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181-065
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1B-04 KUPARUK RIV UNIT 1B-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 1B-04 50-029-20595-00-00 181-065-0 W SPT 6180 1810650 1545 2438 2439 2432 2435 83 136 139 139 4YRTST P Guy Cook 6/13/2025 Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1B-04 Inspection Date: Tubing OA Packer Depth 630 1900 1870 1860IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250612101521 BBL Pumped:1 BBL Returned:0.9 Tuesday, July 22, 2025 Page 1 of 1 Originated: Delivered to:8-Jul-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1B-04 50-029-20595-00 910151309 Kuparuk River Plug Setting Record Field- Final 30-Jun-25 0 12 1B-05 50-029-20237-00 910106098 Kuparuk River Multi Finger Caliper Field & Processed 19-Jun-25 0 13 1B-05 50-029-20237-00 910106098 Kuparuk River Plug Setting Record Field- Final 21-Jun-25 0 14 1B-11 50-029-20657-00 910151309 Kuparuk River Multi Finger Caliper Field & Processed 1-Jul-25 0 15 1B-11 50-029-20657-00 910149873 Kuparuk River Plug Setting Record Field- Final 1-Jul-25 0 16 1B-15A 50-029-22465-01 910106169 Kuparuk River Plug Setting Record Field- Final 20-Jun-25 0 17 1D-101 50-029-22988-00 910151308 Kuparuk River Packer Setting Record Field- Final 6-Jul-25 0 18 1H-103 50-029-23593-00 910082841 Kuparuk River Multi Finger Caliper Field & Processed 21-Jun-25 0 19 1L-24 50-029-22170-00 910151023 Kuparuk River Packer Setting Record Field- Final 28-Jun-25 0 110 2A-16 50-103-20042-00 910150862 Kuparuk River Plug Setting Record Field- Final 27-Jun-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:181-065177-001181-136204-256200-183218-003191-066185-147T40642T40643T40643T40644T40644T40645T40646T40647T40648T406497/9/202511B-0450-029-20595-00910151309Kuparuk RiverPlug Setting RecordField- Final30-Jun-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.07.09 09:29:07 -08'00' Originated: Delivered to:3-Jul-25Alaska Oil & Gas Conservation Commiss03Jul25-NR ! "# $$%$ !&$$'($)*%+ ($)*%,- .WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED3S-705 50-103-20915-00-00 225-047 Kuparuk River WL TTiX IBC FINAL FIELD 20-Jun-252K-23 50-103-20125-00-00 190-014 Kuparuk River WL Hex Plug FINAL FIELD 25-Jun-252L-304 50-103-20613-00-00 210-011 Kuparuk River WL Pressure-Temp Log FINAL FIELD 26-Jun-251B-04 50-029-20595-00-00 181-065 Kuparuk River WL IPROF FINAL FIELD 28-Jun-25Transmittal Receipt//////////////////////////////// 0///////////////////////////////// + ! 1 Please return via courier or sign/scan and email a copy to Schlumberger. " 2"3 +45 %TRANSMITTAL DATETRANSMITTAL #1 67 8 " ! - +" 8 # !(3 . 8 ) "3 8 # !9 3 : 8" +8 6 8 8 " 8 # !;" " 3 - 3 " 3 ""+ 3 + < +3!% T40638T40639T40640T406411B-0450-029-20595-00-00181-065Kuparuk RiverWLIPROFFINAL FIELD28-Jun-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.07.09 09:20:13 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, December 6, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1B-04 KUPARUK RIV UNIT 1B-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/06/2024 1B-04 50-029-20595-00-00 181-065-0 W SPT 6180 1810650 3000 2424 2415 2387 2355 220 388 392 390 INITAL P Sully Sullivan 10/7/2024 MIT IA post Rig work over tested to 3000 psi per Sundry #324-292 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1B-04 Inspection Date: Tubing OA Packer Depth 900 3320 3215 3200IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS241009140411 BBL Pumped:2.3 BBL Returned:2.1 Friday, December 6, 2024 Page 1 of 1 9 9 9 9 9 9 9 999 999 9 9 9 9 9 Sundry #324-292 James B. Regg Digitally signed by James B. Regg Date: 2024.12.06 11:27:24 -09'00' Originated: Delivered to:9-Jul-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1A-11 50-029-20685-00 909447215 Kuparuk River Radial Bond Record Field & Processed 3-Jul-24 0 1 2 1B-04 50-029-20595-00 909359143 Kuparuk River Plug Setting Record Field- Final 5-Jun-24 0 1 3 1C-24 50-029-23063-00 n/a Kuparuk River Plug Setting Record Field- Final 6-May-24 0 1 4 1C-157 50-029-23754-00 909345851 Kuparuk River Water Flow Record Field & Processed 25-May-24 0 1 5 1D-135 50-029-22816-00 n/a Kuparuk River Plug Setting Record Field- Final 25-May-24 0 1 6 1D-145 50-029-23526-00 909335380 Kuparuk River Jewelry Record Field- Final 14-May-24 0 1 7 1E-08A 50-029-20496-01 909539034 Kuparuk River Plug Setting Record Field- Final 1-Jun-24 0 1 8 1F-03A 50-029-20853-01 909382731 Kuparuk River Leak Detect Log Field- Final 18-Jun-24 0 1 9 1F-03A 50-029-20853-01 909424095 Kuparuk River Multi Finger Caliper Field & Processed 2-Jul-24 0 1 10 1G-04 50-029-20835-00 909359162 Kuparuk River Patch Setting Record Field- Final 11-Jun-24 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T39146 T39147 T39148 T39149 T39150 T38151 T39152 T39153 T39153 T39154 181-173 181-065 201-248 223-038 197-184 214-138 210-181 196-096 182-161 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.10 13:03:51 -08'00' 1B-04 50-029-20595-00 909359143 Kuparuk River Plug Setting Record Field- Final 5-Jun-24 0 1 181-06 T39147 Operations shutdownPull TubingFracture StimulatePlug PerforationsSusp Well Insp1. Operations Change Approved ProgramAlter CasingOther StimulatePerforateInstall WhipstockPerformed: Other: Replace TubingCoiled Tubing OpsRepair WellPerforate New PoolMod Artificial Lift ExploratoryDevelopment Service 6. API Number:Stratigraphic 8. Well Name and Number:7. Property Designation (Lease Number): 10. Field/Pool(s):9. Logs (List logs and submit electronic data per 20AAC25.071): 11. Present Well Condition Summary: measuredTotal Depth 8410'feet 1920'feet feet6865'true vertical 9224', 9346'feet measuredEffective Depth 7853'feet 7268', 7402', 7659'feet true vertical 6495'feet 6080', 6180', 6363'feet Measured depthPerforation depth True Vertical depth 3-1/2"Tubing (size, grade, measured and true vertical depth) 2-7/8" L-80 L-80 7385' 7697' 6167' 6389' Packers and SSSV (type, measured and true vertical depth)7268' 7402' 7659' 6080' 6180' 6363' 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: Kuparuk Oil Pool13b. Pools active after work: 15. Well Class after work: StratigraphicServiceExploratory DevelopmentDaily Report of Well Operations WDSPLGasOil16. Well Status after work:Copies of Logs and Surveys Run SPLUGSUSPGINJGSTORElectronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Authorized Title: 2675'2871' CollapseBurst 8336' Casing 6834'8363' 2842' 80'Conductor Surface Production 16" 10-3/4" 50' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 181-065 50-029-20595-00-00 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: ADL0025648 Kuparuk River Field/ Kuparuk Oil Pool KRU 1B-04 Plugs measuredJunk Length measured true vertical Packer Representative Daily Average Production or Injection Data Tubing PressureCasing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf MDSize 80' 324-292 Sr Res Eng:Sr Pet Geo:Sr Pet Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Blue Pack Max Packer: BAKER HB Retrievable Packer: BAKER WL SSSV: None Staff RWO/CTD Engineer 7550-7610', 7786-7802', 7812-7858' 6286-6329', 6450-6461', 6468-6498' Submit in PDF format to aogcc.permitting@alaska.govDue Within 30 days of OperationsForm 10-404 Revised 10/2022 Well Shut-In N/A Contact Name: James Ohlinger Contact Email:james.j.ohlinger@conocophillips.com Contact Phone: (907) 265-1102 By Grace Christianson at 2:31 pm, Sep 11, 2024 Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E= James.J.Ohlinger@cop.com Reason: I am the author of this document Location: Date: 2024.09.11 11:22:49-08'00' Foxit PDF Editor Version: 13.0.0 James J. Ohlinger Page 1/4 1B-04 Report Printed: 9/11/2024 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) 8/8/2024 00:00 8/8/2024 03:00 3.00 MIRU, MOVE RURD P Set herculite and double mats around well prep for spotting rig // Clean up around WSW-06 // Spot well equiment and hang tree in cellar 0.0 0.0 8/8/2024 03:00 8/8/2024 04:00 1.00 MIRU, MOVE RURD P Spot rig over well // level and safe out rig 0.0 0.0 8/8/2024 04:00 8/8/2024 06:00 2.00 MIRU, MOVE RURD P Spot cutting box, spot mud shack and set landings at bottom of stairs. 0.0 0.0 8/8/2024 06:00 8/8/2024 09:00 3.00 MIRU, MOVE RURD P Load 2-7/8" and 3-1/2" PT equipment. Toolhouse spotting OT,KT, HI-Line trailer in place, running hardline. Take on 8.6 ppg seawater to pits, build 35 BBL deepclean pill. Loading 3.5" DP in pipe shed. Rig Accept 9:00AM 0.0 0.0 8/8/2024 09:00 8/8/2024 10:30 1.50 MIRU, WELCTL RURD P RU circ maniflod and hoses to tubing and IA. Open SSSV. Take initial pressures: TBG 150 psi, IA 70 psi and OAn 0 psi. 0.0 0.0 8/8/2024 10:30 8/8/2024 11:30 1.00 MIRU, WELCTL SEQP P PT lines to kill tank 250/2500 psi good Test. 0.0 0.0 8/8/2024 11:30 8/8/2024 13:30 2.00 MIRU, WELCTL MPSP P Reverse down IA up tubing 35 BBL of 8.6 ppg @ 3.5 BPM / 841 psi losing fluid out hole between RBP set at 7423' and packer at 7402'. Perform a rolling test pumping 0.87 BPM at 1100 psi for 10 minutes. No leak in direction of flow observed past BPV. 0.0 0.0 8/8/2024 13:30 8/8/2024 14:00 0.50 MIRU, WELCTL OWFF P OWFF 30 minutes. NO Flow well static. 0.0 0.0 8/8/2024 14:00 8/8/2024 15:30 1.50 MIRU, WELCTL MPSP P Set BPV perform rolling test 1100 psi 0.0 0.0 8/8/2024 15:30 8/8/2024 18:30 3.00 MIRU, WELCTL NUND P Drain void and nipple down tree and tubing adapter 0.0 0.0 8/8/2024 18:30 8/8/2024 22:30 4.00 MIRU, WELCTL NUND P Nipple up BOPs // Stuck LDS // WH hand forgot to cap control line, nipple down adapter cap line nipple back up // Install riser and get RKBs 0.0 0.0 8/8/2024 22:30 8/9/2024 00:00 1.50 MIRU, WELCTL SVRG P Perform BWM 0.0 0.0 8/9/2024 00:00 8/9/2024 06:00 6.00 MIRU, WELCTL SVRG P Perform BWM, found damage to blind rams 0.0 0.0 8/9/2024 06:00 8/9/2024 07:30 1.50 MIRU, WELCTL RURD P Rig up to test BOPE, fill stack and lines. Purge air from lines. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/13/2024 Page 2/4 1B-04 Report Printed: 9/11/2024 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) 8/9/2024 07:30 8/9/2024 17:30 10.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular, UVBR's, LVBRs w/2-7/8" & 3 ½ test joints. 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 & 4 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=3000 PSI, after closure=1700 PSI, 200 PSI attained =23 sec, full recovery attained =120 sec. UVBR's= 5 sec, LVBRs= 5 sec. Annular= 21 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 Austin McLeod. 0.0 0.0 8/9/2024 17:30 8/9/2024 18:00 0.50 COMPZN, RPCOMP RURD P Rig down test equipment 0.0 0.0 8/9/2024 18:00 8/9/2024 19:00 1.00 COMPZN, RPCOMP MPSP P Pull BPV 0.0 0.0 8/9/2024 19:00 8/9/2024 19:30 0.50 COMPZN, RPCOMP RURD P Rig up floor and prep pipe shed for pulling 2.875" Completion 7,381.0 7,381.0 8/9/2024 19:30 8/9/2024 20:30 1.00 COMPZN, RPCOMP THGR P PJSM // Pick up Landing jt screw into hanger // Set down 10K BOLDS // Pull hanger to rig floor Pu Wt 90K // Rig up spooler and prep for laying down completion // 7,381.0 7,340.0 8/9/2024 20:30 8/10/2024 00:00 3.50 COMPZN, RPCOMP PULL P Pull 2.875" completion T/ 5800 7,340.0 5,800.0 8/10/2024 00:00 8/10/2024 06:00 6.00 COMPZN, RPCOMP PULL P Continue out of hole with completion // Lay down SSSV 34 bands recovered and all of control line // Continue out laying down 2.875" completion. Cut joint 20.77' 5,800.0 0.0 8/10/2024 06:00 8/10/2024 08:30 2.50 COMPZN, RPCOMP RURD P Clean rig floor and handling equipment. Offload 2-7/8" decompletion.Prep pipe shed to pick up drillpipe. Load Yellow Jacket BHA. Install wear ring. 0.0 0.0 8/10/2024 08:30 8/10/2024 09:30 1.00 COMPZN, RPCOMP BHAH P PU BHA #1: 6-1/8" x2-7/8" dress off shoe w/string mill. 0.0 47.6 8/10/2024 09:30 8/10/2024 16:30 7.00 COMPZN, RPCOMP PULD P RIH picking up drill pipe singles from pipe shed. SOW 53K at 1400' 1300' to 1400' is sticky with 5-7K bobbles up and down 47.6 7,381.0 8/10/2024 16:30 8/10/2024 17:00 0.50 COMPZN, RPCOMP WASH P Kelly up RIH T/ 7375' Pick up Pump 5 bpm // Top of stump 7375' dpm // Wash down to 7383' 7,381.0 7,383.0 8/10/2024 17:00 8/10/2024 18:00 1.00 COMPZN, RPCOMP CIRC P Circulate High Vis sweep around @ 3.5 bpm chase with seawater @ 5 bpm pump SxS 7,383.0 7,370.0 8/10/2024 18:00 8/10/2024 21:00 3.00 COMPZN, RPCOMP TRIP P TOOH to 30K string wt // ~ 3000' pipe in hole for hanging storm packer for well head work 7,370.0 2,800.0 8/10/2024 21:00 8/10/2024 22:00 1.00 COMPZN, RPCOMP MPSP P Pick up storm packer and set @ 65' COE // Test 1500psi 10min 2,800.0 2,800.0 Rig: NORDIC 3 RIG RELEASE DATE 8/13/2024 Page 3/4 1B-04 Report Printed: 9/11/2024 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) 8/10/2024 22:00 8/11/2024 00:00 2.00 COMPZN, RPCOMP NUND P Nipple down BOPs and remove tubing head 2,800.0 2,800.0 8/11/2024 00:00 8/11/2024 03:00 3.00 COMPZN, RPCOMP NUND P Continue nipple down of tubing head // All studs rusted on // Difficult to get free of casing head and off top of hanger for 7" 2,800.0 2,800.0 8/11/2024 03:00 8/11/2024 06:00 3.00 COMPZN, RPCOMP NUND P Install new tubing head // Torque studs // Test void 3000 psi 10 min // Install BOPs 2,800.0 2,800.0 8/11/2024 06:00 8/11/2024 09:30 3.50 COMPZN, RPCOMP NUND P NU BOPE 2,800.0 2,800.0 8/11/2024 09:30 8/11/2024 10:30 1.00 COMPZN, RPCOMP BOPE P PT breaks 250/3000 psi 2,800.0 2,800.0 8/11/2024 10:30 8/11/2024 11:30 1.00 COMPZN, RPCOMP RURD P Blow down kill and choke lines and drain stack. Pull test plug and set wear ring. 2,800.0 2,800.0 8/11/2024 11:30 8/11/2024 15:30 4.00 COMPZN, RPCOMP TRIP P POOH standing back DP in derrick. 2,800.0 120.0 8/11/2024 15:30 8/11/2024 17:00 1.50 COMPZN, RPCOMP BHAH P Lay down and inspect BHA 120.0 0.0 8/11/2024 17:00 8/11/2024 17:30 0.50 COMPZN, RPCOMP BHAH P Pick up test packer BHA 0.0 12.0 8/11/2024 17:30 8/11/2024 20:15 2.75 COMPZN, RPCOMP TRIP P TIH with packer T/ 7300' COE 12.0 7,327.0 8/11/2024 20:15 8/11/2024 21:45 1.50 COMPZN, RPCOMP PRTS P Set packer 7300' COE // PT casing 3000 psi for 30 min charted and good test // Bleed pressure release packer 7,327.0 7,327.0 8/11/2024 21:45 8/11/2024 22:30 0.75 COMPZN, RPCOMP CIRC P Circulate B/U 7,327.0 7,327.0 8/11/2024 22:30 8/11/2024 23:15 0.75 COMPZN, RPCOMP PULD P Lay down 39 jts drill pipe 7,327.0 6,150.0 8/11/2024 23:15 8/12/2024 00:00 0.75 COMPZN, RPCOMP TRIP P TOOH racking stands in derrick 6,150.0 5,100.0 8/12/2024 00:00 8/12/2024 02:15 2.25 COMPZN, RPCOMP TRIP P Continue trip out of hole with test packer // Lay down test packer 5,100.0 0.0 8/12/2024 02:15 8/12/2024 02:30 0.25 COMPZN, RPCOMP OTHR P Pull Wear ring 0.0 0.0 8/12/2024 02:30 8/12/2024 03:00 0.50 COMPZN, RPCOMP CLEN P Clean floor for tubing run 0.0 0.0 8/12/2024 03:00 8/12/2024 04:00 1.00 COMPZN, RPCOMP RURD P Rig up to run 3.5" Hyd 563 tubing // GBR Torque turn 0.0 8/12/2024 04:00 8/12/2024 05:30 1.50 COMPZN, RPCOMP PUTB P MU and RIH with 3-1/2" completion to 592' 0.0 592.0 8/12/2024 05:30 8/12/2024 06:00 0.50 COMPZN, RPCOMP SVRG P Rig service. 592.0 592.0 8/12/2024 06:00 8/12/2024 14:30 8.50 COMPZN, RPCOMP PUTB P MU and RIH with 3-1/2" completion F/592' T7379.48'. PUW=98, SOW=73K 592.0 7,379.0 8/12/2024 14:30 8/12/2024 15:45 1.25 COMPZN, RPCOMP THGR P Space out and MU TBG HGR. 7,379.0 7,379.0 8/12/2024 15:45 8/12/2024 17:45 2.00 COMPZN, RPCOMP DISP P Circulate CI 7,379.0 0.0 8/12/2024 17:45 8/12/2024 18:45 1.00 COMPZN, RPCOMP THGR P Land hanger RILDS // Test 5000 psi 0.0 0.0 8/12/2024 18:45 8/12/2024 20:00 1.25 COMPZN, RPCOMP RURD P Rig up high pressure lines for setting packer and MIT test 0.0 0.0 8/12/2024 20:00 8/12/2024 22:30 2.50 COMPZN, RPCOMP PRTS P Set packer 3500 psi , first pin @ 1500 psi // Hold tubing pressure 3500 psi 30 min // Bleed tubing 1500 psi // PT IA 3000 psi 30 min good test // dump tubing shear SOV // rig down hoses 0.0 0.0 8/12/2024 22:30 8/12/2024 23:30 1.00 COMPZN, RPCOMP MPSP P Set BPV , test 1000 psi 10 min good test 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/13/2024 Page 4/4 1B-04 Report Printed: 9/11/2024 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) 8/12/2024 23:30 8/13/2024 00:00 0.50 COMPZN, WHDBOP NUND P Start nipple down of BOP 0.0 0.0 8/13/2024 00:00 8/13/2024 01:30 1.50 COMPZN, WHDBOP NUND P Nipple down BOPs and rack back 0.0 0.0 8/13/2024 01:30 8/13/2024 04:30 3.00 COMPZN, WHDBOP NUND P Nipple up production tree // PT hanger 5000 psi 10 min 0.0 0.0 8/13/2024 04:30 8/13/2024 05:30 1.00 COMPZN, WHDBOP RURD P Rig up circulating lines for freeze protect 0.0 0.0 8/13/2024 05:30 8/13/2024 07:00 1.50 COMPZN, WHDBOP FRZP P Freeze protect well 2 bpm @ 850 psi // Pump down IA taking returns up tubing // Rig down LRS // Rig up hoses let well U-tube 0.0 0.0 8/13/2024 07:00 8/13/2024 08:00 1.00 COMPZN, WHDBOP RURD P Rig down U-tube hoses. Rig down annulus valves / 1502 fittings 0.0 0.0 8/13/2024 08:00 8/13/2024 11:00 3.00 DEMOB, MOVE DMOB P Work pre rig move check list 0.0 0.0 8/13/2024 11:00 8/13/2024 12:00 1.00 DEMOB, MOVE DMOB P Jack up rig, Move off. RIG RELEASE 12:00 Noon 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/13/2024 Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: RKB 7,853.0 1B-04 7/10/2022 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set RBP with A1 Injection Valve 1B-04 9/10/2024 bworthi1 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 30.0 80.0 80.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 29.3 2,871.2 2,675.0 45.50 K-55 BUTT PRODUCTION 7 6.28 26.7 8,362.5 6,833.9 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 17.9 Set Depth 7,385.0 String Max No 3 1/2 Set Depth 6,167.3 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection HYD 563 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) 17.9 17.9 0.05 Hanger 7.010 CameronTubing Hanger CXS 7- 1/16" x 3-1/2" EUE Top x 3-1/2"EUE Mod Bottom Prepped for 1/4"(2) Control Line SN: 122191255-1 Camero n Gen 4 2.950 486.1 486.0 0.53 Nipple - X 4.293 3 1/2" x 2.813 X Nipple, HES X Nipple 2.813 7,207.8 6,035.1 40.88 Mandrel GAS LIFT 5.873 3.5" x 1.5" MMG, GLM,SLB MMG 2.920 7,267.8 6,080.3 41.39 Packer 5.990 7" x 3 1/2" Bluepack Packer, VAMTOP SLB Bluepac k 2.894 7,293.9 6,099.9 41.61 Nipple - X 4.281 3 1/2" x 2.813 X Nipple, HES X Nipple 2.813 7,378.1 6,162.3 42.83 Overshot 5.980 INNO 3 1/2" PB Overshot (2' space out, 6.48' swallow to No-Go) Inno Poor Boy Oversho t 4.620 Top (ftKB) 7,381.0 Set Depth 7,697.2 String Max No 2 7/8 Set Depth 6,389.3 Tubing Description Tubing Completion Lower Wt (lb/ft) 6.50 Grade J-55 Top Connection FL4S ID (in) 2.44 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) 7,390.3 6,171.2 43.01 PBR 5.500 BAKER CB PBR W/ RETRIEVABLE THREAD Baker CB 5.5"x4.2 5" W/ret thread 4.250 7,402.0 6,179.8 43.18 PACKER 6.156 BAKER HB RETRIEVABLE PACKER HYD Baker HB 3.000 7,438.8 6,206.4 43.65 INJECTION 4.750 CAMCO KBUG 2.347 7,506.8 6,255.3 44.48 INJECTION 4.750 CAMCO KBUG 2.347 7,544.3 6,282.0 44.75 BLAST RING 2.875 BLAST RINGS (3)2.441 7,641.9 6,350.9 45.63 INJECTION 4.750 CAMCO KBUG 2.347 7,658.1 6,362.2 45.82 LOCATOR 3.500 BAKER CL LOCATOR 2.406 7,658.5 6,362.5 45.82 PACKER 6.156 BAKER WL SET 1B PERMENANT PACKER 3.000 7,679.7 6,377.2 46.07 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 7,696.3 6,388.7 46.26 SOS 3.000 BAKER SHEAR OUT SUB 2.441 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) 1,919.6 1,895.0 22.29 RBP 3.5" P2P RBP WITH A1 INJECTION VALVE MID- ELEMENT AT 1922' RKB, OAL 6.32' TTS P2P CPP3 5361 9/10/2024 1.625 1,923.3 1,898.5 22.38 INJ VALVE A1 INJECTION VALVE (1" ORIFICE), 2.8" OD 9/10/2024 1.000 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) 7,207.8 6,035.1 40.88 1 PROD DMY RK 5.87 3 9/1/2024 SLB MMG 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 7,550.0 7,610.0 6,286.1 6,328.5 C-2, C-2, UNIT B, 1B-04 6/1/1985 12.0 IPERF 60 FT no C1 Sand 7,786.0 7,802.0 6,450.0 6,460.8 A-5, 1B-04 6/1/1985 12.0 IPERF 7,812.0 7,858.0 6,467.5 6,498.4 A-4, 1B-04 6/1/1985 12.0 IPERF Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 7,550.0 7,610.0 1 HPBD 8/5/2001 0.0 0.00 0.00 1B-04, 9/11/2024 8:42:43 AM Vertical schematic (actual) PRODUCTION; 26.7-8,362.5 IPERF; 7,812.0-7,858.0 IPERF; 7,786.0-7,802.0 PACKER; 7,658.5 INJECTION; 7,641.9 IPERF; 7,550.0-7,610.0 HPBD; 7,550.0 INJECTION; 7,506.8 INJECTION; 7,438.8 PACKER; 7,402.0 Nipple - X; 7,293.9 Packer; 7,267.8 Mandrel GAS LIFT; 7,207.8 SURFACE; 29.3-2,871.2 INJ VALVE; 1,923.3 RBP; 1,919.6 Nipple - X; 486.0 CONDUCTOR; 30.0-80.0 Hanger; 17.9 KUP INJ KB-Grd (ft) 32.48 RR Date 7/14/1981 Other Elev 1B-04 ... TD Act Btm (ftKB) 8,410.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292059500 Wellbore Status INJ Max Angle & MD Incl (°) 48.90 MD (ftKB) 8,200.00 WELLNAME WELLBORE Annotation Last WO: End Date 8/13/2024 H2S (ppm)DateComment SSSV: needs pkr to hang off ORIGINATED TRANSMITTAL DATE: 6/28/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4896 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 4896 1B-04 50029205950000 Tubing Cut Record 26-Jun-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 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 181-065 T39089 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.28 13:40:18 -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 tom.osterkamp@conocophillips.com 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): 8410'6865' 7853' 6495'2820 None 8362' 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: 907-267-1102 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 KRU 1B-04 7550-7610' 7786-7802' 7812-7858' 8336' 6286-6329' 6450-6461' 6468-6498' 7/11/2024 2-7/8" P2P-Upper Patch P2P-Lower P2P-Upper Patch P2P-Lower Baker HB Retrievable Baker Permanent SSSV: CAMCO 2842' 8363' Perforation Depth MD (ft): 80' 2871' 6834'7" 16" 10-3/4" 50' Burst 7697' MD 80' 2675' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025648 181-065 P.O. Box 100360, Anchorage, AK 99510 50-029-205950-00-00 ConocoPhillips Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 5550'MD/4714'TVD 5573'MD/4733'TVD 7370'MD/6156'TVD 7388'MD/6170'TVD 7402'MD/6180'TVD 7659'MD/6362'TVD 1922'MD/1897'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 James Ohlinger james.j.ohlinger@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 By Grace Christianson at 12:24 pm, May 14, 2024 Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E= James.J.Ohlinger@cop.com Reason: I am the author of this document Location: Date: 2024.05.14 10:46:54-08'00' Foxit PDF Editor Version: 13.0.0 James J. Ohlinger BOP test to 3000 psig Annular preventer test to 2500 psig SFD DSR-5/14/24VTL 05/21/2024 X 50-029-20595-00-00 X 10-404 X SFD 5/14/2024*&:JLC 6/21/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.06.21 11:04:35 -08'00'06/21/24 RBDMS JSB 062624 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 13, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: James J. Ohlinger Staff CTD/RWO Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Injector 1B-04 (PTD# 181-065). Well 1B-04 was originally spud in 6/23/81 and rig released 7/14/81. The well has primarily been a Kuparuk A-sand and C-sand Injector. The well has developed AnnComm issues that moved it to being a RWO candidate due to leaks. If you have any questions or require any further information, please contact me at +1 907-229-3338. The tubing will be pulled from a pre-rig cut. A new 3.5" completion will be installed with stacked packer to recomplete the well. 1B-04 RWO Procedure Kuparuk Producer - RWO PTD #181-065 Page 1 of 3 General Well info: Wellhead type/pressure rating: McEvoy Gen 1 Retro to Gen III Production Engineer: Banabas Dogah Reservoir Development Engineer: Cody Keith Estimated Start Date: 7/11/24 Workover Engineer: James Ohlinger (265-1102/ James.J.Ohlinger@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Injector Scope of Work: Pull the existing 2-7/8” completion down to the pre-rig cut above the packer. A new 3-1/2” tubing string with a Poor-boy overshot and stack packer. BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T Tubing leaks IC POT & PPPOT Passed – 8/13/2023 T-POT & PPPOT Passed – 2/16/24 MPSP: 2820 psi using 0.1 psi/ft gradient Static BHP: 3459psi / 6394’ TVD measured on 7/31/22 Remaining Pre-Rig Work 1. Pull Patches 2. IC-POT, IC-PPPOT, T-PPPOT and T-POT tests. 3. SBHP 4. Set Plug 5. MIT-IA or CMIT-TxIA. 6. Open lowest GLM in upper completion. Dummy off other GLMs. 7. Cut the tubing at ~7381 RKB in the middle of the first full joint above the packer @ 7402’ RKB 8. Prepare well within 48 hrs of rig arrival. 1B-04 RWO Procedure Kuparuk Producer - RWO PTD #181-065 Page 2 of 3 Rig Work MIRU 1. MIRU Nordic 3 on 1B-04 (No BPV will be installed due to risk assessment done for MIRU/RDMO on N3 w/o BPV.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 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 Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 2-7/8” tubing down to pre-rig cut (~7381’ RKB). a. If not all tubing comes due to subsidence, then work additional steps below to clear buckled 7”, then pull remaining completion. b. *Depending on drifts, go to “Contingency for Subsidence on 7.0”. Install in 3-½” Completion 6. MU 3 ½” completion with poor-boy overshot, nipple profiles, and GLM. RIH with completion. 7. Once on depth, circulate CI brine, space out as needed, land hanger, RILDS, drop B&R, and set packer. 8. Pressure test tubing to 3000 psi for 30 minutes and chart. 9. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 10. Confirm pressure tests, then shear out SOV with pressure differential. 11. Install BPV. 12. ND BOPE. NU tree. PT tree. 13. Pull BPV, freeze protect well at opportune time, and set BPV if necessary. 14. RDMO. Post-Rig Work 15. Install GLD. 16. Pull Ball and Rod 17. Pull any remaining plugs in well. 18. Turn over to operations. 