith are the following items. Please acknowledge receipt ndreturn one signed of this transmittal. copy CBL' s FiNALS/Schlumberger 1L-7 Variable Density "GCT/JB/G. Ring" 9/13/84 Run 1 5191 - 6517 / 1L-8 " " " 9/13/84 Run 2 3256 - 7678 1L-5 " " "GCT/G. Ring" 9/14/84 PME 1L-6 " " "GCT/JB/G. Ring" 9/15/84 . Run 1 /cat 4025 - 7678 5855 - 8298 Receipt Acknowledged: Date: DISTRIBUTION B. Currier BPAE Chevron D & M Drilling Mobil NSK OPs. W. Pasher' G. Phillips Phillips Oil J. Rathmeil State of AK Sohio Union Well Files ARcO Alaska, Inc. Post Office box 360 Anchorage, Alaska 99510 Telephone 907 27'7 5637 RETURN TO: Date: 11/27/84 Transmittal No: 4871 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and returnone signed copy of this transmittal. CBL' s FINALS/Schlumberger *lL-5 "GCT/G. Ring" 9/14/84 PME 4025- 7678 1L-6 "GCT/JB/G. Ring" 9/15/84 Run i 5855 - 8298 1L-7 " 9/13/84 " 5191 - 6517 1L-8 " 9/13/84 " 3256 - 7678 *NOTE: CORRECTED CBL/1L-5 Received 11/08/84 & Transmitted 11/15/8~,~#4855 /cat Receipt Acknowledged: DISTRIBUTION Date: B. Currier Drilling W. Pasher State of AK BPAE Geology- G. Phillips Sohio Chevron Mobil Phillips Oil Union D & M NSK Ops. J. Rathmell Well Files ARCO Alaska, Inc~ Post Office ~,ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 30, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1L-8 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer J G/tw GRU2/L51 Enclosures RECEIVED NOV 0 5 ]984 AJaska 0il & (~as Cons. Commissfon Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany · ' - , ,. STATE OF ALASKA ALASKf. ;IL AND GAS CONSERVATION C ?'IMISSlON WELL COMPLETIO# OR RECOMPLETIO# REI ORT AFID LOG 1. Status of Well Classification of Service Well OIL [~[X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-150 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 029-21175 4. Location of well at surface 9. Unit or Lease Name 224' FSL, 216' FWL, Sec.29, T11N, R10E, UM ~'~'~LQC./-".T;.tT~!'.i$''"'~ .........~'Kuparuk River Unit Top Producing Interval· ,.,i 10. Well Number At 1091' FSL, 1400' FEE, Sec.29, TllN, R10E, UM I VERIFIED .,, 1L-8 At Total Depth ~ 11. Field and Pool 1148' FSL, 1205' FEL, 5ec.29, T11N, R10E, UN 18'H'~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 118' RKB ADL 25659 ALK 2585 .12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 08/29/84 09/0:~/84 09/:~0/84I N/A feet MS L 1 17. Total Depth (M D+TVD)i18. Plug Back Depth (MD+TVD)19. Directional Survey I 20. Depth where SSSV set [ 21. Thickness of Permafrost 7810'MD,6361 'TVD 7698'MD,6258'TVD YES [] NO [] 1851 feet MD 1450' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/$P/GR/Cal/FDC/CNL, CBL/VDL/GR/CCL/JB, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 275 sx Cold Set II 9-5/8" 36.0# J-55 Surf 2398' 12-1/4" 855 sx AS Ill & 250 sx Class G 7" 26.0# J-55 Surf 7779' 8-1/2" 775 sx Class G & 17 bbls AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) ._ 7/+82' - 7500' w/ 4 spf 3-1/2" 7420' 7391' & 71/+5' 7:~06' - 7362' w/12 spf 26. ACID, FRACTURE; CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A · ,,. 27. N/A PRODUCTION TEST Date First ProduCtion I Method of Operation (Flowing~ gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESlZE IGAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.~ el L-BBL GAS-MCF -WATER-BBL el L GRAVITY-APl (corr) Press. 24-HOUR RATE I~F'! 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NON RECEIVED NOV 0 5 198 Alaska 0ii & Gas Cons. Commission Anchorage Form 10-407 GRU2/WC10 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE '.: ;'¥. !-' ~:: [: ~ ~' !~;:~- ~-::;:G:i~o~b~bM~i'.12--~[~'~ ~;~.'-;~ ~::!;: 1.-':,' i~;c~,¢,;~:;~; .:~:::,!:~i-'~:.:i:,~ ~?./i'~Z ;t' ;:-'i-,.¢I i;:?F/o'RI~/1,~T'-i~N.~'E~;T~-' :,:'7...::-:.....,..~" ';~'-", '?.,?.-f. :-.-¢ · NAME - Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase· , · Top Upper Sand 7304' 5898' N/A Base Upper Sand 7360' 5949' Top Lower Sand 7468' 6046' Base Lower Sand 7586' 6154' . . : .. _., _ 31. LIST OF ATTACHMENTS · W~_ll Hi_~nrv (inr. l~dinn add~_nd~,m)_ Wnrknv~_r Well His~nrv_ Cvr~seonie Survey (2 ,.~ . ... - .,. ., ~ ~ , , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~~¢/¢'~.~'~/,~4~-t~' Title Area Drilling Engr. Date ~../- ! ~// --- . / / , 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 Operati°'n' 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". Fnrm 1 C)-Z~g7 Kuparuk River Aulh. or W.O. no. · .~ 204111 Parker 141 O~mtor ARCO Alaska, Inc. Spudded or W.O, b~un Spudded Date and del~l aa of 8:00 a.m. 8/29/84 8/30/84 8/31/84 North Slope Borough imm, Alaska IComplete record for each d~y rl~rtld i U~ ~®11 ~. ADL t25659 ! 1L-8 Drill, Complete & Perforate AP1 50-029-21175 IARCO W.I. 1°'8/29/84 IH°ur 0000 Hrs. IPrl°r statue Spud well @ J~"~ @ 110' 999', (903'), POOH to PU DD Wt. 9.6, PV 11, YP 19, PH 9.5, WL 12, Sol 10 Accept ri~ @ 1600 hfs, 8/28/84. NU diverter sys. 0000 hfs, 8/29/84. Drl 12¼" hole to 999'. 1~"2~'' @ 110' 2420', (1421'), Rn'g 9-5/8" csg Wt. 10, PV 11, YP 15, PH 9.5, WL 10, Sol 14 DD, drl & surv 12¼" hole to 2420', 12 std short trip, C&C, POH. RU & rn 9-5/8", 36#, J~55 HF-ERW BTC csg. 1000', Assumed vertical 1101', 3.6°, N77.5E, 1100.95 TVD, 3.17 VS, 0.69N, 3.10E 1648', 21.8°, N69.5E, !632.05 TVD, 125.31VS, 38.11N, 119.41E 1998', 30.4°, N7OE, 1946.36 TVD, 278.92 VS, 91.40N, 263.87E 2385', 40.1°, N74.5E, 2262.32 TVD, 501.86 VS, 161.37N, 475.69E If a W.O. 9-5/8" @ 2398' 3071', (651'), POH Wt. 8.6, PV 5, YP 6, PH 11.5, WL 20, Sol 3 Fin rn'g 60 its, 9-5/8", 36#, J-55 csg w/FS @ 2398', FC @ 2317'. Cmt w/855 sx AS III w/1/4#/sx Cellophane Flake, followed by 250 sx C1 "G". Bump plug. ND 20" Hydrl, NU & tst BOPE. RIH w/8tt" BHA, tag FC @ 2317', DO FC & cmt to 2385', tst csg to 1500 psi. DO FS + 10' new hole to 2430'. Conduct formation tst to 1~.5 ppg EMW. Drl 8½" hole to 3071'. 