Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
185-205
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 15, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3A-02 KUPARUK RIV UNIT 3A-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/15/2025 3A-02 50-029-21431-00-00 185-205-0 W SPT 5800 1852050 1500 1925 1925 1925 1925 200 425 425 425 4YRTST P Austin McLeod 8/4/2025 MITIA 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 3A-02 Inspection Date: Tubing OA Packer Depth 490 2710 2610 2600IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250804185936 BBL Pumped:1.9 BBL Returned:1.7 Monday, September 15, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.09.15 12:21:14 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 25, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3A-02 KUPARUK RIV UNIT 3A-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2023 3A-02 50-029-21431-00-00 185-205-0 W SPT 5800 1852050 1500 1440 1440 1440 1440 475 650 650 650 INITAL P Austin McLeod 5/28/2023 Post RWO. Sundry 323-155. Tubing replaced. 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 3A-02 Inspection Date: Tubing OA Packer Depth 780 2300 2240 2230IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230528185950 BBL Pumped:1.2 BBL Returned:1 Tuesday, July 25, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 Sundry 323-155. James B. Regg Digitally signed by James B. Regg Date: 2023.07.25 15:37:06 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8690'feet None feet true vertical 6302'feet None feet Effective Depth measured 8256' feet 7903', 8025', 8244'feet true vertical 5975'feet 5709', 5800', 5966'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" x 3-1/2" J-55/L-80 8263' MD 5980' TVD Packers and SSSV (type, measured and true vertical depth) 7903' MD 8025' MD 8244' MD N/A 5709' TVD 5800' TVD 5966' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 4112' 3110' Burst Collapse Production Liner 8654' Casing 6294'8678' 4081' 105'Conductor Surface Intermediate 16" 9-5/8" 74' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-205 50-029-21431-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025632 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3A-02 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 105' ~ ~~ INJECTOR ~~ ~ 323-155 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: HLB MFT Packer Packer: Baker FHL Packer Packer: Baker FB-1 Perm Packer SSSV: None Dusty Ward dusty.ward@conocophillips.com (907) 265-6531Senior RWO Engineer 8108-8208', 8319-8344', 8357-8397' 5863-5939', 6023-6042', 6051-6082' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 9:16 am, Jun 08, 2023 Page 1/6 3A-02 Report Printed: 5/16/2023 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) 4/16/2023 00:00 4/16/2023 02:00 2.00 MIRU, MOVE RURD P Rig down from 3S-26 0.0 0.0 4/16/2023 02:00 4/16/2023 12:00 10.00 MIRU, MOVE MOB P Mob rig from 3S to 3A 0.0 0.0 4/16/2023 12:00 4/16/2023 14:00 2.00 MIRU, MOVE RURD P Prep cellar for backing over the well // hang tree in cellar // stage adapter spool and wh equipment in cellar for spotting rig // spot sub and pit module set mats 0.0 0.0 4/16/2023 14:00 4/16/2023 16:00 2.00 MIRU, MOVE SVRG P Inspect bridals and service bridal line sheaves // Inspect derrick for raising mast 0.0 0.0 4/16/2023 16:00 4/16/2023 22:00 6.00 MIRU, MOVE RURD P Raise and pin derrick // Berm and safe out rig // Safe out landings // Hang bridal lines // spot tanks // attach blocks to topdrive // prep pits for fluid // Rig accepted 21:00 on 4/16/23 0.0 0.0 4/16/2023 22:00 4/16/2023 23:30 1.50 MIRU, MOVE OTHR P Fill pits with fluid // misc prep for well kill // PT lines 3500 psi 0.0 0.0 4/16/2023 23:30 4/17/2023 00:00 0.50 MIRU, MOVE CIRC P Circulate well to 9.6 ppg brine // 337 bbls 0.0 0.0 4/17/2023 00:00 4/17/2023 01:45 1.75 MIRU, WELCTL CIRC P Circulate well to 9.6 ppg brine // 337 bbls // shut down pump no flow at tiger tank 0.0 0.0 4/17/2023 01:45 4/17/2023 02:15 0.50 MIRU, WELCTL OWFF P Observe well for flow at IA, no flow 0.0 0.0 4/17/2023 02:15 4/17/2023 02:45 0.50 MIRU, WELCTL MPSP P Install ISA BPPV // Pressure test 1000psi 0.0 0.0 4/17/2023 02:45 4/17/2023 06:00 3.25 MIRU, WELCTL NUND P Nipple down production tree. Clean and chase threads in tubing hnager neck with pup joint. 0.0 0.0 4/17/2023 06:00 4/17/2023 08:00 2.00 MIRU, WELCTL NUND P Install 7 X 11 DSA. Nipple up BOPs. 0.0 0.0 4/17/2023 08:00 4/17/2023 12:00 4.00 MIRU, WHDBOP RURD P RU to test BOP's flood stack with water purge air out of system. Attempt shell test on breaks against B.R and blanking plug. Fluid bypass out IA valve. Tested CM valves1,2,3,14-16 to 4000 PSI good. Determined choke valves all holding and test pump holding pressure. Attempted to test below B.R. unable to maintain pressure fluid again bypassing blanking plug steady stream flowing out IA. 0.0 0.0 4/17/2023 12:00 4/17/2023 13:00 1.00 MIRU, WHDBOP RURD P Pull blanking plug and BPV. 0.0 0.0 4/17/2023 13:00 4/17/2023 13:30 0.50 MIRU, WHDBOP RURD P Reset IS BPV. Test under BPV to 1000 PSI for 10 minutes. 0.0 0.0 4/17/2023 13:30 4/17/2023 17:00 3.50 MIRU, WHDBOP RURD P Re-rig to accomodate change in test order while E-Line is enroute. 0.0 4/17/2023 17:00 4/17/2023 19:00 2.00 MIRU, WHDBOP NUND T Nipple down stack // Hang tree for nipple up 0.0 0.0 4/17/2023 19:00 4/17/2023 20:00 1.00 MIRU, WHDBOP WAIT T Wait for FMC 0.0 0.0 4/17/2023 20:00 4/18/2023 00:00 4.00 MIRU, WHDBOP NUND T Nipple up tree // Test packoff 5100 psi 15 min good test // test tree 3000 psi 10 min against DH plug // Blow down lines rig down test equipment // Pull ISA plug // 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/25/2023 Page 2/6 3A-02 Report Printed: 5/16/2023 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) 4/18/2023 00:00 4/18/2023 03:15 3.25 MIRU, WHDBOP SLKL T Rig up slick line and slick line lubricator. Make up running tools DPU set to start function at 50 min. Set RBP at 9' COE below hanger in second pup joint. Observe 150 lb wt change during stroke of tool. Pull tools up in riser for pressure test. 0.0 0.0 4/18/2023 03:15 4/18/2023 03:45 0.50 MIRU, WHDBOP PRTS T Pressure test RBP against tree 4000 psi 10 min. RBP failed test. Pulled RBP. RBP still in set position when retrieved. 0.0 0.0 4/18/2023 03:45 4/18/2023 08:15 4.50 MIRU, WHDBOP RURD T Make up running tools DPU set to start function at 50 min. Set RBP at 22' COE 12' in on 1st full joint below hanger. Observe 150 lb wt change during stroke of tool. 0.0 0.0 4/18/2023 08:15 4/18/2023 12:15 4.00 MIRU, WHDBOP PRTS T RU and test RBP though tree and lubricator riser to 4000 PSI for 30 minutes. Consistent pressure fluctuations between 4200 and 4000 PSI. Bleed off pressure from tree and lubricator. IA had continuous stream of fluid throughout testing. 0.0 0.0 4/18/2023 12:15 4/18/2023 13:45 1.50 MIRU, WHDBOP PRTS T R.U. and prep to test CMIT. Perform CMIT to 3000 PSI for 30 minutes. 0.0 0.0 4/18/2023 13:45 4/18/2023 16:15 2.50 MIRU, WHDBOP RURD T Blow down testing equipment RD from testing. RD slickline and standback lubricator. 0.0 0.0 4/18/2023 16:15 4/18/2023 21:15 5.00 MIRU, WHDBOP NUND T ND tree and adapter and NU BOPE 0.0 0.0 4/18/2023 21:15 4/18/2023 22:45 1.50 MIRU, WHDBOP OTHR T Prep for shell test // IA found to have pressure on it , install test chart pressure build to 825 psi level off, consult town team to develop plan forward, mobilize well head tech with BPV 0.0 0.0 4/18/2023 22:45 4/18/2023 23:15 0.50 MIRU, WHDBOP MPSP T Set ISA BPV unable to test due to DH RBP 0.0 0.0 4/18/2023 23:15 4/19/2023 00:00 0.75 MIRU, WHDBOP NUND T Nipple down BOPs 0.0 0.0 4/19/2023 00:00 4/19/2023 01:30 1.50 MIRU, WHDBOP NUND T Nipple up production tree 0.0 0.0 4/19/2023 01:30 4/19/2023 01:45 0.25 MIRU, WHDBOP PRTS T Pressure test pack-offs ( void ) 5000 psi 10 min // Passing Test 0.0 0.0 4/19/2023 01:45 4/19/2023 02:00 0.25 MIRU, WHDBOP MPSP T Pull ISA BPV 0.0 0.0 4/19/2023 02:00 4/19/2023 02:15 0.25 MIRU, WHDBOP PRTS T Test production tree 3000 psi 10 min // passing test 0.0 0.0 4/19/2023 02:15 4/19/2023 04:45 2.50 MIRU, WHDBOP RURD T Rig up HES slickline to pull RBP // Equalize pressures across RBP 800 psi // Pull RBP 0.0 0.0 4/19/2023 04:45 4/19/2023 16:45 12.00 MIRU, WHDBOP WAIT T Wait for 12.8 LSND 0.0 0.0 4/19/2023 16:45 4/19/2023 17:45 1.00 MIRU, WHDBOP COND T Load pits with 12.8 LSND 0.0 