1B-04 RWO Procedure Kuparuk Producer - RWO PTD #181-065 Page 3 of 3 Contingency for Subsidence on 7.0” 7” Casing is currently landed on a Mandrel Hanger. We don’t plan on stretching the 7” Casing as there is only an estimated 39” of subsidence and no known drift issues. If the 7” lower Packoff passes Pre-Rig testing, we don’t plan trying to replace it. Reason being, it is currently held down with lock down screws. If we back them out, there is a chance of the casing growing and we will be forced into cutting casing. Pull Subsided 7.0” Casing 19. Set storm packer or plug in 7” casing and PT to confirm as barrier. 20. ND BOPE. ND old tubing spool. NU BOPE and test flange break. a. Grow/stretch and Cut 7” casing at surface as necessary to deal with subsidence in this step. i. Be aware that the 7” casing is on a mandrel and this step might not be feasible. b. Can’t test flange break with test-joint since packoffs are removed and 7” is above flange. Test 11” 3k flange break to 3000 psig at earliest opportunity. 21. Pull storm packer or plug. Condition fluid as needed. 22. RU Eline and log 7.0” casing for OA cement 23. Cut 7.0” casing with cutter above OA cement. a. Circulate out Arctic Pack diesel/slurry if needed. 24. Pull 7.0” casing down to cut (~2000’). a. Make addition cut/pulls/BHA runs as necessary to remove 7”. b. Test 11” 3k flange to 3000 psig if not already done so. Bore out 9-5/8” and run 7.0” Tie-Back Subsidence Before Running of 5.5” x 3.5” tie-back 1. PU mills and bore out 10-3/4” as necessary to obtain drift for new 7.0” tie-back. a. As drift is regained, pull any additional 7.0” or 3.5” tubing as needed to get 7.0” removed down to cement in OA. 2. Run new 7.0” tie-back casing with overshot. 3. Test casing to 2500 psig. 4. Cement OA to surface. 5. Perform 30 minute no flow test, split stack and land slips, cut excess casing and install IC packoffs. Installed Tie- back spool and terminate 7.0”. Land stack and MU to casing flange. a. Test flange break to BOPE test pressure. 6. Mill plugs in cementer. 7. Circulate out sand on IBP or any lower plug. 8. Pull any lower plugs or remaining 3.5”. 9. Return to “Run New 3.5”. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 7,853.0 7/10/2022 1B-04 fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Tag 7/10/2022 1B-04 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 30.0 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (lb… 65.00 Grade H-40 Top Connection WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 29.3 Set Depth (ftKB) 2,871.2 Set Depth (TVD) … 2,675.0 Wt/Len (lb… 45.50 Grade K-55 Top Connection BUTT Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 26.7 Set Depth (ftKB) 8,362.5 Set Depth (TVD) … 6,833.9 Wt/Len (lb… 26.00 Grade K-55 Top Connection BTC Tubing Strings: string max indicates LONGEST segment of string Tubing Description TUBING String … 2 7/8 ID (in) 2.44 Top (ftKB) 17.9 Set Depth (ft… 7,697.2 Set Depth (TVD… 6,389.3 Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8RDMOD Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model 17.9 17.9 0.05 HANGER 2.875 6.000 1,921.6 1,896.9 22.34 SAFETY VLV 2.313 4.760 2,022.8 1,989.6 24.99 GAS LIFT 2.344 4.750 CAMCO KBUG 3,691.1 3,288.6 41.21 GAS LIFT 2.344 4.750 CAMCO KBUG 4,801.7 4,129.2 39.60 GAS LIFT 2.344 4.750 CAMCO KBUG 5,575.7 4,734.7 36.67 GAS LIFT 2.344 4.750 CAMCO KBUG 6,105.0 5,159.9 37.19 GAS LIFT 2.344 4.750 CAMCO KBUG 6,478.4 5,458.0 36.59 GAS LIFT 2.344 4.750 CAMCO KBUG 6,916.2 5,810.5 37.49 GAS LIFT 2.344 4.750 CAMCO KBUG 7,353.0 6,143.8 42.45 GAS LIFT 2.344 4.750 CAMCO KBUG 7,390.3 6,171.2 43.01 PBR 4.250 5.500 7,402.0 6,179.7 43.18 PACKER 3.000 6.156 7,544.3 6,282.0 44.75 BLAST RING 2.441 2.875 7,658.1 6,362.2 45.82 LOCATOR 2.406 3.500 7,658.5 6,362.4 45.82 PACKER 3.000 6.156 7,679.7 6,377.2 46.07 NIPPLE 2.250 3.668 7,696.3 6,388.7 46.26 SOS 2.441 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 5,550.0 4,714.1 36.84 PACKER - PATCH - UPR 2.29" P2P (W/ Spacer Pipe and Anchor Latch OAL 23') 1/9/2020 1.380 CPP287029 5,554.0 4,717.3 36.82 SPACER / ANCHOR LATCH 2 1/16" P-110 19' of Spacer Pipe and Anchor Latch 1/9/2020 1.600 CPAL287026 5,556.5 4,719.3 36.80 LEAK - TUBING TUBING LEAK 5,556.5' 11/11/2014 5,573.0 4,732.5 36.69 PACKER - PATCH - LWR 2.29" P2P, OAL 4' Max OD 2.29" 1/8/2020 1.380 CPP287038 7,370.0 6,156.3 42.71 PACKER - PATCH - UPR 2.29" P2P Max OD 2.29" (W/Spacer Pipe and Anchor Latch, OAL 18' ) 1/8/2020 1.380 CPP287049 7,374.0 6,159.3 42.76 SPACER / ANCHOR LATCH 2 1/16" P-110 14' of Spacer Pipe and Anchor Latch 1/8/2020 1.600 CPAL287029 7,380.0 6,163.7 42.85 LEAK - TUBING TUBING LEAK @7380' 12/16/2019 7,388.0 6,169.5 42.97 PACKER - PATCH - LWR 2.29" P2P, OAL 3.56' 1/4/2020 1.380 CPP28750 8,362.0 6,833.5 48.27 FISH 3 WRP SLIPS AND NOSE CONE 3/5/2015 Mandrel Inserts : excludes pulled inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,022.8 1,989.6 24.99 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 3:00 2 3,691.1 3,288.6 41.21 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 2:00 3 4,801.7 4,129.2 39.60 1 GAS LIFT DMY BK 0.000 0.0 1/23/2020 7:00 4 5,575.7 4,734.7 36.67 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 9:00 5 6,105.0 5,159.9 37.19 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 10:00 6 6,478.4 5,458.0 36.59 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 9:00 7 6,916.2 5,810.5 37.49 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 8:00 8 7,353.0 6,143.8 42.45 1 GAS LIFT DMY BK 0.000 0.0 1/4/2020 4:30 9 7,438.7 6,206.4 43.65 1 INJ DMY BEK 0.000 0.0 4/26/2006 1 0 7,506.7 6,255.3 44.48 1 INJ DMY BK 0.000 0.0 8/27/2008 1 1 7,641.9 6,350.8 45.63 1 INJ DMY BK 0.000 0.0 2/7/2010 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,550.0 7,610.0 6,286.1 6,328.5 C-2, C-2, UNIT B, 1B-04 6/1/1985 12.0 IPERF 60 FT no C1 Sand 7,786.0 7,802.0 6,450.0 6,460.8 A-5, 1B-04 6/1/1985 12.0 IPERF 7,812.0 7,858.0 6,467.5 6,498.4 A-4, 1B-04 6/1/1985 12.0 IPERF 1B-04, 7/11/2022 7:46:27 AM Vertical schematic (actual) PRODUCTION; 26.7-8,362.5 FISH; 8,362.0 FLOAT SHOE; 8,361.5-8,362.5 FLOAT COLLAR; 8,276.4- 8,277.6 IPERF; 7,812.0-7,858.0 IPERF; 7,786.0-7,802.0 SOS; 7,696.3 NIPPLE; 7,679.7 PACKER; 7,658.5 LOCATOR; 7,658.1 INJECTION; 7,641.9 HPBD; 7,550.0 IPERF; 7,550.0-7,610.0 INJECTION; 7,506.7 INJECTION; 7,438.7 PACKER; 7,402.0 PBR; 7,390.3 PACKER - PATCH - LWR; 7,388.0 SPACER / ANCHOR LATCH; 7,374.0 LEAK - TUBING; 7,380.0 PACKER - PATCH - UPR; 7,370.0 GAS LIFT; 7,353.0 GAS LIFT; 6,916.2 GAS LIFT; 6,478.4 GAS LIFT; 6,105.0 GAS LIFT; 5,575.7 PACKER - PATCH - LWR; 5,573.0 SPACER / ANCHOR LATCH; 5,554.0 LEAK - TUBING; 5,556.5 PACKER - PATCH - UPR; 5,550.0 GAS LIFT; 4,801.7 CASING PUPS; 3,936.3-3,978.4 GAS LIFT; 3,691.1 SURFACE; 29.3-2,871.2 FLOAT SHOE; 2,869.3-2,871.2 FLOAT COLLAR; 2,786.2- 2,787.5 GAS LIFT; 2,022.8 SAFETY VLV; 1,921.6 CONDUCTOR; 30.0-80.0 HANGER; 29.3-33.7 HANGER; 26.7-31.2 HANGER; 17.9 KUP INJ KB-Grd (ft) 32.48 RR Date 7/14/1981 Other Elev… 1B-04 ... TD Act Btm (ftKB) 8,410.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292059500 Wellbore Status INJ Max Angle & MD Incl (°) 48.90 MD (ftKB) 8,200.00 WELLNAME WELLBORE1B-04 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 HPBD 8/5/2001 7,550.0 7,610.0 0.0 0.00 0.00 1B-04, 7/11/2022 7:46:28 AM Vertical schematic (actual) PRODUCTION; 26.7-8,362.5 FISH; 8,362.0 FLOAT SHOE; 8,361.5-8,362.5 FLOAT COLLAR; 8,276.4- 8,277.6 IPERF; 7,812.0-7,858.0 IPERF; 7,786.0-7,802.0 SOS; 7,696.3 NIPPLE; 7,679.7 PACKER; 7,658.5 LOCATOR; 7,658.1 INJECTION; 7,641.9 HPBD; 7,550.0 IPERF; 7,550.0-7,610.0 INJECTION; 7,506.7 INJECTION; 7,438.7 PACKER; 7,402.0 PBR; 7,390.3 PACKER - PATCH - LWR; 7,388.0 SPACER / ANCHOR LATCH; 7,374.0 LEAK - TUBING; 7,380.0 PACKER - PATCH - UPR; 7,370.0 GAS LIFT; 7,353.0 GAS LIFT; 6,916.2 GAS LIFT; 6,478.4 GAS LIFT; 6,105.0 GAS LIFT; 5,575.7 PACKER - PATCH - LWR; 5,573.0 SPACER / ANCHOR LATCH; 5,554.0 LEAK - TUBING; 5,556.5 PACKER - PATCH - UPR; 5,550.0 GAS LIFT; 4,801.7 CASING PUPS; 3,936.3-3,978.4 GAS LIFT; 3,691.1 SURFACE; 29.3-2,871.2 FLOAT SHOE; 2,869.3-2,871.2 FLOAT COLLAR; 2,786.2- 2,787.5 GAS LIFT; 2,022.8 SAFETY VLV; 1,921.6 CONDUCTOR; 30.0-80.0 HANGER; 29.3-33.7 HANGER; 26.7-31.2 HANGER; 17.9 KUP INJ 1B-04 ... WELLNAME WELLBORE1B-04 1B-04 Existing Completion Injector COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Conductor 80 80 16 15.06 Surface 2871.2 2675 10.75 9.95 Production 8362.5 6833.9 7 6.28 Tubing 7697 6389 2.875 2.44 39" estimated subsidnece, shut-in 2/29/24 COMPLETION McEvoy Gen 1 Retro to Gen III XO 3-1/2" Butt box x 2-7/8" EUE pin 2-7/8" J-55 EUE Tubing to surface Camco TRDP-A SSSV @ 1922' RKB, 2.313" ID Camco KBUG GLM @ 2023', 3691', 4802', 5576', 6105', 6478', 6916', 7353' RKB BOT PBR CB @ 7390' RKB Retrievable HB7 Packer @ 7402' RKB Camco KBUG GLM @ 7439', 7507' RKB Blast Rings Camco KBUG GLM @ 7642' RKB Permanent Packer @ 7659' RKB (3.0" ID) 2.25" D nipple @ 7680' RKB (2.25" ID) SOS @ 7696' RKB Surface Casing Production Casing Conductor A-sand perfs C-Sand Perfs Tubing Leak ~ 7380' RKB P2P Patch 7370'-7388' RKB Tubing Leak ~ 5557' RKB P2P Patch 5550'-5573' RKB Tubing Cut ~ 7381' RKB 1B-04 Proposed RWO Completion Injector COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Conductor 80 80 16 15.06 Surface 2871.2 2675 10.75 9.95 Production 8362.5 6833.9 7 6.28 Tubing 7697 6389 3.5" x 2.875" 2.992 x 2.44 Surface Casing Production Casing Conductor A-sand perfs C-Sand Perfs PROPOSED COMPLETION 3-1/2" 9.3# L-80 HYD563 Tubing to surface 3-½" X landing nipple at xxxx' RKB (2.813" min ID 3-1/2" Camco MMG gas lift mandrels @ TBD 3.5" x 7.0" Packer @ xxxx' RKB (4" ID) 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 2-7/8" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE 2-7/8" 6.5# J55 EUEM tubing BOT PBR CB @ 7390' RKB Retrievable HB7 Packer @ 7402' RKB Camco KBUG GLM @ 7439', 7507' RKB Blast Rings Camco KBUG GLM @ 7642' RKB Permanent Packer @ 7659' RKB (3.0" ID) 2.25" D nipple @ 7680' RKB (2.25" ID) SOS @ 7696' RKB Tubing Cut ~ 7381' RKB CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Kuparuk injector 1B-04 (PTD 181-065) report of elevating IA pressure. Date:Wednesday, February 21, 2024 9:12:19 AM Attachments:image001.png AnnComm Surveillance TIO for 1B-04.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Friday, February 16, 2024 1:56 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Subject: Kuparuk injector 1B-04 (PTD 181-065) report of elevating IA pressure. Chris- Kuparuk injector 1B-04 (PTD 181-065) was reported by operations with elevating IA pressure. DHD attempted an unsuccessful IA bleed so the well will be shut in and freeze protected. CPAI intends to conduct the initial diagnostics and depending on the results, the proper notifications for continued injection or repair will be submitted as required. Attached is a current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 7,853.0 7/10/2022 1B-04 fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Tag 7/10/2022 1B-04 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 30.0 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (lb… 65.00 Grade H-40 Top Connection WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 29.3 Set Depth (ftKB) 2,871.2 Set Depth (TVD) … 2,675.0 Wt/Len (lb… 45.50 Grade K-55 Top Connection BUTT Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 26.7 Set Depth (ftKB) 8,362.5 Set Depth (TVD) … 6,833.9 Wt/Len (lb… 26.00 Grade K-55 Top Connection BTC Tubing Strings: string max indicates LONGEST segment of string Tubing Description TUBING String … 2 7/8 ID (in) 2.44 Top (ftKB) 17.9 Set Depth (ft… 7,697.2 Set Depth (TVD… 6,389.3 Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8RDMOD Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model 17.9 17.9 0.05 HANGER 2.875 6.000 1,921.6 1,896.9 22.34 SAFETY VLV 2.313 4.760 2,022.8 1,989.6 24.99 GAS LIFT 2.344 4.750 CAMCO KBUG 3,691.1 3,288.6 41.21 GAS LIFT 2.344 4.750 CAMCO KBUG 4,801.7 4,129.2 39.60 GAS LIFT 2.344 4.750 CAMCO KBUG 5,575.7 4,734.7 36.67 GAS LIFT 2.344 4.750 CAMCO KBUG 6,105.0 5,159.9 37.19 GAS LIFT 2.344 4.750 CAMCO KBUG 6,478.4 5,458.0 36.59 GAS LIFT 2.344 4.750 CAMCO KBUG 6,916.2 5,810.5 37.49 GAS LIFT 2.344 4.750 CAMCO KBUG 7,353.0 6,143.8 42.45 GAS LIFT 2.344 4.750 CAMCO KBUG 7,390.3 6,171.2 43.01 PBR 4.250 5.500 7,402.0 6,179.7 43.18 PACKER 3.000 6.156 7,544.3 6,282.0 44.75 BLAST RING 2.441 2.875 7,658.1 6,362.2 45.82 LOCATOR 2.406 3.500 7,658.5 6,362.4 45.82 PACKER 3.000 6.156 7,679.7 6,377.2 46.07 NIPPLE 2.250 3.668 7,696.3 6,388.7 46.26 SOS 2.441 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 5,550.0 4,714.1 36.84 PACKER - PATCH - UPR 2.29" P2P (W/ Spacer Pipe and Anchor Latch OAL 23') 1/9/2020 1.380 CPP287029 5,554.0 4,717.3 36.82 SPACER / ANCHOR LATCH 2 1/16" P-110 19' of Spacer Pipe and Anchor Latch 1/9/2020 1.600 CPAL287026 5,556.5 4,719.3 36.80 LEAK - TUBING TUBING LEAK 5,556.5' 11/11/2014 5,573.0 4,732.5 36.69 PACKER - PATCH - LWR 2.29" P2P, OAL 4' Max OD 2.29" 1/8/2020 1.380 CPP287038 7,370.0 6,156.3 42.71 PACKER - PATCH - UPR 2.29" P2P Max OD 2.29" (W/Spacer Pipe and Anchor Latch, OAL 18' ) 1/8/2020 1.380 CPP287049 7,374.0 6,159.3 42.76 SPACER / ANCHOR LATCH 2 1/16" P-110 14' of Spacer Pipe and Anchor Latch 1/8/2020 1.600 CPAL287029 7,380.0 6,163.7 42.85 LEAK - TUBING TUBING LEAK @7380' 12/16/2019 7,388.0 6,169.5 42.97 PACKER - PATCH - LWR 2.29" P2P, OAL 3.56' 1/4/2020 1.380 CPP28750 8,362.0 6,833.5 48.27 FISH 3 WRP SLIPS AND NOSE CONE 3/5/2015 Mandrel Inserts : excludes pulled inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,022.8 1,989.6 24.99 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 3:00 2 3,691.1 3,288.6 41.21 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 2:00 3 4,801.7 4,129.2 39.60 1 GAS LIFT DMY BK 0.000 0.0 1/23/2020 7:00 4 5,575.7 4,734.7 36.67 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 9:00 5 6,105.0 5,159.9 37.19 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 10:00 6 6,478.4 5,458.0 36.59 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 9:00 7 6,916.2 5,810.5 37.49 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 8:00 8 7,353.0 6,143.8 42.45 1 GAS LIFT DMY BK 0.000 0.0 1/4/2020 4:30 9 7,438.7 6,206.4 43.65 1 INJ DMY BEK 0.000 0.0 4/26/2006 1 0 7,506.7 6,255.3 44.48 1 INJ DMY BK 0.000 0.0 8/27/2008 1 1 7,641.9 6,350.8 45.63 1 INJ DMY BK 0.000 0.0 2/7/2010 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,550.0 7,610.0 6,286.1 6,328.5 C-2, C-2, UNIT B, 1B-04 6/1/1985 12.0 IPERF 60 FT no C1 Sand 7,786.0 7,802.0 6,450.0 6,460.8 A-5, 1B-04 6/1/1985 12.0 IPERF 7,812.0 7,858.0 6,467.5 6,498.4 A-4, 1B-04 6/1/1985 12.0 IPERF 1B-04, 7/11/2022 7:46:27 AM Vertical schematic (actual) PRODUCTION; 26.7-8,362.5 FISH; 8,362.0 FLOAT SHOE; 8,361.5-8,362.5 FLOAT COLLAR; 8,276.4- 8,277.6 IPERF; 7,812.0-7,858.0 IPERF; 7,786.0-7,802.0 SOS; 7,696.3 NIPPLE; 7,679.7 PACKER; 7,658.5 LOCATOR; 7,658.1 INJECTION; 7,641.9 HPBD; 7,550.0 IPERF; 7,550.0-7,610.0 INJECTION; 7,506.7 INJECTION; 7,438.7 PACKER; 7,402.0 PBR; 7,390.3 PACKER - PATCH - LWR; 7,388.0 SPACER / ANCHOR LATCH; 7,374.0 LEAK - TUBING; 7,380.0 PACKER - PATCH - UPR; 7,370.0 GAS LIFT; 7,353.0 GAS LIFT; 6,916.2 GAS LIFT; 6,478.4 GAS LIFT; 6,105.0 GAS LIFT; 5,575.7 PACKER - PATCH - LWR; 5,573.0 SPACER / ANCHOR LATCH; 5,554.0 LEAK - TUBING; 5,556.5 PACKER - PATCH - UPR; 5,550.0 GAS LIFT; 4,801.7 CASING PUPS; 3,936.3-3,978.4 GAS LIFT; 3,691.1 SURFACE; 29.3-2,871.2 FLOAT SHOE; 2,869.3-2,871.2 FLOAT COLLAR; 2,786.2- 2,787.5 GAS LIFT; 2,022.8 SAFETY VLV; 1,921.6 CONDUCTOR; 30.0-80.0 HANGER; 29.3-33.7 HANGER; 26.7-31.2 HANGER; 17.9 KUP INJ KB-Grd (ft) 32.48 RR Date 7/14/1981 Other Elev… 1B-04 ... TD Act Btm (ftKB) 8,410.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292059500 Wellbore Status INJ Max Angle & MD Incl (°) 48.90 MD (ftKB) 8,200.00 WELLNAME WELLBORE1B-04 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 HPBD 8/5/2001 7,550.0 7,610.0 0.0 0.00 0.00 1B-04, 7/11/2022 7:46:28 AM Vertical schematic (actual) PRODUCTION; 26.7-8,362.5 FISH; 8,362.0 FLOAT SHOE; 8,361.5-8,362.5 FLOAT COLLAR; 8,276.4- 8,277.6 IPERF; 7,812.0-7,858.0 IPERF; 7,786.0-7,802.0 SOS; 7,696.3 NIPPLE; 7,679.7 PACKER; 7,658.5 LOCATOR; 7,658.1 INJECTION; 7,641.9 HPBD; 7,550.0 IPERF; 7,550.0-7,610.0 INJECTION; 7,506.7 INJECTION; 7,438.7 PACKER; 7,402.0 PBR; 7,390.3 PACKER - PATCH - LWR; 7,388.0 SPACER / ANCHOR LATCH; 7,374.0 LEAK - TUBING; 7,380.0 PACKER - PATCH - UPR; 7,370.0 GAS LIFT; 7,353.0 GAS LIFT; 6,916.2 GAS LIFT; 6,478.4 GAS LIFT; 6,105.0 GAS LIFT; 5,575.7 PACKER - PATCH - LWR; 5,573.0 SPACER / ANCHOR LATCH; 5,554.0 LEAK - TUBING; 5,556.5 PACKER - PATCH - UPR; 5,550.0 GAS LIFT; 4,801.7 CASING PUPS; 3,936.3-3,978.4 GAS LIFT; 3,691.1 SURFACE; 29.3-2,871.2 FLOAT SHOE; 2,869.3-2,871.2 FLOAT COLLAR; 2,786.2- 2,787.5 GAS LIFT; 2,022.8 SAFETY VLV; 1,921.6 CONDUCTOR; 30.0-80.0 HANGER; 29.3-33.7 HANGER; 26.7-31.2 HANGER; 17.9 KUP INJ 1B-04 ... WELLNAME WELLBORE1B-04 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1B-04 KUPARUK RIV UNIT 1B-04 Jim Regg InspectorSrc: 1B-04 W SPT 6180 1810650 3000 2612 2619 2640 2619 185 245 254 258 Required by Variance Pass MIT-IA as per AIO 2C.043 30 MinPretestInitial15 Min Type Test Notes: Interval P/F Well Type Inj TVD PTD Test psi Tubing OA Packer Depth 990 3300 3240 3220IA 45 Min 60 Min 50-029-20595-00-00 181-065-0 Brian Bixby 6/6/2023 Well Name Permit Number: API Well Number Inspector Name:KUPARUK RIV UNIT 1B-04 Inspection Date:Insp Num: Rel Insp Num: mitBDB230607094529 MITOP000009843 BBL Pumped:2.2 BBL Returned:2.1 Thursday, July 27, 2023 Page 1 of 1 MEMORANDUM TO: Jim Reggf P.I. Supervisor FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, July 9, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1B-04 KUPARUK RIV UNIT 1B-04 Src: Inspector Reviewed By: P.I. Supry I Comm Well Name KUPARUK RIV UNIT 1B-04 API Well Number 50-029-20595-00-00 Inspector Name: Jeff Jones Permit Number: 181-065-0 Inspection Date: 6/29/2021 Insp Num: mitJJ210701131142 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1B-04 Type Inj w- TVD 6180 Tubing 2450 2450. 2440 _ 2440 - PTD 1 1810650 Type 'fest SPT Test psi 1545 IA 780 3290 3230 3200 - BBL Pumped: 2.2 - BBL Returned: i 2.2 OA 100 250 260 - . 260 .� IntervalREQVAR p/I P Notes: AIO 2C.043; MIT -IA to max. anticipated injection pressure. 1 well inspected, no exceptions noted. Friday, July 9, 2021 Page 1 of 1 Originated: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Delivered to: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above Transmittal Date: APR 2 3 2020 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date: Signed: 18106.5 32792 13 -Mar -20 CD # 1 1 1 1 1 1 API # SERVICE ORDER # FIEL�DNA ME �JOBTYPE DATA TYPE LOGGING DATE PRINTS # 1 4LWELLNAME 2 3 S 6 2M-07 1D-04 1A 01 1A 15 1A-17 16-04 1D-130 1D-135 50-103-20178-00 50-029-20429-00 50-029-20590-00 50-029-20711-00 50-029-22102-00 50-029-20595-00 50-029-22815-00 50-029-22816-00 906173399 906174414 906236618 906270889 906333945 906221237 906340407 906236619 Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk West Sak West Sak Plug Setting Record Packer Setting Record Packer Setting Record Packer Setting Record Packer Setting Record Packer Setting Record Packer Setting Record Packer Setting Record Final -Field Final -Field Final -Field Final -Field Final -Field Final -Field Final -Field Final -Field 14 -Dec -19 16 -Dec -19 24 -Jan -20 26 -Jan -20 21 -Feb -20 4 -Jan -20 0 0 0 0 0 7 8 9 0 0 0 8 -Jan -20 10 -Mar -20 14 -Jan -20 10 15 -Jan -20 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date: Signed: 18106.5 32792 13 -Mar -20 CD # 1 1 1 1 1 1 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Sunday, February 23, 2020 3:50 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: Kuparuk Injector 1 B-04 (PTD* 181-065) Suspected IAxOA communication Attachments: 1B-04 TIO plot 23 Feb 20.JPG Chris- Kuparuk Injector 113-04 (PTD# 181-065) is completing the 30 -day monitor period for the suspected IAxOA communication tomorrow. The IA and OA have not shown indications of communication during the monitor period. Therefore, the well will be returned to normal waivered injection status under AID 2C.043. Please let me know if you have any questions or disagree with the plan. Attached is a copy of the 90 -day TIO plot. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS flips AM Conoco�+Nu _ From: Well Integ-M Sent: Monday, Jan To: chris.wallace@ Cc: CPA Wells Supt pliance Specialist CPF1 & 2 <n1617@conocophillips.com> 1, 2020 11:35 AM <n1617@conocophillips.com> Subject: Kuparuk Injector 113-04 Well Integrity Compliance Specialist CPF1 & 2 Suspected IAxOA communication Chris- Kuparuk Injector 1B-04 (PTD# 181-065) has s wn IAxOA communication while preparing the well for the DAS/DTS logging. While displacing the IA with N2 the OA sh ed a sudden pressure response. DHD was on location and attempted unsuccessful repairs on the IC pack offs. At is point in time it is suspected that the leak is caused by the nitrogen application to the IA. Once the IA was displaced ' h nitrogen, Slick line replaced the dummy valve into GLM # 3 and DHD performed a passing IA/OA DDT. The well will be c ely monitored until the DAS/DTS logging has been completed to ensure the IA and OA pressures are maintained wit ' regulation. The DAS/DTS logging procedure calls for the IA to be charged with N2 to varying pressures so the OA will b eld on an open bleed while the logging is in progress. Once the logging has been completed the IA will be returned t 'ts normal operating condition and once online the OA will be monitored for 30 days to verify IAxOA integrity. If the II continues to show signs of IAxOA, DHD will conduct diagnostics to investigate repair options. Please let me know if you ave any questions or disagree with the plan. Attached are copies of the current 90 -day TIO plot and well bore schematic. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, February 11, 2020 TO: Jim Regg� P.I. Supervisor xC2q Z,� L ZO2f 0 SUBJECT: Mechanical integrity Tests (t ConocoPhillips Alaska, Inc. IB -04 FROM: Brian Bixby KUPARUK RIV UNIT IB -04 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IB -04 API Well Number 50-029-20595-00-00 Inspector Name: Brian Bixby Permit Number: 181-065-0 Inspection Date: 2/2/2020 Insp Now mitBDB200209080112 Rel Insp Num: Packer Depth Pretest Initial I5 Min 30 Min 45 Min 60 Min Weld 1B 04 Type In' M'I D 6180 Tubing 1226 'i Rls' 2223 "1225 PTD slobso Type Test sPT Test psi' 3000 IA sso 3310 3z�o eo BBL Pumped: 3 BBL Returned: 3.1 OA so 394 ssl ss Interval OTHER PIF P Notes: MITIA as per SUNDRY N319- 5 (post patch) and AID 2C.043 " Tuesday, February 11, 2020 Page 1 of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED FEB 0 5 2020 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing pe o s'lwtdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well Q Re-enter Susp Well ❑ Other: tubing patches 2. Operator ConocoPhillips Alaska Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ Stratigraphic ❑ Service Q 181-065 3. Address: P.O Box 100360, Anchorage, Alaska 99510 6. API Number: 50029205950000 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025648 KRU 1B-04 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Ku aruk River Field/ Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8410 feet Plugs measured N/A feet true vertical 6863 feet Junk measured N/A feet Effective Depth measured 7862 feet Packer measured 7402 feet true vertical 6501 feet true vertical 6180 feet Casing Length Size MD TVD Burst Collapse Conductor 50 16 80 80 Surface 2842 10.75 2871 2675 Production 8363 7 8363 6834 Perforation depth Measured depth 7550-7610, 7786-7802, 7812-7858 feet True Vertical depth 6286-6329, 6450-6461, 6468-6498 feet Tubing (size, grade, measured and true vertical depth) 2.875 J-55 7697 6389 Packers and SSSV (type, measured and true vertical depth) Safety Valve- Camco TRCP-1A SSA 1922 1897 Packer- Baker HB Retrievable Packer HYD 7402 6180 Packer- Baker WL Set 1 B Permanent Packer 7659 6362 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf WatePressure Tubing Pressure r -Bbl Casing Prior to well operation: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A INIA N/A 14. Attachments (required per20 AAc 25.070.25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development[] Service ❑Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Q WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-585 Authorized Name: Paul Duffy Contact Name: Paul Duffy/Jan Byrne Authorized Title: Well Integrity Compliance Specialist Contact Email: N1617Aconocoohillios.com Authorized Signature: Date 3 -Feb -20 Contact Phone: 659-7224 VTL 3/-f /2-0 Form 10-404 Revised 4/2017 WW!M J FEB 0 5 2020 Submit Original Only Date Event Summary 12/08/19 (AC EVAL) : MIT -IA FAILED TO 3000 PSI, IA LLR 4.5 GPM 12/16/1 PROGRESS.ECTIVE. IN 01/05/20 SET 2.29" P2P @ 7388' RKB. PERFORMED CMIT-TxIA TO 3000 PSI **PASS** 01/08/20 01 SET 2.29" P2P PACKER SPACER ANCHOR ASSEMBLY @ 7370' RKB. CMIT TBG x IA 3000 ****PASS*** SET LOWER 2.29" P2P @ 5573' RKB 2.29" U 02/02/20 (SW) SW (Brian Bixby) MITIA post patch Passed to 3310 psi. IGS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submitto: urn reco(talaska.gov; AOGCC. Inspectors(0lialaska,riov; phoebe.brooks(dlalaska.cov OPERATOR: ConocoPhillips Alaska Inc, FIELD UNIT/PAD: Kuparuk/KRU/IB Pad DATE: 02/02/20 OPERATOR REP: Beck / Caudle AOGCC REP: Brian Bixby chris.wallaceitialaska.00v Well iB-04 Pressures: Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min. O= Other (describe in Notes) PTD 1810650 Type Inj W Tubing 2226 2218 2223 2225 O = Other (describe in notes) Type Test P Packer TVD 6180 BBLPump 3.0 IA 550 3310 3270 3260 Interval O Test psi 3000 1 BBL Return 1 3.1 OA 194 384 391 388 Result P Notes: MITIA post patch per Sundry # 319-585 at maximum anticipatetl injection pressure per A102C.043 Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD SBI -Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type IN Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Cotles Result Codes W=Water P=Pressure Test 1=Initial Test P=Pass G=Gas O= Other (describe in Notes) 4=Four Year Gyde F=Fail a = go, V = Required by Variance I = lnoondusiye I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Form 10-426 (Revised 0112017) MIT KRU 18-04 02-02-20.xlsx KUP INJ WELLNAME 113-04 WELLBORE 1B-04 C0110C0�11��Ip5 A4vgka, InD. INellAttribut� MaxAngie&MD TD T& Fl. Name WCllbore APl/DWI W¢IlCore SYlua Icl (°) MD (RK31 KIIPARDK RIVER UNIT 50629205906 INJ 8.90 8,200.00 or mKB1 78 .10 8,4100 Comment Nx3(ppml D84 /nnohtlml EnO Date KB-Grtl 12) qlg geleabe Dah SSSV: TROP Last WO: 32.48 714/1981 +am.lrz.