2720', 45.8", N75.SE, 2506.75 TVD, 729.60 VS, 220.30N, 695.74E 3031', 51.1C, N78.5E, 2713.03 TVD, 661.96 VS, 272.66N, 922.52E RECEIVED NOV 0 Alaska 0il & Gas Cons. CornmJssion Anchorage The ~OVl |1 cor~lct lDate Title 10/08/84 Drilling Superintendent ARCO 011 and GaS CompanY Daily Well Hist~ry'-Interim Inatn~t~t~: Thla form Is used during drilling or workover operaflonl. If testing, coring, or perforating, show formation name in describing work psdormed. Number all drill stem te~ts sequentially. Attach description of all coral. Work performed by Producing Section will be reported on "[OIIHm' sheeL~ until final completion. Report official or representative test on "Flnlt' form. t) Submit "lnllrh~' sheets when filled out but not less'frequently than eve~/30 day~, or (2) On Wednetday o! the week in which oll string ia set. Submit we~ldy [or workovera and [ollowing setting of oil string until completion. Alaska North Slope Borough Alaska Field ILease or Unit KuParuk River I ADL #25659 Complete record for each day while drilling or workover in progress Date and dep~ as of 8:00 a.m. 9/01/84 thru 9/04/84 The above is correct For form preparation and distribution see Procedures Manual Section 10. Drilling, Pages 86 and 87/'I 9-5/8" @ 2398' 7810', (4758'), C&C Wt. 10.1, PV 16, YP 14, PH 8.5, ~ 8.1, Sol 12 Drl & surv 8½" hole to 7810'. Log GR. Drl 8½" hole to 7810', 15 std short trip, circ, POH. RU & rn DIL/SFL/SP/GR/CAL/ FDC/CNL, unable to get below 7495', POH, RD Schl. RIH to cond hole f/logs. 3171', 49°, N79.5E, 2802.93 TVD, 1068.83, 3645', 48°, N76.5E, 3115.65 TVD, 1424.42, 4265', 47.4°, N75E, 3529.70 TVD, 1885.52, 4704', 41°, N77.5E, 3814.51TVD, 2174.67, 5327', 41.2°, N77E, 4303.89 TVD, 2608.20, 6259', 39.1°, N72E, 5023.90 TVD, 3199.86, 6872', 31.7°, N74E, 5519.00 TVD, 3560.45, 7371L, 24.6°, N74E, 5959.75 TVD, 3793.92, 7785', 20.9°, N76.5E, 6342.26 TVD, 293o14N, 1027.87E 373.21N, 1374.92E 484.84N, 1822.68E 538.89N, 2108.13E 639.78N, 2530.31E 804.51N, 3098.57E 913.39N, 3442.43E 981.66N, 3665.72E 3952.08, 1022.03N, 3818.70E loafs ITitle 10/08/84 Drillins Superintendent no. 1L-8 , ARCO Oit and Gas Company Daily Well History-Final Report I;~l~ti~a~, Prepere ~d submi, t the "F~M Rl~x~rt" on the fl~ Wedne~ a~er allowable has been a~igned or well is Plugged, Ab~doned, or Sold. *'~M R~' should ~ submt~ ~ ~h~ o~rsUonm ~:.~ f~r ~ indefinite or appr~i~le length of time. On wo~ove~ when an o~cial test is not ~uimd u~n completion, m~ completion ~d mp~:~ d~a m blocks provide. The "FIn~ R~' form may be used for reposing the entire o~ration if space is available. District ICounty or Parish Lease or Unit Title IAccounting cost center code State Alaska IWell no. 1L-8 Field Alaska Kuparuk River North Slope Borough ADL #25659 Auth. or W.O. no. AFE 204111 Drill, Complete & Perforate Parker 141 API 50-029-21175 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prlor status if a W.O. 0000 Hrs. Operator I A.R.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun I Date Spudded I 8/29/84 Date and depth Complete record for each day reported as of 8:00 a.m. 9/05/84 91o6184 9-5/8" @ 2398' 7810', (0'), LD DP Wt. 10.1+, PV 13, YP 7, PH 8.0, WL 8.4, Sol 12 C&C hole f/logs, 10 std short trip, POH. RU Schl, rn DIL/SFL/ SP/GR/Cal/FDC/CNL f/7788'-2400', RD Schl. RIH to 7720', wsh & rm to 7810', C&C, pull & std back 20 stds, LD DP. 7" @ 7779' _ 7810', (0'), RR 10.3 ppg NaC1 RU & rn 202 jts, 7", J-55, 36#, HF-ERW BTC csg to 7779'. Cmt w/475 sx C1 "G" w/1.5% D-79, 1.2% D-112, .05% D-65, .2% D-46 & .25% D-13., followed by 300 sx C1 "G" w/3% KC1, .8% D-60 & .2% D-46. Displ w/10.3 ppg NaC1, bump plug. Instl packoff & tbg head, tst to 3000 psi. RR @ 2400 hfs, 9/6/84. Operations suspended - wait on completion rig. Old TD Released rig 2400 Hrs. Classifications (oil, gas, etc.) ' -. -'- ' 'n~'~ _ Producing. method Flowing Potential test data INew TD ]PB Depth 7810' (8130184) IDate Kind of rig 9/6/84 Type completion (sing[e, dual, etc.) ' Single Official reservoir name(s) Kuparuk Sands ~-"" '-:~,';;G. [ Well no. Date Reservoir Producing Interval O[I or gas Test time,Pr°ducti°n .~Dr,~.,- ......... IOil on test Gas per d-ay'"' u~ ,. Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective dale corrected of;'l~rl/ss/orl The above is correct For form preparation and distribution, Drilling Superintendent ADDENDUM WELL: 1L-8 9/6/84 9/14/84 9/1~7/84 Arctic Pak w/17 bbls AS I, followed by 56 bbls Arctic Pak. Rn CBL/VDL/GR/CCL/JB f/7698'-4500'. Rn gyro f/7698'-surf. Drillin~ Superintendent Date ARCO Oi! and Gas Company Daily Well History-Final Report btl~ctios~'- Prepare Ind submit the "Finlt Rep~rl" on the flrl~ Sqtld~e~cl~y altar allowable has been assigned or wall ia Plugged, Abandoned, or Sold. "Fiaal Reg~l" should b~ submitted also when operatlonl ~ for an indefinite or appreciable length of time. On workovare when an official test Is not required upon completion, report completion and repre~e~l~'lllRl~tFIi~ d~tl In blocks provided. The "Final Rel~rl" form may be used for reporting the entire operation if space is available. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 204111 Westward #1 ICounty or Parish Lease or Unit Title North Slope Borough ADL # 25659 IAccountlng cost center code State Alaska Well no. iL-8 Completion : AP1 50-029-21175 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete Date and depth as of 8:00 a.m. 9/29/84 thru 9/30/84 A.R.Co. W.I. 56.24% Date 9/28/84 Complete record for each day reported I otal number of wells (active or inactive) on this DSt center prior to plugging and ~ bandonment of this well our I Prior status if a W.O. I 1130 hfs 3½" @ 7419' Bkr FB-1Pkr @ 7391' Accept rig @ 1130 hfs, 9/28/84. ND tree, NU & tst BOPE to 3000 psi. RU DA, RIH, perf 7482'-7500' @ 4 SPF. Perf 7346'-7362', 7326'-7346', 7306'-7326' @ 12 SPF. Rn 6.125" gage ring/JB to 7650'. RIH w/FB-1 pkr, set @ 7391'. RU & rn 3½", 9.3#, J-55 IPC EUE tbg w/tail @ 7419', FB-I' perm pkr @ 7391', "D" Nipple @ 7414'. Set pkr, tst tbg to 2500 psi. Tst ann to 2500 psi. Shear PBR. Instl BPV, ND BOPE, NU & tst tree to 5000 psi. Displ well w/30 bbls diesel & 235 bbls crude oil. RR @ 0300 hfs, 9/30/84. FHL Hyd retrv pkr @ 7144' - Shear Sub @ 7419' Old TD Released rig 0300 hfs Classifications (oil, gas, etc.) 0il Producing method Flowing Potential test data rNew TD I PB Depth Date [Kind of rig 9/30/84 Rotary JType completion (single, dual, etc.} Single Official reservoir name(s) Kuparuk Sands Well no. Date · Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct . /~ 10/12/84 Drilling Superintendent Dally Well History-Initial Report, Kup&ruk R.'Evmt Auth. or W.O. n~- AgB 204111 ~est~ard #I Operilor ARCO Alaska, Inc. Spudded or W.O. ~ Co~R~Iete IL em or Urdt Title IDltl Omi am~ d~pt~ aa of a:OO a.m. 9/28/84 Comple4e record for e~ch day reported · 7" @ 7779' 7698' WLM PBTD Moving rig. 9/28/84 North Slope Borough ADL 25659 Completion A~I 50-029-21175 130 hrs Alaska IL-8 RECEIVED NOV 0 5 !9~ Alaska Oil & Bas Cons. Commission Anchorag8 · . :: ! Dill I TIUi ' 1^.R.Co', w.~. 56.24% Prior statul If I W.O. OOL CtiS'l'{J~F,l~ [,,[STING Ft)i:~ ARC'[.] AI,ASISA, ]tJCo I',It.It,~TH SI,Ot.'I.., AbASKA SIIRV~:¥ [)ATi!:I 16,,,SEP,,,84 I', t..:TIi fl 1}$ Iii" qt.3ill.~ b[]CA'I'lt~k: q'/akC;El,~'£1~ll,,,- averaqed d~vlatlon aBd ~:R'l'lC'/',[, Sl,;C'['I(.