0.0 4/19/2023 17:45 4/19/2023 19:15 1.50 MIRU, WHDBOP DISP T Circulate well to 12.8 ppg LSND 0.0 0.0 4/19/2023 19:15 4/19/2023 20:30 1.25 MIRU, WHDBOP OWFF T OWFF while waiting for HES Slickline 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/25/2023 Page 3/6 3A-02 Report Printed: 5/16/2023 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) 4/19/2023 20:30 4/19/2023 22:00 1.50 MIRU, WHDBOP SLKL T HES slick line make up setting tool for Quadco PIIP RBP, make up lubricator, 50 min soak time on setting tool, RIH to 32' center of element wait for setting sequence, good set // Stand back HES slickline for pressure test 0.0 0.0 4/19/2023 22:00 4/19/2023 23:00 1.00 MIRU, WHDBOP PRTS T Pressure test RBP 4000 for 10 min 0.0 0.0 4/19/2023 23:00 4/19/2023 23:30 0.50 MIRU, WHDBOP RURD T Rig down HES Slickline 0.0 0.0 4/19/2023 23:30 4/20/2023 00:00 0.50 MIRU, WHDBOP SVRG T Service TD, BOP moving system, 0.0 0.0 4/20/2023 00:00 4/20/2023 03:00 3.00 MIRU, WHDBOP NUND T Nipple down tree and adapter. Nipple up BOPs 0.0 0.0 4/20/2023 03:00 4/20/2023 04:00 1.00 MIRU, WHDBOP OTHR P Fluid pack surface lines and shell test aginst RBP 0.0 0.0 4/20/2023 04:00 4/20/2023 11:30 7.50 MIRU, WHDBOP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Tested annular on 3-1/2" test joint to 3500 PSI, UVBR's, LVBR's w/3-1/2" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, FOSV, and IBOP. Tested 3-1/2" EUE FOSV Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3000 PSI, after closure=1500 PSI, 200 PSI attained =12 sec, full recovery attained = 110 sec. UVBR's= 5 sec, Annular= 25 sec. Simulated blinds= 5 sec. LVBRs=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2025 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Adam Earl. 0.0 0.0 4/20/2023 11:30 4/20/2023 13:15 1.75 COMPZN, RPCOMP RURD P Blow down and RD testing equipment. R/U Dutch riser assmebly and close annular. Ru slick line to riser. PT slickline to 1500 PSI. 0.0 0.0 4/20/2023 13:15 4/20/2023 15:15 2.00 COMPZN, RPCOMP SLKL P RIH with slick line and harvest RBP. 0.0 0.0 4/20/2023 15:15 4/20/2023 16:30 1.25 COMPZN, RPCOMP SLKL P R/D slick line and dutch riser. 0.0 0.0 4/20/2023 16:30 4/20/2023 17:30 1.00 COMPZN, RPCOMP RURD P Clear floor and prep to pull tubing. 0.0 0.0 4/20/2023 17:30 4/20/2023 18:00 0.50 COMPZN, RPCOMP PULL P M/U Spear to single joint. Engage tubing hanger with spear. Verify spear is set in hanger PU 10K. continue into tubing with spear to stop shoulder. 8,035.0 8,000.0 4/20/2023 18:00 4/20/2023 20:00 2.00 COMPZN, RPCOMP CIRC P Circulate Surface to Surface 8,000.0 8,000.0 4/20/2023 20:00 4/21/2023 00:00 4.00 COMPZN, RPCOMP PULL P Pull 3.5" completion // Control line spooled up and 30 bands recovered 8,000.0 4,680.0 4/21/2023 00:00 4/21/2023 01:00 1.00 COMPZN, RPCOMP CIRC P Circulate ensure good fluid through permafrost // clear floor of spool for control line 4,680.0 4,680.0 Rig: NABORS 7ES RIG RELEASE DATE 4/25/2023 Page 4/6 3A-02 Report Printed: 5/16/2023 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) 4/21/2023 01:00 4/21/2023 07:30 6.50 COMPZN, RPCOMP PULL P Pull 3.5" completion F4680 T/surface Seal assembly recovered tubing partially cut. ** 9 GLM out and 1 SSSV out with all tubing ** 4,680.0 0.0 4/21/2023 07:30 4/21/2023 10:00 2.50 COMPZN, RPCOMP RURD P RU T/ run tubing place GBR tongs on floor, arrange jewelry in running order in pipe shed. reconfigure completion to include seal assembly, confirm tally with engineer Johnathan Coberly. 0.0 0.0 4/21/2023 10:00 4/21/2023 10:30 0.50 COMPZN, RPCOMP SFTY P Hold prejob safety meeting with Nabors, GBR and Halliburton. 0.0 0.0 4/21/2023 10:30 4/21/2023 13:15 2.75 COMPZN, RPCOMP PUTB P Start RIH with cpompletion F/surface T/1500' 0.0 1,500.0 4/21/2023 13:15 4/21/2023 14:15 1.00 COMPZN, RPCOMP CIRC P Circulate and condition mud in well. 3BPM at 220 PSI 1,500.0 1,500.0 4/21/2023 14:15 4/21/2023 16:30 2.25 COMPZN, RPCOMP PUTB P Cont RIH F/1500 T/3381' 3,381.0 3,381.0 4/21/2023 16:30 4/21/2023 17:30 1.00 COMPZN, RPCOMP CIRC P Circulate and condition mud in well. 2.6 BPM @ 450 PSI 3,381.0 3,381.0 4/21/2023 17:30 4/21/2023 19:30 2.00 COMPZN, RPCOMP PUTB P Continue to RIH T/ 6171' 3,381.0 6,700.0 4/21/2023 19:30 4/21/2023 20:30 1.00 COMPZN, RPCOMP CIRC P Circulate and condition mud in well. 2.6 BPM @ 560 PSI 6,700.0 6,700.0 4/21/2023 20:30 4/21/2023 23:30 3.00 COMPZN, RPCOMP PUTB P RIH w/ completion T/ 8024' Stack out // Kelly up attempt to wash down // 2 bpm 650 psi continue to set down @ 8024' no pressure changed // Rotate jt .5 turn set down 8024' rotate additional .5 turn set down 8024' // consult town about cleanout run 6,700.0 8,024.0 4/21/2023 23:30 4/22/2023 00:00 0.50 COMPZN, RPCOMP CIRC P Condition mud while checking pipe counts 8,024.0 8,020.0 4/22/2023 00:00 4/22/2023 05:00 5.00 COMPZN, RPCOMP CIRC P Circulate while processing drillpipe 8,020.0 8,020.0 4/22/2023 05:00 4/22/2023 13:00 8.00 COMPZN, RPCOMP CIRC T Unplanned incorrect original tally unable to determine depth of gutted seal assembly due to old tally. Less pipe recovered from well than recorded in original tally. Continue to condition fluid in well. Increase viscosity to 60 vis to reduce barite sag in well. Continue to process DP while circulating. 8,020.0 8,020.0 4/22/2023 13:00 4/22/2023 18:00 5.00 COMPZN, RPCOMP TRIP T TOOH on stands with tubing F/8020 T/surface. 8,020.0 0.0 4/22/2023 18:00 4/22/2023 19:15 1.25 COMPZN, RPCOMP BHAH T Lay down packer and stripped seal assembly 0.0 0.0 4/22/2023 19:15 4/22/2023 20:00 0.75 COMPZN, RPCOMP CLEN T Rig down tongs, clean floor, load BHA in pipe shed 0.0 0.0 4/22/2023 20:00 4/22/2023 20:30 0.50 COMPZN, RPCOMP BHAH T Pick up clean out BHA #1 0.0 0.0 4/22/2023 20:30 4/22/2023 23:00 2.50 COMPZN, RPCOMP PUTB T RIH on singles 3.5" DP 0.0 1,775.0 4/22/2023 23:00 4/22/2023 23:30 0.50 COMPZN, RPCOMP CIRC T Circulate 4 bpm @ 420 psi 1,775.0 1,775.0 4/22/2023 23:30 4/23/2023 00:00 0.50 COMPZN, RPCOMP PUTB T RIH on singles DP T/ 2500' 1,775.0 2,500.0 4/23/2023 00:00 4/23/2023 00:30 0.50 COMPZN, RPCOMP PUTB T RIH on singles T/ 3340 2,500.0 3,340.0 4/23/2023 00:30 4/23/2023 01:00 0.50 COMPZN, RPCOMP CIRC T Circulate to keep mud conditioned 4 bpm @ 825 psi 3,340.0 3,340.0 Rig: NABORS 7ES RIG RELEASE DATE 4/25/2023 Page 5/6 3A-02 Report Printed: 5/16/2023 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) 4/23/2023 01:00 4/23/2023 02:00 1.00 COMPZN, RPCOMP PUTB T RIH on singles T/ 4850 3,340.0 4,850.0 4/23/2023 02:00 4/23/2023 02:30 0.50 COMPZN, RPCOMP CIRC T Circulate 3.5 bpm 867 psi 4,850.0 4,850.0 4/23/2023 02:30 4/23/2023 03:45 1.25 COMPZN, RPCOMP PUTB T RIH on singles T/ 6500' 4,850.0 6,500.0 4/23/2023 03:45 4/23/2023 05:00 1.25 COMPZN, RPCOMP CIRC T Circulat to keep mud conditioned 3 bpm @ 1123 psi 6,500.0 6,500.0 4/23/2023 05:00 4/23/2023 06:00 1.00 COMPZN, RPCOMP PUTB T RIH on singles T/ 8000' 6,500.0 8,000.0 4/23/2023 06:00 4/23/2023 07:00 1.00 COMPZN, RPCOMP WASH T Wash down to no go on BHA, tag at 8023' no-go at 8012' top of PBR. Repeat 4 times. PR=3 BPM 1300 PSI stack out at 8023' pressure increased top 1500 PSI. 3 times. rotate string 180* retag at 8023' top of PBR at 8012 7ES RKB 8015.7 ORKB. 8,000.0 8,023.0 4/23/2023 07:00 4/23/2023 08:00 1.00 COMPZN, RPCOMP CIRC T Circulate and condition well to 12.9# in and out 72*. 8,023.0 8,000.0 4/23/2023 08:00 4/23/2023 08:30 0.50 COMPZN, RPCOMP CIRC T Pump dry job. 8,000.0 8,000.0 4/23/2023 08:30 4/23/2023 13:45 5.25 COMPZN, RPCOMP PULD T POOH LD singles F/8000' T/239.84' 8,000.0 239.8 4/23/2023 13:45 4/23/2023 14:30 0.75 COMPZN, RPCOMP BHAH T LD BHA #1 boot baskets empty, magnets were clean. 239.8 0.0 4/23/2023 14:30 4/23/2023 15:00 0.50 COMPZN, RPCOMP OTHR T Pull wear ring 0.0 0.0 4/23/2023 15:00 4/23/2023 16:30 1.50 COMPZN, RPCOMP RURD T RU Floor to run tubing PU GBR tubing tongs. 