✓mxoTmss NM Last Tag Ve,l'celecMmn¢(anual ...Iran DeptM1(IIKB) and oab 1Vhllbore Latl MOG Oy Lest Teo: RKB(Eo 4' of RalhOle) ],862.0 101252019 10-04 xemheej CONOVLTOli: i0�0.PA.0 ps E vLvd Ab.6 WsuFT;2M2a .ACE173GxAlII- Gras UFT;x49L1 W6uFr; 4.wv Pakn Pachn S,YAo WRING LEAK: 45595 space,ppNs,554.0 P.Wpacte,sirce WSUW;5.n5.T W6UFr:S.105. OAS LIFr:6AM4 GAS UFT: 8616.x 006 UFT, T.S9.0 paha PCler.7.110. TURING UEM, 7, . 6wrorPipV.3Ta.o Pax"Packm:T,eer. PSR; 7,3ed PACXER y.9R0 1wEMION:7.xb.y INIECn0N;7,5Le7 fwaD;?Rwo IPERF),95a,0.7.810o IWEOTIDN:?Gt9 LOG4TDN:7,656d vAG(ERp.C53s x1PPtEp.61a.7 SOS, ?aa (PERF; 7.]..0.?R120- (PERF: 7.613673580 RSKsatc PROWCTIOI, M TAY25- Last Rev Reason Annotate. End Date Wenbore bb<Motl ay Rev Reason: Replaced DV 1/22/2020 I 15-00 lerouep Casing Strings CONDUCTO eon 16 15.06JID (in) Top 121191 Set DepM (X1(61 Set Depin (NG)... WtlLen 6...Gnde mp Tnreia CONDUCTOR i6 15.06 300 80.6 00.0 VeRL Hr WELDED Caslnp Desc2pLbn OU (In) ID pnl Tep(2K91 Set DepN (2K6) Se+Depro(No1... Wtllan p.. Grade ToplRreatl BURFACE 103/4 9.95 29.3 2,8]1.2 2,fi)5.0 4550 KSS BUTT caukh DescdptM 10D(R) ID(In) TOp Feel SetoepM deal Set De Per UVD1,.. rel 0... Grade TopThmatl PRODUCTION ] 620 267 8,362.5 6,833.9 26.06 K-55 BTC Tu n String9 Tubing Deec,lpllon eel, a+a._ ID (In1 lopl G, or Dept. I2..5d091P (NO)(... 4YI(INm G,551 Tep LOnnecllOn TUBING 2718 2.44 1].9 ].69)2 6,389.3 650 J-55 EUEBROMOD Completion Details Top(TV0) Topincl earn Top(2K6) (2X6) F) here Des Com 10g) 17.9 17,9 005 HANGER MCEVOY HANGER 28]5 1,921.6 1,896.9 22.34 SARETVVLV CAMCO RIA -SSA SAFETY VALVE 2.313 7,3903 6,1]1.2 43.01 PER BAKER CS PER W/ RETRIEVABLE THREAD 4.250 ),402.0 6,1]9.) 43.18 PACKER BAKER He RETRIEVABLE PACKER HYD 3.000 ],544.3 6,2820 44.]5 01ASTRING BLAST RINGS (3) 2,441 7,658.1 6.3622 45.82 LOCATOR OMER CL LOCATOR 2.406 7,650.5 6,362.4 4502 PACKM OMER WL SET IB PERMENANTPACKER 3.000 7,679.7 6.3.4.2 460> NIPPLE CAMCOO NIPPLE NO GO 2.250 16963 6,388.7 46.26 505 BAKER SHEAR OUT SUB 2,441 Other In Hole(Winaline retrievable plugs, valves, pumps, fish, etc.) Top TAd Top and Top fdK31 Ink.) P) Des Com Run Dare m(m) 3,550.0 4,714.1 36.84 Patch Packer 2.29-P2P(CPP2870pI) w119' of Spacer Pipeaod 1/912020 1.380 Ander Latch (CPAL287026). CAL 23' Max OD 2.29" 5,554.0 4,717.3 36826pecer Pipe 21/19 P-110 Spacer Pipe 119)2020 I.Wo 5,556.5 4,719.3 36.80 TUBING LEAK TUBING LEAK IDENTIFIED @ 5558.5' RKB 11/111201 4 5,5]3.0 4,]32.6 36.69 Paldl Pecker 229' P2P(CPMMM). OAL P Max OD 229" 1WO20 1.380 7,370.0 6,156.3 42.71 Patch Packer 2. 9 PPP(CPP28M49)w/ 14' d Spacer Pipe end 11012020 1.380 Ancear Latch(CPAL287029). GAL 19 Max OD 2.29" ),3)4.0 8,159.3 42.76 0 acer Pie 21/1WP- p P 110Spacer Pipe 1182020 1.600 7.380.0 8,163.7 42.85 TUBINGLEAK TUBING LEN( IDENTIFIED @ 7380' She 12/12201 9 7,38a0 8,169.5 ch 42.97 PatPacker 2.29' 1`21`, GAL 3,59, CPp207101 1/42020 1.380 8,3620 6,8335 48.2] FISH 3WRP SLIPS ANO NO CONE 3/52015 Perforations &Slab Top I.Ka1 atm 2Ka ( ) Top RV D1 BIm INo1 (KKB) (2Ka1 United! Zone Slwt Lens (snots/rt bah ) Type Com ].550.0 ],610.0 6,20fi.1 &328.562, C-2,UNIT B, 10-04 6Ii/1986 12.0 (PERF fiO FT nD Ci Send ),]86.0 ],802.0 fi,450.0 Q4W.B A-5, 1B -m N1I19B5 12.0 IPERF ],812.0 6,46]5 -7.498.4 A-0, 10-04 N1119B5 12.0 (PERF Frac Summary shn Da+e Neuron Destined OR Proppannn mematm Oq 8/52001 S+p• WWO0h Top Deptll (2KR) &,610.0 Llnkro FlW43yAvm Vd Chin @bl) Vol3lurty (bbB I &52001 ),550.0 ),610.0 Mandrel Inserts eI tl Top KIS Valve LBhn PmiRlze TRO R. N Top(RKE) (-H0) Make MWel OD(In) sew Type Typ3 Gnl (psB Run Data Co. 1 2,0Q2.01,989.6 CAMCO KBUG 1 GAS LIFT DMY BK 0000 0.0 7/2NUED 3:00 2 3,691.1 3,288.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/2311990 2;00 3 4,801.) 4,129.2 CA ACO KBUG 1 MUFF DMV BK 0.000 00 1123'2020 8110 4 5,5)57 6,]34.7 CPMCO KBUG 1 GAS LIFT DMY BK D.OW 0.0 ]2X1990 900 5 6,105.0 5,159.9 CAMCO KBUG 1 GAS LIFT DMV BK O.OW 0.0 MV1990 111:00 6 6,4784 5,4580 CAMCO KBUG 1 GASLIFT DMV BK 0000 0.0 712X19909:60 ) 6916.2 5,810.5 CAMCO KBUG 1 GAS LIFT MYBK 0000 0.0 723/1990 8:00 0 7353D 6,143.8 CAMCO KBUG 1 GAS LIFT IT BK DOW 0.0 1142020 4'.30 8 ),438.] 6,2064 CAMCO SEW INJ DMY BIX 9.000 0.0 426/2006 1 7.50fi] 6,255.3 CAMCO KBUG / INJ My BK 0,000 0.0 81912008 0 1 ],641.9 6,350.8 CAMCG KBUG 1 IW MY BK 0.000 0.0 N/2010 1 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 3, 2020 Commissioner Jessie Chmielowski Alaska Oil -and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patches set across known tubing leaks in injector KRU 113-04 (PTD 181-065). Please contact Jan Byme or myself at 659-7224 if you have any questions. Sincerer, Paul Duffy Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-476Ofax 1A-22 1 B-04 RIVER Delivered to: yt y/ AOGCC ATTN: N atural Resou rces Tech n icia n II i) Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 -- Anchorage, AK 99501 WL RIVER WL I LDL RIVER Memory PPRO RIVER WL r.r—i— 18 1065 3 195 6 TRANSMITrALDATE24Jan-20 24Jan20-IW 01 FIELD 16 -Dec -19 FIELD 18 -Dec -19 FIELD 19 -Dec -19 1A-17 50-029-22102.00 DWUJ-00159 KUPARUK RIVER WL LDL 1A-15 50-029-20711-00 EOSH-00128 KUPARUK RIVER WL FINAL FIELI LDL I FINAL FIELI X ame Sign ture Date return via courier or sign/scan and email a copy to S mberger and CPAI. 'TSPr1ntCenter2s11bcom Tom .Osterkam conoco hill' s.com Schlumberger -Private 1 1 A Transmittal Receipt signature confirms that package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. " specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. Originated: Schlumberger Delivered to: PTS - PRINTCENTER ' 47 AOGCC 6411A Street '} ATTN: Natural Resources Technician 11 Anchorage, AK 99518 j Alaska Oil& Gas Conservation Commision (907)273-1700 main (907)273-4760 fax 333 W. 7th Ave, Suite 100--A& Anchorage, AK 99501 RIVER I WL I Caliper I FINAL 18 1065 TRANSMITTALDATE TRANSMITTAL# 30-04 1 50.029-21826-00 EOSH-00123 KUPARUK RIVER WL Caliper P FINAL FIELD 13 -Dec -19 1 1B-04 50-029-20595-00 EOSH-00126 KUPARUK RIVER WL LDL 2N347 50.103.20337.00 EDEA -00037 KUPARUK RIVER Memory PPROF FINAL FIELD 16 -Dec -19 1 1B-04 50-029-20595-00 DWUJ-00152 KUPARUK RIVER WL FINAL FIELD 18 -Dec -19 1 Caliper FINAL FIELD 19 -Dec -19 1 1A-17 50-029-22102-00 DWUJ-00159 KUPARUK RIVER WL 1A-15 50-029-20711-00 EOSH-00128 KUPARUK RIVER WL LDL FINAL FIELD 31-Dec1 LDL FINAL FIELD 1 -Jan -2020 1 Imittal Receip N J \ - l�->\ /) A Transmittal Receipt signature confirms that a package (box, IL envelope, etc.) has been received and the contents of the X (_ Name Sign ture O package have been verified to match the media noted above. " Date specific content of the CDs and/or hardcopy prints may or may e return via courier or sign/scan and email a copy to S mberger and CPAI. not have been verified for correctness or quality level at this point.aPTSPrintCenter slbcom Tom.Oste.ooco hilli s.com SLRAuditor- ZrW Schlumberger -Private Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 &2 <n1617@conocophillips.com> Sent: Monday, January 13, 2020 11:35 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: Kuparuk Injector 1 B-04 (PTD# 181-065) Suspected IAxOA communication Attachments: 1 B-04 90 Day TIO plot.JP 3, 1 B-04.pdf Chris- Kuparuk Injector 113-04 (PTD# 181-065) has shown IAxOA communication while preparing the well for the DAS/DTS logging. While displacing the IA with N2 the OA showed a sudden pressure response. DHD was on location and attempted unsuccessful repairs on the IC pack offs. At this point in time it is suspected that the leak is caused by the nitrogen application to the IA. Once the IA was displaced with nitrogen, Slick line replaced the dummy valve into GLM # 3 and DHD performed a passing IA/OA DDT. The well will be closely monitored until the DAS/DTS logging has been completed to ensure the IA and OA pressures are maintained within regulation. The DAS/DTS logging procedure calls for the IA to be charged with N2 to varying pressures so the OA will be held on an open bleed while the logging is in progress. Once the logging has been completed the IA will be returned to its normal operating condition and once online the OA will be monitored for 30 days to verify IAxOA integrity. If the well continues to show signs of IAxOA, DHD will conduct diagnostics to investigate repair options. Please let me know if you have any questions or disagree with the plan. Attached are copies of the current 90 day TIO plot and well bore schematic. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM Cwioca`PNIIips THE STATE °fALASKA. GOVERNOR MIKE DUNLEAVY Dusty Freeborn Well Integrity Compliance Specialist ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, KRU 1B-04 Permit to Drill Number: 181-065 Sundry Number: 319-585 Dear Mr. Freeborn: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 ww W. a o g c c. a I a s ka. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 'o Jerem .Price Commissioner DATED this2 day of January, 2020. IBDMS/��JAN 031020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 DEC 2 3 2019 1 2--t(li kv� A©Ga/, C 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well E Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ElPerforate New Pool ElRe-enterSusp Well ❑ Alter Casing 11Other: Tubing patches 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 181-065 - 3. Address: Stratigraphic ❑ Service 0 • 6. API Number: P.O. Box 100360, Anchorage, Alaska 99510 50-029-20595-00 r2 Z � 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑- KRU 1B-04 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025648 I Kuparuk River Field/ Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total �Depth MD (ft): Total/Depth/TVD (ft): Effective �Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): Casing Length ISize MD TVD Burst Collapse Conductor 50 16 80 80 Surface 2842 10.75 2871 2675 Production 8336 7 -"Tubing 8363 6834 Perforation Depth MD (ft): Perforation Depth TVD Size: Tubing Grade: Tubing MD (ft): 7550-7610,7786-7802,7812- 6286-6329,6450-6461,6468- 2.875 J-55 7696 7858 6498 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Safety Valve= Camco TRCP-1A SSA safety valve MD= 1922' TVD= 1897' Packer= Baker HB Retrievable Packer HYD MD= 7402' TVD= 6180' Packer- Baker WL set 1 B Permanent Packer MD= 7659' TVD= 6362' 12. Attachments: Proposal Summary D Wellbore schematic v 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: Deo -19 Commencing Operations: OIL ❑ WINJ ❑ WDSPL L] Suspended El GAS ❑ WAG GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Dusty Freeborn Contact Name: Dusty Freeborn/Jan Byrne Authorized Title: Well Integrity Compliance Specialist Contact Email: 1\11617 conoco hllli S.COrri Contact Phone: 907-659-7224 Authorized Signature: Date: 21 Dec 19 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test 12" Location Clearance ❑ Other: iBDMSL�t/JIAN 0 3 2010 ,,_,/ Post Initial Injection MIT Req'd? Yes Lv� No /� Spacing Exception Required? Yes No ,LI—d,/ Subsequent Form Required:q� /✓9— �UT APPROVED BY Approved by: COMMISSIONER THE COMMISSION tate: 2 I seI Liv " I-iz1z'-1c9 Form 10-403 Revised 4/2017 Approved applicaocIG I NA rm the date of approval. Submil Form antl Attachments in Duplicate KRU 113-04 (PTD# 181-065) Description Summary of Proposal Well Work Justification & Objectives (and date required if appropriate): 1B-04 was reported to the AOGCC for an increase in IA pressure. The existing tubing patch was pulled and a leak below the known tubing leak was identified. 2 tubing patches need to be set to cover the tubing leaks at 5557' and 7380' to repair tubing x inner annulus integrity. Risk/Job Concerns: - DO NOT CONDUCT WORK UNTIL 10-403 HAS BEEN APPROVED - AIO 2C.043 for TAA while on gas injection - Two tubing leaks; 5557' and 7380' - OA shoe leak - 2 7/8" tubing. Steps: Digital Slickline 1. Brush and flush patch setting areas of 5500'-5600' and 7300'-7400'. 2. Set 2 7/8" Quadco P2P at 7388' (just above PBR at 7390') Set test tool in P2P. 3. Set catcher on test tool and pull DMY valve from station #8 (7353'). 4. Pump 200 bbls of 1% CRW SW followed by 75 bbls of diesel down tubing taking returns up the IA. U- tube to freeze protect MA. 5. Reset dummy valve in station #8 (7353'). Pull and replace if set is abnormal due to inability to test dummy valve. 6. Perform CMIT-TxIA to 3000 psi. Record initial, 15 and 30 min T/I/O pressures. A. If CMIT-TxIA passes, pull catcher and test tool and proceed to step 7. B. If CMIT-TxIA fails, trouble shoot failure mechanism. 7. Set upper patch assembly mid P2P element at 7370'. Overall patch length should be 18'. S. Set test tool in upper P2P at 7370' and perform CMIT-TxIA to 3000 psi. Record initial, 15 and 30 min T/I/O pressures A. If CMIT-TxIA passes, pull test tool and proceed to step 9. B. If CMIT-TxIA fails, trouble shoot failure mechanism. 9. Set 2 7/8" Quadco P2P at 5573'. Set test tool in P2P. 10. Perform CMIT-TxIA to 3000 psi. Record initial, 15 and 30 min T/I/O pressures. A. If CMIT-TxIA passes, pull test tool and proceed to step 11. B. If CMIT-TxIA fails, trouble shoot failure mechanism. 11. Set upper patch assembly mid P2P element at 5550'. Overall patch length should be 23'. 12. Perform MIT -IA to 3000 psi. Record initial, 15 and 30 min T/I/O pressures A. If MIT -IA passes, pull test tool and proceed to step 13. B. If MIT -IA fails, trouble shoot failure mechanism. 13. Turn well over to operations. 14. AOGCC witnessed MIT -IA to be performed once on injection and stabilized. KUP INJ WELLNAME 1B-04 WELLBORE 16.04 ConocoPhilhps Well Attributes I Max Angle&MD TD AIe31ca.InG. FielL Name VIellbore APIIVWI Wellbore Status Incl l') MpIttKBI KUPARUK RIVER UNn 500292059500 INJ 08.90 8.20000 Act DLa InKBJ 8,9100 $C$!/TRDP H35(ppm) Dale pnno!bfion Entl pato KD-D,tl I., Rlg Release pa,e LabtWG- 32 A@ 7/14/1981 1600, "u V1019559.01 PM Last Tag Va,llal acM1emuld'supel) An-pition OepIM1 IM1N9) Welllpre Last Mod By Oa[e In6Y1 ay RKB (Est 4'O(RBPole1 { Iefi20102512019 zembeej rw46Ea: 29 Last Rev Reason - AnnoGOon End Dma wellEore Last Moa By Rev Pennon, LDL, 2M leak at ,339 RKB, Known Leak at 5,5566RKB TURV7AI9 Dbezr Casing Strings basmgDeacnpbon GD (1n) ID (in) Top (nKe) selpepN nNe) set DeptM1 rvp). wuLan p._vraae ropTh real CONDUCTOR 16 15.06 30.0 @9.0 800 65.00 H-40 WELDED Casing oes,d,Un OD an) 1a tint Top (BKB) Get DeplM1 nlKB) bel p, up IN01.. WVLen e... 6rale Top TM1reatl SURFACE 10314 995 253 2871.2 26]50 4551 K-55 BUTT CONWCTOR', 3007130 c asing Descrlpllbn OD(Ip) Ip On) Top (M1KH) semepun in-, ....... M1(Np) WVLen (I. Grate TnpTry,eatl PRODUCTION ] fi20 287 8,3625 58339 2600 K-55 BTC sAFExvI.v; I.nlfi Tubing Sfring5 cab LIFT; x,Due TobmgDaae,iplmn smmg Ma... m(n) Top (nxel satoopm(tt„sat Depm (TVD)(.. yA(Iwtt) Grade Tbpeonneaion TUBING 27;8 244 7.9 ],69].2 53893 650 7.55 EUEBRDAOD Completion Details Top LIKE) TottKel) To'llncl@m Des Nominal 0 (In) 779 179 0.05 HANGER MCEVOYHANGER 2875 suRPACE; xv3Yw12- 1,9216 1,8969 22.34 SAFETY V L V Ovy UTRUP-I A -BSA SAFETY VALVE 2.313 Deal 111.E.L1 7,390.3 B,1712 4301 PER BAKER CB PON W/ REPRIEVABLE THREAD 4.250 ],4020 6,1797 A318 PACKER BAKER HB RETRIEVABLE PACKER HYD 3.Opp 7,5443 6,2820 4475 BOAST RING BLAST PINES (3)) 2.441 ],6581 63622 45.82 LOCATORBIJCER CL LOCATOR 2406 GAG LIFT: 4.WL7 7658.5 6,3624 45.82 PACKER 'BAKER WL SEI' 1B PERMENANT PACKER 3.000 76797 6377LE 2 460] NIPPCAMCODNIPPLE NO GO 2.250 75963 UE 5,5565 6.3867 45.28 SO6 BAKER SHEAR OUT SDB 2,441 GAS LIFT, 5.5757 Other In Hole (Wirellne, retrievable plugs, valves, pumps, fish, etc.) lop(TV0) Topinel OAS UFT; 6, 115.0 Lop LING) ttK01 L) Des Run Oa[e to (in) 5556.5 4,7193 3680 LEAK USI NG DPBUOWN PASSES ALONG W/STATDID 0.000 STOPS. LEAK WAS FOUND Cd 5556 TRKB Gas LIFT; 6.ne.4 ],380.0 61637 42.85 LEAK 42 UBING UP&DOWN PASSES ALONG WI STATION 0.000 51 OPS, SECOND TBG LEAK WAS FOUND @ ]380' d3i512015 RKB GAS u6T; 6916g 8,3620 68335 482] FISH 3 WRP SLI PS AND NOSE CONE GASUF!'. 7.351.9 Perforations & Slots slot LEAK MI; 7,3®.o Dens Top(KKB Him(nK9)lrvD) (Anolsm 1 Kel Linked mase Data ) TYpe cum PeR;"ge,1 7.550.0 7,61003285 6/1/1985 12.0 J6.4675 /PERF 6OFTno C1 SSM .Es A,4DZD ],7850 ],802.0460% 9111985 12.0 /PART INJESL10N: 7.0]8,] ],812.0 ],8580498.4 91/1985 12.0 (PERF Frac Summary Start Date PmpWnt Designed ([I) ProppantlnPo,malldd VN 9 2661 IWEttloN; 9.501,7 stgX Stan Dem T1PD1PRgFe) BIm1nKe) vol nears (eGq vol slnrty (bep 1 8152001 7,5500 7,610.0 Mandrel Inserts But AS on N Top (nKB lop(ND) Valee Isicn Pou Slze TRO Run RLKB) Make Model ODIN) Be, TyPo TYPe Tin (pbl) Run Date com 1 2.0228 19096 0 CO' -BB' 1 GAS LIFT DAY BK 0.000 00 7/2WJ990 3'.00 IPERr; 7,Yq.DAbtO0 HPBD; 7..,,0 2 e,fi911 3,2A8fi CAMCO KBUG 1 GAS LIFT DMY BK 0.000 eD ]/2311990 200 3 4.8017 41292 rAMCO K608 1 GASL FT DMY BK 0000 p.p 121912019 4 5,5757 4,7347 CADDO KBUG 1 GqS HET DMY BK 0.000 0.0 7123/1990 900 5 6,1050 5,1599 CAMCO KBUG 1 GAS LIFT DMV BK 0.000 O0 72311990 1000 6 6,4784 5.4500 CAMCO KBUG 11 GAS LIFT AMY BK 0.000 00 ]/2311990 9'.00 7 6,916.2 5,810.5 CAMOO KBUG i GAS LI FT SKY BK 0000 0.0 7123/1990 8:00 B 7,353.061438 O ,1438 CAMEKBUG 1 GAS GET DMV BK 0000 OF 12,2312018 INJECTION', 7.8019 9 ],438] 621154 CAMCO KRUG 1 INJ MY IBEK 1 0.000 00 41 L0('ATOR2650.t i 2506.7 6,2553 CAMCO KBUG 1 INJ UMY BK 0.000 0.0 821/2008 PACKER; ],65es p 1 7,6419 6,350,2 CAMOO KBUG 1 INJDMV BK 0000 0.0 20/2010 1 MPPLE7M7 Notes: General &Safety Entl Dem aomtlon 8/92010 NOTE'View Schematic w/ Alaska Schema0D90(3 PAGES) ' 6Ob; ].696.3 IPERF: ARB 0. 7=0- IPERF, 7.e1207 s5e.0� PROODCPON: 36.]83625 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 21 December 2019 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 113-04 (PTD 181-065) to reset one retrievable tubing patch and set a second tubing patch to regain tubing by inner annulus integrity. Please contact Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity Compliance Specialist ConocoPhillips Alaska, Inc. Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophilIips.com> Sent: Saturday, December 7, 2019 4:37 PM To: Wallace, Chris D (CED) Cc CPA Wells Supt Subject: KRU 16-04 (PTD 181-0651 report of suspect TxIA communication Attachments: 1 B-04.pdf; 1 B-04 90 day TIO trend 12-7-19.pdf Chris, Kuparuk injector 1B-04 (PTD 181-065) has been reported by operations to be exhibiting suspect TxIA communication due to IA pressure increase. Operations has shut in and freeze protected the well. DHD will be mobilized tomorrow (weather dependent) to do initial diagnostics. The proper paperwork for continued injection or repair will be submitted when a path forward has been determined. Attached is a wellbore schematic and a 90 day TIO plot. Please let us know if you have any questions or disagree with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity i£ Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAMCanoc-mimps t MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday, June 26, 2019 P.I. Supervisor `\ �Cb Ila SUBJECT: Mechanical Integrity Tests �� ConoccPhillips Alaska, Inc. IB -04 FROM: Lou Laubenstein KUPARUK R1V UNIT IB -04 Petroleum Inspector Ste: Inspector Reviewed By: � P.I. Supry J Dlz— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IB -04 Insp Num: mitLOL190611081601 Rel Insp Num: API Well Number 50-029-20595-00-00 Inspector Name: Lou Laubenstein Permit Number: 181-065-0 Inspection Date: 6/10/2019 Wednesday, June 26, 2019 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 4� Min 60 Min Well Il1-04 - Type Inj w - TVD (,iso Tubing 2482 - 248) 2482 2iV PTD i110650 " Type Test SPT Test psi 3000 IA 550 3100 3230 - '1230 BBL Pumped: 28 - BBL Returned: 27 - OA 125 245 _45 245 Interval RFQVAR P/F -P �— Notes: MIT -IA to maximum anticipated injection pressure per A10 2C.043 ✓ Wednesday, June 26, 2019 Page I of I 0 ! MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 03,2017 TO: Jim Regg K .--/a/(7 SUBJECT: Mechanical Integrity Tests P.I.Supervisor 1 � b CONOCOPHILLIPS ALASKA INC 1B-04 FROM: Lou Laubenstein KUPARUK RIV UNIT 1B-04 Petroleum Inspector Src: Inspector Reviewed B�y:nn P.I.Supry J -- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1B-04 API Well Number 50-029-20595-00-00 Inspector Name: Lou Laubenstein Permit Number: 181-065-0 Inspection Date: 4/22/2017 Insp Num: mitLOL170423070147 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I IB-04 - Type Inj I W 'TVD 6180 - Tubing 2531 2530 - 2536 . 2535 - -- SPT Test psi 3000 IA 790 3320 - 3260 - 3245 - PTD 1810650 Type Test T 2.8 BBL Returned: 2.8 - OA 177 240" 248 - 250 BBL Pumped: 1 1 I Interval REQVAR P/F 1 P V Notes: MITIA to MAIP per AIO 2C.043 SCANNED AUG 2 4 2U Page 1 of l Wednesday,May 03,2017 STATE OF ALASKA ALPIPA OIL AND GAS CONSERVATION COM.SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdow n r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: tbg patch Fri 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: _ConocoPhillips Alaska, Inc. Development r Exploratory r 181-0650 3.Address: 6.API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service 50-029-20595-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL25648 KRU 1B-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8410 feet Plugs(measured) None true vertical 6865 feet Junk(measured) None Effective Depth measured 7916 feet Packer(measured) 5550, 5553, 5570, 7402, 7659 true vertical 6537 feet (true vertical) 4714,4717,4730, 6180, 6362 Casing Length Size MD TVD Burst Collapse CONDUCTOR 50' 16 80' 80' SURFACE 2842' 10 3/4 2871' 2675' PRODUCTION 8336' 7 8363' 6834' RECEIVED Perforation depth: Measured depth: 7550-7610, 7786-7802,7812-7858 JAN 2 5 2017 True Vertical Depth: 6286-6329, 6450-6461, 6468-6498 AOGCC Tubing(size,grade,MD,and TVD) 2 7/8 ,J-55, 7696 MD,6389 TVD Packers&SSSV(type,MD,and TVD) SAFETY VLV=CAMCO TRDP-1A-SSA SAFETY VALVE @ 1922 MD and 1897 TVD PACKER=2.28"OLGOONIK PARAGON 2 PACKER W/PATCH @ 5550 MD and 4714 TVD PATCH= 16'SPACER PIPE @ 5553 MD and 4717 TVD PACKER=2.28"OLGOONIK PARAGON 2 PACKER W/PATCH @ 5570 MD and 4730 TVD PACKER=BAKER HB RETRIEVABLE PACKER HYD @ 7402 MD and 6180 TVD PACKER=BAKER WL SET 1B PERMENANT PACKER @ 7659 MD and 6362 TVD 12.Stimulation or cement squeeze summary: N/A r, Intervals treated(measured): SCANNED APP 1 8 ` l?, Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p" Exploratory r Development r Service Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG P- GINJr SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-587 Contact Kelly Lyons/Brent Roger Email: n1617@conocophillips.com Printed Name Ily Lyons ®'- Title: NSK Well Integrity Supervisor Signature l O Phone:659-7224 Date 1-23-17 Form 10-404 Revis 5/2015 1/7"L 3/2% 01,-' RBDMS by JAN 2 5 2017 Submit Original Only • • Iv RECEIVED ConocoPhillips JAN 2 5 2017 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 23, 2017 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. KRU well 1B-04 (PTD 181-065) for a retrievable patch which was pulled and reset in the tubing above the packer. Work was performed under Sundry#316-587. Please call Brent Rogers or myself at 659-7224 if you have any questions. Sincerely, Kelly Lyons Well Integrity Supervisor Attachments • • 1 B-04 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/21/16 DRIFTED DMY PATCH ASSY TO 5550' RKB. PULLED UPPER PII PACKER, SPACEP PIPE, ANCHOR LATCH @ SAME. PULLED LOWER PII PACKER @ 5570' RKB. BRUSHED & FLUSHED PATCH AREA f/5500'TO 5570' SLM AND TBG f/7300'TO 7390' SLM. WITH KOT &CHECK SET CORRELATED TO GLM ©7353' RKB. SET F-STOP @ 7390' RKB. IN PROGRESS. 12/22/16 SET K2 PLUG ON F-STOP @ 7390' RKB. SET SLIP STOP CATCHER ON K2 PLUG. PULLED DV @ 7353' RKB. LOADED TBG/IA WITH 198 BBLS CISW AND 72 BBLS DIESEL (U-TUBE FOR FREEZE PROTECT). SET DV @ 7353' RKB. IN PROGRESS. 12/23/16 CHECK SET DV @ 7353' RKB. PULLED CATCHER, K2 PLUG & F-STOP @ 7390' RKB. LOG STATION STOP FOR MaxFire PROGRAM (2380 PSI / 104 DEG) @ 5576' RKB. IN PROGRESS. 12/24/16 SET 2.29" PII PACKER (#CPP287020) MID-ELEMENT @ 5572' RKB. COMBO MIT TBG x IA TO 2500 (PASS). SET 2.29" PII PKR ((#CPP287017), SPACER PIPE, ANCHOR LATCH (#CPAL287010) MID ELEMENT @ 5549' RKB. MIT IA TO 3000 (PASS). JOB COMPLETE CORRELATED TO SLB LDL DATED 11-NOV-2014. **CMIT against lower packer 1st attempt fail: preTIO=1100/610/40/0, initial=2500/2150/40/0, 15min=2400/2100/4010, 30min=2300/2000/40/0 CMIT 2nd attempt pass: preTIO=2300/2000/40/0, initial=2510/2200/40/0, 15min=2425/2125/4010, 30min=2425/2125/40/0 MITIA pass: preTIO=925/590/40/0, initial=925/3000/40/0, 15min=925/2950/40/0, 30min=925/2950/40/0** 01/08/17 (SW) MITIA Chuck Scheve Passed to 3020 psi. Initial T/I/O/OO =2245/1150/386/0, IA FL @ SF. LRS pressured IA with 1.8 bbl diesel to T/I/O = 2245/3020/452/0 15 min monitor: 2203/2960/459/0 (-60 psi). 30 min monitor: 2225/2950/459/0 (-10 psi). LRS bled IA(fluid) to 1150 psi (1.7 bbl). LRS continued bleeding IA(fluid)for total of 5 min to 800 psi. Final T/I/O/OO =2241/800/371/0 Summary After well experienced slow TxIA communication while on gas injection, an already-existing retrievable tubing patch across a known leak at 5557'was pulled and replaced, in hopes that the slow communication on gas was due to the patch leaking. The 23' Statewide TTS retrievable tbg patch demonstrated its integrity with a witnessed MITIA on 1/8/17 after the well was returned to injection. ! • 1B-04 DESCRIPTION OF WORK COMPLETED SUMMARY KUP INJ • 1B-04 ConocoPhillips s • Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UW Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) i,aci ®tom 500292059500 KUPARUK RIVER UNIT INJ 48.90 8,200.00 8,410.