~: H~)t(J'Z, [')ZSP, [~}{['ldf:C'l'l~:l)[jr~'.l'lj' ~ TARG['J'F gZ[~q~l'l'tt il~' ~(11~l'1't 73 [)NG 43' MIN EAST , . , ARCO ALA~KA~ INC. 1 KUPARIIK NOR'.I'rl ~I.,Ol:':'t:':~ AI.,ASt~,A COI,~PUTA'i IUt,, I)ATF: 5.,',(~C'1'-84 T R {, E 51 ~ H - $ HEASURF**I~ V ER']" I CAI. (). 0 (', 0 I) 0 - 1 ! la',, 100. O0 1 O0: O0 -1 ~. 200,00 200,00 82, 300.00 3,00.00 182. 400 O0 ~00 O0 2fi2, $oo:oo ,soo:oo 600.00 · 599.99 4'~1. 700.00 699,99 581. 800 O0 799.99 681~ 900~00 899.99 781. 1000,00 g9g,g9 881 ' 1100.00 1099,94 1200.00 1199,55 lO}ii, 1300 O0 .1298 ,'iq 1150, ~600.00 1587,50 .1'100,0(~ 1~fl0,27 1562. 1800.00 1'171.~, ,.~53 1900,00' 1~60, : 1742~ 2000.00 19,t'7 72 1829, 2100.00 2032;84 1, gl4. 2200,00 2115 '1,~ l. gq'l. 2300.O0 2195~91 2o~7. 2400.00 2273,21 2155. 2500 O0 2348 12 2230 2600.00 2421,46 2303. 2700,00 2492.89 2374. 9 ~ 2443 2800.00 256]. . 2900,00 2629.34 2511. DA 3000,00 2694,82 2576. 3100,O0 2758,37 2540, 3200.00 2823.74 2705. 3300.00 2889.50 277~. 3400,00 2955,11 2~37. 35U0,00 3021 Ut 2¥03, ~60().00 308}t183 2970, 3700.00 3155,76 3037. 3800.(;o 3222,28 3104, 3900. o0 328~I. b4 ] ~ 7(). Al, [)EVIA'£I.[.,~., AZIM~] fl D t'J (; M I r,; I., E, G ~ 00 0 O0 :, 0 13 O0. 0 20 O0, 0 15 O0 0 12 00. ~ 0 ,1 o 99 0 7 99~i :0..:. 2 99 0 0 gO O 0 1 [{ 2 21.3 '24 22 4 195 N 25 2 a 2] 3 N 67 1 S 78 2 70 73 75 1 N 72 3 '70 1 70 5 7 t 4 72 ~ 7 J 73 3 7 ~ ~ 74 5 7 ~ .I 79 79 1. 7 g 78 3 7~ 2 77 5 77 3 77 2 77 ~ 99 0 17 94 3 19 55 6 41 4,~ l() 18 22 13 44 53 16 50 5 0 20 q 27 23 31 1~ 25 3'1 42 2~ 2 100 P'fi:~,;T 0~' I,,,EAGURED fl E C ;r I (...I ~.,, FEF.T 0, I.) (i '0,12 -0.29 -0 · 40 0,42 ~,0,47 ' 0,49 -0,51 20,51. 0.51 2.33 1.1,01 25,75 46,57 73 ,Off 104 . 64 141,87 183,46' 228,53 277,24 329,69 385 O4 445:35 508.7fi 5'15. O0 642 . 94 712.83 '1~!5,03 858.57 ~',~3, 1010,53 1085.81. 1160,82 1,235,99 1310,42. 1384,23 lq58,36 1532,86 1607,51 D~I(.~I.,i;;yTY. kEC'I'AN S E V E [,' i{ 0 R T H / b ~: t; / 1, 0 ('i F k; g 0,00 0,07 0,20 u 08 0 ~ o19 0.04 0 t' '(.~ 4 O, 0 O2 0; ~17 PAGE I ~ TE 01;' SURVEY; 16-SEP-84 Lb¥ [~bSHING ELEVATION: 118,00 F:r ~GINEILR: BAUMEISTER 1.42 3,65 3,40 3,84 4.02 2 70 3~ 70 2,51 2,07 2,1.6 DIfPI.'li 2,52 2.32 2 7! 2~48 1,92 1,63 1.22 2,35 1,60 1.67 GULAR COLIBDIN'ATE$ itURIZ, DEPARTURE SOUTH EAST/WEST DIST. AZIMUTH ',[' F~:E'r FEET DEG M IN 2.31 2.03 o'35 0,66 2.49 2.39 0,59 0,58 0.22 0,35 0,2 ¢'), 6 1,0 1,7 2,0 2,1 2~, ~ 2, . 22 31, 43. 5'1, 71, 87, 103. .120 .137; 154, 172, ltl9, 205, 221, 235, 249, 203 277! 291 305 336. 351, ]67, 38q., I N 0.19 4 N 0.49 9 N 0 ,'73 7 N 0,87 6 N 1,00 3 N 1,Il 4 N 1,16 0 a 1 17 ~ 2 N 1~17 0 lq 1.04 w 2.43 0 ~ 1 79 L 2 84 I N 10:27 E 11:06 4 N 24,24 E 25 80 3 N 69,62 E 73- I N 99,~9 ~ 104,66 8 a it5,19 E. 141,92 9 N 174,45 E 183,56 ? N 217,14 E 228,bb N 25 20 W N 39 8 E N 68 11 E u 69 57 E; N 70 25 E t~ 72 12 E N 72 39 E N 72 17 E N 71 52 E N 71 43 E 263 36 g 277,41 313~26 g 329,89 360,60 E 385,84 423.88 E 445.53 4~4.80 E 508.92 548,60 E 575,13 614 46 E 643,01 6~2~45 E 712,86 753,14 E 785,03 825.59 E 858,59 71 41 71 43 7.2 17 72 31 72 51 73 12 73 36 74 3 1 N 899.86 F; 933,86 5 N 975,89 ti 1010,75 0 a 1050,27 f: 1086.19 3 N 1124 26 E 1'161 36 0 N 11.9~29 E 1236:72 8 ~ 1271,48 E 1311~32 9 N' 1343,91 E 1385,29 1. a 1416,53 E 1459,56 7 N 14. fl9.43 E 1534,21 7 ~ 1562.,tl E 1b08,99 N 74 29 N 74 54 N 75 13 N 75 28 N 75 40 t~ '75 50 I,I 75 57 ~ 76 3 N 76 7 N 76 10 E E E g E E )) E E E E E E E E E E / . , ARCO AI,ASI<A, IN(..', 1[,-8 NOR'['It ,gl, riPE, Cf,t,~ PIJ T AT '.I' 0 N [)A'I E -.' PAGE 2 DATE OF ${..{RVEYZ 16-SEP-84 gELL¥ ~bSJiING £LgVATION: llb,O0 FT £NTt:RP,.JLAT~U VALIJI'!:,S I.;'I..]R I~;VEPt 100 TRUE S IJ i},-5 t:/A C (.i lJ I{,.:, b ~["~ASIIREI~, VERTICAl., VERTICAl., DF.V][ATIOI'.I hZ]I~iITfl DEP'.I.'H DBl.'TH 4000,00 335~<t 7B 3236,'18 4~ ]¥ 4100.00 34~.1 ;01 ~(~3.0! 4 /'.. 4200,0(.1 3487,51 3~h.9o51 47 50 4300.00 355b.16 341~7.16 47 18 4400.00 3622,97 3504,97 47 20 4500,00 3690.89 3572..89 46 58 4600,00 3760,02 3642,o2 44 4700,00 3~34.56 3716.56 41 9 4800,00 3909,73 37.91.73 41 16 4900,00 3984,74 3866.74 41 ~6 VI:'~:I~'I,].CAI, D,...IGI,[':G RECTANGULAk ('O{JRI)INATES HORIZ, DEPARTURE SECT[C1N SEVERITY NIIRTH/SOUTH LAST/WEST DIST,' AZIMUTH PEET DEG/1 O0 ~'EET FEET t~ 17 4 a lb82.38 a 76 55 F; 1757.1a ,~ 7~{ 17 E 1.831,72 N 79 32 E 1.905 02 i.i .79 46 E 1978[13 N 84 57 E 2050~72 N 82 50 E 2121,56 N 7~ 14 E 2187,81 h 78 1~ E 2253.56 N 78 ~7 E 2319.49 0.28 2,54 0,,30 0,8,8 2.91 9,4'1 .O, 30 0,73 O, 69 40o,99 N 1635 55 E 1683 417,85 m 1708:55 E 1758 434 28 N 1781,~tl E 1833 448:03 N 1853,75 E 1907 461,34 N 1925 03 E 1980 471,55 N 1998:67 E 2053 477,83 ~ 2070,~4 E .2125 489,75 N 2136,17 E 2191 b03,29 N 2200,72 ~ 2257 516,76 N ~265.46 E 2323 5000,00 4059,60 3941..60 41 32 5100,00 413~ 47 4016,47 41 30 5200.00 4209'41 4091,41 41 25 5300,00 4289'37. 41.6,6.37 41 24 5400,0l) 4359.47 42~,47 41 11 5500,00 4435,31 4317~ 31 39 38 5600,0() 4512.77 4.39.~ ~77 39 8 5700,00 4590,38 4~72,3~'.{ 39 b .5800,00 4667,96 .4549.96 3~ 3 5900,00 4745,58 9627.5R 39 7 6000,0{) 4[{23,17 4'1L, 5,17 39 b 6100.00 4000,92 4782,92 3a 56 6200,00. 4978 70 4860 70 3~ 53 6300,00 505b'.54 4938~54 3a 46 6400 O0 5134 'l~ bOlb.7o 3~ 23 6500:00 5213~51 50g~,5~ 37 34 6600,()0 529.], ~ 5175.b4 35 58 6700,00 5375,28 5~b7.28 34 ~3 6800.00 54511, t2 534(). J2 33 7 6900.00 5542.76 5424,76 31 18 7000.00 582u.72 551o.72 29 57 7100,00 571b,02 5598,02 28 lb 7200,00 5804.76 5680,76 26 41 7300,0o 5894,65 577't., ob 25 .JR 7400,00 5984.69 5866.60 25 26 7500,00 6075,45 5957,45 24 I l 760¢),00 6167,25 6049,25 22 t5 7700 0(; 6259 72 6141.72 22 19 7800".00 6352:23 6234,23 22 19 '1810. OL, ~,36.1, d.d h243.qR 22 lg 7~ 16 E 2385.5q 76 20 E 2q51..66 78 25 E 251.7.66 78 19 ~,: 2583.63 78 17 f: ?649.44 7'1 12 E 2'114,43 76 30 E 2777.59 't~ 20 E 2840.58 7~ 12 E 2903,62 75 54 E 29~6.61 75 4U E 75 41 E 3092.49 75 29 E 315~ 32 75 26 E 321o:07 75 13 E 3280.32 74 51 ~ 3341.96 74 29 E 3901,77 7'4 ~0 E 3459,52 '7] 48 E 35~5 23 7.] 40 E 3568[79 73 42 E 36J9,89 13 23 E 3668,64 73 8 E 3714,74 73 9 E 3758,54 73 24 E 3802.04 73 49 E 3844.01. 74 1~ E 3883.68 7~ 8 E 3921.73 74 8 E 3959.72 74 8 E 3963.52 0,15 O. 34 0,26 0,17 0,30 2,bO 0.26 0,12 0.34 0,35 0,18 0,32 0,29 O. 87 '),47 1,55 ],24 1,56 1,~ 1,50 1,39 2.20 1,33 O, 49 1.20 1,44 1,34 0,00 0,00 0,00 530 22 N 2330,39 E 2389 95 543:03 h 2395,31 E 2456:23 556.99 ~ 246U.J6 E 2522,42 570,35~. 2524,~9 Pi 2588,60 583 74 ~ 2589,64 E 2654,62 611 8o N 4,93 E 2783,02 626 68 m b,22 E 284b,07 b41. 