0.0 0.0 4/23/2023 16:30 4/24/2023 00:00 7.50 COMPZN, RPCOMP PUTB T PU Seal assembly RIH W/3-1/2" completion F/surface T/7300 0.0 7,300.0 4/24/2023 00:00 4/24/2023 00:45 0.75 COMPZN, RPCOMP PUTB T RIH W/3-1/2" completion F/7300' T/8024' 7,300.0 8,024.0 4/24/2023 00:45 4/24/2023 01:15 0.50 COMPZN, RPCOMP HOSO P Calculate space out // Pick up 9.99' pup jt // make up hanger 8,024.0 8,024.0 4/24/2023 01:15 4/24/2023 02:00 0.75 COMPZN, RPCOMP CIRC P Circulate mud while rigging down GBR tools 8,024.0 8,024.0 4/24/2023 02:00 4/24/2023 02:30 0.50 COMPZN, RPCOMP THGR P Land hanger and confirm // RILDS and torque // 8,024.0 8,024.0 4/24/2023 02:30 4/24/2023 03:15 0.75 COMPZN, RPCOMP MPSP P Set HP-BPV and test 1000 psi 0.0 0.0 4/24/2023 03:15 4/24/2023 05:15 2.00 COMPZN, RPCOMP CLEN P Flush surface lines and flush BOPs prior to nipple down 0.0 0.0 4/24/2023 05:15 4/24/2023 12:00 6.75 COMPZN, RPCOMP NUND P Nipple down bops // Nipple up tree 0.0 0.0 4/24/2023 12:00 4/24/2023 13:30 1.50 COMPZN, WHDBOP RURD P Rig up cellar to circulate CI 0.0 0.0 4/24/2023 13:30 4/24/2023 17:00 3.50 COMPZN, WHDBOP DISP P Displace well to CI // Fluid never cleaned up order additional 290 bbls CI 0.0 0.0 4/24/2023 17:00 4/24/2023 21:30 4.50 COMPZN, WHDBOP WAIT P Wait on CI // Crew performing misc rig down ops for rig move 0.0 0.0 4/24/2023 21:30 4/25/2023 00:00 2.50 COMPZN, WHDBOP DISP P Hook up CI truck displace well to 9.6# CI 0.0 0.0 4/25/2023 00:00 4/25/2023 00:30 0.50 COMPZN, WHDBOP PACK P Drop ball and rod // Pressure up set packer 3500psi start tubing test 0.0 0.0 4/25/2023 00:30 4/25/2023 01:30 1.00 COMPZN, WHDBOP PRTS P Pressure test Tubing 3500 psi 30min // PT IA 2000psi 30min // Dump Tubing pressure shear SOV 0.0 0.0 4/25/2023 01:30 4/25/2023 02:45 1.25 COMPZN, WHDBOP FRZP P Rig up LRS pressure test lines // Pump 80bbls diesel freeze protect // Rig down let well u-tube 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/25/2023 Page 6/6 3A-02 Report Printed: 5/16/2023 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) 4/25/2023 02:45 4/25/2023 03:30 0.75 DEMOB, MOVE RURD P Rig down little red 0.0 0.0 4/25/2023 03:30 4/25/2023 06:00 2.50 DEMOB, MOVE RURD P Rig down clean pits // Lower derrick // Rig released @ 06:00 on 4/25/2023 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/25/2023 DTTMSTART JOBTYP SUMMARYOPS 3/7/2023 SUPPORT OTHER OPERATIONS (PRE RWO) FT T & IC LDS/GNS (COMPLETE), POT-T (PASSED), PPPOT-T (PASSED), POT-IC (PASSED), PPPOT-IC (PASSED), MIT-OA PASSED TO 1800 PSI 3/26/2023 SUPPORT OTHER OPERATIONS PULLED & REPLACED 2.30'' CII SLEEVE @ 8271'RKB. SET 2.20'' JUNK CATCHER (OAL93'') ON TOP OF PLUG @ 8295'RKB. OBTAINED PASSING CMIT TO 2500PSI. PULLED 1.5'' DMY VLV W/RM LATCH ST#9 @8003'RKB, POCKET OPEN. READY FOR E-LINE. 3/27/2023 SUPPORT OTHER OPERATIONS CMIT TxIA 3000 PSI ***PASSED*** PUMPED 3.4 BBLS DSL TO REACH TEST PRE PSI T/IO=750/450/60 ST T/I/O=3250/3000/460 15 MIN T/I/O=3150/2950/460 30 MIN T/I/O=3150/2950/460 BLED BACK 3.1 BBLS TO STARTING PSI 3/31/2023 SUPPORT OTHER OPERATIONS STRING SHOT OVER INTERVAL: 8018' - 8027' CUT TUBING WITH 2" RCT AT 8027' LOG CALIPER OVER TUBING CUT MADE AT 8027'. TUBING APPEARS TO BE SHIFTED AT CUT, DATA SENT IN FOR FURTHER PROCESSING. JOB COMPLETE, READY FOR RWO 4/16/2023 RECOMPLETION Mob rig to 3A-02, rig up over 3A-02 , rig up lines and pt to 3500 for well circ out, start circulating well to 9.6 ppg brine 4/17/2023 RECOMPLETION Finish circulating well to 9.6 brine check for flow, no flow, install IBS BPV, nipple down tree, install blanking plug, nipple up stack, start 250/4000 test, blanking plug leaking, discuss options with town, nipple down stack nipple up tree, test packoffs 5100 psi 15min, test tree 3000 10 min , pull IBS plug 4/17/2023 SUPPORT OTHER OPERATIONS E-LINE UNIT STAND BY ON RIG TO SET RBP, CHANGE OF PLANS, YJOS RELEASED, PLAN FORWARD TO USE SL WITH FULL PCE 4/17/2023 SUPPORT OTHER OPERATIONS 7ES RIG JOB: SPOT UP EQUIPMENT, STANDBY FOR RIG. JOB CHARGED TO RWO 10449860 4/18/2023 RECOMPLETION Set 1st RBP and test, bad test, pull RBP still in set position, Run and set 2nd RBP in 1st full jt below hanger, test good test, trickle from IA line up and CMIT, passing test, nipple down tree nipple up BOPs, flood lines prep for shell test found pressure on IA, hook up test chart monitor IA pressure build to 825 psi, consult town formulate plan forward, set ISA BPV, nipple down stack 4/18/2023 SUPPORT OTHER OPERATIONS 7ES RIG JOB: SET 3-1/2" RBP @ 15' BELOW MASTER VALVE, UNABLE TO GET PASSING TEST, PULLED 3-1/2" RBP, BRUSHED FROM SURFACE TO 60', SET 3-1/2" RBP @ 30' BELOW MASTER VALVE, PASSING TEST ON PLUG, IN PROGRESS. JOB CHARGED TO RWO 10449860 4/19/2023 RECOMPLETION Finish nipple down stack nipple up of production tree, pull ISA BPV, Rig up HES slickline, equalise and pull RBP, wait on 12.8 LSND 12 hrs, when fluid arrive take fluid on to pits and prep for pumping, displace well to 12.8 ppg LSND, open well observe for flow 1 hr waiting on HES slick line, set Quadco RBP @ 32' from master center of element, pressure test 4000 psi , rig down HES slickline and service rig 4/19/2023 SUPPORT OTHER OPERATIONS 7ES RIG JOB: PULL 3.5" RBP FROM 21' SLM, RIG PUMPED IN KILL WEIGHT FLUID, SET 3-1/2" RBP @ 32' BELOW MASTER VALVE, PASSING TEST ON PLUG, IN PROGRESS. JOB CHARGED TO RWO 10449860 4/20/2023 RECOMPLETION Nipple down production tree, nipple up BOPs, flood lines and stack, pressure test BOPs 250/4000 ann 250/3500, blow down lines rig down test equipment, rig up HES slick line pull RBP, pull RBP OWFF, rig down slickline, pick up spear and spear hanger, pull completion off seat and lay down, circulate surface to surface mug coagulated up, pump dry job , lay down pipe to 4680 4/20/2023 SUPPORT OTHER OPERATIONS 7ES RIG JOB: STANDBY FOR RIG TO PULL TREE AND INSTALL BOP STACK, PULL 3.5" RBP FROM 48' SLM (ZERO @ RIG FLOOR), JOB COMPLETE JOB CHARGED TO RWO 10449860 4/21/2023 RECOMPLETION Continued to lay down dp, pulled seal assembly no cut made, rigged up GBR ran completion per tally, stacked out 8024' unable to pass, circulated well started processing DP 4/22/2023 RECOMPLETION Continue to circulate while processing drill pipe, condition mud for clean out ops, TOOH on stands of 3.5" HYD 563, install wear ring, pick up clean out BHA, RIH on singles 4/23/2023 RECOMPLETION Clean out to PBR top at 8014.7' ORKB. Wash down to 8026'. POOH L/D DP. Pick up packer and stripped seal assembly RIH on stands 4/24/2023 RECOMPLETION Complet running and land completion, run in LDS, set bpv and nipple down stack, nipple up tree, pull BPV, circulate 280 bbls CI, mud strung out order second truck CI circulate in 290 bbls CI 3A-02 RWO Summary of Operations 4/25/2023 RECOMPLETION Dropped ball set packer, performed Tubing and combo test, freeze protect well, RDMO 4/28/2023 SUPPORT OTHER OPERATIONS DELAYED START DO TO NEW FMC 3 1/2 OTIS CONNECTION NOT COMPATIBLE WITH STANDARD CONNECTION SWAP OUT FOR OLDER CONNECTION. SHAKE OFF 2.72" BAIT SUB & 2" RS W/ 2.60" BELL GUIDE PULLING TOOL ON BALL & ROD @ 7931' RKB, PULLED 1.5" SOV @ 7842' RKB SET DV @ SAME. MIT IA 2500 (PASS). PULLED 2.72" BAIT SUB ASSEMBLY & BALL & ROD @ 7927' RKB, PULLED 2.81" X LOCK RHC @ 7942' RKB. IN PROGRESS. 4/29/2023 SUPPORT OTHER OPERATIONS ATTEMPT TO PULL 2.25" CII @ 8232' RKB UNABLE TO PASS 8224' RKB BAILED MUD DOWN TO 8232' RKB, ATTEMPT TO LATCH 2.25" CII SLEEVE @ 8232' RKB. IN PROGRESS. 4/30/2023 SUPPORT OTHER OPERATIONS BAILED ~ 6 GAL. OF MUD FROM TOP OF AVA CII SLEEVE @ 8231' RKB, ATTEMPT TO PULL CII SLEEVE @ 8232' RKB. IN PROGRESS. 5/1/2023 SUPPORT OTHER OPERATIONS RAN 2.25" PUMP BAILER TO 8229' RKB RECOVERED MUD, ON SECOND RUN WITH 2.25" PUMP BAILER TOOLS GOT DETAINED & WIRE PARTED AFTER 5 MIN'S @ BAD SPOT IN WIRE LEAVING ~1100' WIRE & 41' TOOL STRING @ 8229' RKB, BOXED WIRE OFF TOOL STRING @ 9191' RKB, RAN 3 1/2 BAIT SUB 3 1/2 BRUSH @ 3 PRONG WIRE GRAB MOVE WIRE UP TO 5996' RKB. IN PROGRESS. 5/2/2023 SUPPORT OTHER OPERATIONS PULLED 2.72" BAIT SUB BRUSH & WIRE GRAB @ 5917' RKB RECOVER WIRE, RUN 2.72" BAIT SUB BELL GUIDE & 2 1/2 PULLING TOOL SIT DOWN @ 4146' RKB, RAN 3 1/2 BRUSH & WIRE GRAB SIT DOWN @ 7941' RKB RECOVER 10' CHUNK OF WIRE. IN PROGRESS. 5/3/2023 SUPPORT OTHER OPERATIONS CLEAN DRIFT W/ 3 1/2 BRUSH & 2.68" MAGNET TO FISH @ 8191' RKB, SET 2.72" BAIT SUB 2.70" BELL GUIDE W/ 2.5" GUTTED JD (OAL 31.5"), JARRED ON FISH FOR 2.5 HR's NO MOVEMENT. IN PROGRESS. 5/4/2023 SUPPORT OTHER OPERATIONS JAR ON FISH WITH .160 WIRE FOR 2 HR's NO MOVEMENT. JOB SUSPENDED FOR PLAN FORWARD. **** 2.72" BAIT SUB (2.31" G-FN) 2.70" BELL GUIDE W/ 2.5" GUTTED JD, 1.875" RS,2.125" TOOL STRING & 2.25" PUMP BAILER (OAL 44') SEE DRAWING ******* 5/12/2023 SUPPORT OTHER OPERATIONS PERFORM FILL CLEANOUT FROM 2000' CTMD TO A LIGHT TAG ON SLICKLINE TOOLS @ 8184' CTMD, PUMP A FINAL 10 BBL GEL SWEEP AND CHASE OOH WHILE MAINTAINING 1:1 RETURNS, VERIFY THAT WE HAVE THE FISH (SWAB ONLY CLOSED 4 TURNS), RBIH AND PUMP OFF OF FISH AT 3000' CTMD, STANDBY FOR SLICKLINE TO RECOVER 45' TOOLSTRING, MISSED RUN W/ 2" SPEAR TO 8228' FOR CII ISO-SLEEEVE, UNABLE TO LATCH UP W/ 2" SPEAR. JOB IN PROGRESS. 