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 10-04.1/23/201710:03.44 AM SSSV:TRDP Last WO: _ 32.48 7/14/1981 Verliczl schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,842.0 8/2/2014 Rev Reason:PULLED PATCH,GLV C/O,SET ppmven 1/23/2017 HANGER;17.9 PATCH Casing Strings Casing Description OD(in) ID/in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ' CONDUCTOR 16 15.062 30.0 80.0 80.0 65.00 H-40 WELDED • Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WI/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 29.3 2,871.2 2,675.0 45.50 K-55 BUTT i Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 26.7 8,362.5 6,833.9 26.00 K-55 BTC T - ` Tubing Strings ..,. 56.10, - Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/Ft) Grade Top Connection TUBING 2 7/8 2.441 17.9 7,6972 6,389.3 6.50 J-55 EUE8RDMOD SAA CONDUCTOR;30.0-80.0- Completion Details Nominal ID SAFETY VLV;1,921.6 r Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 1r 17.9 17.9 0.05 HANGER MCEVOY HANGER 2.875 GAS LIFT;2,022.8 1,921.6 1,896.9 22.34 SAFETY VLV CAMCO TRDP-IA-SSA SAFETY VALVE 2.313 7,390.3 6,171.2 43.01 PBR BAKER CB PBR W/RETRIEVABLE THREAD 4.250 7,402.0 6,179.7 43.18 PACKER BAKER HB RETRIEVABLE PACKER HYD 3.000 7,544.3 6,282.0 44.75 BLAST RING BLAST RINGS(3) 2.441 I 7,658.1 6,362.2 45.82 LOCATOR BAKER CL LOCATOR 2.406 SURFACE;29.3-2,871.2 7,658.5 6,362.4 45.82 PACKER BAKER WL SET 16 PERMENANT PACKER 3.000 7,679.7 6,377.2 46.07'NIPPLE CAMCO D NIPPLE NO GO 2.250 GAS LIFT;5691.1 la 7,696.3 6,388.7 46.26 SOS BAKER SHEAR OUT SUB 2.441 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) I°) Des Com Run Date ID(in) 5,549.0 4,713.3 36.85 PATCH 2.29"PII PACKER((#CPP287017),SPACER PIPE, 12/24/2016 1.380 GAS LIFT;4,801.7ill ANCHOR LATCH(#CPAL287010),23.64'OAL/ 1.38"ID) 5,572.0 4,731.7 36.70 PATCH 2.29"PII PACKER(#CPP287020/3.55'OAL/1.38" 12/24/2016 1.380 PATCH;5,549.0 ID) 8,362.0 6,833.5 4827 FISH 3 WRP SLIPS AND NOSE CONE 3/5/2015 PATCH;5,572.0 Perforations&Slots Shot GAS LIFT;5,575.7 ; Dens Top(WD) Btm(TVD) (shots/f Top(1168) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,550.0 7,610.0 6,286.1 6,328.5 C-2,C-2, 6/1/1985 12.0 IPERF 60 FT no Cl Sand GAS LIFT;6,105.0 UNIT B,1B- 04 • 7,786.0 7,802.0 6,450.0 6,460.8'A-5,1B-04 6/1/1985 12.0 IPERF GAS LIFT;6,478.4 7,812.0 7,658.0 6,467.5 6,498.4 A-4,1B-04 6/1/1985 12.0 IPERF GAS LIFT;6.916.2 Stimulations&Treatments Proppant Designed(Ib) Proppant In Formation(Ib) Date 8/5/2001 GAS LIFT;7,353.0 1 Stimulations&Treatments Min Top Max Btm Top(WD) Btm(TVD) Vol Clean Vol Slurry Depth(ftKB) Depth(ftKB) (ftKB) (ftKB) Stg# Date Stim/Treat Fluid Pump(bbl) (bbl) PBR;7,390.3 .;, I 7,550.0 7,610.0 6,286.1 6,328.5 1 8/5/2001 PACKER;7.402.0 Mandrel Inserts St ati on INJECTION;7,438.7 N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Com 1 2,022.8 1,989.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 3:00 2 3,691.1 3,288.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 2:00 3 4,801.7 4,129.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 7:00 INJECTION;7,506.7 4 5,575.7 4,734.7 CAMCO KBUG 1 GAS LIFT DMY 'BK 0.000 0.0 7/23/1990 9:00 5 6,105.0 5,159.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 10:00 6 6,478.4 5,458.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 9:00 7 6,916.2 5,810.5 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 8:00 HPBD;7,550.0 I 8 7,353.0 6,143.8 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/23/2016 IPERF;7,550.0-7,610.0 9 7,438.7 6,206.4 CAMCO KBUG 1 INJ DMY BEK 0.000 0.0 4/26/2006 1 7,506.7 6,255.3 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 8/27/2008 0 INJECTION;7,641.9 1 7,641.9 6,350.8 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 2/7/2010 Notes:General&Safety LOCATOR;7558.1 End Date Annotation PACKER;7,6585 8/5/2010 NOTE:View Schematic w/Alaska Schematic9.0(2 PAGES) NIPPLE;7,679.7 SOS;7,696.3 IPERF;7,78657,802.0 IPERF;7,812.0-7,858.0 FISH;8,362.0- f PRODUCTION;26.7-8562.5 • - • . A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(cjalaska.gov AOGCC.Inspectorsaalaska.gov phoebe.brooks@alaska.gov chris.wallace@alaska.gov OPERATOR: ConocoPhillips Alaska,Inc FIELD/UNIT/PAD: Kuparuk/KRU/ 1B Pad DATE: 01/08/17 OPERATOR REP: Beck/Sumrall AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 18-04 Type Inj. W TVD 6,180' Tubing 2,245 2,245 2,203 2,225 Interval O P.T.D. 1810650 Type test P Test psi 1545 Casing 1,150 3,020 2,960 2,950 P/F P Notes: Post patch OA 386 452 459 459 FINAL T/I/O=2241/800/371 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT KRU 1B-04 1-08-17.xls i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,January 10,2017 TO: Jim Regg P.I.Supervisor ((1 1(1�4 7 SUBJECT: Mechanical Integrity Tests t CONOCOPHILLIPS ALASKA INC 1B-04 FROM: Chuck Scheve KUPARUK RIV UNIT 1B-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry -Je-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1B-04 API Well Number 50-029-20595-00-00 Inspector Name: Chuck Scheve Permit Number: 181-065-0 Inspection Date: 1/8/2017 Insp Num: mitCS170109061554 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IB-04 Type Inj W TVD [ 6180 - Tubing 2245 2245 - 2203 • I 2225 - PTD 1810650 ' Type Test SPT Test psi 1545 IA 1150 3020 - 2960 - 2950 - BBL Pumped: [ BBL Returned: OA 386 452 - 459 - 459 Interval OTHER f P/F P vI Notes: Tested post tubing patch. _ SCANNED APR 0 5 Z017 Tuesday,January 10,2017 Page 1 of 1 • ,4•\� 11. I jy�‘v THE STATE Alaska Oil and Gas tv -s..���, Of/� L /� SKA Conservation Commission j� 1`� 333 West Seventh Avenue Anchorage,GOVERNOR BILL WALKER Alaska 99501-3572 Main: 907.279.1433 (4' Aa4/1j* Fax: 907.276.7542 www.aogcc.alaska.gov Brent Rogers Well Integrity Supervisor SCANNED MAR . 5 '07. ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1B-04 Permit to Drill Number: 181-065 Sundry Number: 316-587 Dear Mr. Rogers: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /' Daniel T. Seamount, Jr. Commissioner DATED this / �day of November, 2016. RBDMS v- NOV Z 8 2016 0 • RECEIVED STATE OF ALASKA NOV 1. 6 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well 17 Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program f Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: Tubing patch i✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 181-0650 3.Address. Stratigraphic r Service 6.API Number. P. O. Box 100360,Anchorage,Alaska 99510 50-029-20595-00 . 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA ' Will planned perforations require spacing exception? Yes r No p d KRU 1B-04 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025648 . Kuparuk River Field/Kuparuk River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8410 ' 6865 • 7916' " 6537' Casing Length Size MD TVD Burst Collapse CONDUCTOR 50' 16 80' 80' SURFACE 2842' 10 3/4 2871' 2675' _ PRODUCTION 8336' 7 8363' 6834' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7550-7610,7786-7802,7812-7858 6286-6329,6450-6461,6468-6498 2 7/8 J-55 7696 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SAFETY VLV=CAMCO TRDP-1A-SSA SAFETY VALVE MD=1922 TVD=1897 PACKER=BAKER HB RETRIEVABLE PACKER HYD MD=7402 TVD=6180 PACKER=BAKER WL SET 1B PERMENANT PACKER MD=7659 TVD=6362 12.Attachments: Proposal Summary 17 Wellaore Schematic 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 14.Estimated Date for 15. Well Status after proposed work: 11/18/16 OIL r WINJ r WDSPL r Suspended r Commencing Operations: 16.Verbal Approval: Date: GAS r WAG GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdow n r Abandoned r 17.I hereby certify that the foregoing is true Contact: Brent Rogers/Kelly Lyons Printed Name Brent Rogers Phone:659-7535 Email: N1617(cr�,conocophillips.com Title: NSK Well Integrity Supervisor Signatureele.,g)47' Date:November 14,2016 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: _ 5 Pi(1-- 1 4 ` �} Rug Integrity r BOP Test Mechanical Integrity Test r Location aearance r Other: t- mac— 11 II1II 0 Post Initial Injection MIT Req'd? Yes r No r Spacing Exception Required? Yes r No V Subsequent Form Required: /Q `/®L RBDMS - NOV 2 8 2016 OVEDBY /��/7//�Approved by: COMMISSIONER OMMISSION Date:0:4-rrir !l�/`�6 Submit Form and Form 10-403 Revised 11/2015 for 12 months the date of approval. Attachments in Duplicate cpartnpicNnAr • • 1►� N O 16 2016 ConocoPhillips AOGGC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 November 14, 2016 Mr. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. KRU well 1 B-04 (PTD 181-065). The request is for approval to pull and reset an existing patch for a tubing leak above the top packer.The well is exhibiting minor TxIA communication on gas injection and this is an attempt to repair by changing out the patch equipment. , Please call Kelly Lyons or myself at 659-7224 or Dusty Freeborn/Jan Byrne at 659- 7126 if you have any questions. Sincerely, /&4/4/4. Brent Rogers Well Integrity Supervisor Attachments • 1B-04 • DESCRIPTION SUMMARY OF PROPOSAL Slickline 1.RIH and pull Statewide top patch assembly. Top packer is at 5550'. 2.Pull lower patch packer at 5570'. g n B 3.Brush tbg in patch vicinity from 5530'-5590'. IP 4.Set K-2 plug on F-stop below gas lift mandrel at 7353'. (This is to use as a base to pump against when circ'ing out well). (PBR is at 7390'). 5.Pull DV at 7353'. 6.RU LRS to tubing and pump 195 bbls (33 T, 162 IA) of corrosion inhibited water(CRW-132 1% by volume) followed by 72 bbls (12 T, 60 IA) of diesel down tubing, taking returns off the IA. Hook up T to IA and allow to u- tube until equalized. _ ' 7 C.o/t i �L'r t l v�. #c11 fK J* r Gema�oS. 7.Reset DV at 7353'. Confirm with tattle tail that there is good set since canAot obtain MITIA with hole in tubing. 8.Pull K-2 plug. ✓ E-Line 1.Set Statewide 2-7/8" paragon packer with mid element at 5572'. Correlated to 11-11-14 LDL- Previous packer set was at 5570'. Will want to extend patch length by 3' (2' lower and 1' higher to avoid setting in exact spot as initial patch set). Slickline 1.RIH with TTS test tool and set in lower packer at 5571'. 2.Perform CMIT to 2500psi. Record pre, initial, 15min and 30min TIOs on WSR. If CMIT fails, will need to pull and reset packer. 3.Pull test tool. 4.RIH with upper patch assembly, (anchor latch, spacer pipe and top packer). Mid element of packer to set at 5549'. 5.Perform MITIA to 3000psi. Record pre, initial, 15min and 30min TIOs on WSR. 6.If MITIA fails, RIH with test tool and obtain MITT to 2500psi. If patch appears to be the culprit pull and reset top patch assembly and repeat MITIA. 7.RDMO. Turn well over to DSO. The well can be returned to injection with passing MITIA. Should be brought on water injection initally, per communication with the AOGCC. After a witnessed MITIA is achieved, the well will then be WAG'ed to gas for a 30 day monitor period. rk-' KUP INJ • 1B-04 Conor i'hiIIips 6` Well Attributes Max Angle&MD TD Alaska,Inc ` Wellbore APUUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) c<xr000wamp, 500292059500 KUPARUK RIVER UNIT INJ 48.90 8,200.00 8,410.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1B-04.5/6/2015 L46:40 PM SSSV:TRDP Last WO: 32.48 7/14/1981 Vertwel schematw(actuap Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,842.0 8/2/2014 Rev Reason:SET PATCH hipshkf 5/6/2015 HANGER;17.9 ®i•- ® Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 30.0 80.0 80.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 29.3 2,871.2 2,675.0 45.50 K-55 BUTT 1 ' : Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WVLen(I...Grade Top Thread 1 " PRODUCTION 7 6.276 26.7 8,362.5 6,833.9 26.00 K-55 BTC � .,r,..a.,,,m r.,.�aammmaa . .r Tubing Tubing Strings m.. r. ���; Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(NG)(...Wt(Ib/ft) Grade Top Connection TUBING 27/8 2.441 17.9 7,697.2 6,389.3 6.50 J-55 EUE8RDMOD -M.�CONDUCTOR 30060.0• - Completion Details ,._' Nominal ID SAFETY VLV;1,921.6 P11. Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 17.9 17.9 0.05 HANGER MCEVOY HANGER 2.875 GAS LIFT;2.0228 1,921.6 1,896.9 22.34 SAFETY VLV CAMCO TRDP-)A-SSA SAFETY VALVE 2.313 . .11 I 7,390.3 6,171.2 43.01 PBR BAKER CB PBR W/RETRIEVABLE THREAD 4.250 7,402.0 6,179.7 43.18 PACKER BAKER HB RETRIEVABLE PACKER HYD 3.000 7,544.3 6,282.0 44.75 BLAST RING BLAST RINGS(3) 2.441 7,658.1 6,362.2 45.82 LOCATOR BAKER CL LOCATOR 2.406 SURFACE,29.3-2,871 2- 7,658.5 6,362.4 45.82 PACKER BAKER WL SET 1B PERMENANT PACKER 3.000 7,679.7 6,377.2 46.07 NIPPLE CAMCO D NIPPLE NO GO 2.250 GAS LIFT;3,691.1 7,696.3 6,388.7 46.26 SOS BAKER SHEAR OUT SUB 2.441 I Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) rt Des Corn Run Date ID(in) 5,550.0 4,7)4.1 36.64 PACKER 2.28"OLGOONIK PARAGON 2 PACKER W/PATCH 5)4)2015 1.380 GAS LIFT;4,801.7 5,553.2 4,716.7- 36.82 PATCH 16'SPACER PIPE 5/3/2015 1.750 PACKER;5,550.0 5,570.0 4,730.1 36.71 PACKER 2.28"OLGOONIK PARAGON 2 PACKER W/PATCH 5/3/2015 1.380 PATCH;5,553.2 k 8,362.0 6,833.5 48.27 FISH 3 WRP SLIPS AND NOSE CONE 3/5/2015 PACKER;5,570.0 -a" Perforations&Slots Shot GAS LIFT 5575.7 Dens Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT,6,105.0 7,550.0 7,610.0 6,286.1 6,328.5 C-2,C-2, 6/1/1985 12.0 IPERF 60 FT no Cl Sand UNIT B,18- 04 GAS LIFT;6,478.4 7,786.0 7,802.0 6,450.0 6,460.8 A-5,18-04 6/1/1985 12.0 IPERF 7,812.0 7,858.0 6,467.5 6,498.4 A-4,1B-04 6/1/1985 12.0 IPERF GAS LIFT;6,916.2 Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(ND) GAS LIFT;7,353.0 I (ftKB) (ftKB) (ftKB) (f1KB) Type Date 8/5/2001Com 7,550.0 7,610.0 6,286.1 6,328.5 HPBD •C-SAND HPBD Mandrel Inserts PBR,7,390.3 St PACKER;7,402.0 -•. on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1' 2,022.8 1,989.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 3:00 INJECTION,7,438.7 2 3,691.1 3,288.6 CAMCO KBUG 1 GAS LIFT -DMY BK 0.000 0.0 7/23/1990 2:00 3 4,801.7 4,129.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 7:00 4 5,575.7 4,734.7 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 9:00 INJECTION;7,506.7 5 6,105.0 5,159.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 10:00 6 6,478.4 5,458.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 9:00 1. 7 6,916.2• 5,810.5 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 8:00 8 7,353.0 6,143.8 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 8/2/2001 4:30 I 9 7,438.7 6,206.4 CAMCO KBUG 1 INJ DMY BEK 0.000 0.0 4/26/2006 HPBD;7,550.0 1 7,506.7 6,255.3 CAMCO KBUG ' 1 INJ DMY BK 0.000 0.0 8/27/2008 (PERF;7,550.047,610.0-1 -1 O .; 1 7,641.9 6,350.8 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 2/7/2010 II 1 Notes:,General&Safety INJECTION;7,641.9 End Date Annotation 8/5/2010 NOTE:View Schematic w/Alaska Schematic9.0(2 PAGES) LOCATOR,7,658.1 PACKER;7,658.5 `• I NIPPLE;7,679.7 I SOS;7,696.3 y.. (PERF;7,7860-7,802.0 i ''.--- ...-- IPERF, (PERF;7812.0.7,858.0-. FISH;E,362.0 PRODUCTION FISH;E362.0 ` • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday, October 01, 2016 11:07 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report of IA pressure anomaly KRU injector 1B-04 (PTD 181-065) 10-1-16 Attachments: 1B-04 90 day TIO trend 10-1-16.jpg; 1B-04 schematic.pdf Chris, KRU WAG injector 1B-04 (PTD 181-065) is experiencing an unexplained IA pressure anomaly while on gas injection. The well was recently WAG'ed to gas injection on 9-10-16. Since then, there has been a slow, steadily-rising IA pressure trend. Yesterday the operator bled the IA, which prompted the trend review. Upcoming initial diagnostics with DHD are to include an MITIA,T&IC packoff tests and a IA drawdown test,with extended bleeding as necessary. Pending a passing MIT,the well will then go on a 30 day clock, keeping the well on gas injection. If unexplained repressurization continues, the well will then be WAG'ed to water injection for another 30 day monitor period in anticipation of an AA submittal. A follow up email will be submitted at the conclusion of the monitor. If the MIT fails, 1B-04 will be shut in and freeze protected with appropriate well intervention work with slickline/Eline as needed to identify the leak source. Please let me know if you disagree with the plan forward. Attached are the 90 day TIO plot and schematic. Kelly Lyons/ Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 LU U LU U1 = 01 d w ce a t' G O tn ti Crw = d '0d a, z v w fD y w Q' a cc 1- col Lu i--- ,_._ 0 J J w OAD O , 0 0 Bap .m- C� J, fl O l0 a] CD r i I t I I , 18 .coh a1 a1 cn cn Id" h d f„,„„i. h A. y vi C RS SD (ID01 0.1 hill. SO 01O R m cr. ❑ U fO r. G1 3 41toCi Ci SO .- Q CO cO t0 = 7 1-4 II- 0 N 0 N C) Mal 1 (I)ti o Cl. f- - c 1 1 F F ' r C SOX I 1 t v 1 r N c R LI R H 1i H H Ii H H " , CU R7 0 0 0 Cl Cl Cl 0 0 '�-, R R 1' H H V H II Z O Ca❑o n v1 o n Cl 1n a,nn rn t in V r`i r7 CJ Cl •_ cy v 10W is • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations f" Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing 9 r Change Approved Program Rug for Redrill r Frforate New Pool r Repair Well r Re-enter Susp Well r Other: WINJ to WAG wi 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 181-0650 3.Address: 6.API Number: Stratigraphic r Service 17 P. O. Box 100360,Anchorage,Alaska 99510 50-029-20595-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL025648 KRU 1 B-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8410 feet Plugs(measured) None true vertical 6865 feet Junk(measured) None Effective Depth measured 7916 feet Packer(measured) 7402,7659 true vertical 6537 feet (true vertical) 6180,6362 Casing Length Size MD TVD Burst Collapse CONDUCTOR 50 16 80 80' SURFACE 2842 13 2871 2675' PRODUCTION 8336 10 836336834' RECEIVED Perforation depth: Measured depth: 7550-7610; 7786-7802; 7812-7858 MAR 0 7 2016 True Vertical Depth: 6286-6329; 6450-6461; 6468-6498 AO w CC Tubing(size,grade,MD,and TVD) 2.875, J-55, 7697 MD,6389 TVD Olgoonik TTS Paragon Patch from 5550-5570 MD Packers&SSSV(type,MD,and TVD) SAFETY VLV-CAMCO TRDP-IA-SSA SAFETY VALVE @ 1922 MD and 1897 TVD PACKER-BAKER HB RETRIEVABLE PACKER HYD @ 7402 MD and 6180 TVD PACKER-BAKER WL SET 1B PERMENANT PACKER @ 7659 MD and 6362 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation 4899 0 10 3064 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service ' Stratigraphic r Copies of Logs and Surveys Run 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG 17 GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Darrell Humphrey/Bob Christensen Email: n1139c conocophiliips.com Printed NameRobert D. Christensen Title: NSK Production Engineering Specialist Signature / / . / / 'hone:659-7535 Date 3/3/06/4 0 Form 10-404 Revised 5/2015 Mt yr ,,f' � y/6 RBDMS LA- KA 0 7 2016 Submit Original Only • 1 B-04 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/10/15 STATE WITNESSED (JONNIE HILL) MIT-IA PASSED TO 3000 PSI. 07/30/15 IC POT FAILED, 00 POT PASSED, OC PPPOT PASSED 08/02/15 RE-ENERGIZE IC PO. IC POT(PASS), IC PPPOT(PASS). 08/19/15 RE-ENERGIZE OC PO COMPLETE 02/27/16 Well placed in WAG (MI) Injection service f KUP INJ • 1B-04 ConocWhillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/DWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) a...,h lktn 500292059500 KUPARUK RIVER UNIT INJ 48.90 8,200.00 8,410.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1904,5/6/20151,4940 PM SSSV:TRDP Last WO: 32.48 7/14/1981 • Vertical schemehc(actual) - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,842.0 8/2/2014 Rev Reason:SET PATCH hipshkf 5/6/2015 HANGER;179 tirvir Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 30.0 80.0 80.0 65.00 H-40 WELDED Casing Descr phon TOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 29.3 2,871.2 2,675.0 45.50 K-55 BUTT 7 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread •i PRODUCTION 7 6.276 26.7 8,362.5 6,833.9 26.00 K-55 BTC Tubing Strings w"'"""'""'"'"""""".""'"'""" eeu,m"nmeor,a w,,,.,o r'eeauyppy �n - ya'TubingDescription StringMa...ID To ftKB Set Depth ft...Set Depth ND Wt lb/ft Grade TopConnection ' P (in) PI ) P ( P (TVD) ( ) TUBING 2 7/8 2.441 17.9 7,697.2 6,389.3 6.50 J-55 EUE8RDMOD _MA.CONDUCTOR;30.0A0.o0,1A.r-/' Completion Details Nominal ID SAFETY VLV;1,921.6 Ell( Top(ftKB) Top(TVD)(ftKB) Top Incl 17 Item Des Com (in) 17.9 17.9 0.05 HANGER MCEVOY HANGER 2.875 li 1,921.6 1,896.9 2234 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.313 GAS LIFT;2,022.8 7,390.3 6,171.2 43.01 PER BAKER CB PBR W/RETRIEVABLE THREAD 4.250 7,402.0 6,179.7 43.18 PACKER BAKER HB RETRIEVABLE PACKER HYD 3.000 2.441 7,544.3 6,282.0 44.75 BLAST RING BLAST RINGS(3) 7,658.1 6,362.2 45.82 LOCATOR BAKER CL LOCATOR 2.406 3.000 SURFACE;29.3-2.871.2I 7,658.5 6,362.4 45.82 PACKER BAKER WL SET 1B PERMENANT PACKER 7,679.7 6,377.2 46.07 NIPPLE CAMCO D NIPPLE NO GO 2.250 GAS LIFT;3,691.1 1 7,696.3 6,388.7 46.26 SOS BAKER SHEAR OUT SUB 2.441 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (") Des Com Run Date ID(in) 5,550.0 4,714.1 36.84 PACKER 2.28"OLGOONIK PARAGON 2 PACKER W/PATCH 5/4/2015 1.380 GAS LIFT;4,801.7 al 5,553.2 4,716.7 36.82 PATCH- 16'SPACER PIPE 5/3/2015 1.750 PACKER;5,550.0 Az:- 5,570.0 4,730.1 36.71 PACKER 2.28"OLGOONIK PARAGON 2 PACKER W/PATCH 5/3/2015 1.380 PATCH;5,553.2 - 8,362.0 6,833.5 48.27 FISH 3 WRP SLIPS AND NOSE CONE 3/5/2015 PACKER;5,5700 __ _,_ Perforations&Slots Shot GAS LIFT;5,575.7--i-- Dens Top(ND) Btm(ND) (shots/f • • Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT;6,105.0- 7.550.0 7,610.0 6,286.1 6,328.5 C-2,C-2, 6/1/1985 12.0 IPERF 60 FT no C1 Sand UNIT 8,iB- 04 GAS LIFT;6,478.4 7,786.0 7,802.0 6,450.0 6,460.8 A-5,1B-04 6/1/1985 12.0 IPERF 7,812.0 1,858.0 6,467.5 6,498.4 A-4,1B-04 6/1/1985 12.0 IPERF GAS LIFT;6,916.2 Stimulations&Treatments Min Top Max Btm Depth Depth Top(TVD) Btm(ND) GAS LIFT;7,3530 (ftKB) (ftKB) (ftKB) (ftKB) Type I Date Com 7,550.0 7,610.0 6,286.1 6,328.5 HPBD 8/5/2001 C-SAND HPBD Mandrel Inserts PBR;7,390.3 'i St ati PACKER;7,4020 on Top(ND) Valve Latch Port Size TRO Run . N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 2,022.8 1,989.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 723/1990 3:00 INJECTION;7,438.7 I 2 .1 ,2LI2:000 3 4,801.73,691 43,129.288.6 CAMCOCAMCO KBUGKBUG 1i GAS GAS LIFTFT DMYDMY BKBK 0.0000.000 0.0 0.0 723/1990 723/1990 7:0 4 5,575.7 4,734.7 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 723/1990 9:00 INJECTION;7,508.7II 5 6,105.0 5,159.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 723/1990 10:00 6 6,478.4 5,458.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 723/1990 9:00 I 7 6,916.2 5,810.5 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 723/1990 8:00 8 7,353.0 6,143.8 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 82/2001 4:30 9 7,438.7 6,206.4 CAMCO KBUG 1 INJ DMY BEK 0.000 0.0 4/26/2006 IPERF;7HP,55BD;0.0.7,67,5510.00.0-1-- 1 1 7,506.7 6,255.3 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 827/2008 0 - 1 7,641.9 6,350.8 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 2/7/2010 11 1 Notes:General&Safety INJECTION;7,641.9 End Date Annotation 8/5/2010 NOTE:View Schematic w/Alaska Schematic9.0(2 PAGES) LOCATOR;7,658.1 - PACKER;7,658.5 Iiii NIPPLE;7,679.7 SOS;7,696.3 IPERF;7,786.0-7,802.0 IPERF;7,812.0-7,856.07- FISH;8,362.0- PRODUCTION;26.7-8,362.5 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission r7 TO: Jim Regg 611 7/15 DATE: Tuesday,June 16,2015 P.I.Supervisor / SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1B-04 FROM: Johnnie Hill KUPARUK RIV UNIT 1B-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J� NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1B-04 API Well Number 50-029-20595-00-00 Inspector Name: Johnnie Hill Permit Number: 181-065-0 Inspection Date: 6/10/2015 Insp Num: mitJWH150612054158 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well; 8-04 'Type Inj " TVD 6180 ' Tubing 2340 • 2340- 2340 - 2340 PTD 1810650 • IType Test SPT Test psi 1545 IA 1380 3000 2880 - 2880– — Interval OTHER P/F P ./ OA 320 • 425 425 • 425 1 _ L - Notes: MITIA post patch per Sundry 314-668 1 6bbls diesel , S M ;IU, 1 3101a Tuesday,June 16,2015 Page 1 of 1 RECEIVED STATE OF ALASKA A�. .SKA OIL AND GAS CONSERVATION COMMISSION 4/AY i1os alb REPORT OF SUNDRY WELL OPERATIONS l 4 01 tit SA 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r .1- _ . . .own r Performed Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool rRepair Well Re-enter Susp Well r Other:Tubing patch Fe- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 181-065 - 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-20595-00 7.Property Designation(Lease Number): ' 8 Well Name and Number. ADL0025648 K0.J 1 B-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s) N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary Total Depth measured 8410 feet Plugs(measured) None true vertical 6865 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 7402, 7659 true vertical 0 feet (true vertical) 6180,6362 Casing Length Size MD TVD Burst Collapse CONDUCTOR 50 16 80 80' 0 0 SURFACE 2842 13 2871 2675' 0 0 PRODUCTION 8336 10 8363 6834' 0 0 f..k. Perforation depth: Measured depth: 7550-7610,7786-7802,7812-7858 ',No V1 M1V' I d 2.0a True Vertical Depth: 6286-6329,6450-6461,6468-6498 Tubing(size,grade,MD,and TVD) 2 875,J-55, 7696 MD, 6389 TVD Olgoonik TTS Paragon Patch from 5550-5570 MD Packers&SSSV(type,MD,and TVD) PACKER-BAKER HB RETRIEVABLE PACKER HYD @ 7402 MD and 6180 TVD PACKER-BAKER WL SET 1B PERMENANT PACKER @ 7659 MD and 6362 TVD SAFETY VLV-CAMCO TRDP-1A-SSA SAFETY VALVE @ 1922 MD and 1897 TVD 12 Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation _ N/A N/A N/A N/A N/A 14.Atti 4IM l P?