64 N 2837,52 E 2909,16 650 83 N 2898,71 E 2972,19 N 77 10 E N 77 12 E N 77 14 E N 77 16 E N 77 1'7 E N 77 ~8 E N 77 17 E h77 ib E N 77 15 g ,~ 77 ~3 E 072,2'1 ia 2959 89 ~ 3035 27 N 77 12 E ~87.74 ~ 3020~83 E 3098~12 N 77 10 E 719,13 N 3142:48 f: 3~,,23, . N 77 6 E 736,8H N 3202,73 E.: 3285 96. N 77 4 E 750,~3 N 3262,28 £: 3347:57 N 77 2 g 766,65 N 3319 97 £ 3'407,34 N 76 59 F 7U2,24 N 3375:58 E 3465,03 N 76 57 ' 3 797,06 ~, 3429,12 E 3520,67 b 76 54 u · 812.78 N 3480,50 E 3574,14 N 76 51 E 827.13 N 3529,54 E 3625,17 n 76 48 E 840,89 N 357b,31 g 3673,84 N 76 40 E 854,16 M 3620 46 E 3719,86 N 76 43 E 879.32 N 3704 06 E: 380 .:00 N 76 E ~9i.19 ~ ]744,32 £ 3848,91 h 76 36 E 902.13 N 3782.44 E 3888.54 N 76 35 E 9J2.52 N 38~9 ~5 E 3926,5b- h 76 33 E 922.91 N 3855:'9o E 3964,51 N 76 32 g q23,ga N 3~b9.25 g 3968,31 N 76 32 E ARCO AI.,A~KA, I'NC. 1[,-8 KUPARUK NOR'I'll L;I,13PE, AbfiSK^ C(~,MPI.ITA"I'It.jI'~ I)A'I'I<: .r',.-OC"1'-84 PAGE; 3 DATE r)F SI..IRVI<Y: 18-$EP-84 Kl~:hl.~ t3USttI. N(., EL~EVAT.IONI [.: m G 1 N ~: t!: k: B A U M E I $ T E R I";'It"'R[~II,AT[~[~ V t~L~i,:,5 FUR LV[<I,, l(JOo t;'~b;T I)~" IqEA,SlJt;~El~ I)EPT ol.,A C(~ MF,,A$1IREI) VER'I'ICA[, V[.,']R"J'ICA[, DEVIAT]C)I~ AZIMUTH D E P'I.' ! i t>EP'l'lt DE P'l; H DEG MIN b 1.'. G llB,O0 FT u, 0() 1,42 2 52 2~31 0,28 0,15 0,18 I , 39 O, O0 0.0o ~ 0.00 k 0 2.20 N 1,04 w 2 t.~'l,17 1,,,263,36 ["' 27-/ 249,71 N 'B~9 R6 E 933 400 99 N lh35:b5 E; 1683 530~22 N 2330,39 E 2380 672,27 ~ 2959,89 E 3035 827,13 N 3529,54 F 3625 923,94 N 3859,25 E 3968 N:'Y25 2u w 1 41 g 84't':~':''''.',,'1~'~,:''~ ~4 29 E g9 .N70 13 £ 95 ,N 77 10 ~: 27 N 77 12 ...... 17 N 76 48 ~,. 31 N 76 32 .. 0,00 o, 00 . 1000,00 999,99 R~.1,99 0 17 2000.00 19<,'1 72 ,1,'829,72 30 23 30NO ()0 2694:82 257f>. 8~ 50 4000:00 3354,78 3236,78 48 29 5000,00 4059.60 6000.00 4~J23,17 4705,17 39 6 7000,0~) 562~,7~ 5510,7~ 29 57 7810,0() 6361,4~ 0243.48 22 19 ARCO ALASKA 11-,-8 KI.IPAPIIK ~tJRTl-i MEASURED D I~.; P 1' 1-~ 58.90 118 218:00 318,00 418,00 518.01 618,()1 718,01 818,0'l 91R,O1. 1018,01 1218.5~';, 1319,9l 1422.45 1526.5~ 1632,6i 1741,.11. 1852,1'8' 1965,70 2082,36 2202,81 2328.21 2459,43 2595,23 2736. 2883.¢)4 3036,45 319!, 3O 3343.42 3494,55 3643,48 3793,59 3944.44 40')5.4 4245,2O 439? 4539~67 '[NC , ALASKA 3.'RI]H VERT IC.A[, U E P T H 91.~,00 1018,00 1118.00 121..~ :~(' 131.~ 1 ,t 18, ,.)() 'L51.8.0o 181~,00 191.B,00 · 2018, O0 2118,01) 2218.0() 2418,00 251d,00 26 ! 8, O0 2 '7 I ~.~. 00 2918,00 2(41 H, 301~,00 311.~'~,00 32 :l 8.0 (.) 3~18.0o 3518,00 361 ~ ,,)0 3~ 18, O0 3818,00 C()~PUT AT,I fin £h.Tr.:RI:'iIi..;ATEO VALUE~ F'OR S' S b 14- ,. r, A Vi::RI'ICAL I) l< I-' T ii C,)URSE', D E V I A T I 0 N A Z ,f h', II 'J' H DF.fi; M1rJ i.,gG MI ,'.1 I ~{,OO (.,, O0 1 (,0, O0 2o0.00 3 00,00 '100,00 5O0.00' 600. O0 7 t) 0 ,.¢) 0 0 ,0,.~ 27 0 14 O: 20 0 1.5 0 ! 0 ' 0 2 0 0 0 u E 2.~l 57 h:. lo 54 W 31 58 w. 1954 W 27 ' 3 .w" 21 54 ~ 1.9 25, 18 41 W 19 9 k 29 34 39. 28 35 20 38 4'7 4L 42 43 27 4'7 56 50 3H 4~ 44 7 I 3 ~,~ E 72 9 E 73 .2 E 73:46 E 74 25 E 76 10 g 77 25 g 79 3 I< 8() 0 I:.': 79 ,13 E 2 ~ 0 (), 0 () 290¢", O0 30O0. O0 3100.00 3200.00 3~0(.,.00 3400,00 .3 50 t,, 0 (; 3600,00 3700, O0 4a 'Sb 48 14 4'7 59 48 13 4~ 36 48 32 47 22 4'; 2u 46 44 4 ! '11 78 78 7'1 77 77 76 79 85 78 45 23 48 22 12 56 22 43 28 I.)ATF:: 5-0CT-84 l!.: V K,N 1 "ECT'[ r) ir E E 'T 0.0 -0,1 -0,3 -0,4 -0,4 -0.5 -0.5 -0,5 '0.5 -0.2 3,4 13,2 29.4 52,0 80,9 116.1 158.6 206,4 200.1 32O, ,1 3B7 ' 63g.6 7.3 ~ , 5 H46,0 9D].7 1079., 3 1193.4 1306,3 1416,4 l ,528 0 1640:8 1753.7 1864.9 19 '! 2,7 2079.0 2173.3 O0 0 0 7 0 l 3 2 8 4 5 4 4 5 0 ? PAGF. I)ATE OF SLIRVEY: 16-8EP-84 KEb[,¥ HL,I~HiNG ELEVATIONI EN G I N EER: FEET (JF SU[:i-bEA I)EPTH L) 0 G i., E G SEVERITY PEG/1 O0 R EC'I'A t'JGU I.,^ R CO0 NCJRTI.t/SOUTH EAS P' E LC T 0,0 U O, O0 0,28 0,73 1.,17 1,52 1,81 2,06 2,15 2.21 2,22 2,17 2 4,76 I O. 09 17,10 24,42 34 ,'14 48,87 (:4,57 81,'10 100.51. 120,62 142, 13 1(;5,45 188,71 21 l 74 233~34 254,61 275,78 297 5 ] 319 96 342 87 366 92 391 72 417 08 440,70 460,37 473.82 456.81 0 0 0 u 0 0 1 1 l 1 1 0 2 12 2'7 110 lbl 247 304 308' 440 522 611 7O7 927 104] 1156 1267 1375 1484 1594 1705 1814 1920 2027 2.1.22 BAIJMEISTER RDZNA'£ES T/WEST ET 0,0 () 0,01 0,21 O, 15 (;,08 0,.1~ 0,04 0,13 (.), 02 0,01 o 11, 2' ~ , 8 3,4B 3,51 .3,H3 3,27 3,70 2,08 2,79 2' 36 2,67 2 73 2:60 1,93 1~22 2,42 1,41 ~) 79 0 ,'m 3 'l 1,08 1,89 0,38 0,29 ().42 '),73 1,11 0 70 1~26 0,94 HORIZe DIST, FEET El O, :g§ o ,21 ~ 0 ,55 w 0 ,'16 W 1 ,90 ~ 1 .02 h 2 .12 w 2 ,16 w 2 ,17 w 2 118,00 F~ DEPARTURE AZIMUTH DEG ,, . . 35 i' 9:~:,;,: N 6 :: t 0 08 N 29 34 "N 28 45 N 28 50 h 28 0 E 0 E 33 w 44 w 7 w 29 W 2~2 6 20 1 ~ n 27 45 W I', 22 ~] W N 51 E N 69 5 E N 69 59 E N 70 47 F. N 72 26 E N 72 36 E N 72 4 E N 71 47 E n 71 41 E a 71 42 E N 72 25 E N 72 50 E n 73 20 F._ N 73 59 N 74 39 n 75 12 E .17 W 2,51 ,90 W ~,35 ,93 E ,76 71. ~; 29, 9 ,24 E 52,14 ,17 E 80,94 ,89 E 1'16 ~0 ,03 £ 158~,4 ,24 E 206,59 ,12 E 260.29 .16 g 320.34 .21. E 387,46 .71 ~ 463.06 ,38 E 547,96 ,26 E 639,73 ,60 [ 73~,50 .21E 846,03 55 E 961,87 :85 E 1079,57 41 E 1194,07 :48 E 1307,24 ,44 E 1417.53 ,'lb k 1529,43 ,96 E 1642,36 ,24 E 1755,51 ,15 ~i 1866,91 .54 F: 2~17 .00 E 2177,13 CIJI,41,'[JTAT*[f3r,~ l'~A'i"l.:.:: PAGE 5 ARC(':) ALASKA, 'I;,IC, I)ATI< OF SJ.)RVJ't.:.¥Jl 16-,SEP,-84 16-8 KELI, Y BUStlING [<I.,EVATION: KiJPA P. Ij h' NOt<Th 'SL,~]Ph:, ALA:~KA EJ'~¢;IN~:ER: BAUMEI~'rER I;,I'r[':I<I.:~IJLATF. D VALiI[':5 F'OH EVI'.:f': 100 r'l:i[;:'l' O[" ,SUJS-SI{A IJl"]PTtl q'J{L{[,] SIJ[~,-SJ,fA C[)lit.,:,SE: VK;t{'.I'[C~}., () {'/I (.,] i.., [': G Ri';CTAI~IGUI.~AR CUORi.)II,JATES HDRTZt DEPARTURE MEA$I.IRED VERTriCAi,, VF:R'F1CAI, DEV'[ATII)N AZIMU'I'P~ SF;C'.F',ION SEVERITY NORTH/6Ou'.rH EAST/WEST DIST, AZIMUTH DEP'rrt DEPTH DI!jP['H DEG MIr~ t.>E(] ~'~I{'. FI!':t/iT L)EG/100 FEET FbJET FEET DEG r,~ 7[{ 1'2 E 2260,78 ~;,60 N 7R 1~ E 2348,84 (.).30 ,% 7~3 21 Pi 2~7.].2 0 33 N 78 25 ~': 2525.2{ 0~27 h V7 43 E 2100.01 3.26 r,, 7u 2~ [,; 27.~I.85 0.28 N '16 lB E 2863,00 U 49 {.4 76 0 F', 2%;44.20 0130 N 75 48 E ~02b.47 0.15 N 75 37 E ~ 75 29 ~.; 3187.0(> N 75 18 E 3267.02 N 74 49 E 3345,39 N 74 23 E 341q.31 N 73 54 E 3488,59 N 'l] 29 E 3553.40 N '/3 41 £ 3613,6U N 73 2...2 ~3 3669.7() ~ 73 8 E 3721.3~, 0,33 i},13 o, 2.:{ 1,55 1.bh 1,97 1.43 1..t5 2.14 1 , 41 1,11 1..46 1.84 O.O0 0,00 0,00 504 17 N 2207,80 E 2264 522:73 N 2294.29 E 2353 540,~9 N 23~1 02 ~; 2441 55,,51 N 2467~58 E 2530 576,.{6 1~1 2554,01 E 2618 594,13 N 2639.29 E 2705 b~2,86 N 2719 07 E 2787 63~.98 m 2798:03 F; 2868 o51,38 N 2876,96 E 2949 671,24 N 2955.82 E 303~ '~ 15 6)1 , 711.3V, 731.50 llB,O0 PT 3034 21 E 311t,93 N 77 10 E 3112~3B E 3192,64 N 77 7 E 3189,B6 E, 3272,66 N 77 5 E 61.9.1 .q6 4918.0(} '48()¢,.0{) ~8 58 6250.48 bO 18,,.)0 ,~9,')0. O0 3~J 53 6378.5q 5118,00 ~00o.00 38 25 6505.65 5218.00 510o.0o 3'1 2H 6~30,02 531B.00 5200.0() 35 ~3 6751,68 541. 