5/12/2023 SUPPORT OTHER OPERATIONS ASSIST COIL: PULLED TOOLSTRING FROM 8178' SLM, ENTIRE TOOLSTRING RECOVERED. TURN WELL BACK TO COIL. 5/13/2023 SUPPORT OTHER OPERATIONS LATCH & RETRIEVE CII ISO-SLEEVE @ 8230'.POOH L/D SLEEVE RIH ATTEMPT TO PULL CATCHER NO GO @ 8231' POOH REDRESS W/ 2.25 OD SPEAR RIH ATTEMPT TO LATCH NO GO POOH M/U 2.14 OD RIH AND WASHED DOWN FROM 8230' TO 8240' POOH NO CATCHER L/D SPEAR AND M/U 1.74 TAPERED MILL RIH TAG UP @ 8242' & UNABLE TO MILL AHEAD. POOH W/ CATCHER SUB ON THE MILL. RIH HOLDING WHP = 700 PSI W/ OVERSHOT TO 8250' CTMD TO LATCH CA2 PRONG,. PUH W/ 300 PSI WHP INCREASE. POOH & WHP DECREASING. OOH & DID NOT RECOVER PRONG. RBIH TO 8251' HOLDING 700 PSI WHP. PUH AND WHP INCREASES TO 1056 PSI. POOH W/ WHP MAINTAINING @ 1050 - 1100 PSI TO SURFACE. DO NOT HAVE PRONG. FP TUBING & COIL. RDMO. SUSPEND JOB TO TURNOVER TO SLICKLINE FOR PRONG & PLUG RECOVERY ****JOB IN PROGRESS****** 5/15/2023 SUPPORT OTHER OPERATIONS RECOVER FILL @ 8256 'RKB. ATTEMPT TO PULL 1.81' 'CA-2 PRONG UNABLE TO LATCH, JOB IN PROGRESS. 5/16/2023 SUPPORT OTHER OPERATIONS PULLED EQ PRONG &1.81'' CA-2 PLUG BODY @ 8256'RKB. IN PROGRESS 5/17/2023 SUPPORT OTHER OPERATIONS TAG @ 8365' RKB. SET 2.25 CII SLEEVE @ 8232'RKB. JOB COMPLETE 5/21/2023 ACQUIRE DATA (PRE-SW) BLEED AND LOAD IA FOR SW MITIA PREP COMPLETE. 5/26/2023 ACQUIRE DATA (AC EVAL) RECORDED AND CHARTED MIT-IA PASSED TO 3330 PSI Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,365.0 3A-02 5/17/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled 1.81" Plug, Tagged, Set ISO sleeve 3A-02 5/17/2023 fergusp Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 31.0 105.0 105.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 30.6 4,112.1 3,110.1 36.00 J-55 BTC PRODUCTION 7 6.28 23.7 8,677.8 6,294.2 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 28.7 Set Depth 8,021.0 Set Depth 5,797.0 String Ma 3 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L-80 Top Connection H563 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) 28.7 28.6 0.12 Hanger 7.040 7 1/16" x 3.5" FMC Gen 4 Tubing Hanger fmc TC- A- EN 2.900 530.4 530.3 2.79 Nipple 4.250 3.5" x 2.813" X-NIPPLE SN# 000482973-7 Halliburt on 2.81" "x" 2.813 7,842.8 5,663.6 41.75 Mandrel INJ 5.968 3.5" X 1.5" MMG, L-80, 9.3# HYD563. SN# 23928-08 SLB MMG 2.920 7,903.0 5,708.6 41.50 Packer 6.280 Halliburton 3.5" x 7" MFT Packer Vam P x B S#0004113579 Halliburt on MFT 2.897 7,942.9 5,738.5 41.48 Nipple 4.250 3.5" x 2.813" X-NIPPLE SN# 000482973-3 Halliburt on 2.81" "x" 2.813 8,008.4 5,787.6 41.38 Locator 4.500 Baker Locator 2.992 8,009.1 5,788.1 41.37 Seal Assembly 3.980 Used Baker 80-40 Gutted seal assembly (2' OFF TAG) Baker 80-40 2.992 Top (ftKB) 8,011.1 Set Depth 8,262.7 Set Depth 5,980.1 String Ma 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade J-55 Top Connection BTC ID (in) 2.87 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) 8,011.1 5,789.6 41.36 PBR 5.125 BAKER PBR 3.000 8,024.7 5,799.9 41.24 PACKER 6.078 BAKER FHL PACKER 3.000 8,062.4 5,828.3 40.93 Mandrel INJ 5.312 CAMCO KBUG 2.920 8,100.1 5,856.8 40.62 BLAST RINGS 4.500 CARBIDE RINGS (4) 2.867 8,232.1 5,956.9 40.76 NIPPLE 4.520 AVA BPL PORTED NIPPLE 2.296 8,241.6 5,964.1 40.76 SEAL ASSY 5.000 LOCATOR SEAL ASSEMBLY BAKER 2.438 8,243.7 5,965.6 40.76 PACKER 6.150 FB-1 PERMANENT PACKER 3.000 8,256.5 5,975.4 40.77 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 8,262.0 5,979.5 40.77 SOS 3.750 CAMCO 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) 7,995.0 5,777.6 41.45 ISO-SLEEVE 2.25" CII SLEEVE (OAL13" 1.875" ID) 5/17/2023 1.875 8,256.5 5,975.4 40.77 NIP REDUCER NIPPLE REDUCER 2.25" OD X 1.81"I ID 3/13/2002 1.810 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) 7,842.8 5,663.6 41.75 1 INJ DMY RK 1 1/2 0.0 4/28/2023 0.000 8,062.4 5,828.3 40.93 2 INJ DMY BK 1 9/4/1991 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,108.0 8,208.0 5,862.8 5,938.6 C-4, C-3, C-1, UNIT B, 3A-02 11/13/1985 12.0 IPERF 120° ph; 5" Hyper Jet II 8,319.0 8,344.0 6,022.7 6,041.6 A-3, 3A-02 11/13/1985 4.0 IPERF 90° ph; 4" Hyper Jet II 8,357.0 8,397.0 6,051.4 6,081.6 A-2, 3A-02 11/13/1985 4.0 IPERF 90° ph; 4" Hyper Jet II 3A-02, 5/31/2023 7:54:14 AM Vertical schematic (actual) PRODUCTION; 23.7-8,677.8 IPERF; 8,357.0-8,397.0 IPERF; 8,319.0-8,344.0 NIP REDUCER; 8,256.5 PACKER; 8,243.7 IPERF; 8,108.0-8,208.0 Mandrel INJ; 8,062.4 PACKER; 8,024.7 ISO-SLEEVE; 7,995.0 Nipple; 7,942.9 Packer; 7,903.0 Mandrel INJ; 7,842.8 SURFACE; 30.6-4,112.1 Nipple; 530.4 CONDUCTOR; 31.0-105.0 Hanger; 28.7 KUP INJ KB-Grd (ft) 35.19 RR Date 9/8/1985 Other Elev 3A-02 ... TD Act Btm (ftKB) 8,690.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292143100 Wellbore Status INJ Max Angle & MD Incl (°) 56.13 MD (ftKB) 3,100.00 WELLNAME WELLBORE3A-02 Annotation Last WO: End Date 4/25/2023 H2S (ppm) DateComment SSSV: LOCKED OUT 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8690'None Casing Collapse Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writt en approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Dusty Ward dusty.ward@conocophillips.com (907) 265-6531 Senior RWO Engineer Tubing Grade: Tubing MD (ft): 8064' Md and 5829' TVD 8283' Md and 5995' TVD 1863' MD and 1741' TVD Perforation Depth TVD (ft): Tubing Size: J-55 8302' 4/7/2023 Packer: Baker FHL Packer Packer: Baker FB-1 Perm Packer SSSV: Baker FVL Safety Valve (locked out) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025632 185-205 P.O. Box 100360, Anchorage, AK 99510 50-029-21431-00-00 ConocoPhillips Alaska, Inc. KRU 3A-02 Kuparuk River Oil PoolKuparuk River Oil PoolKuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6302' 8295' 6005' 3505 psi 8295' MD 105' 3110' 105' 4112' 6294'8678' 16" 9-5/8" 74' 4081' Perforation Depth MD (ft): 8108-8208', 8319-8344', 8357- 8397' 8654' 5863-5939', 6023-6042', 6051- 6082'3-1/2" x 2-7/8" 7" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 7:43 am, Mar 14, 2023 323-155 X VTL 3/21/2023 SFD 3/16/2023 X X BOP test to 4000 psig Annular preventer test to 2500 psig 10-404 DSR-3/14/23GCW 03/21/23 3/22/23Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.03.22 11:14:35 -08'00' RBDMS JSB 032323 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 22, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Dusty K Ward Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Injector 3A-02 (PTD# 185-205). Well 3A-02 was drilled and completed in September of 1985 and has largely been an Kuparuk A-sand and C-sand injector. In 2019 a patch was installed to try and fix tubing leaks. Additional leaks have pushed this to a rig workover. If you have any questions or require any further information, please contact me at +1503-476-2519. The tubing will be pulled and a new completion will be ran with a stacked packer. 3A-02 RWO Injector Kuparuk Injector P&R Tubing PTD #185-205 Page 1 of 2 Already Done Pre-Rig Work 1. Plug set in tubing tail and tested. CMIT-TxIA to 2500 psig and CDDT both pass. Remaining Pre-Rig Work 2. T-PPPOT and T-POT tests. 3. Put hold open sleeve in SSSV as necessary through wellwork. 4. Open lowest GLM in upper completion. DV off the rest. 5. CMIT-TxIA to 3000 psig. 6. Cut the tubing nominally at ~8035 RKB in the middle of the first full joint above the production packer. 7. Prepare well for rig arrival 48-72 hrs before of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3A-02. (No BPV will be installed due to internal risk assessment for N7ES on MIRU/RDMO). 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 workover fluid as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/4000 psi. Test annular 250/3,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to first packer (~8035’ RKB). Install in 3-½” Tubing 6. MU 3 ½” completion with overshot, packer, GLMs, and nipples. RIH and overshot tubing stub. 7. Once on depth, space out as needed and land hanger. Circulate in CI brine at opportune time. 8. Drop ball/rod and set packer. 9. Pressure test tubing to 3500 psi for 30 minutes on chart. 10. Pressure test inner annulus to 3000 psi for 30 minutes on chart. 11. Shear SOV. 12. Install BPV and confirm as barrier. 