&i Rte Gt 9l c,` s 071,&25 283) 15 Well Class after work: Copies of Logs and Surveys Run r Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ P WAG r GIN,' r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 314-668 Contact Brent Rogers/ Kelly Lyons Email N1617@conocophillips.com Printed Name Br nt Rogers Title Problem Well Supervisor Signature / /i - Phone:659-7224 Date 05/08/15 Form 10-404 Revised 5/2015 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA RECEIVED May 8, 2015 Mi,Y S201 i AOGCC Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 1B-04 (PTD 181-065) for a retrievable patch set in the tubing above the packer. The patch was under Sundry# 314-668. Please call Kelly Lyons or myself @ 659-7224 if you have any questions. Sincerely, Brent Rogers ConocoPhillips Problem Well Supervisor Enclosures 1B-04 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/05/15 BRUSH AND FLUSH TBG W/LRS TO 5,600' SLM ***JOB COMPLETE*** 05/03/15 SET 2.28" OLGOONIK TTS PARGON PACKER @ 5570' RKB. SET 2.5"TEST TOOL @ 5570' RKB. LRS PERFORMED CMIT,PASSED. PRE MIT-T/I/0-175/25/80 INITIAL MIT- , 2500/2375/90 15 MINUTES T/I/0-2400/2300/90 30 MINUTES-T/I/0-2375/2275/90 05/04/15 SET 2.28" OLGOONIK PARGON 2 PACKER W/PATCH @ 5550' RKB. LRS PERFORMED MIT-IA,PASSED. PRE T/I/0-175/0/80 INITIAL MIT-T/I/0-175/3000/80 15 MINUTES T/I/0- 175/2900/100 30 MINUTES T/I/00175/2860/100 Summary A 20' Olgoonik TTS retrievable patch was set in the tubing. A pre-injection MITIA passed following the patch set. The well is still currently SI due to a derated injection line. A witnessed MITIA will be scheduled when the well is BOI and stablized. 1B-04 DESCRIPTION OF WORK COMPLETED SUMMARY KUP INJ 1B-04 ConocoPltiIIips Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(111(13)c„,„,-,lvnip, 500292059500 KUPARUK RIVER UNIT INJ 48.90 8,200.00 8,410.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1504,5/6/20151:46:40 PM SSSV:TRDP Last WO. 32.48 7/14/1981 •0n0ca Sc emanc EE)MMEM 1 Date 5/6/2015 HANGER;17.9 Ma+`ate Casing CONDUCTOR• 16 11 :11 (TVD)... 11 11 •" 1 DED {1 - ) ID(in) Top(MB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread J Casing Description OD 1 1 Set Depth(ft,,KB). Set Depth 1 1 Th I1` .Jf ••• • 11 yya�pay.�•,eiunuuu•,. m .. •.. read Tubing Strings1 scription String Ma...ID(in) Top(ftKB) Set Depth M..Set Depth )(„.Wt(Ib/ft) Grade Top Connection Tubing •- 1 RD •• II TUBING ✓•.An CONDUCTOR 30.0-80.0• Completion Details Nominal ID SAFETY VLV;1,921.6 ft•'; Top(ftKB) Top(TVD)(ftKB) Top Ind(") Item Des Com (in) I17.9 17.9 0.05 HANGER MCEVOY HANGER 2.875 I 1,921.6 1,896.9 22.34 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.313 GAS LIFT;2,022.6 7,390.3 6,171.2 43.01 PBR -- BAKER CB PBR W/RETRIEVABLE THREAD 4.250 7,402.0 6,179.7 43.18 PACKER BAKER HB RETRIEVABLE PACKER HYD 3.000 7,544.3 6,282.0 44.75 BLAST RING BLAST RINGS(3) 2.441 7,658.1 6,362.2 45.82 LOCATOR BAKER CL LOCATOR 2.406 SURFACE;29.3-2,871.2- 7,658.5 6,362.4 45.82 PACKER BAKER WL SET iB PERMENANT PACKER 3.000 7,679.7 6,377.2 46.07 NIPPLE CAMCO D NIPPLE NO GO BAKER SHEAR OUT SUB Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 2.250 GAS LIFT;3,691.1 7,696.3 6,388.7 46.26 SOS I 2.441 Top(TVD) Top incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 1.380 5,550.0 4,714.16 ,714.1 36.84 PACKER 2.28"OLGOONIK PARAGON 2 PACKER W/PATCH 5/4/2015 GAS LIFT;4,601.7- 5,553.2 4,716.7 36.82 PATCH 16'SPACER PIPE 5/3/2015 1.750 PACKER;5,550.0 5,570.0 4,730.1 36.71 PACKER 2.28"OLGOONIK PARAGON 2 PACKER W/PATCH 5/3/2015 1.380 i1 PATCH;5,553.2 8,362.0 6,833.5 48.27 FISH 3 WRP SLIPS AND NOSE CONE 3/5/2015 PACKER;5,570.0 �Fl Perforations&Slots Shot GAS LIFT;5,575.7 Dens Top(TVD) Btm(TVD) (shotstf Top(ftKB) Btm(ftKB) (,ftKB) (ftKB) Zone Date t) Type Com GAS LIFT;6,105.0 7,550.0 7,610.0 6,286.1 6,328.5 C-2,C-2, 6/1/1985 12.0 IPERF 60 FT no C)Sand UNIT B,18- 04 GAS LIFT;6,478.4 7,786.0 , 7,802.0 6450.0 6,460.8 A-5,1B-04 6/1/1985 12.0 IPERF 7,812.0 7,858.0 6,467.5 6,498.4 A-4,1B-04 6/1/1985 12.0 IPERF • GAS LIFT;6,916.2 Stimulations&Treatments • Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) GAS LIFT;7,353.0 gni (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 7,550.0 7,610.0 6,286.1 6,328.5 HPBD 8/5/2001 C-SAND HPBD Mandrel Inserts PBR;7,390.3 St PACKER 7,402.0 °" 0-• air on Top(TVD) Valve latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com 2,022.8 1,989.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 3:00 INJECTION;7,438.7 2 3,691.1 3,288.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 2:00 3 4,801.7 4,129.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 7:00 4' _5,575.7 4,734.7 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 9:00 INJECTION 7.5067 Ifil 5 6,105.0 5,159.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 10:00 6 6,478.4 5,458.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 9:00 7 6,916.2 5,810.5 CAMCO KBUG 1 GAS LIFT DMY BK 0.000' 0.0 7/23/1990 8:00 -8 7,353.0 6,143.8 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 8/2/2001 430 • 9 7,438.7 6,206.4 CAMCO KBUG 1 INJ DMY BEK 0.000 0.0 4/26/2006 HPBD,7,550.0 1 7,506.7 6,255.3 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 8/27/2008 IPERF;7,550.P7,610.0_1 i 0 w 1 7,641.9 6,350.8 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 2/7/2010 i1 INJECTION;7,841.9 a Notes:General&Safety End Date Annotation 8/5/2010 NOTE:View Schematic w/Alaska Schematic9.0(2 PAGES) LOCATOR;7,658.1 PACKER',7,658.5 "r • NIPPLE;7,679.7 SOS;7.696.3 IPERF;7,786.0-7.802.0-. (PERF;7.812.0.7.858.0 FISH;8.362.0 PRODUCTION;26.7-8,362.5 Ima.~roject Well History File Cover ~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan 'activity or are viewable by direct inspection of the file. Organizing RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Diskettes, No. [] Maps: [] Other, No/Type [] Other items scannable by large scanner BY: BEVERLY ROBIN VINCENT~MARIA WINDY OVERSIZED (Non-Scannable) [] Logs of vadous kinds n Other Project Proofing BY: BEVERLY ROBIN~HERYL MARIA WINDY Scanning Preparation _ x 30 = ~ = TOTA PAGES BY: BEVERLY ROBIN VINCENT SHERYL~/VINDY Production Scanning Stage f PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: K YES NO DATE: ,/-/7-~,.~S/ BY: BEVERL'~--~'~INCENT SHERYL MARIA WINDY , FOUND: YES NO Stage 2 IF NO IN STAGE 1 PAGE(S) DISCREPANCIES WERE ReScanned (individual page [,~pecial at~e~tiot~] .e'ca~m#lg cr~mplered) RESCANNED BY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked {done) 12110/02Rev3NOTScanned.wpd • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 "'IED iLL 0 8 2u June 27, 2011 Commissioner Dan Seamount K ° ; . Alaska Oil and Gas Commission 333 West 7 Avenue, Suite 100 ,a ; ,`SSi011 Anchorage, AK 99501 ri Commissioner Dan Seamount: ut Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 3/21, 5/9, 5/23 and 5/24, 2011. The corrosion inhibitor /sealant was pumped 6/18, 6/19, 6/20 and 6/21, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, MJ L veland 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 06/27/2011 1A,1B,1E,1L,1Q,1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 1A -03 50029206150000 1810880 16" N/A 23" N/A 1.7 6/20/2011 1A -04A 50029206210100 2001940 18" N/A 23" N/A 2.5 6/20/2011 1A -16RD 50029207130100 1820310 SF N/A 22" N/A 5 6/18/2011 1B -03 50029205880000 1810560 SF N/A 23" N/A 5 6/21/2011 1B-04 50029205950000 1810650 18" N/A 18" N/A 2.5 6/21/2011 18-05 50029202370000 1770010 _ 31" 6.40 2'9" _ 5/24/2011 6 6/21/2011 1B-07 50029206160000 1810890 72" _ 1.00 22" 5/9/2011 2.5 6/21/2011 1B -08A 50029206350100 1971120 18'8" N/A 29" N/A 4.5 6/21/2011 1B-09 50029206550000 1811340 _ SF N/A 23" _ N/A 5 6/20/2011 1B -10 50029206560000 1811350 SF N/A 23" N/A 6 6/21/2011 1B-12 50029223650000 1930610 13'4" 2.00 24" 5/9/2011 6 6/21/2011 1B -101 50029231730000 2031330 3" N/A 22" N/A 1.7 6/21/2011 1B -102 50029231670000 2031220 11'2" 0.60 36" 5/9/2011 1.7 6/21/2011 1E-05 50029204790000 1800580 _ 19" N/A 19" _ N/A 1.7 _ 6/19/2011 1E -22 50029208840000 1822140 14" 1.75 17" 3/21/2011 1.7 6/19/2011 1 E -23 50029208580000 1821840 58' 10.75 2'5" 5/23/2011 3.4 6/19/2011 1E -30 50029208140000 1821390 15'5" 1.75 16" 3/21/2011 2.5 6/19/2011 1E -105 50029232430000 2050060 20" N/A 20" N/A 6 6/19/2011 1L-16 50029212020000 _ 1841810 14'9" 2.00 35" _ 5/23/2011 6 6/20/2011 1L-18 50029221450000 1910350 SF N/A 18" N/A 2.5 6/19/2011 1Q-24 50029225840000 1951210 7'8" 1.00 12" 5/9/2011 - 5 6/18/2011 1Y-02 50029209410000 1830590 40'10" 5.00 41" 5/912011 - 8.5 6/18/2011 . MEMORANDUM TO: Jim Regg P.I. Supervisor ~~$~j 2rZZl~cj ~, ~ FROM: Jeff Jones Petroleum Inspector ~ State of Alaska A-aska Oil and Gas Conservation Commission DATE: Monday, July 06, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 B-04 KUPARLJK RIV L1NIT 1B-04 Src: Inspector NON-CONFIDENTIAL Reviewed B~ P.I. Suprv~-~~ Comm Well Name: KUPARUK RIV LTNIT 1B-04 API Well Number: 50-029-20595-00-00 Inspector Name: JeffJones Insp Num: miUJ090706092740 Permit Number: 181-065-0 ~ Inspection Date: 6/24l2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ is-oa Type Inj. ~' TVD 6iso IA 660 »~s ~ i~6o »so P.T.D 1810650 TypeTest SPT Test psi 1545 QA 220 290 290 290 Interval aYaa~rsT p~ r ~ Tubing ZZBO zaso zz~s 2300 NOtes: 1.1 BBLS diesel pumped. 1 well inspected; 3 exceptions noted: 2 bolts not properly engaged on tubing adapter and S-riser to pilot connection is leaking. Mr. Colee will address these items. ~ ~ ~?t ~ f~ p 7( I~`~~i F q, ti~:' «o:.g ~'~ ~ ~" ~ / ~~4~~. Monday, July 06, 2009 Page 1 of 1 `~'1 ~~' "s ~~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 i~ v ~~ ATTN: Beth ~~ ~~~ t ~1 R ~ ? ~ i- J d Well Job # Log Description ~YX~------- NO.4914 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/14/08 i L-23 12097405 SBHP SURVEY j 07/17/08 1 1 2A-17 11975793 PRODUCTION PROFILE 9 _ fL p L 09/10/08 1 1 3G-25X 12080437 LDL ~ - 3 ~-j(o 09/21/08 1 1 2C-04 12100444 INJECTION PROFILE L. C / 09/14/08 1 1 3M-13 12096541 LDL - (~L/ ( (~Cf 09/10/08 1 1 2Z-13A 12100446 LDL Q(o- (~ O ~U 3 09/15/08 1 1 1 F-06 12096510 PRODUCTION PROFILE 07/17/08 1 1 3C-14A 12080436 SCMT - S~ 09/22/08 1 1 iC-111 12100451 INJECTION PROFILE ~t p ~ 09/20/08 1 1 30-15 12100452 LDL - ~ Sa 09/21/08 1 1 iC-117 12100453 INJECTION PROFILE o r 09/23/08 1 1 1 R-11 11966277 SBHP SURVEY ~ - (~ 09/25/08 1 1 iR-35 11966279 SBHP SURVEY p ` 09/25/08 1 1 1 R-14 11966286 LDL ( 09/29/08 1 1 2X-18 12080443 PRODUCTION PROFILE 09/30/08 1 1 iR-34 12080444 GLS gL - 10/01/08 1 1 2A-13 12096547 PRODUCTION PRO ILE .= L ~/ 10/02/08 1 1 1 D-01 12097422 GLS 10/03/08 1 1 1 R-07 12097425 PRODUCTION PROFILE ter: '~- ( 10/06/08 1 1 1H-19 12096548 INJECTION PROFILE L 10/03/08 1 1 1 B-16 12097426 GLS ~ - =' 10/07/08 1 1 36-09 12100442 PRODUCTION PROFILE - 09112/08 1 1 3K-103 12096550 USIT - 10/06/08 1 1 2X-05 12096551 INJECTION PROFILE - ~~ 10/07/08 1 1 18-04 12096552 INJECTION PROFILE -- 10/08/08 1 1 1A-02 12096553 INJECTION PROFILE ~ 10/09/08 1 1 16-16 12096554 PRODUCTION PROFILE G~ C - ~ 10/10/08 1 1 2D-15 12096555 PRODUCTION PROFILE J~~ . 10/11/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • ~~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 '~~ JUL ~ ~ ~~~ ATTN: Beth ~', i ~ I ~ ~ f / Y ~ NO. 4759 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnkeri 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 1~ o~S Well Job # Log Description Date BL Color CD 06/25/08 iG-14 11964620 INJECTION PROFILE - yx,, •~r`~, •~ d~° a °~ A/ .=,~~~P~( 06/13/08 1 1 3A-16 11964621 LDL r ='" _ ~~ a ,• , <_• ., 06/14/08 1 1 1 B-14 12061702 LDL ~ ff _, ~~~ -.° °?' f 06/15/08 1 1 2N-327 12061704 PRODUCTION PROFILE y~~)°"'- ~- q~gp'~~~-; B'/ ~-~" ~~- 06/17/08 1 1 iB-04 12061705 INJECTION PROFILE ~° { (•F~"' ^-~` `. 06/18/08 1 1 2D-05 11964625 INJECTION PROFILE/LDLti;-~- , . f3~ ~e t-R_p 06/18/08 1 1 1 E-12 11964628 G LS ? `"~ `'~ •-~°,> ~; ; ~`, ,>a ~ ; ~ ~ 06/20/08 1 1 3A-O6 12061708 INJECTION PROFILE '"` ~ ?' ~'.~ ~ ~ ~4pU,i~ { ~ .~ ~w) 06/21/08 1 1 2A-08 11964629 INJECTION PROFILE a~_~ ~ ~'`; ~"??~~,~' /~` ,; ~~`~ 06/21/08 1 1 1 L-11 11964630 PRODUCTION PROFILE ~''= -'~"' ~ 06/23/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Ernail to: Winton_Aubert@adrnin.state.ak.us; Bob]leckenstein@adrnin.state.ak.us; Jirn_Regg@adrnin.state.ak.us 6fSf!- g I ~4104 OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU /18 08f21/04 ASRC - Arend s p 0 P Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes 1= Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT KRU 1 B 08-21-O4.xls MEMORANDUM TO: Cammy O Taylor Chairman State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 16, 2002 SUBJECT: Mechanical Integrity Tests Phillips lB Pad KRU Kuparuk THRU: Tom Maunder ~~/'~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector ~c)~-~--~c_~-~'~ ,,.~e_~,~. ~c~,.~,.c~ NON- CONFIDENTIAL P~oker Depth Pretest Initial i5 ~Jn. 30 ~Jn. w~,,I ~-o~ !~,~,~.1 ~ I~.v.~.l ~o~ I~,~1 ~,~o I ~,~o I ~,~o I ~o I,nt~'l '~ P.T.D.I 181-133 IZv~etestl, ,, P ITestps~l 1527 I C~singl !50 I ~o I ~so I ~eo I ~ I, ~ ~ ~' I~v""~-! ~ I~'v'~' I'~'~° I~'~g ! ~oo I~oo I~oo I~Oo I,~,~%,1 . 181"~5 ITvpetestI P ITestpsii ,1~5 I C~singl 550 I ~0~01 ~0~01 ~O~Ol P~F I ~' ITypJmnj.! F I'I'T.V.D.! '6341 ITubingl =~oo I =soo I =~oo I =~ool Ilnterva'l 4 Type testl, P I Test psiI 1585 I Casing l. 250 I 2QOO I ' 1950 l. 1925 I PIE .'1' 13 [Typelnj. II F !T'V'D'I ~==~1 I~u~'"~ll'=~l~° I =s~°l =s~° I =s~°I lntervall 4" Tyl~etestI P ITestPsil 1557 I casing, l,lOO6" I" i950 1,192° I 1920 I P/F '1 _P I Type Ini'l' F' I T.V.D. I 4837 I Tubing ) 25OO I 25'0O I 25OO I 2500'l~nterva~"l"'4"' Type test.. I P ITestpsil '1209 [.Casin.. gl ............. ~0" I 2050 I 2000 I 2000 I P/F I'P I Typelnj.I F IT.V.D. I 6109 [Tubingl 2500 i 25001 :~5°° I '25°° 'llntervall 4 Typetestl ' P ITestpsil 1527I CasingI 550 'l 2025 I 2°°°l 2000 I P/F "1 13- I Cype~ni.I F i~.v.~:l ~o~ I~u~,,gI ~so I ~oI ~oI ~o I~nterva~l 4 Typetestl. P'ITestpsil 1524 ICasingI 0 I 2.10°1 2o5O '1 2,°5°1 P/FI ~P I Notes: w~,~I ~-0~ P.T.D.! 177-001 Notes: we,I 19:07 P.T.D.I 181-089 Notes: I ' Welll 19-08 P..T,'D.I 197-112 Notes: wellI 19-09 P.T.D.I I181-134 Notes: Welli 1B-12 P:T.D.,I 193-061 ~otes: Type IN J, Fluid Codes F = FRESH WATER INJ. g = GAS INJ. S -- SALT WATER INJ. N -' NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Phillips lB Pad in the Kuparuk River Field and witnessed the routine 4 year MITs on the above 7 wells. The pretest tubing and easing pressures on all wells was observed and found to be stable. The standard annulus pressure 'tests were then performed with all 7 wells demonstrating good mechanical integrity. M.l.t.'s performed: Z Attachments: Number of Failures: _0 Total Time during tests: 4 Houm cc: MIT report form 5/12/00 L.G. 020616-MIT KRU 19 Pad CS.xls 7/8/2002 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 August 28, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 1B-04 (181-065) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the stimulation treatment on the KRU well 1B-04. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad RECEJVED S£P 0 5 2001 Alaska Oi't & Gas Cons. Commission Anchorage ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_X HPBD 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 498' FNL, 621' FEL, Sec. 9, T11N, R10E, UM 5. Type of Well: Development _ Exploratory _ Stratigmphic _ Service__X (asp's 549818, 5969547) 6. Datum elevation (DF or KB feet) RKB 94 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 B-04 At top of productive interval 1 359' FSL, 1865' FEL, Sec. 9, T11 N, R10E, UM At effective depth At total depth 4318' FNL, 2369' FEL, Sec. 9, T11N, R10E, UM (asp's 548104, 5965816) 9. Permit number / approval number 181-065 / 10. APl number 50-029-20595 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 80' SURFACE 2840' PRODUCTION 8019' 8410 feet Plugs (measured) 6865 feet 7916 feet Junk (measured) 6537 feet Size Cemented Measured Depth True vertical Depth 16" 200 sx Permafrost 80' 80' 10-3/4" 15oo sx Fondue, 250 sx AS II 2934' 2722' 7" 700 sx Class G, 676 sx AS I 8113' 6669' Perforation depth: measured 7550'-7610',7786'-7802',7812'-7858' true vertical 6286' - 6328', 6450' - 6461', 6468' - 6498' Tubing (size, grade, and measured depth) 2-7/8",6.5#, J-55 Tbg @ 7697' MD. Packers & SSSV (type & measured depth) RECEIVED SEP 0 5 2001 Alaska Oil & Gas Cons, Commission Anchoroge BAKER HB RETR. HYD SET @ 7402' MD; BAKER WL SET lB @ 7658' MD; CAMCO TRDP-1A-SSA @ 1923' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl Water Injector Water Injector Casing Pressure . Tubing Pressure 15. Attachments Copies of Logs and Surveys run m Daily Report of Well Operations __X Oil __ Gas __ Suspended _ Service _Water Injector X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,/~ ~,~~ Title: Wells Team Leader Michael Mooney Questions? Call Mike Mooney 263-4574 Date ~/~/ Prepared by Sharon Al/sup-Drake 263-4612 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE Date Comment 1B-04 Event History 08/01/01 PULLED 1' CV'S @ 7439',7S07',7642'RKB. SET 1' DV'S AT SAME DEPTHS. PULLED 1' DV @ 7353'RKB (STATION #8) LEFT POCKET OPEN FOR CIRCULATION IN MORNING. PREP FOR HPBD IN PROGRESS [OPEN-CLOSE C SAND] 08/02/01 CIRCULATED 165 BBLS SEAWATER INTO CASING, PT TUBING & CASING TO 3500#, HELD GOOD, SET 1' DV @ 7353'RKB [OPEN-CLOSE C SAND] 08/03/01 PUMPED 6300# OF 20/40 SAND TO COVER A SAND PERFS IN TWO STAGES USING SLICK WATER [HPBD] 08/04/01 TAGGED SAND PLUG TOP @ 7916' RKB. PULLED DV'S @ 7439', 7507' & 7642' RKB. SET FRAC SLY @ 1923' RKB. [TAG, OPEN-CLOSE C SAND] 08/05/01 PERFORMED HPBD ON C SAND THROUGH OPEN C SAND MANDRELS- 1800 BBLS TOTAL WATER W/3 SAND STAGES (6034# TOTAL) FINAL ISIP 2828 PSI- FINAL FRAC GRADIENT .89- BROUGHT ON WELL TO C SAND ONLY INJECTION- NEEDS A SAND CLEANOUT [HPBD] 08/06/01 PULLED FRAC SLEEVE @ 1923' RKB, RAN HFCV'S @ 7439', 7507' & 7642' RKB [SSSV WORK] Page 1 of I 8/27/01 AI.AUW(A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Pull tubing Alter casing Stimulate __ Plugging Perforate _ Repair well Other X 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic Service X 4. Location of well at surface 498' FNL, 622' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 1359' FSL, 1865' FEL, Sec. 9, T11N, R10E, UM At effective depth 1023' FSL, 2205' FEL, Sec. 9, T11N, R10E, UM At total depth 963' FSL, 2361' FEL, Sec. 9, T11N, R10E~ UM 12. Present well condition summary Total Depth: measured 8 41 0 feet true vertical 6865' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 94' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1 B-04 9. Permit number/approval number 81-65 , 10. APl number 50-029-20595 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8 2 7 8' feet true vertical 6777' feet Junk (measured) None Casing Length Size Structural Conductor 8 0' 1 6" Surface 2871' 10 Intermediate Production 83 6 3' 7" Liner Perforation depth: measured 7550'-7610', true vertical 6285'-6326', Cemented Measured depth 200 Sx Permafrost 80' 3/4" 1500 Sx Fondue & 2871' 250 Sx AS II 700 Sx Class G & 8363' 676 Sx AS I 7786'-7802', 7812'-7858 6447'-6458', 6464'-6495' Tubing (size, grade, and measured depth) 2 7/8" J-55, TT @ 8533' Packers and SSSV (type and measured depth) Baker packers HB @ 7387' and lB @ 7643', Camco TRDP lA@ 1907' 13. Stimulation or cement squeeze summary Intervals treated (measured) True ve~ical depth 80' 2677' 6831' R'E .EIYED DEC 1 1 1990 AlaSKa u,l 'Anchorage Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation :15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Reoresentative Daily Averaae Production or Iniection Data _ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure - 0 - - 0 - - 0 ~ 760 -0- -0- -0- 1000 1900 2350 16. Status of well classification as: Water Injector ~ Oil _ Gas .... Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 Date SUBMIT IN DUPLICATE KRU 1B-04 Water injection into 1B-04 began September 10, 1990 with an initial rate of 1875 bbl of produced water per day RECEIVED DEC l I 1990 Alaska Oil & Gas Cons. Gornn¥isslon Anchorage , (' STATE OF ALASKA COM~i~XSION ~ AI.~,.~<A OIL AN D GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspende~ve~l, Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate~'~' ~""_~_' ~ ~ Change approved program ~ Pull tubing _ Variance _ Perforate _ other _//~! ~ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 498' FNL, 622' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 1359' FSL, 1865' FEL, Sec. 9, T11N, R10E, UM At effective depth 1023' FSL, 2205' FEL, Sec. 9, T11N, R10E, UM At total depth 963' FSL, 2361' FEL, Sec. 9~ T11N, R10E, UM 12. Present well condition summary Total Depth: measured 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 6. Datum elevation (DF or KB) ~'(~ ~ RKB 94' 7. Unit or Property name Kuparuk River Unit 8. Well number 1B-04 9. Permit number 81-65 feet 10. APl number 50-029-20595 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 841 0' feet Plugs (measured) true vertical 6 8 6 5' feet Effective depth: measured 8278' feet Junk (measured) true vertical 6 7 7 7' feet None Casing Length Size Cemented Measured depth Structural Conductor 80° 1 6" 200 Sx Permafrost 80' Surface 2 8 71 ' 1 0 3/4" 1500 Sx Fondue & 2 8 71 ' Intermediate 250 Sx AS II Production 8 3 6 3' 7" 700 Sx Class G & 8 3 6 3' Liner 676 AS I Perforation depth: measured 7550'-7610', 7786'-7802', 7812'-7858' true vertical 6285'-6326X', 6447'-6458', 6464'-6495' Tubing (size, grade, and measured depth 2 7/8" J-55, TT @ 8533' Packers and SSSV (type and measured depth) Baker packers HB @ 7387' and lB @ 7643', Camco TRDP lA@ 1907' True vertical depth 80' 2677' 6831' RECEIVED AUG ! o 19 0 .41 .Oil& Gas Cons, C. aissi . chora 13. Attachments Description summary of proposal _ Detailed operation program _ BOP sketch_ Propose converting well from oil producer to water injector. 14. Estimated date for commencing operation 115. Status of well classification as: August 15, 1990 I Oil __ Gas _ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service Water Iniector Signed'~/3" {J~ ~1_ ~,,,(~ ,. ' Title ~li~t'~ (~~~i~'~..~ ~rl~ate FOR COMMISSION USE ONlY C/ Conditions of approval: Notify Commission so representative may witness Plug integrity_ B~)~ Test_ Location clearance m Mechanical Integrity Test/~ Subsequent form require Approved by the order Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY I Obl~ll£ C. SMITH 1 0- /'/~- '~ --ov~.d CoPY Commissioner Date SUBMIT IN TRIPLICATE ( ARCO Alaska, Inc? Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 .. ~ ..... ?-:~'. '- DATE: 10-31-85 ?~'-~' ~-.~.~i~-¥'~-,~ ~-~*- TRANSMITTAL NO: 5421 RETURN ~: '~CQ -~KA, INC. KUPARUK OPE~TIONS ENGIN~NG .. ~CO~S CLE~ AT~lllSB P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH AR~ THE FOLLOWING IT~24S. RECEIPT AND RETURN ONE SIGNED COPY OF T~IS TKANSMITTAL. FINALS/ SCHL/ CEMENT <ONE * OF EACH> -~lA-3 / CEMENT. EVALUATION TOOL 1B-4'~ .CEMENT EVALUATION TOOL -'~lR-9 / CET LOG 1R-10'' .CET LOG ~IR-11 / CET/CEL ~lR-12/ CET LOG ~'~A-13 - CBL/VDL \2A-13 / CET/CEL J2U-3-" CEMENT EVALUATION TOOL ~J2U-10/ CEMENT EVALUATION TOOL '~2Z-13/ CET LOG ~2Z-14 .w C~T LOG ~'2Z-15~' CET LOG '~2Z-16-. CET LOG ~3B-4'~. CEM~:NT ~VALUATION TOOL ~'3B-12~ CET LOG ~3B-12 "' CEMENT EVALUATION LOG W/ AC ~3B-16 / CEMENT ~:VALUATION TOOL ~3C-9 '/ CET LOG ~3C-10~' CET LOG PLEASE ACKNOWLEDGE 05-04-85 RUN #1 7468-8287 05-28-85 t{UN #1 7200-7995 07-17-85 RUN #1 5990-8084 07-16-85 RUN #1 7500-8632 07-25-85 RUN #1 5744-7129 07-26-85 RUN #1 4992-8144 07-13-85 RUN #1 6388-7554 07-24-85 RUN #1 6382-8032 03-26-85 RUN #2 6100-6600 . 05-19-85 RUN #1 '5450-6950 07-09-85 RUN #1 6000-8411 07-09-85 RUN '#1 5500-8173 07-01-85 RUN #1 2700-6617 07-01-85 RUN ~1 6100-8011 05-31-85 RUN #1 6000-7743 07-14-85 RUN #2 6139-8089 07-0 ~-85 RUN Sl 5500-8096 05-09-85 RUN #1 6186-7762 07-14-85 RUN #i 7485-8210 07-14-85 RUN #1 8190-8805 RECEIPT ACKNOWLEDGED: DISTRISUTION: BPAE DRILLING*BL W. PASHER B. CURRIER L. JOHNSTON ,. hXXON CHEVRON MOBIL PHILLIPS OIL D & M NSK CLEkK*BL J. RAThMELL STATE O~' A.aA,*~ ~.u SOHIO /SE UNION VAULT/~O* FILMS ARCO Alaska. in~' Post O'tfic~_. ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RJSTUPJ~ TO: DATE: 08-21-85 TRANSMITTAL NO: 5292 ARCO aLASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLEI{K ATO-1115B P.O. BOX 100360 ANC HOP, AGE, AK 99510 TRANSMITTED kECEIPT KUPARUK ' lB-1.. -'lB-2. '~lB-4' ~ 05-16-85 ' 1C-4 07- 24- 85 CAMCO "1C-6~'' 07-25-85 CAMCO ~ iD- 8 -~ · U 7- 30- 85 CAMCO --1H-3 ~' 07- 30- 85 CmqCO ~'lQ-13''~ 06-24-85 CAMCO ~ 1Q-14-~ 06-23-85 CAMCO "iQ- 15'"' O 6- 21- 85 CAMCO "lQ-16'~ 06-21-85 CAMCO ' 1R- 5'"' 07-05-85 'CAMCO - 1R_6-/ 07-06-85 CAMCO ' iR- 7/ 07- 06- 85 CAMCO 'lR-8 ," 07-08-85 CAMCO "2A-2 .... 07-04-85 OTIS ~2W-7" 07-26-85 DRESSE~ "'2V- 3 07-11-85 OTIS "2W-15'' 08-04-85 OTIS 3B-t 06-14-85 ???? ' 3B-2~--' ' 06-14-85 CAMCO -3B-3'~ 06-28-~5 OTIS "3B-3" 06-15-85 CAMCO -3B-4 ~ 06-15- 85 CA~]CO - 3B-5 -~- 06- 26- 85 CAMCO ' 3 B- 6 ~ 06- 26 - 85 CA~CO ~3B-7-~ 06-28-85 ' CA~/CO 3B-7-~ 06-27-85 CAHCO 3B-8~ 06-28-85 OTIS ~3B-9-~' 07-18-85 CAS]CO ~3B-10-'~ 07-20-85 CAMCO '3B-11-~ 07-20-85 CAMCO 3B-12-~ 07-21-85 CAMCO 3B-13. 05-29-85 OTIS ~3B-14. 05-29-85 OTIS RECEIPT ACKNO~¢LEDGED: AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. WELL PRESSURE REPORT--ENVELOPE 05-30-65 CAMCO ~3 FACE DATA · B-15 . 05- 30- 85 CAMCO 3B-16-"' CAMCO ~ 3C-11 HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE 05-28-85 OTIS 05-28-85 OTIS 07-29-85 CAMCO DISTRIBUTION: BPAE* DRILLING W. PAShER B. CURRIER L. JOHNSTON EXXON CHEVRON* ~BIL* PHILLIPS OIL* D & ~* NSK CLERK J. RATHMELL* STATE OF ALASKA* SOHIO* UNION* K. TULIN/VAULT ARCO Alaska. Inc. ~s a Subsidiary of Altar~ticRichfieidCompany ARCO Alaska, Inc. [ Post Office B~X 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 24, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1B-4 Dear Mr. Chatterton- Enclosed is the Well Completion Report for 1B-4. questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU11/L117 Enclosure If you have any RECEIVED SEP26 ~ At;~S.ka OU & Gas Cons. Corrlmissiorl ltnchora.ge ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany , STATE OF ALASKA ALASKA'"L ..