8,0o 5300.0b 31 52 6870,85 5518,00 5400.00 32 2 6987,61 5618,00 55~(),00 30 6 7102,24 5718,00 560n.00 2N 13 7214,80' 5818,00 5700.ho 2~ 28 7325,91 5916,0u 580o.n0 25 +9 7436.92 60.iN.O0 . 59,.)0.(~n 24 59 7546.51 611.~.00 6000.',)u 23 24 7654,90 6218,00 6100,00 22 19 7763.0~ 031~.0() 020O.0O 22 19 7810,00 6361,48 6243.4{'~ 22 1q 751,73 N 3265,60 k 3351 00 N 77 2 E 77].36 N 3336.87 £ 3424 86 N 76 59 E 79U,2,~ N ]403,53 E 3494 07 80%{.42 N 3465,74 E 3558 78 N 7~ 52 E 826.38 N 3523.58 E 3618 96 N 76 48 E 841 20 N 3577,32 E 3674 89 N 76 46 E 856:0'/ N 3626.79 E 3726 46 N 76 43 E 870,10 l.l ]673,15 f. 3774,'80 N 76 40 E 890 43 h 3'i62 [:,: 3867 9 N-76 5 9O7 H4 ~ 3802 E 3909 4 N 76 4 E 919,0~ h 3~,42,07 E 3950,47 N 76 32 g 923,94 N 3859,25 E 3968.31 N 76 32 ARCO A [.,A,S K A ~, 1L-H KUPARUK NORTH ,SI, OP}!',, AbASKA ti A$t< tIPPER BASE [,(.)w~:R ~AND P t~ 't D TOTAl, DEPTit ((.)tPU /k'l'l;f')r,( f)A'I'E: 5-D. CT-H4 PAGE 6 l)A'ti.: ()F 81JRVI<Y: 16..$EP-B4 K~';b[,,Y hOSt,~JLi,~G E. LEVA'tlONI 118,00 Mi<A~!,I Ri:ir) PEP'I:H L'; U R FA C t..: bOCA~I'ON TVF) R EC. TAI~GI.) [,AR ,I~OORDINA TE$ S i) B - S ii; A ,~'. ¢, & :'~ .... 867,36 N 3664 04 E 8'74 34 N ""36 , .;7 44 E ARCO A L, ASKA, lb-8 KIIPARUK NORTH ,SI`OPE~, A6ASKA MARKER T(.~P I. JPP[!:I{ SAND BASF; t~PPER 7(]P [,U :*~ E I',~ BASE LOWER SAN[) P B'l D TOTAl, DEPTH C(JMPII'PAT.£1)H I')ATE :' **~********~ 51 k AT [Gi,~APri l(I. MEASIIRI,iD b t (. I "84 PAGE 7 ' DATE OF' 5UI~VE¥; 16,,,5EP-84 K£1.~.i.~Y t~,i...15HING ELEVATION: 118,00 FT ENGINEER: ~AtJMEIS'I'ER ["'ROM [,IRIGIa= 224' FSi,, T VI.,) S t.j h-,5,E A 5898 25 5948~65 h046.31. 6154,14 6257, 6361.48 5780.25 5830.65 5928 31 6036:34 6~39,87 624~.48 SURFACE bOCATION AT RIOE, ECTANGUhAR ' 807i36 NI ~i'~664'04~7 E 874 34 N ~:,,,'"'i!.368;7644 E 8~7 52 N 3731,62 g 900 66 'N . 77,25 E 912 3i N 38~8,32 g 923:94 N :3859,25 E FINAL WELD [,OCA'['I[)N TRUE MEASIIRED VI~:RT.[ CAi DEPTIi DkPTH 781~,00 ~301 n T T D: $IIP.-SEA VERTICAl,, P E P T ti 6243,48 SCHLUMBEROER ARCO ALASKA. INC. KUPARUK NORTH SLOPE. ALASKA SEPTEMBER 19, 1984 TVW PLOT FROM OCT DATA JOB REFERENCE 89S32 SN WELL' 1L-8 SURFACE LOCATION- 1L-8 (224' FSL, 216' FWL, S29, T11N, RIOE, UM VERTICAL PROJECTION -4ooo -3ooo -mmo -~ooo o o ,ooo2000 3000 4000 ~.:`..~...~.~}..:.~.~..~i...`~-x-~"~-F~..~-~.+~-~.f.`~.~.~.~.~i~.~.~u~";~.~..~.~.~.~.;.~.1L:'''';'4-'-;''J'''~''': ....... :'--J": ....... ~ ........ 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' ~ .' ........... :::::::::::::::::::::::::::::::::::::::::::::::::::::: .... ....... ....... ......... ;...; ......... ?-.:..-i ........ ; ........... ..................... · .... ?'"t ....... ?'"?'"?"'~'"! .......... ? ........... ~ ............... ~ .................. ~ ................... ~ ................ +-.-~ ............. iiii!i!i!ili!i !ii!!!!i!iii!!!i!i!ii :. i!iiiiiiiiiii!!!i!!iiiiii!!i!i!ti!ii!iiiiiiii!! iiiiiiiii ii ::::::::::::::::::::::::::::::::::: ========================================================================== ....... ........'''i''-'i'''!'''-i''' ': ' :" 18 SuggeSted form to be inserted in each "Active" well folder to d~.eck for timely ccmpliance wJ.~h our' regulations. ' "Operator) We~l Na~ ahd Number and Materials to be received by: /~~ Reports · Date .Required Date Received Rem. arks --. , .Ccmpletion Report Yes ·~Well . History. Yes / / -.. _S~ples /¢/~ '~" P/ ' ' D/¥- _-- Core Chips -' · .,Yd ~-. ------- d Core Description /'~F'J' ~"t~- · . · . Registered Survey Plat y~ ~--' /?--~ O< . Inclination Survey /~ _Directional Survey yc3_~/ / / _~_y~F?/_,¢.e,~ ~~ Drill Stem Test Reports ~CddctiOn Test ~ F~ .~* ~--~ ARCO Alaska ..... Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 23, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas ConservatiOn Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Monthly Reports Dear Mr. Chatterton- Enclosed are the Monthly State Reports for the following wells' 2G-9 1L-8 2D-6 2B-16 2G-10 1L-4 2D-5 2B-15 2G-11 1L-3 2D-4 2B-14 2G-12 1L-2 2B-13 2G-13 Sincerely, Area Drilling Engineer JBK/SH/tw. HILL/01 Enclosures RECEIVED NOV 0 5 l~J Alas~.,~ 0~ & Gas Cons. Commlsslor~ Anchorage ARCO Alaska. Inc. is a Subsidiary of AllanticRichiieldCompany .... STATE OF ALASKA ALASKa, JIL AND GAS CONSERVATION C~,MMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~ X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-150 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21175 4. Location of Well atsurface 226' FSL, 214' FWL, Seco29, T11N, R10E, UM 5. Eievation in feet (indicate KB, DF, etc.) 117' RKB, Pad 87' 6. Lease Designation and Serial No. ADL 25659 ALK 2585 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1L-8 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of September , 19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0000 hfs, 9/29/84. Drld 12-1/4" hole to 2420'. csg. Drld 8-1/2" hole to 7810'TD as of 8/30/84. Ran logs. Circ tstd 7" csg. Secured well and RR @ 2400 hfs, 9/6/84. Ran, cmtd & tstd 9-5/8" hole clean. Ran, cmtd & 13. Casing or liner ru.n and quantities of cement, results of pressure tests 9-5/8", 36#, J-55, HF-ERW BTC csg w/shoe ~ 2398'. Cmtd w/855 sxs AS II I "G" cmt. 7" 26# J-55 HF-ERW BTC csg w/shoe @ 7779' Cmtd w/775 sxs Class "G" + 250 sxs Class 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/SP/GR/Cal/FDC/CNL f/7788' - 2400' 6. DST data, perforating data, shows of H2S, miscellaneous data c, ED N/A NOV 0 5 Alaska Oil & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge· SIGNED TITLE Are~_ Dr~ ! ! ~ ng Eng~ neet DATE NOTE-R on i is requ ed for each calendar month, regardless of the status of operations, and must be f~Jed/in duplicate with the Alaska Oil and Ga~ Conservatid~i Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 ~ I I I /MI~3 1 Submit in duplicate ARCO Alaska, in,.. Posl office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 29, 1984 Mr. C. V. Chatterton State of Alaska O11 and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached in duplicate are subsequent notices on the following wells at the Kuparuk River Field' Well Action Date Performed 1F-4 Fracture 9 / 1 8 / 84 1F-7 Fracture 9/21 /84 1L-1 Fracture 1 0/23 / 84 .~1~8~ Fracture 1 0 / 1 6 / 84 1Y-2 Fracture 10/9/84 1Y-2 Acidi ze 10/22/84 1Y-3 Fracture 1 0/7/84 1Y-5 Fracture 1 0/4/84 1Y-1 4 Fracture 1 0/6/84 2C-4 Perforate 1 0 / 1 6 / 84 If you have any questions, please call me at 263-4253. M.ike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) RECEIVED OCl'2 9 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E)I( OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-150 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21175 9. Unit or Lease Name KUPARUK RIVER UNIT 4. Location of Well SURFACE LOCATION' 226' FSL, 214' FWL, SEC. 29, T11N, R10E, UM BOTTOM HOLE LOCATION' 1385' FSL, 1100' FEL, SEC. 29, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 117' (RKB) I ADL 25659, ALK 2585 12. 