13. ND BOPE. NU tree. 14. Pull BPV, freeze protect well, and set BPV if necessary. 15. RDMO. Post-Rig Work 16. Pull BPV 17. Replace SOV with DV if needed. 18. Pull any balls/rods and plugs. 19. Hand over to operations. VTL 03/21/2023 State witnessed MIT-IA required after stabilized injection 3A-02 RWO Injector Kuparuk Injector P&R Tubing PTD #185-205 Page 2 of 2 General Well info: Wellhead type/pressure rating: FMC Gen III. Tubing Spool: 7-1/16” 5M psi top flange, 11” 3M psi bot flange Production Engineer: Brian Lewis Reservoir Development Engineer: Lynn Aleshire Estimated Start Date: 4/7/2023 Workover Engineer: Dusty Ward (265-6531/ dusty.ward@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Injector Scope of Work: Pull the existing 3-1/2” completion down through pre-rig cut. Stack new packer and 3.5” completion. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T Failing due to leaks. CMIT-TxIA and CDDT Passed 12/15/2022 MIT-OA Passed 3/5/2017 IC POT &PPPOT PASSED – 1/27/2019 TBG POT &PPPOT PASSED – 1/27/2019 MPSP: Last measured SBHP shown below indicates MPSP of 3505 psig using 0.1 psi/ft gradient. (4000psi estimated from static wellhead pressure and estimated gradient on 10/10/2019.) Static BHP: Last measure SBHP was 4107 psig at 8309’ MD / 6015’ TVD on 2/2/2017. 3A-02 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 105 105 16 15.06 62.5 H40 Welded Welded Surface 4112 3110 9.625 8.92 36 J55 BTC BTC Production/ Intermediate 8678 6294 7 6.28 26 J55 BTC BTC Tubing 8302 6010 3.5 x 2.875 2.992 9.3 J55 HYD563 HYD563 PROPOSED COMPLETION 3-1/2" 9.3# L-80 HYD563Tubing 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) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE Seals PBR 3.5" x 7.0" Packer @ 8064' RKB Production Mandrel Blast rings Nipple w/ Nipple reducer Seals 2.875" x 7.0" Packer @ 8283' RKB D nipple @ 8296' RKB SOS @ 7338' RKB Surface Casing Production/Intermediate Casing Conductor A-Sand Perfs C-Sand Perfs Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 8,360.0 3A-02 2/2/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set CII & 1.812" CA-2 Plug 3A-02 12/15/2022 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: PATCH DEPTH CORRECTED TO TBG TALLY 52’ adjustment. 4/11/2017 condijw NOTE: RIG RKBs PROD CSG vs TUBING ACCOUNTS FOR CSG/TBG TOPS 10/12/2012 osborl NOTE: LEAK FOUND IN BOTTOM OR PIN-END; MANDREL PATCHED 4/20/2002 2/20/2002 lmosbor 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 31.0 105.0 105.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 30.6 4,112.1 3,110.1 36.00 J-55 BTC PRODUCTION 7 6.28 23.7 8,677.8 6,294.2 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 28.7 Set Depth … 8,301.7 Set Depth … 6,009.6 String Ma… 3 1/2 Tubing Description TUBING 3.5"x2.875" @ 8274' Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE 8RD 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) 28.7 28.7 0.12 HANGER 8.000 FMC GEN III TUBING HANGER 3.500 1,863.0 1,740.7 40.50 SAFETY VLV 5.937 BAKER FVL SAFETY VALVE (LOCKED OUT 11/11/2010) 2.810 2,707.6 2,290.4 52.74 GAS LIFT 5.312 CAMCO KBUG 2.920 4,884.7 3,603.5 49.65 GAS LIFT 5.312 CAMCO KBUG 2.920 5,855.1 4,252.1 46.69 GAS LIFT 5.312 CAMCO KBUG 2.920 6,297.5 4,556.7 46.74 GAS LIFT 5.312 CAMCO KBUG 2.920 6,708.2 4,843.0 44.86 GAS LIFT 5.312 CAMCO KBUG 2.920 7,056.3 5,089.8 44.68 GAS LIFT 5.312 CAMCO KBUG 2.920 7,401.1 5,338.3 43.10 GAS LIFT 5.312 CAMCO KBUG 2.920 7,750.4 5,594.9 42.15 GAS LIFT 5.312 CAMCO KBUG 2.920 8,003.5 5,783.9 41.42 GAS LIFT 5.960 MERLA TPDX 2.875 8,050.1 5,819.0 41.03 PBR 5.125 BAKER PBR 3.000 8,063.8 5,829.3 40.92 PACKER 6.078 BAKER FHL PACKER 3.000 8,139.1 5,886.4 40.67 BLAST RINGS 4.500 CARBIDE RINGS (4) 2.867 8,271.1 5,986.4 40.77 NIPPLE 4.520 AVA BPL PORTED NIPPLE 2.296 8,280.6 5,993.6 40.77 SEAL ASSY 5.000 BAKER LOCATOR SEAL ASSEMBLY 2.438 8,282.7 5,995.2 40.77 PACKER 6.150 BAKER FB-1 PERMANENT PACKER 3.000 8,295.6 6,004.9 40.78 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 8,301.0 6,009.1 40.78 SOS 3.750 CAMCO 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) 7,742.4 5,589.0 42.18 PERM PATCH OWEN PERM PATCH ACROSS #8 MANDREL, OAL= 22.3', EFFECTIVE LENGTH= 21.62' (E2E) 4/20/2002 2.375 7,744.0 5,590.1 42.18 LEAK LEAK DETECTED AT TOP OF PATCH -IDENTIFY LEAK IN PATCH W/ EV CAMERA / ACOUSTIC LDL (10/8/2018) 6/26/2017 2.375 7,754.0 5,597.6 42.13 LEAK VIDEO LOG. IDENTIFIED THREAD LEAK AT 7754 FT ( BOTTOM OR PIN END OF GAS LIFT MANDREL #8). 2/20/2002 8,271.0 5,986.3 40.77 ISO-SLEEVE 2.25" CII SLEEVE 12/15/2022 1.875 8,271.1 5,986.4 40.77 NIP REDUCER AVA PORTED NIPPLE REDUCER 3/13/2002 2.250 8,295.0 6,004.5 40.78 TUBING PLUG 1.812" CA-2 PLUG (25" OAL) 12/15/2022 0.000 8,295.6 6,005.0 40.78 NIP REDUCER NIPPLE REDUCER 2.25" OD X 1.81"I ID 3/13/2002 1.810 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,707.6 2,290.4 52.74 1 GAS LIFT DMY BK 1 0.0 4/25/1996 0.000 4,884.7 3,603.5 49.65 2 GAS LIFT DMY BK 1 0.0 4/25/1996 0.000 5,855.1 4,252.1 46.69 3 GAS LIFT DMY BK 1 0.0 4/25/1996 0.000 6,297.5 4,556.7 46.74 4 GAS LIFT DMY BK 1 0.0 4/25/1996 0.000 6,708.2 4,843.0 44.86 5 GAS LIFT DMY BK 1 0.0 4/23/1996 0.000 7,056.3 5,089.8 44.68 6 GAS LIFT DMY BK 1 0.0 4/23/1996 0.000 7,401.1 5,338.3 43.10 7 GAS LIFT DMY BK 1 0.0 5/20/2017 0.000 7,750.4 5,594.9 42.15 8 GAS LIFT DMY BK 1 0.0 4/23/1996 0.000 8,003.5 5,783.9 41.42 9 GAS LIFT DMY RM 1 1/2 0.0 1/10/2019 0.000 8,101.4 5,857.8 40.62 1 0 INJ DMY BK 1 0.0 9/4/1991 0.000 3A-02, 2/15/2023 2:55:34 PM Vertical schematic (actual) PRODUCTION; 23.7-8,677.8 IPERF; 8,357.0-8,397.0 IPERF; 8,319.0-8,344.0 NIP REDUCER; 8,295.6 TUBING PLUG; 8,295.0 PACKER; 8,282.7 NIP REDUCER; 8,271.1 ISO-SLEEVE; 8,271.0 IPERF; 8,108.0-8,208.0 INJECTION; 8,101.4 PACKER; 8,063.8 GAS LIFT; 8,003.5 LEAK; 7,754.0 GAS LIFT; 7,750.4 PERM PATCH; 7,742.4 LEAK; 7,744.0 GAS LIFT; 7,401.1 GAS LIFT; 7,056.3 GAS LIFT; 6,708.2 GAS LIFT; 6,297.5 GAS LIFT; 5,855.1 GAS LIFT; 4,884.6 SURFACE; 30.6-4,112.1 GAS LIFT; 2,707.6 SAFETY VLV; 1,863.0 CONDUCTOR; 31.0-105.0 KUP INJ KB-Grd (ft) 35.19 RR Date 9/8/1985 Other Elev… 3A-02 ... TD Act Btm (ftKB) 8,690.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292143100 Wellbore Status INJ Max Angle & MD Incl (°) 56.13 MD (ftKB) 3,100.00 WELLNAME WELLBORE3A-02 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OUT Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,108.0 8,208.0 5,862.8 5,938.6 C-4, C-3, C-1, UNIT B, 3A-02 11/13/1985 12.0 IPERF 120° ph; 5" Hyper Jet II 8,319.0 8,344.0 6,022.7 6,041.6 A-3, 3A-02 11/13/1985 4.0 IPERF 90° ph; 4" Hyper Jet II 8,357.0 8,397.0 6,051.4 6,081.6 A-2, 3A-02 11/13/1985 4.0 IPERF 90° ph; 4" Hyper Jet II 3A-02, 2/15/2023 2:55:36 PM Vertical schematic (actual) PRODUCTION; 23.7-8,677.8 IPERF; 8,357.0-8,397.0 IPERF; 8,319.0-8,344.0 NIP REDUCER; 8,295.6 TUBING PLUG; 8,295.0 PACKER; 8,282.7 NIP REDUCER; 8,271.1 ISO-SLEEVE; 8,271.0 IPERF; 8,108.0-8,208.0 INJECTION; 8,101.4 PACKER; 8,063.8 GAS LIFT; 8,003.5 LEAK; 7,754.0 GAS LIFT; 7,750.4 PERM PATCH; 7,742.4 LEAK; 7,744.0 GAS LIFT; 7,401.1 GAS LIFT; 7,056.3 GAS LIFT; 6,708.2 GAS LIFT; 6,297.5 GAS LIFT; 5,855.1 GAS LIFT; 4,884.6 SURFACE; 30.6-4,112.1 GAS LIFT; 2,707.6 SAFETY VLV; 1,863.0 CONDUCTOR; 31.0-105.0 KUP INJ 3A-02 ... WELLNAME WELLBORE3A-02 ISSUED AS:PRELIMINARYDATE:ISSUED BY:AS BUILTFOR:APPROVALMARK-UPQUOTEREVIEW07-JUN-21PKMXX17'-314"[5261]3'-912"[1156]4'-734"[1418]2'-0"[610]2'-934"[859]2'-0"[610]2'-0"[610]BY NABORSBY OPERATORPIPE RAMCL WELLCHOKE LINE7BILL OF MATERIALS413121NOQTY DESCRIPTIONBOP, RAM 1358" 5M CAMERON "U" (DOUBLE)1DRILL SPOOL 1358" 5M w/ (2) 318" 5M OUTLETS.BOP, RAM 1358" 5M CAMERON "U" (SINGLE)36GATE VALVE, MANUAL 318" 5MGATE VALVE, HYDRAULIC 318" 5M22BOP, ANNULAR 1358" 5M CAMERON T-9012434455556724" HEIGHT.678KILL LINE5API TARGET BLIND FLANGE 318" 5M48DSA 318"5M x 2116" 5M1FF-TICKET #:THIS DRAWING IS SHOWN TRUE SCALE ONLY WHEN PRINTED ON THIS SIZE PAPERTHIS DOCUMENT AND THE INFORMATION CONTAINED HEREIN IS A CONFIDENTIAL DISCLOSURE. IT IS SHOWN TO YOUR COMPANY WITH THE UNDERSTANDING IT IS NOT TO BEREVEALED TO OTHERS OR USED FOR ANY PURPOSE WITHOUT THE WRITTEN CONSENT OF NABORS INDUSTRIES.REV.XREFDESCRIPTION APP.DATEBYTITLE COPYRIGHTED©DATE:DRN BY:ER:BDWG:APP:RIG:SCALE:NABORSSHT NO. OFNABORS RIG 7ES13 5/8" 5M BOP STACK LAYOUT14002 7ESPKM NTS27-MAY-21 SMB7ES-0008-01B REVISED AND ISSUED FOR INFORMATION 07-JUN-21 PKM3470945 01 01DRILLER SIDEOFF DRILLER