~ AND GAS CONSERVATION C(~ MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REVISED OIL I~Ix GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO A]aska~ inc. 81-65 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20595 4. Location of well at surface 9. Unit or Lease Name ~98' FNL, 622' FEL, Sec.9, T11N, R10E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1359' FSL, 1865' FEL, Sec.9~ T11N~ R10E~ UN 1B-~ At Total Depth 11. F~eld and Pool 963' FSLs 2361' FEL, Sec.9~ T11Ns RIOE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 9~' RKBJ ADL 256~8 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. 115. Water Depthl if offshore ,16. No. of Completions 06/23/81 07/08/81 07/1 ~/81 *J IN/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8~10'ND,6865'TVD 8278'ND,6777'TVD YES J~X NO []J 1922 feet MD 1650' (Approx) 22. Type Electric or Other Logs Run D IL/BNCS/GR, FDC/CNL/Cal, CBL/VDL/CCL/GR, CBL/CCL/GR, CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE.WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65.0# H-~0 Surf 80' 2M' 200 sx Permafrost 10-3/~" ~5.5# K-55 Surf 2871' 13-3//+" 1500 sx Fondu & 250 sx AS II 7" 26.0# K-55 SUrf 8363' 8-3/M' 700 sx Class G & 676 s: 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) 7550' - 7610' 2-7/8" 7697' 7~02' & 7658' 7786' - 7802' w/12 spf 7812' - 7858' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production ' '1 Method of Operation (Flowing, gas lift, etc.) 12/1~/81I FI owing Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 3/6/82 5 TEST PERIOD. I~ 0 0 -- 6~/6~ -- Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. -- _. 24.HOUR RATE "IF 0 0 .... 28. CORE DATA Brief description of iithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core chips. NONE RECEIV[D SEP 2 6 1985 Alaska 0ii & Gas Cons. Commission Anchorago Form 10-407 * NOTE: Well was recomplet;ed 5/30/85. TEMP2/WC09 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' 30. . · . GEOLOGIC MARKERS FORMATION TESTS . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7550' 6286' N/A Base Upper Sand 7605' 6325' Top Lower Sand 7774' 6442' Base Lower Sand 7851' 6494' ,. · 31. LIST OF ATTACHMENTS '~21 I hereby certify that the foregoing is true and correct to the best of my know~edge Signed____ &//~ , ~-~~ ....... Title Associate Engineer 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 2.3: Attached supplemental records for this well should show ~he details of any multiple stage cement- ing an~i the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 'i ARCO Oil and Gas .~,any A Well History- Initial Report- Daily h~tnlG~JM~: Pml:mr~ Ind ~bmlt the "lnltJ&l ~rt" on the first We~neKliy erie! · wall ia spudded or wort~over operations ire et&fled. Dilly wort( poor to spudding Bhould be ipmmirlzed on the form giving iflclueiv~ ds,es only. Dtstrl,~L Alaska Field Kuparuk River Auth. or W.O. no. AFE 703265 ISt&te Alaska IVell rm. ICoLIrt~. I)lLfisrl Or North Slope Borough kea~e or Unit ?itlo ADL 25648 · I Recompletion API S0-029-20595 wws #1 Operltor ARCO Alaska, Inc. Sledded or W.O. begun Workover IARCO W.I. ID'*a 5/25/85 IH°ur 1600 hrs. rri°r ststus Dill Ind ~pth · - of 8:00 i.m. 5/~/~ 5/27/85 5/28/85 5129/85 5~30~85 :Complete recorO for lach day relx)rtea The IDove is correct 56.24% if a W.O. 7" @ 8363' 8278' PBTD, POOH & LD 3½" tbg 9.8 ppg NaCl/NaBr Accept tis @ 1600 hfs, 5/25/85. RU to kill well. Pull BPV. RIH, pull d,,mmy in GLM @ 7383'. Kill well by pmp'g 45 bbls BridgeSal pill, followed by 9.8 ppg NaC1/NaBr. Cftc well. ND tree, NU BOPE. Pull BPV. TAt BOPE to 250/3000 psi. Pull 2-way ck vlv, pull & LD tbg hgt. Circ 9.8 ppg brine, observe well; well dead. Pull & LD 3½" tbg'& jewelry. 7" @ 8363' 8278' PBTD, Ctrc fill @ 8000' 9.8 Ppg NaCl/NaBr POH w/3½" Cbg. Rel retry pkr & POH. fill @ 7846', wsh to 8000'. RIH w/bit & scrpr, tag 7" @ 8363' 8278' PBTD, NU BOPE 9.8 ppg NaC1/NaBr Cart, POH. RIH, log CET f/8000'-7200' ND BOPE, chg out tbg spool, NU BOPE. . RIH w/BP, set @ 7500'. 7" @ ~8~M' 8278' PBTD, Rn'g 2-7/8" CA 9..8 ppg NaC1/NaBr NU & tat BOPE. RIH w/DP, unset BP. RIH w/WL pkr & tailpipe assy, set pkr @ 7643~. RIH w/2-7/8" compl string. RECEIVED SEP 2 6 AJaska OJJ & Gas Cons. Commission Anchorage Signature , For form pr~psrstion'--~'~ci see ProceOures Manual. Se~Jon 10, Drilling, PAges 86 And 87. IC)ale 6/14/85 DrillJ ug S-~u erinte~dent ARCO Oil and G Company Well History-Final Report Instructions: Prepare and submit the "Final Rel~orr' oD the first Wednesciay after allowable has been assigned or well is Plugged. Abanc~oned. or Sold. "Final Rapoll" should be submitted also when operations are suspended fo~ an indefinite or aDoreciable length of time. On workovers when an official test is not required uDon completion, report completion and representative test gala in blocks provided. The "Final Ref~ort" form may be use0 for reporting the entire ol:)era.on it space is available. Accounting cost center cocte District ICounty or Parish State Alaska I North Slope Borough Alaska Field 1Lease or Unit tWell no. Kuparuk River ADL 25648 lB-4 Auth. or W.O. no. ~ Title AFE 703265 I Recompletion WWS #1 AP1 50-029-20595 Operator J A.R.CO. W.I. ARCO Alaska, Inc. J 56.24% Sl~udded or W.O. begun jDate Workover J 5/25/85 Date and depth Complete record for each gay reporteC as of 8:00 a.m. 5/31/85 t otal number of wells (active or inactive) on this dst center prior to plugging and banctonment of this well our i Prior status if a W.O. 1600 hrs. 7" @ 8~ 8~' 8278~ PBTD, RR 9.8 ppg NaCl/NaBr Rn 243 its, 2-7/8", 6.5#, J-55 EUE 8RD IPC tbg. Set pkr, shear PBR, set BPV. ND BOPE, BTU & tst tree. Displ well to crude. Tst SSSV. RR @ 2400 hfs, 5/30/85. SSSV @ 1922', Retrv Pkr @ 7402', Pe'rm Pkr @ 7658', "D" Nipple @ 7680' , Tailpipe ~- ~697' . Old TD Released rig 2400 hrs. Classifications (git, gas, etc.) Oil Progucing method Flowing Potential test data jNew TD Date PB Depth 8278' PBTD l Kind of rig 5/30/85 Rotary t Type compJetion (single, 0ual. etc.) Single Officialrese ; im;:)k Et\! E D Well no. Date Reservoir Producing Interval Oil or gas Test time SEP Alaska OJJ & G ]sJ co.s. cO¢ilmJs~;Jofl , ;Pump size, SPM X length Choke size T.P. C.P, Water % GOR Gravity ~0~]~}iG~le Effective date corrected .... ,, ,, The above is correct Signature For form preDaratio~ a~strib~tion, see Proceaures Manual, SeCtion 10, Drillin~, Pages 86 and 87. Date ITitle J 6/14/85 Drilling Superintendent ARCO OII and Gas cofrnpany O Well History - Initial Report- Dally PreOam eno ~uOmit the "lni#e[ I~e~efl" on tl~ flret WeOneses-y Iftor · well is SOuOOeCl or wortsover oDeritions ere mirte~. Dilly wort[ I~f~or to ~l=uooing shouIcI be i&immarizeO on the tofm giving inciu~iv~ Clates only. l:ielO Alaska North Slope Borough t'"' ADL 25648 of Unit ITl., Re comp le ~ ion Alaska Kuparuk River Au~. or W.O. AFE 703265 WWS fl tell no. 50-029-20595 09~retor ARCO Alaska, Inc. SI)uOCleO or w.o. ~)egun ~o;~oYer Dire IHour 5/~5/85 Dire Ind Otl)~ u ot 8.00 a.m. 5/27/85 5/28/85 5/29/85 5/30/85 ComDtote re¢or(~ tot eech Cl~y re~x)rtecl 1600 hrs. IARCO W.I. Prior ~tatus if · W.O. 7" @ 8363' 8278' PBTD, POOH & LD 3½" tbs 9.8 ppg NaCl/NaBr Accept ri~ @ 1600 hfs, 5/25/85. RU to kill well. Pull BPV. RIH, pull dummy in GLM @ 7383'. Kill well by pmp'g 45 bbls BridgeSal pill, followed by 9.8 ppg NaC1/NaBr. Circ well. ND tree, NU BOPE. Pull BPV. Tst BOPE to 250/3000 psi. Pull 2-way ck vlv, pull & LD tbg hgt. Circ 9.8 ppg brine, observe well; well dead. Pull & LD 3½" tbg'& jewelry. 7" @ 8363"- ' 8278' PBTD, Circ fill @ 8000' 9.8 ppg NaCl/NaBr POH w/3½" tbg. Rel retry pkr & POH. fill @ 7846', wsh to 8000'. RIH w/bit & scrpr, tag 7" @ 8363' 8278' PBTD, NU BOPE 9.8 ppg NaC1/NaBr Circ, POH. RIH, log CET f/8000'-7200' ND BOPE, chg out tbg spool, btU BOPE. · RIH w/BP, set @ 7500'. / 7" @ ~5-~83~ 8278' PBTD, Pm'g 2-7/8" CA 9.8 ppg NaCl/NaBr NU & tst BOPE. RIH w/DP, unse~ BP. RIH w/WL pkr & tailpipe assy, set pkr @ 7643;. RIH w/2-7/8" compl string. The &Dove is correct RECEIVED 56.24% / D,,, 6/14/85 DrillJ:,K S'~u erinte'ndent ARCO Oil and G(. Company {r .ily Well History-Final Report Inltl'~clienl: Pr~ptre lng suPmlt the "F|nll llllN~ll'* o.n the first WeDnesDay after allowable has I~eefl assigned or welt is Plugged. AOlnOOne¢. or SOLO. "Filial R~I'I" should De auOmitteo also when operations are suspenDeD for an inoelin,te or appreciaDle length Ot time. On worKovers when an official test il not I'l¢luireo upon completion, rel~311 completion eno representative Test ~3ata tn OIocks Drovioe(~ The "Final R~rt" form may De use¢ for repofltng the entire Ol~rstlon it SPece is avsilsPle. District ICounly or Partsn Alaska Fielcl ~Lease or Un,,. I Kuparuk P, tver Auth. or W.O. no. [ Title AFE 703265 I WWS #1 North Slope Borough ODeretor A~CO Alaska, Inc. SpuOclecl or W.O. ~)egun Workover APL 25648 Date end Depth Ss of 8:00 a.m. 5/31/85 Recompletion AP1 50-029-20595 IA R.Co. W I. 56.24% Dst, 5/25/85 Complete recorcl tot sion Oly reDcrteo Accounting cost center cone_ S:ate Alaska OlD TD t otal numoer of wetl5 {acttve or ,nactwe) on This DSt center prior to plugging anti banOonment of this well our tPrior Stltus if s W.O. 1600 hrs. I 7" @ 8-B~3~3t 8278¢ PBTD, RR 9.8 ppg NaCl/NaBr Pm 243 its, 2-7/8", 6.5#, J-55 EUE 8RD IPC tbg. Set pkr, shear PBR, set BPV. ND BOPE, NU &tst tree. Displ well to crude. Tst SSSV. RR @ 2400 hfs, 5/30/85. SSSV @ 1922', Retrv Pkr @ 7402', Perm Pkr @ 7658', "D" Nipple @ 7680 ' , TailpiPe ~ ~697t. IWell nO. New TD Released ng Date 2400 hrs. Classifications (oil. gas. etc.) Oil ProDucing methocl Official reservoir name{s) Flowing Kuparuk Sands Potential test oats [ PE De.mn Kin(3 0f rig 5/30/85 Type completion (single, Dual. etc.) Single 8278 ' PBTD Rotary Well no. Date Reservoir ProDucing Inlervat Oil or gas ['~est time ProOuction Oil on test IGas per , Pump size, SPM X lengt~ C~oke s~ze T.P. C.P. Water % GOR Gravity correcte~ The adore iS correct ~'-~ ~Oi~i~; £'" ...... j Signature ~ Date iT,lie A~ChOr~'O~u erlntendent ~ ~_~/ [ 6/14/85 Drilling~O P ' ~e PrOCedureS M~I, ~CtiOn 10, Drilling, Pages 86 an~ 87. RETURN TO: ARC'" ",laska, Inc. ~st Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. 'BOX 100360 ANCHORAGE, AK 99510 DATE: 06-19-85 TRANSMITTAL NO: 5230' PAGE 1 OF 2 TRANSMITTED HERE%4ITH .ARE THE' FOLLOWING ITEMs. PLEASE ACKNOWLEDGE RECEIP? AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. SEQUENCE OF EVENTS PRESSURE, FLUID,~ AND ACID DATA lB-! SBHP 05-30-8 lB-2 SBHP' 05-30 -8 :~'4 SBHP 05-16-8 ,~ ~,~ 'L PRE-WORKOVER 05-24-8 ID-8 SBHP 04-29-8 1E-lA TUBING LEAK 05-03-8 1E-11 LEUTERT BH SMPL 06-02-8 os- -8 iS-27 TEMP/SPIN-LEAK 05-03-8 1E-27 TUBING LEAK 05-04-8 1G-6 _R~SSURE F~L- 05-07-8 OFF 1H-6 SBHP 04-29-85 1L-5 PBU W/E-LINE 04-27-85 1L-5 PBU 04-29-85 lQ-1 iSIP ~ 05-30-85 .!Q-! SBHP 'A'SDS 05-26-85 lQ-3 TAG FILL BHP 05-18-85 lQ-4 SBuP 'C'~ ,- ,?: SD ETC 05-10-85 iQ-4 SBHP ETC 05-14-85 1~4 ACID JOB 05-17-85 lQ-5 iSIP TEST 04-29-85 1~7 ACID JOB 05-26-85 !Q-9 'C' SD PBU 05-12-85 1~9 PSU 'C'SD ETC 05-13-85 1Y-12 FA~ LL-OFF TEST 05-05-85 2A-2 RHP 05-27-85 2A-4 'A'SD BHP 05-!0-S5 2A-4 'A'SD BHP 05-09-85 2A-4 'A'SD BHP 05-11-85 2A-5 SBHP 05-05-85 ***CONTINUED ON THE 'FOLLOWING RECEIPT ACKNOWLEDGED: FROM WELL SERVICE REPORTS (ONE COPY OF 5 CAMCO 5 CAMCO 5 CAMCO 5 CAMCO 5 CAMCO 5 CAMCO 5 CAMCO 5 OTIS 5 CAMCO 5 CAMCO 5 CAMCO 5 CAMCO 5 CAMCO BPAE* DRILLING B CURRIER L. uOHNS~ON CHEVRON * ~0~ ~., '~ EACH ) CAMCO CAMCO CAMCO B. J. HUGHES CAMCO CAMCO CAMCO CAMCO NOWSCO/B. J.HUGHES B. J. HUGHES NOWSCO/DOWELL CAMCO /.% CAMCO ' ~ CAMCO OTIS CAMCO CAMCO CAMCO CAMCO PAGE *** U T"I ON: W. PASHER EXXON PHiLLLIPS OIL* J. P~ATHMELL,~ ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany A~as~a O:;[ & ~as Gaas. ~'' DATE: ARCO Alaska, Inc. Post Office Bo 0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 17, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached in duplicate are subsequent following wells at the Kuparuk River Field' notices on the Well 1B-2 1B-4 1E-lA 1E-lA 1E-27 1E-30 1F-6 1F-13 1G-1 1Q-5 1Q-6 1Q-7 1Q-11 1Q-13 1Q-14 1Q-15 1Q-16 1Y-2 ..~1Y-8 '1Y-12 2A-2 2C-8 2C-1 4 2H-15 2V-2 Action Date Performed Fracture Fracture Cancellation (Reperf) Cancellation (Frac) Cancellation (Frac) Polymer Proiect Cancellation (Frac) Cancellation (Frac) Cancellation (Stressfrac) Acidize Acidize Fracture Cancel lation Fracture Fracture Fracture Fracture Conversion COnversion Conversion Conversion Cancellation Acidize Stimulation Conversion (Frac) (Perf) 6/14/85 6/14/85 115185 6/23/85 6/24/85 6/25/85 7/2/85 7/1/85 7/2/85 7~2/85 3/30/85 3~30/85 3/30/85 3/31/85 7/2./85 6~30~85 5/16/85 If you have any questions, please call · T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) me at 263-4212. ARCO Alaska, Inc. I$ a Subsidiary of AllantlcRichfieldCompan!** ARCO Alaska, Inc. ( Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 11, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Subsequent Sundry Reports Dear Mr. Chatterton. Enclosed are Subsequent Sundry Reports for the following wells' 1B-2 1B-4 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L64 Enclosures RECEIVED JUL 1 5 lgB§ AlaSka Oil & Gas Cons. commiss|otl Anchorage ARCO Alaska, Inc. is a Subsidiary ol AtlanticRichlieldCompany O STATE OF ALASKA O(M ALASKA IL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLx~ OTHER [] 2. Name of Operator ARCO Alaska~ Inc. Address Po 0. Box 100360~ Anchorage~ AK 99510 4. Location of Well Surface= ~98' FNL~ 622' FEL~ Sec.9~ T11N~ R10E~ UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 98' 6, Lease Designation and Serial No. Anl 256~.8 ALK ~.6~_ 7. Permit No. 81-65 8. APl Number 50- 9. Unit or Lease Name 10. Well Number 1B-~ 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 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). Accepted rig ~ 1600 hrs, 5/25/85. Killed well. ND tree. NU BOPE & tstd to 3000 psi - ok. Pulled 3-1/2" tubing. Retrieved pkr. Ran CET f/8000' - 7200'. Tstd csg to 2000 psi - ok, Ran 2-7/8" completion assy w/tail ~ 7697', pkrs ~ 7658' & 7~02', & SSSV ~ 1922'. ND BOPE. NU tree & tstd to 5000 psi - ok. Disp we]] w/257 bb]s crude. Set BPV. Secured well & released rig ~ 2~00 hfs, 5/30/85. RECEIVED J U L 1 5 1985 Alaska 0il & Gas Cons, Commission Anchorag~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~) (~J'}~b/)~.~ ~..~/~ Title Associate Enqineer The space belo~Jfor Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10~t03 Rev. 7-1 .-80 GRU10/SN05 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate O STATE OF ALASKA O~M ALASKA IL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Nan)~i~L-~er~SKA, INC. 3. Adc~.ss 'Oo BOX 1 00360, ANCHORAGE, ALASKA 9951 0 4. Lo~,~(~: LOCATION' 498' FNL, 622' FEL, Sec. T11N, R10E, UM OTHER [] 5. Elevatio~nlfeet((~t)e KB, DF, etc.) 12. 7. Permit No. 81 -65 8. APl Number 50- 029-20595 9. Unit or Lease Name KUPARUK RIVER UN ! T 10. Well Number 1B-4 11. Field and Pool KUPARUK RIVER F I ELD I 6. Lease Designation and Serial No. KUPARUK R ! VER O I L ADL25648 ALK 466 , POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate E~ Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] ~ Abandonment [] [] Other [] 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 June 14, 1985, the "A" sands of Kuparuk well 1B-4 were hydraulically fractured and propped to improve production. The treatment consisted of 327 BBLS of gelled diesel as pad and carrying fluid and 11,920 LBS of 100 mesh and 20/40 sand as proppant. 51BBLS of gelled diesel was used as a flush. Prior to pumping, equipment and lines were tested to 5000 psi. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ..~, ~d~.-~ (Z~..,¢.~-~,~ Title The-space below for Commission use KU PARU K O?ERAT i ONS COORD i NATOR Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Post Office x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 3, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Kuparuk 1B-4 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to convert 1B-4 to a selective single completion. Since we expect to start this work on May 10, 1985, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, J. B. Kewin Area Drilling Engineer JBK/JWR/tw SN/L029 Enclosure RECEIVED MAY 0 1985 0it & Gas Cons. Commission A~chorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LLx~ OTHER [] i 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 498' FNL, 622' FEL, Sec.9, T11N, R10E, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 98' 6. Lease Designation and Serial No. ADL 2RE;/~R Al K 7. Permit No. 81-65 8. APl Number 50-- 029-20595 9. Unit or Lease Name 10. Well Number 1R-4 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate ~ Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing ~L~ Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment . [] Other 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). ARCO Alaska, Inc., proposes to convert well 1A-3 to a selective single completion. The procedure will be as follows: 1. Well will be killed with brine. Weight to be determined after running pressure bomb. Current completion assembly will be pulled. A CET will be run to test for zone isolation between the A'and C Sand. required. A retrievable packer will be run to test casing. The well will be completed as a selective single. After the rig is released, an acid and/or frac job will be done. A squeeze will be performed, if A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wirelinework. subsurface safety valve will be installed and tested upon conclusion of the job. RECEIVED Estimated Start: May 10, 1985 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed )~'~_~_ .J ,YI~ Y [~ ~)~1~¢~ Area Drilling En,i neet The space below for ~ommission use '1-- ~/ The s,s,m, .t _ MAY 0 3 1985 '~'7[/7/~ Alaska 0ii & Gas Cons. Commission Anchorage Conditions of Approval, if any: Approved by COMMISSIONER -Approved Copy Returned. By Order of the Commission Date Form 10-403 (JWR) SN/053 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE Of ALASKA ~) .ALASKA£~.~,'LAND GAS CONSERVATION C(~ MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-65 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20595 4. Location of well at surface 4~8 ' FNL, 622' FEL, Sec ~, ll 1N, R10F_, UM 9. Unit or Lease Name Kupaurk River At Top Producing lnterval 1386'FSL, 1812'FEL, Sec 9, TllN, R10E, UM 10. WelINumber 1B-4 At TotaI Depth ¢¢~/'FSL, ~'FEL, Sec 9, TllN, R10E, UM 11.FieIdandPooI ~lbO ¢,~.~i Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 94' RKB ADL 25648 Kuparuk River 0il Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ] 15. Water Depth, if offshore I 16. No. of Completions 6/23/81 7/8/81 7/14/81I -- feetMSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8410' MD O~(~31v~ 8278 ' MD 6-/77'11/~) YES [~ NO []I 1957 feet MD 1650 (approx) 22. Type Electric or Other Logs Run DIL/BHCS/GR, FDC/CNL/CAL, CBL/VDL/CCL/GR, CBL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-40 Surf 80 24 200sx Permafrost 10 3/4" 45.5# K-55 Surf 2871 13 3/4 1500 -x Fondu & 25~) sx AS II -- 7" 26~ K-55 Surf 8363 8..3/4,' 700 sx Class .., ~ ~, .~ ,. ~ 24. Perforations'open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD , interval, size and number) . SIZE DEPTH SET (MD) PACKER SET (MD) · 3 1/2" 7508' 7439' 7550'-7610' . 7786'-7802' w/12 SPF 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 7812'.- 7858 ' . , , ,~ DEPTH. INTERVAL... . (MD) AMOUNT& KIND OF MATERIAL USED N/A "." . . '. · , 27. PRODUC"~'ION TEST ' " Dat~, F rst Product on , "' I Method of Operation· (FI, owing,.gas lift, etc.) - 12/14/81I F']'owJ. ng . .... ,'. :'. "' ' Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I'G'AS-OILRATIO 3/:6/82 5 ~ '.. · . TE,S'E PERIOD I1~ 0,';. 0~" -- r,~/64'] -- · Flow Tubing Casing Pressure CALCULATED OIL-BBL .GAS-MCI~ WATER-BBL OIL GRAVITY-APl (corr) 'Press. '24-H©,U.R RATE, 0 ' ' 0 · " ' :-- "28. CORE DATA r 'Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. . · , , · ' N/A ., , -I~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' 30; - GEOLOGIC MARKERS FORMATION TESTS "i NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk River Form. 7519' 6264' Base Kuparuk River Fot'm. 7927' 6545' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed , . , Title Area 0os. 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 Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 [ NORTH ~LOPE -~,GI,.I~RI~,~ TRAi!SHITTAL ~ //0'¢ J. J. Pawelek/Ann Simonsen DATE' /"/Z--' ~'~ WELL NAME' Transmitted here:.;ith are the f°l'lowing' PLc~c-~..~ HOTE' BL - BLUEL~r.'E,,,, S - SEPIA, F - FILM, , . T - TAPE E R_, UR,~ ,,-~.,.~FT TO RECEIVED DATE' ARCO ALAS }gA I ~' ~ A~ask~ Oil & Gas Cons. Commission , .,,-. Anchorage ATTH' ANN SI:'n:'q~','~u,~,_',, - AFA/311 P.O. BO:,: 360 ~. .- ~,, 9c"10 , NORTH SLOPE E~GINEERIi~G J. J. Pawe'Lek/Ann Simonsen DATE' WELL ""'":' I l/"~l'iL · ~-'~ here,..:i Transml~d th are the following · -- ~ -- PLEASE ~{OTE' 9L BLUEL!iIE S £EP.,-,, F- FILM, EEcE'r PT ACK;;OWL r~E'GF_D· B'Y [OHNIE C. SMIfil DATE' ARCO ALAS>CA, INC. ATTIC: A;~;i SIMONSE~! - AFA/3tl P.O. BOX .360 A:~C;":C''~?~: AK om510 RECEIVED ...... · .,,.,T I 4 Nasl(a Oil & Gas Cons. Coi~BissJori Anchorage STATE OF ALASKA (" ALASKA L AND GAS CONSERVATION C(~,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] X OTHER [] 2. Name of Operator ARCO Alaska, 3. Address P.O.Box 360, 4. Location of Well Surface Location: Inc. Anchorage, AK 99510 5. Elevation in feet (indicate KB, DF, etc.) KB=98~0 12. 498' FNL, 622' FEL, Sec. 9, TllN, R10E 7. Permit No. 81-65 8. APl Number 5o- 029-20595 9. Unit or Lease Name Kuparuk -~36~1~~ 10. Well Number 1 1. FielO and Pool F uparuk River Field I6. Lease Designation and Serial No. I~ uparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Perforate Stimulate Repair Well Pull Tubing NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) [] Alter Casing [] Perforations [] Altering Casing [] Abandon [] Stim u lat ion [] Aba ndonment [] Change Plans [] Repairs Made [] Other [] 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). Began clean out operations on 8/27/81. Tested CTU to 3400 psi & Flow . Lines to 2800 psi. BPV left in TBG HGR.. RD to pull BPV. RU CTU and re-press test CTU and flow lines. RIH & pump deisel. Good returns throughout. Total diesel pumPed 120 bbl. RU WL unit & test Lub to 3000 psi. RIH w/Shifting tool, lock into release sub & release Vann gun, chased to 7523' (WLM). SITP=850 psi. Open well to tank, FTP=100 psi . RU CTU and press test CTU & Flow Lines. Pump diesel and flow returns to tank. Tagged obstruction @ 7561~', believed to be Vann gun. Pumped total 135 bbl diesel. Well displaced W/diesel. RD & SI well 8/30/81. Flowed at rate of 160 B~PD no Prod logs or pressure survey run. RECEIVED OCT 1 & 1981 Alaska Oil & Gas Cons. Commission A. chorage 14. I hereby certify ~hat the foregoing is true and correct to the best of my knowledge. ~ ~ ~~-~-~--~ Area Operations Engineer Signed ,; _, ---., __ . Title The space bel~ for Commission use ~ Conditions of Approval, if any: ~/ Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate October 9, 1981 Mr. P. A. VanDusen District Drilling Engineer ARCO Alaska, Inc. P. O. Eox 360 Anchorage, ~ Alaska 97510 Dear ~r. VanDusen~ %~e have recently received completion reports on several wells where the repOrted bottom hole location cannot be. verified by the directional surveys that have also been submitted. The list of the wells, in question is enclosed. we would appreciate your checking to determine the data used in arriving at the bottom hole locations for these wells. Since w~ have an internal program to cross-check the accuracy of the submitted data, it is necessary to detemine why the discre- pancies exist. If you could have a m~ember of the department that determines this data call Mrs. Elaine. Johnson at 279-1433 it should pin- point where and why there are differences. Thank you for your help in this matter. Yours very truly, Harry W. Kugler · Commissioner Enc 1 o sure HWK: be ALASKA OIL AND GAS CONSERVATION COMMISSION i~LL LCCATIO;i~ DISCP. EPA}~CIES Kuparuk 25647 Kuparuk 25648 Kuparuk 25649 A-2 The following 'are all in the Prudhoe Bay Unit: DS 12-12 DS 14-11 DS 14-19 DS 14-20 DS 16-4 DS 16-5 DS 17-7 DS 17-8 DS 17-9 P. A. Van Dusen(~ Eeptember 2, I981 Incomplete Completion Reports Well Name and Number Comp 1 e t i on / Ab a ndo nme nt Suspension Date Prudhoe Bay Unit DS 16-1 Prudhoe Bay Unit DS 14-9A Prudhoe Bay Unit DS 16-4 West Sak 18 Prudhoe Bay Unit' DS 16-5 Kuparuk C- 8 Prudhoe Bay Unit DS 14-19 ?rudhoe Bay Unit DS 17-7 Prudhoe Bay Unit DS 14-20 Prudhoe Bay Unit DS 12-11 Kuparuk A-2 Prudhoe Bay Unit DS 17-8 1-9-81 3-21-81 3-27-81 4-17-81. 4-21-81 5-15-81 6-6-81 6-10-81 6-30-81 7-1-81 7-2-81 7-2-81 Overdue (?) ComPletion Reports ~oe .Ba~ Unit DS 16-14 Kuparuk A,3 Prudhoe Bay Unit DS 17-9 Prudhoe Bay Unit DS 12-12 7-9-81 7-14-81 7-24-81 7-25-81 7-26-81 ARCO Alaska, Inc./ Post Officer~ Telephone 907 277 5837 September 28, 1981 Mr. Harry Kugl.er State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 12-11. DS 16-4 West Sak #18 DS'I 2-12 DS 16-5 A-2 DS 14-9A DS 16-14 A-3 DS 14-19 DS 17-7 B-4 DS 14-20 DS 17-8 C-8 DS 16-1 DS 17-9 Dear Sir' Enclosed please find the Completion Reports for the following wells: A-2, A-3, B-4 and C-8. Although these Kuparuk wells have been per- forated, production test data has not been obtained; this information will be forw. arded to your office when available. Also enclosed are Completion Reports for the following wells: DS 12-12, DS 14-19., DS 14-20, DS 16-4, DS 16-5, DS 17-7, DS 17-8 and DS 17-9. Production test information is not applicable'for these wells since they have not yet been perforated but will be submitted to your office when we obtain the information. Previously unreported information such as locations for bottom hole, producing interval and geological forma- tions have been.added to the updated Completion Reports. DS 14-9A and West Sak #18 have been plugged and abandoned. An updated Completion Report with Drilling Histories 'for these wells is enclosed. Information regarding west Sak #18 is of a confidential nature and we would appreciate securely storing the report where it will receive minimum exposure. The initial Gyroscopic Survey for DS 16-1 was unacceptable and a rerun is presently, being authorized by our engineering staff. An updated Completion Report for this well will be sent to your office subsequent to our. receiving an acceptable survey. The remainder of the requested information - an overdue Completion Report on DS 16-14 and an incomplete Completion Report for DS 12-11 was sent to your office August 27, 1981 and was apparently enroute at the time of your September 2, 1981 letter to this department. Also included are completion Gyroscopic Surve~~~[~12, DS 17-7 and DS 17-9.' Si ncerely, pi.str~i~.ct Drilling Engineer SEP) 0 1981 A)~ska 0il & Gas Cons. Commiss[or~ Anchorage C~.:.