10. Well Number 1L-8 1 1. Field and Pool KUPARUK RIVER F! ELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation ~ Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On October 16, 1984, the "A" sands of Kuparuk well 1L-8 were hydraulically fractured and propped to improve production. The treatment consisted of 310 BBLS of gelled ater as pad and carrying fluid and 18,900 LBS of 12/20 sand as proppant. The flush consisted of 30 BBLS of gelled water and 38 BBLS of gelled diesel. Prior to pumping, equipment and lines were tested to 5000 psi. RECEIVED OCT 2 9 :t9t 4 Alaska 0it & Gas Cons. Commission Anchorage The space below for Commission use 10/12/84 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 12, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are our notices of intention to fracture Kuparuk Field wells 1L-1 and 1L-8. If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) AlaSKa 0il & Gas Cons. (;0mt~issi0n Anchorage Alaska. Inc. is a Subsidiary o! AtlanlicRichlieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 226' T11N, R10E, UM FSL, 214' FWL, SEC. 29, BOTTOM HOLE LOCATION. 1385' FSL, 1100' FEL, SEC. 29, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 117' (RKB) I ADL 25659, ALK 12. 7. Permit No. 84-150 8. APl Number 50- 029-21175 9. Unit or Lease Name KUPARUK RIVER UN IT 10. Well Number 1L-8 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL 2585 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT 'REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate I~ Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" sand in Kuparuk well 1L-8 be hydraulically fractured and propped to improve production. The treatment uses gelled water as the pad and carrying fluid and 12/20 sand as the proppant. Gelled diesel will be used as a flush. Lines and equipment will be pressure tested to 5000 psi prior to starting job. Pre-post frac logs are included in the treatment program. Fluid- Gel led Water 250 BBLS Gel led Diesel 35 BBLS Proppant- 12/20 Sand 19,000 LBS RECEIVED ANT I C ! PATED START DATE- OCT 1 October 16, 1984 -,~Ul~~t'.', -,: ~.. ,,. ..... , Alaska Oil & Gas Cons, 6ommiss WOrk'~[epb~t~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. //~,¢.~JJ~ KUPARUK Signed _ _ , -, ~ Title OPERATIONS COORDINATOR The space below for Commission use Date 10/12/84 Conditions of Approval, if any: Approved by. 81' LIPIIII[ C. SMITfl z~-pproved Copy _!a -/,¢ -¢ By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~r.'c:'.,o:~9-. A~aska 9c~510 Telephone 907 277 5637 Date: 10/03/84 Transmittal No: 4743 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 - ; mitted herewith are the following items. Please acknowledge receipt eturn one signed copy of this transmittal. Schlumberger Tapes RFT 1169520 9/07/84 -"--OM-'---T"- . 9/07/84 " 2764 - 6866.5 RFT ~/69503 _- 8/28/8'4 "'-- 3~Z02~-'6~86 7-- OH fi69_)22 B/08~4 " 3344 - 8621 ~' OH 1fl69517 9/04/84 " 2383.5-7825 OH ~[6952~ 9/D7/84 " 4067.5-9007 - 6683 - 6529 2G-10 / 2D-7 J !! 2B-16 1L-8 / 2D-6 / Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BP kE Chevron DISTRIBUTION D&M Drilling Geology Mobil W.Y. Pasher G. Phillips Phillips Oil J.J. Rathmell .,".State' of Alaska:: ,.~-. .... _..:,, .... Sohio Union NSK Operations R&D Well Files ARCO Alaska, Ir~ Post Office ,~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 14, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plats - 1L Pad Wells 1-8, 9-16 Dear Elaine' Enclosed are as-built location plats for the subject wells. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU1/L36 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfietdCompan¥ SEC 30 SEC 34 a6 ~7 SCALE: 1": 300" BASIS OF ELEVATION IS 1L MIDDLE & 1L SOUTH PER LHD & ASSOCIATES. BASIS OF LOCATION IS 1L NORTH 81 flLSOUTH PER LHD 8~ ASSOCIATES Z 5 ~- ' '- ':--x 2 8 · ,~-~ ,"- ~ D.S. ¢ · ,; -~ LOCATION SCALE ~ -i : I MILE ,/ DRIL 'SITE 1.L CONDUCTORS AS .BUILT LOCATIONS _-----: _:::__-T.::__- :%: :. - _: ~__~..~-~.:__ _ : _:. _;_~.: -- -:~.-_ ~.__ :-._ :--:-' .... .-- ::__~._-_- LOCATED IN SEC. 30, TIIN R ',OE,UMIAT MER. C/ELL ~ Y:D,q,49,~90.896 LAT 7C°!6'196499'' X: 53'q,q16.785 LONG. 149°4C'37 763" 144 FE_ £23 F3L E~ B5 71' L.,S.81 8' WELL ¥: ~.,949,Z. 5C 868 LAT. 70°!6'2C..c398'' X: 539,916./G8 LONG. 14~°40'3~ 769" 144 FE~ 285 FSL EL 85.4c' 0.G.81.5' WELL Y= 5,949,31C 448 LAT 70°16'Z0 830?'" X: 539,q~5.572 LC NS.149°4C"57.78C" 1~4 FE~ 3.~.} F'~L E,.85.6--)' O.S 81 NELL Y-'- 5,q4q,~TO.889 LAT. 7C°16'21 42_0/" X:539,'~14.q56 LONG. 149°40'57 ~89" 144 FEL 405 FSL E~.85.91 0 G 81.1' LOSATED INSEC2.9, TiIN RICE, UMI~T MER. WE~_L 5 Y: 5,94q,3-~4 468 LAT. 7C°i6'/I 4367" X:540,275 Oil LONG. 149c40''7 ~(5" .-16 FWL 4C4 ~e_ EL.SD 45 0.S.8~.~' WEL_ 6 'r: 5,q49,3, ~ 4.546 LAT. 70° 16' kG.8473'' X:540,275 607 Lc'NG !49c4c'~7.296 216 FWL 344FSL EL 88.47 O.G.8r-.O WELL 7 Y: ,243,Z¢4~ 58=,~ LAT 7c~°.. 16';'0.3~74'',., X:C4C,,Z 76.,- (. 3 LONG. 14q°4C.'''7 289" 216, FWL 284 FS_ E-.88.67 0 O 8" .2' WELt_ 8 Y:5.,9'+ 4,194 524 LAr. 7F c X:D4C,L76 '?JI LC ?_16 FWL 2¢L~.FS_ E_.38 ( ~ ( '3 ~ 4' ~.r_R~SY CERT;¢Y T'qL~ I ¢,M PROPERLY Ri:GISTERED & L:CE:,SE? TO PPACTiCF LAND SUR'vF¥.%G iN THE STATE OF ALA:,~A I~ THAT THiS PL~T ~FFRFSENT~ A 3URVEY MADE uNDER MY ~:INECT SUPErtoS:ON ~ T~AT Au~ DETAILS ARE CC;RRECT AS OF 8~/84 WELLS .-4, 7..-'~5/e4 A.E: LS 5-8 ARCO"Al~sko, Inc. DRILL SITE I.L CONDUCTOR AS-BUILT LOCATIONS WELLS I-8 1 C:]te. AUGUST ~984 ISC31~: AS SH~JWN Drquqhts.q'or.~ydr~ey !Dwg.no.: NSK 9.05.112d ~ i i ~ i MEMORANDUM TO: THRU: FROM: State of Alaska ~SKA OIL Ai~D GAS CONSERVATION CO~.R. IISSION C.V./C~~e~to~ DATE: September 10, 1984 ~" - & ,~: / FILE NO: D lI 27 I~ .-'~;~'-:/~ ' · Lonnie C. Smith Co, is sioner Ben LeNo~m ~~ ~~ SUBOECT: Petrote~ Inspector Witness BOPE Tests on ARCO's Kuparuk 1L-8, Sec. 29, TllN,R10E,UM, Kuparuk River Unit. Thursday, August 30, 1984: I departed my home at 6:00 am for a 6:~=-~m"sh°w~P'and 7':30 ~ departure via Alaska Airlines, Flt. #55 for Deadhorse, arriving at 9:10 am. Weather: +30°F, Fair, no wind. BOPE tests on Kuparuk 1L-8 began at 6:15 pm and were completed at 7-30. pm. BOPE inspection report is attached. Meter proving at ARCO's Kuparuk CPF-1 began at 9:00 pm . . . Friday, August 31, 1984: . . . and was completed at 1:00 am, the ~ubj ect' 0'f ~a~ sepa~ra'~ ~eport. Saturday_,__ September 1, 1984: Standing by on Kuparuk 2D-6. Sunday, September 2, 1984: B~OPE tests on ARCO's Kuparuk 2D-6 and ~i6 Were ~bmpleted, ~u~jecus of separate reports. .eptember 3, .1984: BOPE Jests on ARCO's Kuparuk 2G-10 were · the subjeC~ of a separate report. Tuesdat~,. Se~ptember 4, 1984: I departed Deadhorse via Alaska AirllneS~~ Flt~-~54 ~t-~'i'O~$0 am arriving in Anchorage at 12:30 pm and at my home at 1:00 pm. In summary, ~ witnessed successful BOPE test on ARCO's Kuparuk 1L-8. Attachment 02-00IA(Rev. 10/79) O~ #4 lSA .... STATE OF ALASKA ALASKA OIL & ~AS ODNSERVATION Cflv~[[SSION B.O.P.E. Inspection Report Operator Well Location: Sec Dril linq Contractor Representative Permit ~" ~.