SIDE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS FEB 0 7 LG'R 1. Operations Abandon Ll Plug Perforations Ll Fracture Stimulate LJ Pull Tubing Ll Operations shutdown LJ 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 patch_❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConcocoPhillips Alaska Inc Development ❑ Exploratory ❑ Stratigraphic ❑ Service ❑✓ 185-205 3. Address: 6. API Number: P.O. Box 100360, Anchorage Alaska 99510 50-029-21431-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025632 3A-02 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10, Field/Pool(s): NA Kuparuk River Field 11. Present Well Condition Summary: Total Depth measured 8678 feet Plugs measured NA feet true vertical 6294 feet Junk measured NA feel Effective Depth measured 8678 feet Packer measured 8064' feet true vertical 6294 feet true vertical 5849' feet Casing Length Size MD TVD Burst Collapse Conductor 74' 16" 105' 105' Surface 4081' 9 5/8" 4112' 3110' Production 8654' 7 8678' 6294' Perforation depth Measured depth 8108'-8208', feet 8319'-8344', 8357'-8397' True Vertical depth 5863'-5939' feet 6023'-6042' 6051'-6082' Tubing (size, grade, measured and true vertical depth) 3 1/2" J-55 8275' 3542' 2 7/8" J-55 8275'-8302' 3542'-6009' Packers and SSSV (type, measured and true vertical depth) Baker FVL SSSV 1863' 1741' Baker FHL Packer 8064' 5829' Baker FB -1 Packer 8283' 5995' 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: NA NA NA NA NA Subsequent to operation: NA NA NA NA NA 14. Attachments (required per 20 AAC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil LJ Gas WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑✓ 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: 318-050 Authorized Name: Sara Carlisle Contact Name: Rachel Kautz/Sara Carlisle Authorized Title: Well Integrity Supervisor Contact Email: n2549(cZconocoohillios.com Authorized Signature: Dale: 2/5/2019 Contact Phone: 659-7126 Form 10-404 Revise 4/2017 Submit Original Only vrc. RBDMS FFR 1 17019 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 5, 2019 Commissioner Hollis S. French Alaska Oil & Gas Commission 333 West 7`" Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well KRU 3A-02 (PTD 185-205). An existing retrievable tubing patch was pulled for diagnostic investigation and then later replaced with a new retrievable tubing patch to cover a confirmed tubing leak. The patch remains set with a passing MIT -IA but the well continues to exhibit IA pressurization. As a result, 3A-02 will remain shut in for further diagnostics. A new 10-403 will be submitted for the next repair attempt. The associated 10-403 Sundry number for this work is 318-050. Please contact Rachel Kautz or myself at 659-7126 if you have any questions. Sincerely, Saza Carlisle Well Integrity Supervisor ConocoPhillips Alaska, Inc. Executive Summary 06/20118 10/05118 10/06/18 10107/18 10108/18 01/08119 01/10/19 01111/19 01128/19 Kuparuk injector 3A-02 was identified again with slow IA pressure increase during water injection. It was suspected that a previously set retrievable patch assembly was no longer sealing a known tubing leak. The stinger patch assembly was pulled and a camera log was ran to confirm the location of the leak. The camera confirmed the location of the tubing leak to be at -7744', near the top of an old permanent patch. A new stinger patch assembly was designed and then set to cover the leak. After the patch was set, a MITIA to 3000 psi was performed and passed. The well was returned to water injection in preparation for a state - witnessed MITIA; However, while on injection the IA pressure increased indicating that the well is still leaking \despite the patch. 3A-02 will remain shut in until further plans for leak detection and remediation are established. BRUSH & FLUSH, GAUGE TBG w/ 2.78" GAUGE RING TO PATCH @ 7726'RKB. PULL P2P PACKER,10' SPACER & STINGER @ SAME. SEND PATCH TO SHOP FOR INSPECTION. JOB COMPLETE. DRIFT W/ 2-1/2" DMY KICK OVER TOOL DRIFT TO CII SVL @ 8271' RKB. PULLED RM-DMY @ 8004' RKB. RAN 1.5" TEST DMY TO TO 8004' RKB TO ENSURE A VALVE COULD BE SET PRIOR TO IA N2 BLOW DOWN. NO ISSUES SETTING TEST DMY. IN PROGRESS. HALLI BURTON N2 PUMPED 300,000 SCF DOWN IA PUSH FLUID OUT EMPTY POCKET TO FIRMATION. DHD SHOT IA FLUID LEVEL @ GLV MANDREL 8003' RKB. SET RM-DMY @ 8004' RKB. LRS BULL HEADED DOWN TBG 290 BBL OF CLEAN 8.9 BRINE FOLLOWED 67 BBL OF METH FREEZE PROTECT. SET. PERFORM BASELINE PASSES W/ CAMERA TO 8250' RKB, DID NOT TAG PLUG. LOGGED UP PASS WITH ACOUSTIC TOOLS TO 2700' RKB, POOH. PROBLEMS WITH DIRTY FLUID TO 600 RKB. CLEAR TO 7400' RKB. CLOUDY FUILD BELOW 7400'. RKB IN PROGRESS RAN EV CAMERA/ ACOUSTIC COMBO. DIRTY FLUID AT 7400'. PUMP 7 BBL OF METH TO MOVE CLEAN FLUID DOWN THRU LEAKING PLUG. INCREASE IA TO 3000 W/ N2. LEAK FOUND AT 7744' RKB W/ CAMERA. PERFORM ACOUSTIC PASS AND STATIONS OVER LEAK. BLED IA DOWN TO 1500 PSI PULLED CIC SLEEVE @ 8271' RKB AND CA -2 PLUG @ 8295' RKB. RESET CIC SLEEVE. IN PROGRESS PULLED DV @ 8004' RKB. DRIFTED DMY PATCH TO OWEN PATCH @ 7742' RKB. BULLHEAD 156 BBLS CISW, 25 BBLS MEOH, 40 BBLS DIESEL DOWN IA TO FORMATION. SET DV @ 8004' RKB. BRUSHED & FLUSHED TBG DOWN THRU PATCH @ 7742' RKB. IN PROGRESS. SET 2.72" P2P (#CPP35203), 4' SPACER PIPE, 2.80" NOGO, 14.99' STINGER WITH 6 AVA SEALS MID-ELEM @ 7737' RKB. MITIA TO 3000 (PASS). IA DDT PASSED. JOB COMPLETE. MIT -IA TO 3000 PSI (PASSED) KUP INJ WELLNAME 3A-02 WELLBORE 3A-02 �' - �--,�10^c^�p�� W WINa.Vf AaskapS KUPARUe Alaska, IflD. KUPARUK max a.11a1p a •m.. ... ell Attributes 50029rc43100 INTJ""smug n6,13 MDmNeI Act elm mKBl RIVER UNIT 500292143100 INJ 6.13 3.100.00 0,690.0 Comment SSSV: Ha H]6(FPm) Date La.IWO'. Em Oem 35.9 M) 918/1985M LOCKED OUT ]Am. rnvmts mne:n Ara m=el:=naman=la=�.ep Last Last Tag An,wmim DelNn atKel End Date Welllwe rBas^Mm By Tag: SLM 8,350.0 D220D 3A-02 Pp Rev Reason Annomi0n I End Data I Lanmre LaatMm ey Last Rev Reaaon'. SET PATCH EXTENSION 111112019 3A-02 Irvrort8l Strings oescrippan OD lintm0n1 Tup(EKB) Bn Delw,(K.) set ..En Rv.,_j 1Le^u... Grme rop rn,em 16 15.06 31.0 1050 105.0 62.50 H-00 WELDED mKB1 sn O735 BiCTn.eaa ACE 10an 9y81 8.92 30 mKB1 4112.1 Description OD (in) ID(In) Tap I.H.) atlD=PIn INNeI--- ..TVD.... Wr,Len 11... Gleae Top Tnmaa ] fi28 23] 8.677.8 6.294.2 26.00 J-55 BTC HnrvcER. xe7 CONOIICTOfl: ]16105.0 Casing C.a.d CONDUCTOR BUR Caaing PRODUCTION Tubing Strings Descnp9on sn lava... mlm1 roptnNel sat oapm m -set Dzpm jND 4. W10em) Graaa ropeonnm4on 31/2 2.99 287 8,301] 6009.6 931] J-55 E BRD s PPErvbiK T.0 Tubing TUBING 3.5"x2 875" @ 82]4' GPILIFT:2.M.e Completion Details N -I. ToplrvOl Top Intl Ca,�, ID In Tw lnxel IRHB) 1'1 Imn Dev 28] 28.] 0.12 HANGER FMC GEN III TUBING HANGER 1500 SAFETYVLV BAKER FVL SAFETV VALVE (L GKED U 11n1 101 2.810 SURFACE: ]P.64.1121 GASUFT;4.9eKa 0,050.1 5,819.0 41.03 PBR BAKER PBR 3.900 &963.8 $629.3 60.92 PACKER BAKER FHL PACK 3.000 8,139.1 5.886.4 40. OIAST RINGS CARBIDE RINGS (4) 2. 7 .UFT ; 99S.+ 8, ]1.1 5,90fi4 407] NIPPLE ADA BPL PORTED NIPPLE 2.296 8,280.6 5.993.6 40.]7 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2438 GASUFT:433?5 0.282.) 5,995.2 40.77 PACKEP BAKER FB -1 PERMANENT PACKER 3.000 GASLIFT: B,]IWx 8.295.6 6,004.9 4 . 8 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,301.0 6009.1 40.78 SOS CAMC. SHEAR OUTSUB 2441 GASUFT.7d563 Other In Hole (Wireline retrievable plugs, valves, pumps, Dan. 0. UFT,],40L1 Toplrvol Topinct Cam Run Date ID(in) TOPInKBI (ft") f)Pes 7,]3].0 5,585.0 42.21 PACKER T7T P2P PACK ER(CPP36203), UAL 26 MAX 002.8' 111112019 1.625 PACKER T737,0 7741.0 5,587.9 42.19 SPACER PIPE 2-1117 PUID SPACER PIPE W/28'NOGO AND 1/1112019 1.499 SEA -STINGER LEAN,J7M0 SPACERPIPB PERM PATCH, ),]424 ],]42.4 5.M9.0 42.18 PER PATCH OV EFERMPAECTIVVE CH ACROSS GTH 21#8 MMANDREL. DAL= 42002 2.375 7,]44.0 5,590.1 42.18 LEAK IDENTIFY LEAK IN PATCH W/EV GAMERAI 101812018 23]5 ACOUSTIC LDL GAe LIFT; ].JA.4 82]1.0 5,906.3 40,11151-11v'-0 225 CIC SLEEVE 1182019 1.8]5 8,2]1.1 5,906.4 4U ]> NIP REDUCER AVA PORT EO NIPPLE REDUCER 311312002 1250 8,295.6 6,0059 40.]8 NIP REDUCER NIPPLE REDUCER 2.25' D%1.81'1 ID 3/132002 1.81 GAS UFi: a.W3.s Perforations &Slots sa Den PER.M91 PACNER e.mxa TeP1TVD1 Btm (ND1 IaM1otsM rop 1108. em20 In. -V Ileal unxmmne Date 1 8,108.0 8.208.0 5.8fi2.8 5, 38.fi Com, G3,G1, tV1311985 11.0 UNIT 0, 3A-02 Cm TyPRE FH WERE 120deg. phi 5'Hyper Jet 11 INJECTIOMe.1014 8.319.0 8,344.0 6, 22.] 