~'AN STATE OF ALASKA O[ ALASKA D GAS CONSERVATION C ,./IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well -. OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] _ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-65 - 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 50- 029-20595 ., 4. Location of well at surface 9. Unit or Lease Name 498'FNL, 622'FSL, Sec 9, TllN, R10E, UM 'i~OC~Tlblqst Kuparuk River At Top Producing I'nterval VFRIFIED 10. Well Number 1386'FSL, 1812'FEL, Sec 9, T11N, R10E, UM Su~. ~ B-4 "7(~ I ~.,~ At Total Depth ~.~ ~ .,'B. H. _ /~ i 11. Field and Pool .9~FSL, ~'TFEL, Sec 9, T11N, R10E, UM '"' ' ' Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. ' .... Kuparuk River 0i 1 P0ol 98' RKBI ADL 25648 , , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 6/23/81 7/8/81 7/14/81 -- feet MSLI 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set J 21. Thickness of Permafrost 8410' MD 8278'MD YEs[~X NOI-1 1957 feetMDJ 1650 (approx) 22. Type Electric or Other Logs Run DIL/BHCS/GR, FDC/CNL/CAL, CNL/VDL/CCL/GR, CBL/CCL/GR. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-40 surf 80 24' ' 200sx Permafrost · 10-3/4". 45.5# K-55 surf 2871 13-3/4 1500sx Fondu & 250 sx AS II 7''r 26# K-55 surf 8363 ' '8-3/4 700sx Class G · · , 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) , 7550-7610 3-1/2 7508 7439 7786-7802 w/12 spf ... ,, 7812-7858 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED RODDC iON 27. P T TEST ' ,,, Date First Production I Method of Qperation (Flowing, gas lift, etc.) n/a · :.:· Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO ... TEST PERIOD ~. Flow Tubing'., Casin~P~essure :. CALCULATED· OIL-BBL GAS-MCF WATE~-BBL OIL GRAVITY-APl (corr) Press. . . . .. 24-.HOUR RATE.~ : 28. ~ ' ' COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. , , , , , . .~, ,. ,~ , . ,~.~m~ mmmmm. ~mm~ I~ imm ~, mmm ~ - ' Kt:Lt: V n n/a ':" ' ' '" " " ""' : SEP: 0198] '.?'. " ,~ : ." '. Alaska 0il&'Gas Cons. C0mmis~i0rt '. ~. Anchorage. Form 1'0-407 Submit im duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME MEAS. DEPTH TRUE VERT. DEPTH Top Kuparuk 7519' 6263' Top Upper Sand 7550' 6285' Base Upper Sand 7605' 6324' Top Lower Sand 7774' 6441' Base Lower Sand 7851' 6493' Base Kuparuk 7927' 6543' TD 8380' 6856' 31. LIST OF ATTACHMENTS Drilling History 32. I hereby certify that the foregoing is true and correct to the best · Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. n/a of my knowledge Dist. Drlg. Eng. 9/17/81 Title 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 c6'mpletion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 September 2, ~1981 . ~ Mr. P.~ A. Van Dusen District Drilling Engineer Arco~. Alas ka~ ~Inc. P.O.-:Box 360' ' Anchorage, Alaska 99501 Rem ~erdue Data Submission ~ar Mr. Van ~sen= ,. Wells on the arrayed lists are those for which C~pletion ~e~rts (form 10-407) are either inc~p'lete or apparently overdue, with completion, abande~ent, or suspension dates prior~ to August 1,' 1981. The first list is of those wells for which an incomplete Completion Peport was filed, with the comment that the locations at the top of the producing interval, and at the total depth were "to be submitted" or "N/A." Theicompletion dates go back to January, 9. The second list is of those wells for which available information indicates the wells have been cc~-~pleted, .but the 30 day filing period has passed without! a Completion Report having been submitted. : we need to be brought up-to-date on directional survey problems that may be responsible for these late filings, or have the required directional surveys, and reports submitted to us. We would appreciate a respon~se at your earliest convenience. Sincerely yours, Harry Keg ler Commissioner B~K / JAL/g lh ARCO Alaska, Inc. Post Office B. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 27, 1981 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive· Anchorage,' AK 99501 Subject: DS 12-11 DS 12-12 DS 13-5 DS 14-11 DS 16-14 DS 17-9 DS 17-10 DS A-3 DS A-4 DS B-5 Dear Sir' Enclosed please find' · The Monthly Drilling Reports for DS 14-11, DS 13-5, DS 17-10, DS A-4. 2. The subsequent Sundry Notice forDS 16-12. e The Well Completion Reports for DS 12-11, DS 12-12, DS 16-14, DS 17-9, DS A-3, DS B-4, DS B-5. Sincerely,· P, A. VanDusen District Drilling Engineer PAV/GLA:sp Enclosures AUG ! ARCO Alaska, inc. is a subsidiary of Aiii3ntlcRichfieldCompany . · · STATE OF ALASKA ALASK/~,"~L AN D GAS CONSERVATION ~MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-65 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 50-029-20595 4. Location of well at surface 9. Unit or Lease Name 498'FNL, 622'FEL, Sec 9, TllN, R10E, UM Kuparuk River At Top Producing Interval 10. Well Number To be submitted. B-4 At Total Depth 11. Field and Pool To be submitted., Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. ~paruk River 0i 1 Pool 98' RKBI ADL 25648 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 6/23/81 7/8/81 7/14/81 __ feet MSLJ ] 17. Total Depth (M D+TV D)8410, MD18. Plug Back Depth (MD+TVD) 82 78' MD YES [~X 19. Directional SurveYNo[] I20' Depth where sSsv set1957 feet MD I21' Thickness °f Permafr°stlE50 ( aDurox ~ . , , 22. Type Electric or Other Logs Run DIL/BHCS/GR, FDC/CNL/CAL, CNL/VDL/CCL/GR. CBL/CCL/GR. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-4Q ~urf Rfl 24 200sx Permafrost 10-3/4" 45.5# K-.~5 _~urf 2R71 1.~-_~/4 1~f1¢1~ Fnnrl,~ ~ ?~qfl ~v /),~ TT 7" 26# K-R~ ~urf R~t~.~ R-_~/zl 71'1f'1~¥ rlla** ~ 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) 7550-7610 ~- !/2 7508 7439 7786-7802 w/12 spf '. 7812- 7858 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED n/a , . 27. PRODUCTION TEST Date First Pr. oduction ":. " I Method of Operation (Flowing, gas lift, etc.) n/a I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ . I Flow Tubing Casing Pressure CALCULAT,ED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ ' 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit.core chips. ' RECEIVED n/a AUG z; 198I · . ,..... . .. Alaska, Oil & Gas Cons. Commission , Anchorage ' . Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTHi GOR, and time of each phase. To be submitted n/a ,, 31. LIST OF ATTACHMENTS ~, ,11.,,,g H,otory J2. i hereby certify that the foregoing is true and correct to the [Jest of my knowledge Signed_ ,~./1~. ~~ Title.. 2' ~""~"" (~'' uisL. Dr'lg. Eng oat~ INSTRUCTIONS iGeneral' 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,.Ithis well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item. 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10~,07 B-4 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 0100 hrs, 6/23/81. Drld 13-3/4" hole to 2895'. Ran multishot. Ran 69 its 10-3/4" 45.5#/ft K-55 csg w/shoe @ 2871'. Cmtd 10-3/4" csg w/1500 sx Fondu & 250 sx AS II-ko ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000'~psi - . NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-3/4" hole to 8311'. Ran DIL/BHCS/ GR, FDC/CNL/CAL, CNL/VDL/CCL/GR. Drld 8-3/4" hole to 8410' TD. Ran 189 its 7" 26#/ft K-55 csg w/shoe @ 8363'. Cmtd 7" csg w/700 sx Class G cmt.~ Displaced cmt in DP w/NaC1/NaBr. Instld 7" packoff & tstd to 3000 psi - ok. Tstd csg to 3000 psi - ok. Cleaned out cmt to 8278' PBTD . Arctic packed 7" x 10-3/4" annulus w/300 bbls H20, 250 sx AS I & 11~ bbls Arctic pack while running Gyro. Ran CBL/CC[/GR. Ran 3½" perf completion assy w/tail @ 7508' & pkr @ 7439' on CCL. Tstd tbg hanger & packoff to 3000 psi - ok. Displaced well to diesel. ND BOPE. NU tree & tst to 3000 psi - ok. Tstd tbg to 3500 psi & ann to 200 psi - ok. Tstd tbg to 200 psi & ann to 3500 psi - ok. Dropped perf bar & perf'd 7550-7610, 7786-7802 & 7812-7858 w/12 spf. Flowed well to tst tanks to clean up. SI well. Released perf guns. Bull headed 50 bbl diesel. Pulled dummy valve. Closed SSSV. Instld tree cap & tstd 3000 psi - ok. Secured well & released rig @ 2400.hrs, 6/14/81. RECeiVED AUG ~ 1 ]98] Alaska Oil & Gas Cons. Commissio~ Anchorage July 14, 1981 Mr. Bob Hines ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. Boss-16844 D.S. B-4 (SEC9 TllN R10E) Kuparuk Field North Slope, Alaska Date of Survey~ July 10, 1981 Operator: Johd Samec Dear Mr. Hines: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Yours very truly, SPERRY-SUN, INC. Kirk Afflerbach District Supervisor KA/pr Enclosures COMPLE T ! ON" R EP'ORT-'-FOE'"SPERRY';'S-i~N-B-~FI~'-~'YND'SEY ~ ................ t~AD'! US' 'OF "CURVAT"URE--r"~E ARCO ALASKA INC, WELL B-~ ~UPARUK F[ELD NORTH SLOPE~ ALASKA ~' -.-..SURVEY DATE JULY [0 GYROSCOP iC '-'SURVEY ........................................................................... BO55 Z6844 COMPUTER DATE Z6 AUG MEAS. DRIFT VERTICAL.:, SUB,:'; .: .J::DRI::FjT:;.;;;i;i;:~;:i?i.~i.!~;TOTAL:" COOR'DINATES .::, ,C.L 0 ;:$::?U':~Ei:;::i:E~!$:i.':i::i;:'' :$EVERITY SECTION D~H ANGLE'. DEPTH SEA :'i..::'i.:. "...' .'.: !..' DEG/1OOFT DISTANCE ........ - ......... ...... . =...._ ..... .......................... ............ = _... ................................... D ~ ~ 0 0 0 0,00 -98,00 S O.OOW 0.00 5 0.00 W 0.00 ..5 0 0 0 W 0.000 ':--I-O0~"-OTl'8'--"'~g'9'*-99"-~- ........ ! ;' 99'~TSF~-~J~;.'!&'o'r~ i{:-'O" 23 :~S':;~:".:~'~F~il;.O ;'10 "W ' . 0.25' .:5~72~'~'~;:::0'~'' W".';'.;::"o. 300 2'00:":'.::0:. 7.:' 199,99':.. lOZ,gg.:-::~:'~?Ne'i"90W~:~ ::?0" 32 :: 5:"/'?'~:~:~:;~::::'0 ':~4':~:.w'-:" 0'55':::5-753:;3~:~i8'W::: 0,183 300 0 5 299,99 201,9g :':}':N67'SoW?:'~:~f:~?:.O.ZS:'S.'-'.?:':..'/:.O,61 W:'. ':": 0.67 S:)f"65 1~'~?'28 W ' 0.033 ---~'O-~0' ~ 39'9;'99 ......301-~-9"9--~'2'~;~S'0W" '"'~'""~'~'"'~ 0~ ~5 .... 5 ....... ~ ..... 0-"74"--W':'~'''~ ........ O; 75'--5-'78 ..... 25--58'-W ............ 0.050 500 0 36 499e99 401,99 534e20W 0,09 5 1,26 W ~,26 5 85 ~3 20 W 0.~67 600 0 19 599e99 501e99 S75eSOE 0,73 S 1,02 W 1e25 S 5~ 16 50 W - 0.283 ..... 70'0--0--32- ...... 699 ~ 99'-T ..... 60~'~'99' ~$24-;5'0W .~.,:.;~h:?':~:::'~;.'l '32 '~'S ::7~7 ..... :0,73 ~'W--":'"~ 'T '~' "-1,5 I'~'S ':-2 9'F 1'~T5~4'' W ....... 0 · 217 -~'0"~-'1--'-~ 999~'97'--'-90 l",'97~S33-;-~'OE:~ m ":":"":' ' --~' ' 00 '~S '-'-:'~:-'0','86": E:'-'~''-~ ........... ~ · 09 .... 5'-I'2'-'I'~3 Z E .......... 0 · 600 ~00 2 28 ~099.9~ ~00~.9~ 5~2.30E 6.85 5 2.07 E 7cZ5 5 ~200 5 ~6 1~99,68 ~0~,68 ~ 8.60E Z3.5~ S 3.29 E ~3.90 S ~3 ~3 Z7 E 2.800 1 .7 19 1299.06' 1201.06 :~:.$ 2.80E:::':.~':;~;-:~;~:~::'-24.~3 :'5 "'7'~:'~T'4'38:'E':'::"T;';'~:'.'Z4.83":5:'iO-."'~'O~'8":"E ...... 2.052 1500 ~2 O' ~496.20' 1398.20';">::~S. 6.50W;:~?.-57.5~:'5 :-:-:~';-0.78-:'.: 57.60"rS:';'-'O:-~6~4.~':E'' .'~ Z~55 '-Z~0--~-5---~'~--}5-e'3; 2~ .... Z~e5',2"~'-5--~-;~e-' '"""~""~"8'I', 3~'-S ........ :"~ ...... ~'; ~1 "W 1700 18 31 1688.88 1590,88 $ 4.60W 110,59 5 3,64 W 110,65 5 1 ~3 1~ W 2,950 1800 19 51 1783e32 1685e32 51~e80W 1~2e96 $ 9,17 W 1~3e25 S 3 4~' 23 W 1.779 "T1~-0,-21-~ ..... z s 7~. 77" ~ 778,77 :'.~i~';'2'OW :?~:~.~:~.:.~ ? 7.3~'T-s ~".T.'.TTi~8 ;'38:W '21oo', 27 3o '~2o58.73 ~ ~e6o.73/':.:':.sZT.6ow~:~?:zs~.s2 s' :.~'):'-::~z.~o.. ~~~ 5~2'I~'6-';' 28 2048-'~-28~I7;~-0W' ":"?'"" 3~02;' 82-'-5"~-~-$~'; 33'~W 2300 33 8 2231e35 2133,35 S17e70~ 352e85 S 72,39 W 360,20 S 11 35 38 W 2,901 2400 35 39 2313e85 2215,85 517,70W. ~06,68 S 89.57 W ~16.~2 S 12 25 15 ~ 2.517 .,..~.:~ ..~ ?.: . ; :.~..;~ :~:;.::...:~-~:.::;..{~:::~::??~;:?~:?.?:;:.. . ..... :.-..;.; 0.00 0.25 0,43 0.44 0,35 0.44 0.98 1.47 2.16 2.61 3,60 6.01 12,06 22,26 36.58 55,12 78.55 107.27 139.91 175.49 214.64 258,30 306,57 415.57 RECORD OF SURVEY 4EAS. DRIFT VERTICAL iii;~ DOG LEG SUB DRIFT :..?iiiTOTAL COORDINATES C~'E 0~'$ U:':R~:;E:~i!!::iS SEVERITY 3EPTH'ANGLE .... DEPTH ............. SEA ................. DIRE-~ DIsTANcE .............. ~'~'G[~E ............... ~'DEG/IOOFT D M DEG. D M SECTION DISTANCE 26n0 ~0 45 2~69,83 2371,83 516,60W :j. 526e08.. ~ 126,80 W 5~1,~ 5 5 W 1,5 2~ 40 gl 2545.51 24~7.51 ' S15':90W::~:~'588,83 S 145'09 W' 606.44 5;'13::50::.:31 W ..:~ 0.3 -2'800--4'0--52~262 i' ~'2'-' 2523' 12'~$I 5 '"8'OW ~6'51 "78 'S ......... 162'; 96 "W .......... 671 · 85 ...... $' =:1~ ..... 2==15" W .......: ..... 0 ' 0 2900 ~ 33 2696.33 2598,33 S~7,40W 71~,9~ S 18~,79 W 737,69 S 1~ ~5 59 W 0,9 3000 ~ 30 277~0~8 2673018 S~6.~OW 778J37 $ 201,~2 W 803,94 S 1~ 29 15 W 0.3 310'O'-4'~'-43~,':2845.93':'-2747093"~?'~$~6,70W'.~;~:842e03 $ ~:;:? 220,10 W ':: ::~870.32 S'.14'='38:~[56:W'": 0.2 3200 ~ 52 2920.47 .2822'~7 :::.;.:~17'~0W::.::.~:~:~905.8~ :S :~:.;l~::;.~Sj~]~J"32.:W :::: 0.2 3~00 -3400-/+I--30---3069 · 72---297~ ,'72 .... SI6',"80W'~03'3-,:35"~S ........... 277 '68"~" W::::==~070, O ~-~5'~I5~-2~28 .... W 0 . 306 3500 41 20 3144,69 30~6.69 516020W 1096,80 S 296.~7 W 1~36.16 S 15 7 34 W 0.310 3600 ~1 20 32~9,76 3~21,76 S16,20W 1160,2~ S 31~.90 W 1202,22 $ 15 1~ 6 W 0.000 -~700"':4"~ .....I'2''329'~ogO"-:-3196~90"~'$I6'e:I'OW?~'223061' ~$ ~33"-26=:W"::'~;~1268'18 ..... 5"i15'1'~:'7:' W'~ .... 0.1~0 3800 ~ 3370021' 3Z72e21 :;:?S15:'90W::~:~-:lZ86,86'S ~'~ ~51.'39~'W :: : 1~3~'97 W 0,173 3900 -~000'-'~'1 ........ ~--3~2'~036 ....... 3423e~6 SI6'~OOW':'~-~l'2e6~"~ ............ 387'88'W ...... 1~64,93'~S '15"'2'1-=13 W ..... 0.277 4~00 4~ 7 ~596,76 3498,76 Sl~,70W ~475,99 5 405026 W 1~30.62 5 1~ 2~ 12 W 0.578 ~200 ~1 3 3672012 3574012 S15,70W 1539,43 S ~22,50 W 1596.35 S 15 20 50 W 0.~37 :"~:~ ~-40-5-~-"~3747~'60'""3649~60':=Si5:~'~"0W~;~I602"64 S.;~ :~'~ 440,03 W" 1661,95'~$:~15~:'/2i~11'W' ' 0,228 ~ ~ ~2~~'3822,99 ~ ~:457'81. W 0,459 4500 ~0 46 3898046 : 3800,~6;~ ~S15'50W:~:.~%729001 S ~475'67~ W 0,503 -'~6'00--40--24---"3976'e 39 ..... 3876 e-' 39-~'%4-~8'0W-~79"I'~' 82-5 ............. 492';68"~ W ......... 1858 ' 32'~'=S:==I 5::22~2 7'-W ..... 7' 0 · 470 /+700 /+0 12 /+050,6/+ 3952,6/+ $14,90W 185/+,36 S '509,26 W 1923.02 $ 15 21 23 W /+800 39 36 4127,33 4029,33 S15,70W 1916.25 S 526.19 W 1987.19 S 15 2~1~ 16 W 4900' 39'" 2 7'-' 4204, ~ 5 '"='~ ~ 06 ' ~ 5 '::"-S ~' 5 e-5'OW:~:I9 77 ' ~ 7-S ? 54~ '"317W :':: '~ '":2050 · 85::'5:7:15'::: 2'~44 W" 5000 39 ~1:: 4281.61 4183.61: SlS.90W:~r' ~:2038'81: S : ::560'52: W :: W 51'00 39 10 4358.93 ~260.93 S~S.70W.:..:;2099.B3 S 577.79 W' 2~77e87 $ 15.'Z3~t:;~ 5 W ~200--38~ I---S43 6,6 2---4338' 62---S'~'5~90W-~ 60 ~'4'1 '"' S .......... 594,94': W': .......... 2240 ;8 5300 38 2 ~5~4e92 ~416,92 S15e90W 2220,23 S 611,97 W 2303,03 S 15 24 36 W 8L 99 34 0.204 0.682 0,170 0.175 0.359 0,326 0,817 /+76'35 605,98 · 671.42 737,32 803.62 '~ 870.05 936070 1003.39 1069,83 1136,00 1202.07 1268,05 1333,84 1399,34 1464,81 1~0,49 17Z7,~1 179~oll 1~58,18 1922.87 1987.03 2114e29 2177,71 22/+0.67 2~02.87 ~,RCO WELL BOSS_! 6844 RECORD OF SURVEY TRUE : :i. .:.. DOG LEG 4EAS, DRIFT VERTICAL SUB .DRIFT :!:::TOTAL COORDINATES C L 0 S U R E 5 SEVERITY 3EPTH"ANGLE DEPTH ...... SEA ............... DIREC .................... DISTANCE A'NG~E ............ DEG/LOOFT D N DEG, D H $ SECTION DISTANCE · 5500 37 ZO 6673,45 4575,45'"'515,30W.:;';.!;:f2337,70 5 '6~6,66 W 242~,96.$.15 25.:i'.:i:.:-2 W 0,34L 5%,....,3 36 3! ~753,4~ ...... 4655,66··:515,30W:!!:;·:12395,·565 ·1660,69 W 248~,965':15 2~:--_ii51.W 0,650 ~57~'~'0'-36 ...... 1 ..... ~834,0- 4736',07':--515"'30W'-;-2652,6~'5 .... ..... 676,11 W ........ 254~'12""5'--15-24-~2 ...... W ..... 0.500 5800 35 53 4915,0! 6817,01 515,20W 2509,30 5 691,56 W 2602,85 5 15 2~ 29 W 0,138 5900 36 68 4995,54 6897,56 5Z5,30W 2566,50 $ 707,15 W 2662,L6 5 ~5 26 16 W 0,9L7 "6000"37 9 ...... 5075,~1 .... ~977,41"::'-515,~0W7~:2'626,52 5 ' 723,08 'W - 1722,31'5:"~5 24':':'12 W ' 0,352 6100 37 ZO ~155,09' 5057,09.:·'517,:80W;?!;2682'62 5· :·1740,36 W 2782,7Z 5 [5 25')·65 W 0,877 6200 37 36 5234,53 5 .'760'71W 2863,28 '5:15:3[:; 6 W 1,409 -6300-'36--~5 ...... 53~4*Z9'---5216;I9'~23·;'70W ...... 2795',45-'"'5 .......... 783.89'W ........ 2903,28 .... 5-'~15'3¢"5~ .... W .... 1,184 6400 36 51 5394,25 5296,25 $25,10W 2850,03 S 808,66 W 2962,53 $ 15 50 25 W 0,514 6500 ~6 31 5474e43 5376e43 526.30W 2903,88 5 834e56 W 3021.42 S 16 2 4 W 0,540 '66-00"-36"'"13 .... ~554e'93 ......5656~93'~529~OW~'95'6e34"$ ..... i'~'862e22'-W.~.:'"-.~3079eS1 $':::'"16';'1~'4~'W ..... 1,090 6700 36 21 5635.,53:5537,5371~·!·532·,30W_?i~3007,19 5· '::;· 892,53 W · Z,063 6800 35 55: 5716,27 5618,27.+.i':~$34,50W:~i-ii:!i.3056,63 5 925,00'W 3193,34 516'50;i;16 W: 0,873 .... 6900-37 .... 9---5'796~6-! ........ 5698-'"61''-S35';70W"~105','i~-:$ ...... 959"24'~W ....... 3249.9~'"5~"'17 .... 10~ .... l"W- 1,309 7000 39 15 5875,18 5777.18 536,50W '3155,13 S 995,69 W 3308,51 $ 17 30 52 W 2,108 7100 40 7 5952.13 5854,13 S37,80W 3206,03 5 1034.25 W 3368,72 5 17 52 66 W 1.035 77 3'-'~0'-~9 ......6028'~9 .... 5930,19~'$~0";'20W~!:3256,68-5 .... 1075,11 W ...... 3629,36'5~"18!"i~6!:'~13 W 1,242 7;).,.0 61 40 6103,36 6005,36 542,60W:';:::'.i.:.i3305,96 $ 1118,71W 3490,10 S 18 61:66 W 1,360 7600 63 9 6177,17 6079,17 546,00W.;-i~3354,21 5 1165,82 W 3551,0~ 5' 19 9 57 W 2,175 '~-0-'~'--26 62'49*'3~ .... 615~'36 56~"J"i~W----3~O'~'38'"S 1216-','49-"W .............. 3512"37'"'5 ....... i9'%~0-45'-'-W ...... 1,665 7600 45 9 6320.28 6222,28 569e30W 3647,89 5 1269,63 W 3676,15 $ 20 L2 65 W 0,937 7700 66 ~8 ..... 6390,07 .... 6292,07 ........ S69.,..60W _3~.96-45 .S ..... 1323,85_W ......... 3736,81..$.....20...~. 56 w 1,151 7600~"67 60 6458,27 6360,27 550,20W 43561,56 5 1379,79 W 3800,85 5 ~ Z.~.'~ '9 w 1,405 7900 68 6 6525,31 6627,31 :S49e30W'~";:~:~3589,50 5 1636,~2 W-. 3866,26"5 21.48:35 W 0.661 8000 47 56 6~92,18 6696,18 $50,30W :-:ii-'3637,49 5 Z693,21:W::!- .'3932,05 5 22 19 - 6 w 0,576 -8100--48--39--6658,70 ..... 6560,70 -$5~;'~'~W~3-6'84',23"~5 ...... 155~'*'66-"W ........... 3997'56--~'-22"50--i0'-'~ ...... 1.289 8200 48 54 6724,58 6626,58 553,70W 3729,5~ 5 1611,68 W 4062,81 5 23 22 6 w 0,888 2366,13 2624,80 248~,78 2543,95 2602,67 2661.95 2722,11 2782,53 2843,15 2903,20 2962,50 3021,42 3079,50 3136,75 3193,06 3249,36 3307,47 3367,07 3486,47 35~5,90 3605,26 3724,43 3785,19 3845,94 3908,79 3969,83 AR¢OWELL,.B-~ AUG .1. RECORD OF SURVEY TRUE. DOG LEG ~EA5. DRXFT VERTICAL SUB DRXFT'L::".~;~TOTAL COOED[NATES' C L 0 $ U R E:~"$ SEVERITY DEPTH ANGLE DEPTH SEA D[REC DISTANCE ANGLE DEG/IOOFT D N DEG~ D M 5 .-. HOLE CLOSURE 4095.15 FEET AT 5 23 38 7 W SECT[ON DISTANCE ARCO_. WELL. . ['.:'~ ......................................................... BOSSy.._.]..&044 ............ 'r .'~"I 26 At. JO X. 'E OLATE V TXCAL D PT.O, :CO0 X AT S ' ND C .OSUR O FOR TRUE CODE MEASUreD VERTICAL TOZAC ¢OORDINAZE$ C L 0 $ U ~ ~ SUB NAME DEPTH DEPTH DISTANCE ANGLE SEA . ..~ 7519 6262,89 3410e27 S 1226,~0 W 362~,09 S 19 ~6 ~6 W 616~ T op-KU'PAR U ' D TOP UP SND 7~50 6284 C'3 .......... 7550 .......... 6284 C-~ 7573 6301 B~P SND 760~ 6323 B ................................... 7605 ................... 6323 TOP LW SND 7774 6440 A-4 7774 6440 A'3 ...... : ............................ 7784 ......... 6~.47 A-2 7811 6465 BS LW SND 7851 6492 A'~I .......................... 7851 ................. 6~92 BS KUPARUK 7927 6543 KINGAK SHL 7927 6543 PBTD ................ ~ ..... 8278 ........ !~:.'i ........ 6776 TD 8380 6855 3424.76 S 1242. · 93'='"""-:ii'3424.76'"~$ 1242. 69 W 3643.25 $ 19 .56 36 W 6186 69 W 3643.25 .....:& ..... 19'56':36':w 6186 ,23 i'..:i.:ii13435'49':iSi:ii 1254,86 W · 36,57,50. $ .20 3:55: W 6203 1272.11 W :3677,26' 5 20 14 20 W 6225 '81---'3'4:'50,22'-S .......... 1272 "1 i"'-W ......... 36 77 ' 26 ....... S' ~ 2 O" ::'l'~ ='20 '"~ ...... 6225 · 72 3529,58 S 1364.79 W 3784.26 S 21 8 24 W 6342 · 72 3529.58 S 136~.79 W 378~,26 ~ 21 8 2~ W 63~2.72 e49'."~:::~'~;:3534,'33~:$ .: '~ 1370'~1.'W ......... 3790.72 ~:"S 21: 1i W: 6349.~9 .68. 3546.79~: :s: ~:: ::::~: 1 ~ 86. o 2 ~ ~ :. 38 o 7 · 99 eS~ .~:.. : 3565,96::'5~' 1~08e61 W:: 383~,10 S 21 W 6394,54 ~54 3565,9-6-5-=" .......... 1408'6i 'W .............. 383~,10 ..... S'""21 .... 33 ..... i'7"~'W ..... 6394,54 e35 3602e64 S 1~'51e61 W 388~e10 S 21 56 4~ W 6~45,35 e35 3602.6~ $ 1~51.61 W 3884,10 $ 21 56 "85'~3766:e07~':$:'~='' ;;' 1656.04:7 W~:~' ~. 4114.09 :]~: ~S 23 44'~'0'~W ~T"6678,85 :::;:: I655,~5 W ':.:::: 4169,89 . · :: ... ,'89 ,81 .. ARCO. WELL..B~. ........................................... BOSS....16844 .... AUG i MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, HEASURED DEPTH TRUE VERT!CAE SUB HD-TVD VERTICAL DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 198 198, 100 0 298 298, 200 0 398 398, 300 0 498 ....................... 498, 400 .............. 0 ..................... 598 598, 500 o ... ~.?:!?: 698 698, 600 0 798 798 · .............. 700 0 898 898, 800 0 998 998, 900 0 0 0,32 $ 0,44 W 0 0,28 S 0,61 W 0 0,15 S 0,73 W 0 0,08 $ 1,24 W 0 0,73 S 1,03 W 0 1,30 S 0,73 W 0 2,77 $ 0,23 E 0 3,96 S 0,83 E ................. 1098 1198 1299 1400 1502 1605 1710 1816 1923 2032 2144 2260 1298 · 12 O0 1398. 1300 1498. 1400 1598, 1500 6,75 $ 13,31 $ 3,21 24,28 S ~,24 39,07 S 57,98 S 0,74 82,65 S 1,51 1798, 1700 ':'.:::'lT?.'!~i!i.i~i '": 6 148,14 $. :;;:~' 10,47 W 1898, 18oo z4..~-.:-'">]~. ' 7 '" 185,69. s. 20.64 w 1998, ......... 1900 ........~ .............................. 10 .................................... 227,92 ....S 2098, 2000 46 12 276,65 S 47,66 W 2198, 2100 62 16 332,48 S 65,39 W 2380 ........................... 2298, ........... 2200 .......... 82 ........ ~ ............. 20 2506 2398, 2300 108 :: 26 2637 2498, 2400 139 : 31 2769 2598e 2500 171 32 2902 2698, 2600 204 33 3'036 2798, 2700 237 33 395,79 $ 85,52 W 468,26 $ 109,06 W 549,33 S 133,38 W 632%43 S 156,77 W 716,21 S 182~!..7 W 801,21 S 207i07 W 3170--V 2898. .......... 28 oo'"" 2~:7i~i~!~y'' .......... ~4 886.65 $ 233.Z~9' W 3304 2998, 2900 '.:- 30.6:":!ii'ti-.i~:.:?i:i:::i<]i- 35 - .' 972,23 S." 259,43 3438 3098 · 3000 - 340 i:';;'.::~!"!: i.'~iiii:!ill-::' 34 1057 · 37 S 284,57. W 3571 3198. 3100 372 ..... 3"2 ................................ 1141,'87-'$ ................. 30'~'; ~+'6-- W 3704 3298, 3200 406 34 1226.15 S 333,98 W '3837 . 3398, 3300 439 33 1310e16 S 357,72 /~---3'969 3~98e ............ 3~00'-~~ ...... . ' 32 ....... '" 1393e16 S--'Y"'382'e'~5"W AP, CO WELL I~-"~ BO.%,% 1684,4 ~ 2~ AUG 1 MEASURED. DEPTH' AND' OTHER ' DA~-~,'-'F;~'R'-~'~"R'~-:-~'~/E~ .... IO'O-'-FEET :oF' "SUB" SEA DEPTH' .: TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL. DEPTH DEPTH ,SEA DIFFERENCE CORRECTION TOTAL COORDINATE& _ 4234 3698, 4-367 ......................... 3798, 4499 3898, 4631 3998. 4762 4098. 4891 4198, 3600 536 33 3700 568 32 3800 601 33 3900 633 32 4000 ......... 664 .......................... 31 4100 693 i..;-~i 7 ;:.'.'~::~.~: ....... 29 1560,98 $ 428,28 W 1644.89'S 1728.45 $ 475,16 W 1811.29 $ 497,53 W 1892,89 $ 1972,20 $..4- 541,18 W · - 5021 4298, 4200 30 2051.70'$.-- ' 563,98 W 5150 4398. ...... -4300 752 29 ................................... 2130.28 -S ........ 585i~'9-5 ...... W ........................ 5278 4498, 4400 780 28 2207,35 $ 607,51 W 5405 4598, 4500 807 27 2282.15 & 629,34 W ~655 ~798, '::: ~700'::~.:':~::'7857:~:~:::~'~:~:.~:: ~:~::~;~:::.:~;:~.' 2~ :" .~::' ::'.:': ~,: 2427,07 S :: ' ;:~'::~668.9'3.W 5903 4998. 4900 905 2~ 2568,23 $ 707.6~ W 6028 5098. 5000 930 6154 5198. 5100 955 6280 ......................... 5298. .......5200 6405 5398. 5300~i!;:.:;::1007 6529 5498, 5400:'::'-;103! 66'53 5598. .......... 55'0'0' ib'5'5 6777 5698. 5600 1079 6902 5798. 5700 1103 7029 5898. ........ 5800 .... 7160 5998. 5900 25 25 27 ,~"' - :: 25 2640.83 S 727.53 W 2713,52 $ 750,69 W . 2784,45 $-'~ ."778e'6:~'W ' - 2852.57 S' '.' :-809,83 W 24 2919,31 &. 842,'2~ W 24 ................................ 2983.54 S 877~'-8'-0~-W' 24 3045.41 S 917.14 24 3106.01 S 959.85 .................... . 28 3169,98 S 1006,54 W 31 3236e66 S 1058e.ll W 7293 6098, 7428 6198. 7568 6298. 7711 6398. 7859 6498, .. 8008 6598, 8159 6698e 1162 eooo .:'.i:!! oz,e7 s-'.,.: zzz . e w 6100 1230 36 ................................... ~36'~49'-"$ ........i179e~'i ..... W ......... 6200 1270 40 3433.16 S 1252t~1 W 6300 1313 43 3499,67..S ...... 1329~6 ~ 6400--'~'~ ........ ~ ........ 48 ........................... S569.82 $ 'i: 141~,%2:'W''' 6500 1410 '::i 49 3641,30 S 1497,77:W 6600 1461 51 3711,34 $ 1586e53..'W ARCO. WELL , .............................. BOSS.~.16844 ..... . ........................ 26 AUG INTERPOLATED VALUE5 .FOR EVEN...Z. OOO_..EEET:_OE.~_.MEASURED DEPTH, MEASURED DEPTH TRUE VERTICAL .............. SUB DEPTH SEA TOTAL COORDZNATE$ 1000 999, 2000 :1968. 3000 2771. 4,000 3521e 5000 6000 5075, 7000 5875, .......... ~.01,, 3.99 5 ........... 0,85..E 1870, 215.0/+ 5 28,8/.+ W 2673, 778,50 $ 200,6Z W 3Z+23, lZ+12.70 $ 387.65 W ~+183, 2038.99 5 5'59.77 W ~+977." 262/+,,59 5 722,72 W ' 5777,' ?'; " -':;- 3155 ,49 S 995,15 W 8000 ....................... 6592, ......... 6'~.-~;' .........36'37';77~'5 .............. 14,92 HOR!~ONT,~L ARCO ALASKA iNC, KUPARUK B-4 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE: I" = I000' AUGUST 2?, 1981 T !1 N, R I0 E, U.M. 200o ~o0 ~Oo I0 TVD = 6758~ T MD = 8250' : " / AL-L .... DEP?H-~- -'SHOW N .........................................../ ARE TVD ' :. 400' 800- 1200. 1600' SURFACE LOCATION IS 498' SNL, 622' WEL, SEC. 9 T I! N, R I0 E, U.M. VERTICAL SECTION ARCO ALASKA INC. KUPARUK B-4 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE: I' = I000' AUGUST 2:7, 1981 ALL DEPTHS SHOWN ARE TVD , , ~ - ''$600~ ..... - ...... 