~Casing Set 'Repre~ntat ive Location, Genera] Wel 1- Sign C~neral Housekeeping ~j~/~, Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves.~ · H.C.R. Valve Kill Line Valves Check Valve TeSt Pressure ACCUMUIATOR SYSTEM Full Charge Pressure ~ Pressure After Closure .. Pump incr. clos. pres. 200 psig. Full Charge Pressure Attained: psig psig rain ;~O sec. min,.9 ~sec. Controls: Master ~fP/~ Remote ~/~ Blinds switch cover~--~-- Kelly and Floor Safety Valves · Upper Kelly. Test Pressure Lower Kelly.. Test Pressure Bal 1 Type . Test Pressure Inside BOP Test Presmare Choke Manifold Test Pressure No. Valves__ /~D No. flanges .--~ O Adjustable Chokes ~ Hydrauically operated choke Test Results: Failures.. / Test Time'. /'~/~'. hrs. Repair or Replacement of failed eqUipn~nt to be made within days and Inspector/ccmmission office notified. Distribution orig. - AO&G~C cc - Operator cc - Supervisor Inspector August 23, 1984 Mr. J. B. Kewin Area Drilling Engineer A~RCO Alaska, Inc, P. O. Box !00360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 1L-8 ARCO Alaska, Inc. Permit ~o. 84-150 Sur. Loc. 226'FSL, 214'~L, Sec. 29m TllN, R10E, IN. Btmhole Loc. 1385'FSL, lt00'FEL. Sec. 29, TllN, R10E, U~. Dear Mr. Kew~n. Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the re~alattons promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the- Federal Water Pollution Control Act, as amended. Prior to commencing operations you ma~ be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Jeffrey B. Kewin Kuparuk River Unit 1L-8 August 23, ].984 equipment so that a representative of the Commission may be p~esent to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. 'tn the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very tru!_~v yours, : ~' i/i ~ ~ ?I~.._..~ ~ -~ C. V. ~natterton ~ai~ano~_- = Alaska Oil and Gas Conservation Co~ission BY O~DER OF ~E COMMISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of F~virop~ental Conservation w/o encl. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 14, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1L-8 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 1L-8, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat ° A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment Since we estimate spudding this well on August 26, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, JBK/JG/tw GRU8/L93 Attachmehts ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED AUG 2 0 ]984 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION CO,v, MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. 2. Name of operator DRILL [~X REDRILL [] DEEPEN [] EXPLORATORY [] SERVICE [] STRATIGRAPH lC lb. Type of well DEVELOPMENT OIL I~X DEVELOPMENT GAS [] SINGLE ZONE [] MULTIPLE ZeN E}(~ ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 226' FSL, 214' FWL, Sec.29, T11N, R10E, UM At top of proposed producing interval 1293' FSL, 1414' FEL, Sec. 29, T11N, R10E, UH At total depth 1385' FSL, 1100' FEL, Sec. 29, T11N, R10E, UN 5. Elevation in feet (indicate KB, DF etc.) RKB 117', PAD 87' 6. Lease designation and serial no. ADL 25659 ALK 2585 n~:r~ 9. Unit or lease name Kuparuk River U 10. Well number A ~ 1L-8 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 1098' @ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7849' MD, 6331' TVD feet 2490 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICKOFF POINT 1000 feet. MAXIMUM HOLEANGLE 42 oI (see20AAC25.035'(c) (2) 15. Distance to nearest drilling or completed 1L-7 well 58' ¢ 1249'TVD feet 18. Approximate spud date 08/26/84 2712 3043 psig@ 80°F Surface psig@ 6162 ft. TD (TVD) SIZE i Hole Casing 24" 16" I12-1/4" 9-5/8" ~8-1/2" 7" Weight 62.5# 36.0# Proposed Casing, CASING AND LINER Grade H-40 J-55 HF-ERW 26.0# J-55 HF-ERW .iner and Cementing Program SETTING DEPTH Coupling 22. Describe proposed program: Length MD 80' 29' I 29' 2369' 29' I 29' 7821 ' TOP TVD I 28' I 28' MD BOTTOM TVD 109~ 109' 2398'I 2277' I 7849'1 6331' I I QUANTITY OF CEMENT (includestagedata) ± 200 cf 850 sx AS Ill & 250 sx Class G ±400sxClassG extended & ±375 sx Class G blend ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7849' MD (6331' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set at approximately 2398' MD(2277' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2712 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed) by the workover rig,with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) -23.' herebycer~SiGNED////~///~~'thatthef°reg°ingistrueandc°rrect to the best of my TITLE knowledge Area Drilling Eng, neer DATE The space~O'~w ¢~or~issi~-"6n ~se CONDITIONS OF APPROVAL Samples required Mud log required I Directional Survey required ' I APl number ~YES ~O ~YES ~NO ~ ~ES ~NO ] 50_0~'~// Permit number ~~~Appr°val~~date SEE COVER LETTER FOR OTHER REQUIREMENTS // .*T. Form ~ 0~01 ~3 Submit in triplicate PERMIT TO DRILL 1L-8 installed and tested upon completion of the job. 1L-8 will be 58' away from 1L-7 at 1249'TVD. There are no other close wellbores or crossings anywhere downhole. Top of cement for the production string will be placed at 2927'MD, approximately 500'MD above the top of the West Sak Sands. If the Ugnu is hydrocarbon bearing, cement will be brought 500' above it. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED AUG 2 01986 Alaska 0il & Gas Cons. Commission Anchora.g~ Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" X 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/10" side outlets. 5. 10" ball valves, hydraulically actuated, w/10" lines to reserve pit. Valves to open automatically upon closure of annular preventer. $. 20" 2000 psi annular preventer. ?. 20" bell nipple. 3 Maintenance & Ooeration 1. Upon initial installation close annular preventer and verify ~hat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. DR not shut in well under any circumstances. 16" Conductor RECEIVED I' ~ULAI~ PREYEI~TER · PIPE BLIND ' RAI~ 4 DIAGRAM ~1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. i1" - 3000 psi casing head 3. 11' - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool $. 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams g. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACIT7 TEST '1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NAOC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MAJtIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEN]. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREYEN~R AND lj'j)ktVJ~S L)ID$~ DON'~T TI~ST AGAINST CLOSED CHOKES 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD 'FOR 10. MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR lO MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 B. ~,~'PI~SSb~E DOWN$'I~REAM 01; CHOKE ISOLATION ~AL¥]~S~. TO ZERO PSI TO TEST VALVES. TEST-REKAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9.OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES' ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. RECEIVED AUG 2 0 ..... n;~ ~ R~s Corls. O0~iSS~Oll thru'8)' 3 (21 thru <6) Add: .~ ~-~-f~ defined: Ol a ' po ,,,,,,..,,,...,.,,.,..,,..,. :]',"il i:sl w~ii ce rtY.'. .'::',.~,,.... . "ated proper distan .from prope line .................. ii. Is 'i proper distance fr m other wells · · '?:' : 0 ' undedicat'ed.,acreage available in this pool ............. i' ddviated,and is Well bore'ptat'included' . .~A 8. Can. per'it..:be a~pr0ved before'ten-day wait ............. · __ . . 9 .'Does operat' have ' ' _... or a Is a conservation' order needed ' ®eeee®eeee®eeeeeeeeee®ee®eeeeeeee®eeee Is administrative approval needed · eeeeeeleeeel~e~eeee~eeee~eeeeeeeeee 12. 13. 14. 15. 16. 17. i8. 19. 20. Is conduCtor'string provided ..................... ,~,,J,,~ Is enoUgh cement used to circulate o;'co;~;;;~;';;~ ;J;~;;e . Will cement, tie in surface and intermediate or production strings ... ~-~ff Will cement cover all known productive horizons ..................... #~'ff Will.surface casing protect fresh water zones ...~.., ..... ~ . Will all casing give adequate safety in collapse, tension ;nd burst.. IS this well to be kicked off from an existing wellbore ............. ~ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate.well bore separation proposed ........................... ~ ' 21. 22. 23. 24. Is a diverter system required ........................................ Are.necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~/gr~ psig Does the choke manifold comply w/API RP-53 (Feb.78) .................. 25. Additional requirements ............................................. ~J~ . Additional. Remarks:~/~_~i //.-2~~ ~4)//.J. ~ g~' ?:~d/~ /A,'7 /=R~/W 5u/~F~f ~ /~/ TVD- Cl-osF---sT 0 i--.3 ~Z HO r.n~ Geology: En~ineerin~: HWK ii- LCS ~,W ~ rev: 12/08/83 6. CKLT INITIAL GEO. UNTT ON/OFF 'POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIXl No special'effort has been made to chronologically organize this category of information. I i:',,i C, 00 0 0 0 0 0 0 0 0 00 O 0 () 000 0 0 0 0 0 0 000 O00 000 0 O0 0 0 0 o oo 000 o 0 0 01.6 006 0O8 004 004 002 012 006 065 065 065 065 065 065 065 2 3 9 2 I~' T . ~'a 53 F' a 53 ~ :.] ?',:~ 'J' F Y E: ~ 0 C .K S * * [) A 7 A () E; P T ,..,ap ~.4 p H i DEPT 7 ~325, t..t 0,9 U ,. 3 9, .3 '7 i!3 0 2.2383 5 ..1.. 25 '7 7 ii (.! 0, ()0 0 U SF b U '!',.t C ~J 1., $ ,[ Z E 1 1 4 4 R. Ef>R COi:)E ~6 73 2,,4 i 2 l, IbD 10'3,. 2500 GR 0,25 .] 9 !.~I R A, 'r 1606.000 r,..,, F'C.,~..'" [ SI 0 1 6O ,lin I 0 4 4 4, 4 4 4 4. 4 4 4.., 4 2000 0000 ~(':) 3: 2Soo 3,9668 373,0()0C, 92,09 09'(/)7 50 0 304:7 0996 N P H I 4 ,,::,,, I, 42 t:,, ;',.~ C b,! [, N P H 1' !54. ,3 A b 7 .... 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"'999' ,2.500 -999,250t.i 168. 2500 - 999,2500 .-999,250 ~'~ 7,1172 -999. 2500 -999.2500 -999.25O0 2.3242 -999.25O0 -999.25u0 .,999. 2500 2 . 66q9 ,-999.2 '999. 2500 '999,2500 2.4297 -999. 250O -999,2500 -999. 2500 2,8164 -999.2500 -999.2500 -999.2500 2.691. q -999.25()0 -999.2500 -999.2500 I b H C A L .1 R r',~ R A CAb£ C A b I R N R A I: L.., P: CAb I I D M C A ,b i 1 l.i M CAbl R N R A CALl: R io R h I 1.,, N R ;~ R A C A b 1 RNR~ C a I., I 3,4238 9,1,719 -999 · 2500 .s, 2617 i 0,7 109 -999. 250,0 3,50P9 9,1,'119' -999. 250O I. "5qd 9 -999, :2500 I, bOOb 10 · 164.1 -999. 250() 7, B 86 '7 -999. 2500 - 999 · 250 ('l 3438 2,,. ..... ) -999.250( -999,2500 2.6836 -999,250(! -999,2500 2,3945 -999.25O0 -999,2500 2.7813 -999,2500 -999.2500 2,'124b '999.2500 -999,2'"C ~ P [,i I' - 999.2 :'.5, {~ 0 ?4 C hl L - 999 o 250 (.} f,. R i ii -q99. 250 (5 le C,N L, 2.1% 2:3 l: h D 11. 2. ()~,~2b Ga · ..9 q 9. 2500 NRAT -999,251~0 FCNL 2. ~ 75 tl I .[., D ~6. 9375 G~{ -9q9. :2500 - 9 g 9.250 u l.' 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R :4 R A C A L I R,"~i RA 2.6816 -999,~50C -999,25'00 2. 3105 q q ~:,l 2500 -999,2500 3 -999,, 2500 -999,2500 '999.2500 -999.2500 2.1875 '999' .. .250 o 3, I 09 4 -999.2500 99 q - ~ ~ 0 n :~99,25Oo 99. 2500 .J, 2500 -999. 250() -999.25OO 6.1719 -999,2500 -999,250() 2.7559 -999,250{) -999 . 2500 2. 2670 -999,2500 -999. 2500 :P iP {HOG )EPT :P ~ p H J: )EPT · l P )EPT 3P '~ P t"~ I S P ',IPH 1 DEPT SP L) E P 'I ~P NpH i OEP'J' SP 9 S P 39,209 ;'t i',~: C i~ 3600,0 ',.'~ 0 n S F b 2., 23 ~.) 5 9 i.%' l..~ (3 .36, {, 2 i i '.~} C ;! il, jSO0 0000 $~.'I.,U 2.5ofi5 I L.,U 93,937 '5 g R tl), u 1 C} '7 r,~ rl h q 'J. 9 f} 8, () u (") ;'~' F C ~"4 !. 8. g359 55.93 75 G -, 0,0 01t 0 ,x'R A T 23 ! 0. O000 F'Ci,iL 5,31.25 I0b !31.. 625,9 GR 0.0298 i,4 b', A 'I' !,890.00('~0 FCI'~ U 3 b, ii. 562 I ,~, .39.8 473 '? G a I 5 0 4; _c~9 :25(>0 250{} -999 2~' 3,5139.t. -99q,2500 - 999.2 50 0 3.9531 m ~".'. :, ' 570,5 f)00 1 10,750o 3,72bu 4,. 222 'I 6,9 3 '7 a 3,6816 6 , 5 000 3,32,4 '2 93.9 375 a98.75o0 6.5,93'7b 3. 4297 5"" . 6 2539 81:6'250 3,0484 465.7500 I 0.00 () 0 84,5000 3,3477 553.5()00 25 5938 391~437 R ;'~i R A C A b 1 RI'. RA. CAI, I I L M C A L 1 C A L, 1 I b a C a L, .I1 R b.~ R A C A L, I R P,,;t R .A i la M (:ALI C A b i C A L I ! - 9 99.2 5 ill O -999.2.500 3,3555 -999 '250~ '999' ,2500 3.6 7 7 7 13, ~,09 3. ii 1 3 11..:~ 0 7 , .,t.9375 3.~359 12.4375 4.1.523 2,962 9 13.0859 3. 8242 9.3750 10.3:L25 4. 0625 5.7031 12'1562 4,0547 8.6953 3.5469 29,140~ :L1.,3954 :'~ l!l iii iI:-I i[4 [:.t ~ R f.t 06 )EPT ~ P .~p ) E P I; ~' p H T SP ~ h 0 b "IP .Fl '[ I) K p T SP SP R H 0 b aPH I SP NPhI D E P a H 0 ~3 D E P T' - 1, 12.7500 G 2 ,, ,,1 ;,; 55 i.; k' H 0 4 4. f'~ 91 8 ,',i C -10 '.)5O -12 5 ,. '75 (, 0 G ~.;: ¢> fi 7 ./4.~' i) ,~,:' H z, ,~ .... 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(,'. 0703 ], 9082 12,'7344 10,6953 4.01.56 '8.35,!.6 i I, 0t~25 4', 4844. 1b,8203 11,5703 12. ~ 59 q 3.8 '7 3 0 4,4 4, '7 !.5 0 o 2 0 0 o. 0 0 0 0