6,Od1.fi A-3, 3A-02 11/1311985 4.0 IPERF 90 deg. ph 4"Hyper Jat 11 8,357. $39].0 .051.4 6,081. A-2, 3A-02 1111 1985 4.0 (PERE 90deg.PM1;4'Hyper Jeill Mandrel Inserts St IPERBe100.08dr9.0- stEEYE-O;e H0 NIPPLE: e.nTt MPREdKER BZIt.t aFALAssv:6IDD9 PACKER; a.m2) Top 11YD1 Wlce l]Ln PMShe TRO Pun Us9 Run DM Com N Top IM1KB) InKB) MWe Model OR 9n) Sery TYW TYPe 0=- 2,JW.fi 299.4 CAMC KB 1 GA LIFT DMV BK 0. 0.0 4!251 996 2 6,0647 3,8 3.5 CAMCO KBUG 1 GAS LIFT OMY 8K 0.000 0.0 42511 96 3 5,855.1 d,25 .1 CAMCO KBUG 1 ASLIFT DMY BK 0.000 0.0 42511996 y fi, ].5 4,SSfiJ CAMC KBUG 1 GA LIFT OMY 0K 0. 0.0 412511996 5 6,708. 4, 43.0 GAMDD 0UG 1 GASLIFT DMY BK 0.000 0.0 23/1 96 6 7.056.3 5, 9.8 CAMCO KBUG 1 GASLIFT DMY BK 0.000 00 4/29199 7 ),40,1 5,338 CAM 0 KBUG 1 GASLIFT DMY IK 0 Up 512 201) 8 ],]50.45.594.9 CAMC KBU i GASLIFT --BK 0.000 0.0 412311 96 9 ,003.5 5]83.9 ME U TPD% 112 GASLIFT DMY RM 0000 00 1/1N2019 1 8,1016 5,85]. CAM O IK Ba1 INJ OMY 0K 0.000 00 914/1991 0 Notes: General &Sa NEPtE. S."eE MPFEouCER, e.E,6 End Date Mnamian 412611996 NOT 11.4 PPO Bine In 7" Csg 2120002 NOTE: LEAK FOUND IN BOTTOMORPIN-END; MANDRELPATCHED 4/92002 509: e.301.0 1011 M12 NOTE: RIG RKBS PROD CSGvs TUBING ACCOUNT FOR CSGRBG TOPS 41112017 NOTE: PATCH DEPTH CORRECTED TO TBG TALLY 52' adjustment. 1PE4aF;9.31908,W.0� IPERF; 9.35/.08.38?0� 1RODUGTI0Mx334a Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Thursday, January 24, 2019 12:54 PM To: Wallace, Chris D (DOA) Subject: KRU 3A-02 (PTD 185-205): DNE Exceeded on IA Hi Chris, Water Injector KRU 3A-02 (PTD 185-205) has been ongoing diagnostics and patch repair for known TxIA communication under 10-403 Sundry #318-050. After installing the patch, the well achieved a passing MIT -IA to 3000 psi while shut in 1/11/19. The well returned to injection 1/16/19 and achieved a passing MIT -IA to 3000 psi on 1/22/19 while online. While on injection, the IA pressurized above DNE to 2025 psi on 1/23/19. This email serves to inform that the IA exceeded DNE and was subsequently bled down below DNE within two hours. The well is being shut in and CPAI will continue diagnostics and repair. A 10-404 will be submitted when the repairs are complete. Please let me know if you have any questions or concerns. Sincerely, Well Integrity Supervisor, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549Culcop.com Cell: 907-331-7514 1 sara.e.carlislePcop.com tioF 7,4 yw\�\ Ii/j ,sv THE STATE Alaska Oil and Gas f Conservation Commission tit Of € tx _ � 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 104F\--777 of Main: 907.279.1433 ALAS'" Fax: 907.276.7542 www.aogcc.alaska.gov Travis Smith Well Integrity Supervisor swim i E I ' 0 0 RECEIVED STATE OF ALASKA FEB 0 7 ALASKA OIL AND GAS CONSERVATION COMMISSION ��� 20 APPLICATION FOR SUNDRY APPROVALS 24656 46 lg 20 AAC 25.280 AOG 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well [ roll--- Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill [11 Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ii] " Other: Tubing patch ❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development ❑ ` 185-205 3.Address: 6.API Number: Stratigraphic ❑ Service E P.O.Box 100630 Anchorage,Alaska 99510 50-029214310000 7.If perforating: N/A 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? elf 11- KR U. 3A-02 Will planned perforations require a spacing exception? Yes ❑ No ❑., ✓ °ice 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025632' 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): 8678 ` 6294 • 8678 6294 3000 NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 16" 105' 105' Surface 4081' 9-5/8" 4112' 3110' 3520 2020 Intermediate Production 8654' 7" 8678' 6294' 4980 4320 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8108'-8208',8319'-8344', 5863'-5939',6023'-6042', 3-1/2" J-55 8275' 8357'-8397' i 6051'-6082' 2-7/8" J-55 8275'-8302' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker FVL safety valve,Baker FHL packer,Baker FB-1 packer 1863'MD/1741'TVD,8064'MD/5829'TVD,8283'MD/5995'TVD 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: 2/15/2018 El WINJ ❑� • WDSPL ❑ Suspended ❑ Commencing Operations: OIL 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 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: Travis Smith Contact Name: Travis Smith/Rachel Kautz Authorized Title: Well Inte.rity Supe .:L•tiggill Contact Email: n2549Aconocophillips.com Contact Phone: 659-7126 Authorized Signature: ff /� Date: �/ �� li COMMmSIO USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 - 050 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ®`. Location Clearance ❑ Other: p R E3 i)f'.)i. L_ r._. �No ❑ FLS , °� ��18 Post Initial Injection MIT Req'd? Yes Spacing Exception Required? Yes ❑ No V Subsequent Form Required: /0_ .4 a V APPROVED BY Approved by" P J grp-r COMMISSIONER THE COMMISSION Date: Z --f Cl.-/8 1l 47h1 ,2(7„O Y i�� LJ I41f A Submit Form and Form 10-403 Revised 4/2017 Approved applications i f e date of approval. Attachments in Duplicate • S ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 February 4, 2018 Commissioner Hollis S. French Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 3A-02 (PTD 185-205)to pull and replace a retrievable tubing patch with a new retrievable tubing patch. Please contact Rachel Kautz or myself at 659-7126 if you have any questions. Sincerely, /7,4 40'4110 Travis Smith Well Integrity Supervisor ConocoPhillips Alaska,Inc. • KRU 3A-02 DESCRIPTION SUMMARY OF PROPOSAL Tubing Patch for KRU 3A-02 KRU 3A-02 (PTD 185-205) is an injector that was reported to the AOGCC on March 6, 2017 for a failed diagnostic MITIA and suspect IA pressurization. A subsequent LDL identified a tubing leak near the existing permanent tubing patch set at —7743' RKB. A retrievable tubing patch was set across the leak in August 2017, however, the injector was again reported for showing signs of IA pressurization. It is suspected that the retrievable tubing patch is not holding anymore and needs replaced. CPAI proposes the following repair plan: 1. Pull the existing retrievable tubing patch set at —7730' RKB. 2. Set a new, longer retrievable tubing patch across the leak interval. 3. MITIA to AOGCC requirements. 4. Return the well to injection. 5. AOGCC witnessed MITIA once thermally stabilized. 6. Submit 10-404 post-repair. NSK Well Integrity Supervisor CPF3 &WNS KUP INJ 4110 ConocoPhillips0 well Attributes Max Angle&MD TD Alaska.Inc. Wellbore APIIUWI Field Name Wellbore Status lIncl(°) MD(ftKB) 3A-02 KB) Act Btrn(ftKB) - e1,'I 500292143100 KUPARUK RIVER UNIT INJ 56.13 3,100.00 8,690.0 --. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3A-02,8/29/2017 3.51:33 PM SSSV:LOCKED OUT Last WO: 35.19 9/8/1985 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,360.0 2/2/2017 Rev Reason:SET PATCH ppmven 8/29/2017 1-t>: Casing Strings '�ir Casing Description OD(In) ID(in) Tap(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(L..Grade Top Thread HANGER;28.7 I 'I'1� I CONDUCTOR 16 15.062 31.0 105.0 105.0 62.50 H-40 WELDED j � � Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) "Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 30.6 4,112.1 3,110.1 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread Uam PRODUCTION 7 6.276 23.7 8,677.8 6,294.2 26.00 J-55 BTC Tubing Strings `7` SetTubing Description String Ma...ID(in) Top(ftKB) Depth(ft..f Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection CONDUCTOR;31.0-105.0 • '� TUBING 31/2 2.992 287 8.301.7 6,009.6 9.30 J-55 EUE 8RD 3.5"x2.875"@ 8274' Completion Details SAFETY VLV;1,863,0a AlNominal ID Top(ftKB) Top(TVD)(ftKB) Tap Incl(°) Item Des Corn (in) 28.7 28.7 0.12 HANGER FMC GEN III TUBING HANGER 3.500 GAS LIFT;2,707.6 1,863.0 1,740,7 40.50 SAFETY VLV BAKER FVL SAFETY VALVE(LOCKED OUT 2.810 11/11/2010) 8,050.1 5,819.0 41.03 PBR BAKER PBR 3.000 8,063.8 5,829.3 40.92 PACKER BAKER FHL PACKER 3.000 8,139.1 5,886.4 40.67 BLAST RINGS CARBIDE RINGS(4) 2.867 SURFACE;30.6.4,112.1- 8,2 5,986,4 40.77 NIPPLE AVA BPL PORTED NIPPLE 2.296 GAS LIFT;4,884.6 6,280.671.1 5,993.6- 40.77 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.438 8,282.7 5,995.2 40.77 PACKER BAKER FB-1 PERMANENT PACKER 3.000' GAS LIFT;5,855.1 8,295.6 6,004.9 40.78 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,301.0 