4400;~ 6400~ _ ~ TVD = 6758' TMD = 8250' Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. · Operat°r, 'Wel 1' Name and N and Materials to be received by: ,~--/~- Reports Date Required Date Received Remarks Completion Report Yes Well History Yes Core inscription ~d ~. Registered Su~ey Plat :~,~ , ,, , Inclination Su~ey _ _ . . ..... Dire~ional pr~U~ion T~t Re~rts , ~ ~ /Z-~l~,,, 1 ' ilORTtt 2LOPE EilGI~IEERI~G TO' TRA:'~" FROM' J.J. Pawelek/Ann Simonsen DATE- ~--~O -- ~/ WELL HAME: Transmitted herewith are the following' ~ ~ ~. B~- BLUELT~, PLeAsE IIOT~ ."~ SEPIA, F - F, ILM, T - TAPE ~SE RETUR¢I RECEIFT TO' DATE' ARCO Al_AS!SA, INC. ATTN' A~:I SIM0~SE!I - AFA/311 P.O. BOX 360 ' ~ " QG~ A;~CiiOR.AGE A,-, ~l 0 AUG 2 i. 1'J~1 A!aska Oil & Ga.: Cons. Commissioa Anchor~g,3 ARCO Alaska, Inc. ('~ Post Office B%.~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 20, 1981 Hoyle H. Hamilton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: Please find attached for your approval Sundry Notices for work we have planned for wells on B-Pad and D-Pad in Kuparuk Field. Since~ JSD/slz Attachment RECEIVED Alaska Oil & Gas Cons. C°rnmissior~ AJ~chorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ', STATE OF ALASKA ALASKA ~ AND GAS ~)ONSERVATION C ..,MISSION SL NDRY NOT C .$ AND RI PORT$ ON I;LL$ DRILLING WELL 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box '360, 4. Location of Well Surface Location' CO~'MPLETED WE L L]~ZI Anchorage, Alaska 99510 498' FNL, 622' FEL, TllN, 10E 5. Elevation in feet (indicate KB, DF, etc.) _ KB = 92.0 12. Sec. 9, OTHER [] 7. Permit No. 81-65 8. APl Number 5o- 029-20595 9' unit °r Lease Name lfuparuk ~ 10. Well Number P,-4 11. Field and Pool Kuparuk River Field I 6. Lease Designation and Serial No. Kuparuk River Oil · Pool. ^BT, P. 5651 Chec~t Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each coml:~-etion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 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). ARCO Alaska, Inc. proposes to clean out heavy, viscous oll and mud in cased well B-4 in the Kuparuk sands. The work will be done with a coiled tubing unit with a BOP unit tested to 4000 psi. A 3000 psi lubricator will be used for all wireline work. Ail circulated and flow fluids will be diverted to tankage on location. After the well is cleaned out, it will be flowed and tested. The expected starting date is 8/21/81. RECEIVED AUG ,? 0 1981 AJaska Oil & Gas Cons. Comrnisslon Anchorage Subsequent Work Reported on Form No. ~ Dated --/--,/--z 14., hereby certify that th~goinglstrueand correct to the.best of my knowledge. S,gned ~,.~,.'~ %~~.~ ~ Title Operations Area Engineer Returned Approved OV Date .. 8/18/Sl COMMISSIC) NER B~/ Order of the Commission Date Form 10-403 :-' e ,'. 7-i-80 Subm,! "IntentionS" tn Tr,pticate and "SuDsequent Repofls" ih Duohcate NORTH SLOPE ENGINEERING ( TRANSMITTAL TO' ~'~ ~ ~ FROM' J. J. Pawelek/Ann Simonsen DATE- ,~ "'/Z.... ~ / WELL NAME- Transmitted herewith are the following' PLEASE NOTE - BLUELII,IE, _- SEPIA, F - FILM, T - TAPE , P~LEASE RETURN RECEIPT TO ARCO ALASKA, INC. ATTN' ANN SIMONSEN - AFA/311 P.O. BOX 360 ANCHORAGE, AK 99510 RECEIVED Alaska 0ii & Gas Cons. Commission NORTH SLOPE ENGINEERIHG TO- TRANSMITTAL FROM: DATE' ,, ~:~- ~'~/ WELL NAME' J. J. Pawelek/Ann Simonsen Transmitted herewith are the fol'lowing- PLEASE NOTE' BL - BLUELIHE, S - SEPIA, F - FILM, ~ TAPE REC.EI PT ACKHOWLED . LEA~SE RETURN RECEIPT TO' RECEIVED DAT~uG- i Z ]98~ ARCO ALASKA, INC. Alaska Oil & ~as Cons. Commission ATTN:- ANN SIMONSEN - AFA/311 Anchorage P.O. BOX 360 ANCHORAGE, AK 99510 NORTH SLOPE ENGINEERING TRANSMITTAL FROM: J.J. DATE' WELL NAME' ,~""~" Transmitted herewith are the following: PLEASE NOTE:~- BLUELINE, - SEPIA, F - FILM, Pawelek/Ann Simonsen T - TAPE '~PLEASE RETURN RECEIPT TO: .ARCO ALASKA, INC. ' ATTN' ANN SIMONSEN P.O. BOX 360 ANCHORAGE, AK 99510 DATE' - AFA/311 t ECEIVED; AUG i ! 1981 Alaska Oil & Gas Cons. Commis~io~ Anc~omgo ARCO Alaska, Inc. Post Office z 360 Anchorage, A~aska 99510 Telephone 907 277 5637 July 21, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 12-10 DS 16-14 DS 12-11 DS 17-'7 DS 14-18 DS 17-8 DS 14-19 A-1 DS 14-20 A-2 DS 1 6-13 B-3 Dear Sir: Enclosed please find: l) The monthly reports for DS 16-14 &~B-4~. 2) The subsequent Sundry Notice for DS 14-18. 3) The Completion Reports for DS 12-10, DS 12-11, DS 14-19, DS 14-20, DS 16-13, DS 17-7, DS 17-8, A-l, A-2 & B-3. 4) The Gyroscopic Surveys for DS 12-10, DS 14-20, DS 16-13, A-1 and B-3. Sincerely, P. A. VanDusen District Drilling Engineer PAV/KJG:sp Enclosures RECEIVED JUL 2 1 Igg] LASKA AND GAS CONSERVATION CO ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS . Drilling well [~] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 81-65 3. Address 8. APl Number P,0, Box 360, Anchorage, AK 99510 5o-029-20595 4. Location of Well at surface 498'FNL, 622'FEL, Sec 9, TllN, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 98' . RKB APL 25648 For the Month of. June ,19 81 9. Unit or Lease Name Kuparuk River 10. Well No. B-4 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool '12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0100 hrs, 6/23/81. Drld 8-3/4" hole to '6844', as of 7/2/81. See attached Drill ing History. 13. Casing or liner run and quantities of cement, results of pressure tests 16", 65#/ft, H-40 condUctor to 80'. Cmtd w/200 sx Permafrost. 10-3/4" 45.5#/ft, K-55 csg w/shoe @ 2871'. Cmtd w/1500 sx Fondu & 250 sx AS II. See attached Drilling History. 14. Coring resume and brief description n/a 15. Logs run and depth where run None to date. · 16. DST data, perforating data, shows of H2S, miscellaneous data None to date. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~S,GNED ,~7~/~. 7/~,~~ T,TLE Dist. Drilling Engineer DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 S~bmit in dul~liCate B-4 DRILLING HISTORY NU hydrill & diverter. Spudded well @ OlO0 hrs, 6/23/81. Drld 13-3/4" hole to 2895'. Ran multishot. Ran 69 jts 10-3/4" 45.5#/ft K-55 csg w/shoe @ 2871'. Cmtd 10-3/4" csg w/1500 sx Fondu & 250 sx AS II. ND hydrill & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW- ok. Drld 8-3/4" hole to 6844', as of 7/2/81. ALASKA OIL AND GAS CONSERVATION COMMISSION H~gle H. Chairman Hamilton Thru: Lonnie C. Smith/~ Commissioner ~ .~ Doug Amos /-~~ Petroleum Inspector June 29, 1981 Witness B.O.P.E. Test on ARCO ' S Kuparuk B-4 wel 1, Sec. 9, TllN, R10E, UM, Permit No. 81-65 on Parker Rig No. 141. Saturday june 27, 198_1.. I traveled this date from Brinkerhoff Rig %1 to parker Rig %141 to witness the B.O.P.E. test on Arco' Kuparuk B-4 well. The B.O.P.E. test commenced at 9:00 PM and was concluded at 1:18 AM 06-28-81. The lower kelly cock failed and was replaced and retested during this test. I filled out an A.O.G.C.C. B.O.P.E. test report which is attached. In summary, I witnessed the B.O.P.E. test on Arco's Kuparuk B-4 well. There was one failure which was corrected and retested during this test. I filled out an A.O.G.C.C. B.O.P.E. test report which is attached. Note: The threaded connections on the choke and kill lines have been welded. ~o~ #4 4/81 ' ALASKA OIL & -GAS CONSERVATION CQv~JSSION B .0. P .E. Insp~cgcion Report. _Inspector D~G ~ ~ ~ .Operator ~,~ Location: Sec Prillinq Contractor ~~ Rig # /~/ Representative · ! Permit # // /O.3/~Casing Set @ 2.~_ 71 ft. Representative _~/~ //~IF~ Location, Genera] Well Sign Ceneral Housekeeping__ Peserve pit Rig ~.BOPE Stack [iAnnular Preventer ..... ams \, Blind Rams, ! Choke Line Valves... % H.C .R. Valve I~IKill Line Valves- I Check Valve__ Test Pres sure ACCUMULATOR SYSTEM Full Charge Pressure _~/~/~ psig Pressure After Closure /~;L~/g psig Pump incr. clos. pres. 200 psig. / Full. Charge 'Pressure Attained: ~ N2 Z~o~.Z~-~ ~lO0! ~o psig ! ~ ~ · Controls: Master ~9/C min D7 sec. min 2gsec. Remote ~5k2 Blinds switch cover'~Z~S Kelly and Floor Safety Valves Upper Kelly ~/ Test Pressure Lo~er Kelly..~' / Test Pressure Ball Type ~z' j Test Pressure Ins ide BOP ) ~'~ Test Pres sure Choke Manifold No. Valves .... No. flanges__ Adjustable Chokes Hydrauically operated choke /~'~Test Pressure Test Results: Failures I , Test Time.' ~- ~ hrs.. Repair or Replacement of failed equipment to be made within days and Inspector/Ccmmission office notified. Remarks: ~ (~,z/¢/~ ~//,./ d~ & ,,'/dj. ,,, ~/3/,~~ ~ /t( Di stribut ion orig. - BO&CCC cc - Operator cc - Supervisor Inspector ALASKA L AND GAS CONSERVATION C .,¢iMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 3. Address 8. APl Number P.O..Box 360, Anchorage, AK 99510 50- See below 4. Location of Well 5. Elevation in feet (indicate KB, DF, etc.) See be1 ow See below 6. Lease Designation and serial No. See bel ow ' 9. Unit or Lease Name See be1 ow 10. Well Number See below 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. 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 Operat ons (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). In preparation for its Increment I Waterflood of the Kuparuk Sands, ARCO Alaska, Inc. intends to perform a water injectivity test in .two wells in late July and August, 1981. The purpose of the test is to gain pertinent data on the ability' of the Upper, Middle, and Lower Kuparuk Sand segments to accept injected waters. In addition, reservoir pressures in offset wells will be'monitored to attempt to determine response to the injection. We anticipate a maximum of three weeks of testing, injecting into the B-1 (Lower Kuparuk) and B-2 (Upper & Middle Kuparuk) wells. Continuous monitoring of pressures and periodic production logging will be used to aid in determining injection characteristics. Monitoring of reservoir pressures in three offset wells during the injection, the A-3, B-4, and B-5 will be used in evaluating reservoir response to the injection. Water for the injection testing will be produced from our water source wel 1 No. 1. Expected start, date is July7 27 1981. WELL API NUMBER L(~CAT~ON ELEVATIONS UNIT NAME LEASE DESIGNATION B-1 50,029-20465 Sec 9 Tl lN RI OE KB = 98' Kuparuk 25648 ADL 25648 B-2 50-029-20531 .Sec 4 Tl lN RI OE KB = 98' Kuparuk 25648 ADL 25648 50-029-20595 Sec 9 TllN RIOE KB = 98' Kuparuk 25648 ADL 25648 - 50-029-20237 Sec '9 TllN RIOE KB = 89.5' KuP. aruk 25648 ADL-25648 A-3 Not Assigned Sec 5 TllN RIOE KB'= 100' KUparuk 25647 ADL 25647 WS-1 50-029-20090 Sec 9 TI, I,~. RIOE KB =;98' Kuparuk 25648 ADL 25648 hereby certify that the foregoing is true and rlbrrect to the best of 14. I Signed' ~~' ,,/i~//~/~,.~ ,/,.'~' Title The space'below for Commission use Conditions of Approval, if any: '~IGIHAL 8Y RARRY ~. KUG[ER Approved by [. m, pproveu Copy By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "intentions" in Tri'Plicate and "Subsequent Reports" in Duplicate J~ J~l L STATE OF ALASKA (~~M ALASK AND GAS CONSERVATION ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 1-)( 2. Name of Operator 7. Permit No. 'ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, AK 4. Location of Well 5. Elevation in feet (indicate KB, DF, etc.) See bel ow 12. See below I 6 . Lease Designation and Serial No. See bel ow 8. APl Number 50- See below 9. Unit or Lease Name See bel ow 10. Well Number See bel ow 11. Field and Pool Kuparuk River Field Kuparuk River 0il 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 o¢ 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). In preparation for its Increment I Waterflood of'the Kuparuk Sands, ARCO Alaska, Inc. intends to perform a water injectivity test in two wells in late July and August, 1981. The purpose of the .test is to gain pertinent ..data on the ability of .the Upper, Middle, and Lower Kuparuk Sand segments to accept injected waters. In addition, reservoir pressures in offset wells will be monitored to attempt to determine response to the injection. We anticipate a maximum of three weeks of testing, injecting into the B-1 (Lower Kuparuk) and B-2 (Upper & Middle Kuparuk) wells. Continuous monitoring of pressures and periodic production logging will be used to aid in determining injection characteristi, cs. Monitoring of reservoir pressures in three offset wells during the injection, the A-3, B-4, and B-5 will be used in~eval'uating reservoir response to the injection. Water for the injection testing will be produced from our water source wel 1 No. 1. Expected start date is Jul~r 27 1981. . WEEL API NUMBER L(~CAT~ON :,ELEVATIONS UNIT NAME .LEASE DESIGNATION B-1 50-029-20465 Sec 9 TllN RIOE KB = 98' Kuparuk 25648 ADL 25648 50-029-20531 Sec 4 TllN RIOE KB = 98' Kuparuk 25648 ADL .25648 50-029-20595 Sec. 9 TllN RIOE KB = 98' Kuparuk 25648 ADL 25648 B-5 50-029-20237 Sec 9 TllN RIOE KB = 89.5' Kuparuk 25648 ADL 25648 A-3 Not Assigned Sec 5 TllN RIOE KB = 100' Kuparuk 25647 ADL 25647 WS-1 50-029-20090 Sec 9 T!?~I~ RI OE KB = 98' Ku.paruk .25648 ADL 25648 14. I hereby certify that the foregoing is true and qprrect to the best of [~ J · Signed J~-~,~"~' /~ "~/~'//~'~//D'~' g~ .~--~ Title The spac~below for Commiss~oP use my knowledge. Conditions of Approval, if any: Approved by. By Order Of --' COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate May 13, 1981 Mr. P. A. VanDusen District Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Kuparuk River B-4 ARCO Alaska, Inc. Permit No. 81-65 Sur. Loc..: 498'FNL, 622'FEL, Sec 9, TI1N, RiOE, UM. Bottomhole Loc.: 966'FSL, 1722'FEL, Sec 9, TllN, R10E, ~6o Dear Mr. VanDusen: Enclosed is the approved application for ~rmit to drill the above referenced well. Well samples and a mud log are not required. A directional survey is required. 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 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordi~ator'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 regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen Kuparuk River B-4 -2- Hay 13, 1981 commencing operations 'you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded, we would also like to be notified so that a repre- sentative of the aoauaissi~ may be present to witness testing of blowout preventer equipment before surface casing shoe is dril led. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, ~Oy ~ H. Hamilton Chairman of DY Alaska Oil & Gas Conservatiom Commission Enclosure c,~ DePar ~nt of Fish & Game, Habitat Section w/o enc1. Department of Environmental Conservation w/o/encl. ARCO Alaska, Inc.~i Post Of.qce 550 Anchorage. Alaska ~95!0 Telephone 907 277 5:~G7 May 5, 1981 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservati on Commi ss i on 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamil ton: ARCO Alaska, Inc. proposes to drill a development well, -? Kuparuk B-4, commencing on approximately June 3, 1981. Attached please find: 1. A "Permit to Drill" application form. 2. A plat showing a) surface and target locations, b) vertical directional planning. 3. A plat showing the proposed wellbore in relation to other wells within 200' and other wells on B pad. 4. A plat showing conductor locations on B pad. 5. A determination of maximum pressure to which BOPE could be subjected. 6. Diagrams and operational procedures for the 20" 2000 psi diverter stack and 13-5/8" 5000 psi RSRRA stack. Please feel free to contact us at 263-4270 if we can be of any assistance. P. A. VanDusen District Drilling Engineer PAV/ELP:sp Attachments RECEIVED - 8 1981 Alaska 0il & Gas Cons. Commission Anchorage ARCO Aiaska, Inc. is a Subsidiary of AtlanticRichfieidCompany STATE OF ALASKA 'O~,~ ALASKA ILAND GAS CONSERVATION C v~MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~[ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL[X] SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name 498'FNL, 622'FEL, Sec 9, TllN, RIOE, UM RECEIVE[' Kuparuk River At top of proposed pr.oducing interval 10. Well number 1320'FSL, 1620'FEL, Sec 9, TllN, RIOE, UN MAY-~ 1..q~tl B-4 At total depth 11. Field and pool /~/~/m~, /c n,,.,, .,I ,.~ D ..~,-u I 966'FSL, 1722'FEL, Sec 9, TllN, R10E, UM ~,?~':',.;i~,~.~r."'r~'.'. r:...,, ..... h0~ _~,~Kuparuk 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no.A-~0.,,-,,;r},,Q,~j~ ..... ;[r~l'$~)~r 0i 1 Po01 63 Tundra/71'=Pad/98':RKBI ADL 25648 ALK 466 .. 12. B~,nct.~nfQrrq~tion ~ee 2qAAC 25.025) Federal Ins. Company TypeU'lI ~ I.~as ~on(] Surety and/or number #8011-36-40 Amount ¥ $500,000 13. Distance and cl~rection'~r~-nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 miles NW of Deadhors'q~es 1320 'feet well 12(~' ['a ~;llrfac9 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 8515 MD/7108 TVD ~eet 2560 6/3/81 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures ~ p$ig@q00F Surface Tem,~ KICK OFF POINT1000feet. MAXIMUM HOLE ANGLE38oI (see 20 AAC 25.035 (c) (2) 3205 psig@6288 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT , Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 72 corrug~ted Cellar 5' surface 5' ~,.5', Rackfil!ed ...... 2'4 16 65# H-40 Weld 80' surface 80' ,80' ~-o,~., 13-3/4 10-3/4 45.5# K-55 BTC 2930' surface 2930'12700' 1)~. 8-3/4 7 26# K-55 BTC 8515 surface 8515'1 7108' 3,Sa I I . 22. Describe proposed program: ARCO Alaska, Inc. proposes to drill a Prudhoe Bay/Kuparuk River Oil Pool development well to 8515'MD = 7108'TVD. Selected interVals will be logged and tested. A 20" 2000 psi' annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8" 5000 psi RSRRA BOP stack will be installed on the 10-3/4" surface pipe and tested upon installation and weekly to 3000 psi The well will be completed with 3½" 9.2# J-55 BTC tbg and pkr. Non-freezing fluids will be left in uncemented annuli thru the perma- frost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent report' A downhole safety valve will be installed w/the completion string and shut and tested upon conclusion of job. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space below for Commission use CONDITIONS OF APPROVAL · []YES ~}~AI O OYES [~lql O ~].Y ES []NO 50- O l-'~ ' 1' O -S"~ Approval date Permit number ~,~.~/ 05/13/81 I SEE COVER LETTER 'FOR OTHER REQUIREMENTS APPROVED BY~~, . ,COMMISSIONER DATE May 13, 1981 by order of the Commission . _ Form 10-401 Submit in triplicate Rev. 7-1 '80 ARCO ALASKA, INC. PRO B, NELL NO: 4 PROPOSED KUPRRUK FIELD, NORTH SLOPE, RLRSKR ~~ SCALE I IN. : 1000 FEET ERSTHRN WHIPSTOCK, INC. . 2000 1000 0 49t FT 9 I0 _0 . ! 000 ............ r'"-:- 2000 _ . ..................... 3000 . " ' "~ "' ;...' .~..~:, .,-, ~-,.,,,, .-: ....... + ....... 4000 ....~,,:~ - ....... ,.~. ~. ~; ~, ~ H ,. . . . , .. . . · ; ~ ......... ......... .......................... 5000 "K-5 TVD=5088 T~=59~ DEP=2~0 . ~ ............. ; ............................... _ 2000 . 3ooo._: ....... i ....... 4000 '" . . .................. I ............. I ........... I .............. / ................ : ~ ......... ; ......... ~.: ........ ~ ....... ~ _. ......... ;. :.,L..i....L.i .... L..~ .... L...-~ --..: ..... ! .... ! .... ~... ,.: ....... ! , .:.-~- .......... ~ ....;-~. ~-..~---'- -~-.~.. ~-.~ ...... +-.-~.;-.L.;--~-~-..:..-~ .......... i .... ' } ~ -~... ~-;-~ 000 .~--:--.,-.-~--F 2000 ,.-~.-~-~ ........ 3000 ~--F4.-'~-.~--~- 4000.-~,-~ ......... ',- 5000...L..-4~-~..[:., 4 .~, 4.~-,-.;.4-~.-'~, 4-~ ~-.i ....... '~..~-~-,;.., .......... .." -3603 FT (TO TARGET) - . . TRRGET!(TOP KUP SANDS} ~VD=6288 THD='7476 DEP=3603 ERSTMRN NHIPSTOCK, INC. 5CRLE 1 IN. -- 100 FT. NORTH 300 200 ! O0 0 1 O0 PO0 300 400 500 600 400 " 200 .................... ~ / ...... .,, A r ~ ~ ~r ' ' ~--~--~--~ -- ~(3 --+ --~ - -~ - - .- .... ~ , , ..~ . .~. ~ A A A ~ A , y ,._ X = LAT = LONG WELL .'-'1 y _._ X : LAT = LONG --- WELL #2 WELL ;.'-" 3 Y = X = LAT --- L'O 1',1G = y ~ X = LAT = LONq : WELL .~4 y .-- X -- LAT = LONG = WELL ~5 5,969,646o72 549,457°40 70°19:40.290" 149°35,~6o05~,,' 5,969,647.44 '. 549,577,73 70°13'40o2q0'' 149°35~c .,2.543" 5,969o646,89 549,697,~7 70o19,40.276'' 149o35'49.,048'' 5,q69,647~3! 549,B17o62 70o19:40o272'' 149o3~'45o539'' 5,969,647°24 543,737o6~ 70o19~40o263', 147°35~42°03['' .. --- ..0.057,.33 LAT 70°1q~40 Lg~q = 14q°$-S' 3.8.'$ 27'' WELL ~6 WELL ..'~7 Y ' 5,969,647o31 X = 550,1,7'~ o :,?- LAT = 70°19 ~ 40°''~,.. '~"- LONG = 149°35'35o035'' WELL -'-'8 Y = 5,969,646°98 X =- 550,297°79 LAT = 70o19:40°237" LONG = 149°35~31o522" I HEP. EBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA ArID TttAT THIS PLAT REPRESENTS Arid AS- BUILT SURVEY MADE BY ME, AND THAT ALL DI:qENSIONS AND OTHER DETAILS ARE CORRECT AS. oF: 'DATE t :7/,~ -." .,' .': ....::': c.. . ..-' .. ' RECEIVED 7'-.::" ;-,:_:. -.. / "./-.. : ..... MAY - 8 19 81 Gas Cons Corn''/(/ ;:'L;.,9'.' '~ Alaska Oil & . mission'- : -. :- Anchorage "' ' ' ' . .-. ' -:. P.O. D, WELL6 I -8LOCATIOM'5 AS- BUILT ' II I I II III Ill II I II II I II '1 -- IIII III AtlanticRichfi~l~Company '~ tDATE: iDRAWIN? No,: -- I I ,.: ........ ALASKA DISTRICT-- KUPARUK been .... e in tlne_~UV_~' testing · ressu- RF~ anu b ~ o PPg eserVO~r P i ~rom anced Y ' EX ected~ be 3205js g g ~11 b~b~lls for ~ 10.4 PPg mg~ (elgg_]~ ~og~t~o~. be subjected . , d th~ Bq~_,eq ~ll~ng op~r~ ~nd Pr~~' o assumes ~ ~ gaS o · 3205], tut: ",- P [15B ~ l~ ~ =r tempera _.4 ~n pressure- the 5000 9s3 RECEIVED MAY - 8 ]981 Alaska 0il & Bas Oons. Commi$$io. A~chorage Surface ~lv~rter 1. 1'6" Bradenhead. 2. 16" x 20" 2000 psi double stud~L=_d adapter, 3. 20" 2000 psi drilling spc..sl w/iS" side outlets. 4. 10" ball valves, hyraulicaily actuated, w/10" lines to reserve pit. valves ta open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bel'i nipple. 'Maintenance & O~eration ~ '. I. Upon initial installation close annular I preventer.and verify that ball valves ! have opened properly. · i 2. Close annular preventer and blow air ~__ . through diverter lines every 12 hours. I 3. Close annular preventer in the event that gas or fluid flow to surface is ' ~detected. If necessary, manUally over- ride and close ball valve to upwind --- diverter line..~.Do not shut .in well under .any circumstances. Alaska Oil & G~s Cons. Commissio~.~ Anchorag~ .. 16" Conductor 1 . '1.: 3 10" 4. lO" 3000 PSI x 13-5/8" 5OSC PSZ adapter spool 5. 13-5/8" 5000 PSI 6i;e r~s 6. 13-5/8" 5000 PSZ drilling stool w/choke and kill lin~s 7. 13-5/S" 5000 PSI pipe rams 8. 13-5/8" 5000 PSi blind rams 9. 13-5/8" 5000 PSi annular ACCUMULATOR CAPACITY TEST 1 CHECK A:;D FILL ACCUHULATOR R~'ER':OIR' LEVEL NIT;4 HYD.%AULIC FLUID. 2. ASSU2E THAT ACCU~ULATOR PRESSURE IS 3OCS 2SI WITH 1500 PSI 'DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TiHE THEN CLOSE ALL UNITS Sit.'.ULTA:;E- OUSLY AND RECORD THE TIXE A;;D PRESSURE REZAIN- ING AFTER ALL UNITS ARE CLOSED 'JITH PU~'tP OFF. 4. RECORD OX IADC REPORT. THE ACCEPTASLE LO~EP, LIMIT IS 45 SECONDS CLOSI~;G TIME AXD 1200 PSI REMAINII:G PRESSURE. - 13-5/8" BOP STAC:< TEST FILL BOP STACK AND HANIFOLD NITN ARCTZC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE- TRACTED. PREDETEP;,IINE DEPTH THAT TEST PLUG ~,,D SEAT tN NELL:-:EAD. RUN iN LOCK WILL SEAT DOWN SCREW, IS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON HANIFOLD. 4. lEST ALL COHPONENTS TO 250 PSI AND HOLD FOR lO HI~;UTES. 5. I~CREASE PRESSURE TO 1800 PSI AND HOLD FO.A . I: UTES. TO ZE O PSI. ' 6. OPEN ANNULAR PREVENTER A,iD CLOSE TOP SET OF P[PE ~'.1S. 7. [I~;~:E PRESSURE TO 3000 PSI ANDHOLD FOR lO , ,' · ':.~ 8. ~L~SE%~LVES. DIRECTLY UPSTREA'4 OF CHOKES. "' BLEED DOW~ISTREN.I PRESSURE TO ZERO PSI TO TEST VALVES. TEST RDIAINI~;G UNTESTED HANIFOLD W. LV~S. IF AnY, ~TH 3000 PSi UPST~;:'~ OF ~ W. LVE AHD ZERO PSI DOW~;STRE$;'I. BLEED SYST:H ~ I I TO ZERO PSI - .... 9. OPEN TOP SET OF PiP. ~J.IS AND CLOSE ~ SET OF PtPE ~S. . 10. illCREASE PRESSURE TO 3000 PSi AND HOLD FOR · ~[NUTES. BLEED TO ZERO PSi. , ~ il. OPEN ~OTTO;i SET OF PiPE RF:.1S. BACK, OFF RUN- ~ NI~;S uOI;iT AHD PULL OUT OF HOLE. C~CSE 5LI;;D ~~~ · Pm;~s AnD TEST TO 3000 PSi FOR ]0 ~[~;UT~S. ~~ :~C ~ BLE~O TO ZERO PSi. , ~ ~ ~ I ~ ~ ~ 12. CPE:I BLI:',9 R~'.IS A;ID RECOVER TEST PLUG. ,.',AKE '"' '- SURE HA;I[FOLD A:iD L!XES ARE FULL CF ARCTIC MAY - 8 - 15. ~.CC.3 TEST [:;FOR:,~TIO:i CN ELuWC~T lEST FO.D~ SIGN AND SE::9 TO 2~ILL.:,S v~sc~. . 16. 2ER, FC~I C~:PLETE $CPE TEST ONCE A NEEK · FU:;CTIGNALLY OPERATE BCPE gAILY. CHECK LIST FOR ~,~EW WRJ,I, PERMITS Compsny ~ ~ o Lease & Well No. IT~ APPROVE DATE (1) Fee / (2) Loc. 2~t~ ( 8) (3) ..A~min (~ thru (4) Casg > .~'-tg-~l (12 thru 20) (5) ROPE (21 thru 24) 1. Is 2. Is 3. Is 4. Is 5. Is 6. Is 7. Is operator the only affected ~arty ................................. 8. Can permit be approved before ten-day Mit .......................... e 10. 11. YES NO 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. the permit fee attached .......................................... ~11 to be located in a dmfined pool ............................. ~11 located proper distance frcm property line .................. v~ll located proper distance from other ~lls .................... sufficient undedic~ted acreage available in this pool ~11 to be dmviated and is ~11 bore plat includmd ............... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided .................................. . ..... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cemmnt cov~r all known prcductive horizons ..................... Will surface casing protect fresh ~ter zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this ~11 to be kicked off from an existing ~llbore ............. Is old ~llbore akandonnmnt procedure included on 10-403 ............ Is adequate w~ll bore separation proposed ........................... Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~_£y~ psig .. Does the choke manifold ccmply w/API RP-53 (Feb. 78) ..... (6) Add: 25. Additional requirements ............................................. ,. _~_ Additional Remarks: Geology: En~neering: / rev: 03/10/81 ,. . iNIT I_~L ~ .GEO. UNIT !~ 0N/OFF POOL CL~S STATUS AREA NO. SHORE ..