6,009.1 40.78 SOS CAMCO SHEAR OUT SUB 2.441 GAS LIFT;6,297.5 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) GAS LIFT;8,708.2 7,726.0 5,576.8 42.26 PATCH 2.72"PIIP PACKER(CPP35099)W/10.62'SPACER t3/16/2017 2.375 8 2.375"STINGER(OAL 19'6") 8,271.0 5,986.3 40.77 SLEEVE-O 2.25 CII SLEEVE 7,743,0 5,589.4 42,18 PATCH SET PATCH ACROSS#8 MANDREL w/10'SPACER 4/20/2002 2,375 GAS LIFT;7,058.3 PIPE 8/16/2017 1.875 GAS LIFT;7,401,1 8,271.1 5,986.4 40.77 NIP AVA PORTED NIPPLE REDUCER 3/13/2002 2.250 REDUCER 8,295.6 6,005.0 40.78 NIP NIPPLE REDUCER 2.25"OD X 1.81"I ID 3(13/2002 1.810 PATCH;7,726.0 REDUCER Perforations&Slots Shot GAS LIFT;7,750.4, Dens PATCH;7,743.0 i Top(TVD) Btm(TVD) (shotslf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,108.0- 8,208.0 5,862.8 5,938.6 C-4,C-3,C-1, '11/13/1985 12.0 IPERF 120 deg.ph;5"Hyper UNIT B,3A- Jet II 02 GAS LIFT;6,003.5 F 8,319.0 8,344.0 6,022.7 6,041.6 A-3,3A-02 11/13/1985 4.0 (PERF '90 deg.ph;4"Hyper Jet II 8,357.0 8,397.0 6,051.4 6,081.6 A-2,3A-02 11/13/1985 4.0 IPERF 90 deg.ph;4"Hyper Jet II FOR;8,050.1 L i Mandrel Inserts PACKER;8,063.8 .I t aln Top(TVD) Valve Latch Port Size TRO Run INJECTION;6,101.4 1 R Top(66KB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Corn Ilir1 2,707.6 2,290.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/25/1996 (PERF;6,108.0-8,208.0- I 2 4,884.7 3,603.5 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0,0 4/25/1996 3 5,855.1 4,252.1 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/25/1996 4 6,297.5 4,556.7 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/25/1996 SLEEVE-0;6,271.01111 5 6,708.2 4,843.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/23/1996 NIPPLE;8,271.1. 6 7,056.3 5,089.8 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/23/1996 NIP REDUCER;6,271.1 7' 7,401.1 5,338.3 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/2017 '11 r 8 7,750.4 5,594.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/23/1996 ll9 8,003.5 5,783.9 MERLA TPDX 1 1/2 GAS LIFT DMY RM 0.000 0.0 5/26/1995 SEALA ASSY;0,260.6 = 1 8,101.4 5,857.8 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 9/4/1991 0 INotes:General&Safety PACKER;8,282.7 " End Date Annotation 4/26/1996 NOTE:11.4 ppg Brine in 7"Csg 2/20/2002 NOTE:LEAK FOUND IN BOTTOM OR PIN-END;MANDREL PATCHED 4/20/2002 NIPPLE;8,295.5, 1/10/2011 NOTE:View Schematic w/Alaska Schematic9.0 NIP REDUCER;6,295.6 ' 10/12/2012 NOTE:RIG RKBs PROD CSG vs TUBING ACCOUNTS FOR CSG/TBG TOPS 1 4/11/2017 NOTE:WSR from 4/22/2002 states top of patch set at 7691'RKB when correlated using 199410g. SOS;e,361.e 1 4/11/2017 NOTE:Patch depth aligned to tubing tally with 52'adjustment. IPERF;8,319.0-8,344.0--1-• IPERF;6,357D-8,397.0 PRODUCTION;23.7-8,677.8 s • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Monday,January 1, 2018 6:38 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: KRU 3A-02 (PTD 185-205) Report of IA re-pressurization Chris, Kuparuk injector 3A-02 (PTD 185-205) has again shown signs of IA pressurization on while on water injection. The well has been shut-in. The well was on a 30-day monitoring period of water injection, which will not be completed because of this increasing IA pressure. Our intent is to continue with further diagnostics. Once a plan forward has been developed,the proper notifications and/or necessary paperwork will be submitted. Please let us know if you have any questions or disagree with this plan. Thanks, Travis SCANEVI From: NSK Well Integrity Supv CPF3 and WNS Sent:Sunday, December 10, 2017 10:21 AM To:Wallace, Chris D(DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: RE: KRU 3A-02 (PTD 185-205) Report of IA re-pressurization Chris, Di.:nostics have been completed on Kuparuk injector 3A-02 (PTD 185-205). The well passed packoff testing,a diagn• is MITIA, and an IA draw-down test. At this point, = believe the IA anomalies shown earlier while on water injection were thermally induced. CPAI intends to bring the well on ater injection for a 30-day monitoring period to ensure that it continues to behave normally. If no problems are seen durin: is monitoring period,we will treat it as a normal well. If a problem is observed,we will shut- in the well and notify the AO Please let us know if you have any quest• ' or disagree with this plan. Travis From: NSK Well Integrity Supv CPF3 and WNS Sent:Thursday, November 23, 2017 12:02 PM To:Wallace, Chris D(DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: KRU 3A-02 (PTD 185=205) Report of IA re-pressurization Chris, f�i 0 /85-_ 2_05- Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Sunday, December 10, 2017 10:21 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: KRU 3A-02 (PTD 185-205) Report of IA re-pressurization Chris, Diagnostics have been completed on Kuparuk injector 3A-02 (PTD 185-205). The well passed packoff testing, a diagnostic MITIA,and an IA draw-down test. At this point, we believe the IA anomalies shown earlier while on water injection were thermally induced. CPAI intends to bring the well on water injection for a 30-day monitoring period to ensure that it continues to behave normally. If no problems are seen during this monitoring period,we will treat it as a normal well. If a problem is observed,we will shut- in the well and notify the AOGCC. Please let us know if you have any questions or disagree with this plan. Travis From: NSK Well Integrity Supv CPF3 and WNS Sent:Thursday, November 23, 2017 12:02 PM To:Wallace,Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: KRU 3A-02 (PTD 185-205) Report of IA SCANNED Chris, Kuparuk injector 3A-02 (PTD 185-205) has shown signs of IA re-pressurization during water injection. The IA was bled yesterday from 1600 psi and appears to be re-pressuring rather quickly. The tubing has been patched for TxIA communication in the recent past. CPAI intends to shut-in and freeze protect the well as soon as possible. We then plan to investigate the re-pressurization with diagnostics. Once a plan forward has been developed,the proper notifications and/or necessary paperwork will be submitted. Please let us know if you have any questions or disagree with this plan. Attached is a schematic and a 90-day TIO plot. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Thursday, November 23, 2017 12:02 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 3A-02 (PTD 185-205) Report of IA re-pressurization Attachments: 3A-02 schematic.pdf; KRU 3A-02 TIO Plot 90-day 11-23-17.docx Chris, Kuparuk injector 3A-02 (PTD 185-205) has shown signs of IA re-pressurization during water injection. The IA was bled yesterday from 1600 psi and appears to be re-pressuring rather quickly. The tubing has been patched for TxIA communication in the recent past. CPAI intends to shut-in and freeze protect the well as soon as possible. We then plan to investigate the re-pressurization with diagnostics. Once a plan forward has been developed,the proper notifications and/or necessary paperwork will be submitted. Please let us know if you have any questions or disagree with this plan. Attached is a schematic and a 90-day TIO plot. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 Eij 1 STATE OF ALASKA A OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations H Fracture Stimulate H Pull TubingLJ H Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing 111 Change Approved Program III Plug for Redrill El Perforate New Pool El Repair Well L Re-enter Susp Well ❑ Other: Tubing Patch Q 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 185-205 3.Address: Stratigraphic ❑ Service 0 6.API Number: P.O.Box 100630 Anchorage,Alaska 99510 50-029214310000 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025632 KRU 3A-02 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 8690 feet Plugs measured RECEIVED true vertical 6302 feet Junk measured feet SEP 0 6 2017 Effective Depth measured 8678 feet Packer measured 8064 feet true vertical 6294 feet true vertical 5829 feet C Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 16" 105' 105' Surface 4081' 9-5/8" 4112' 3110' 3520 2020 Intermediate Production 8654' 7" 8678' 6294' 4980 4320 Liner Perforation depth Measured depth 8108'-8208', 8319'-8344', 8357'-8397' feet 1 � aEo DEC 0 5 L True Vertical depth 5863'-5939', 6023'-6042', 6051'-6082' feet Tubing(size,grade,measured and true vertical depth) 3-1/2" J-55 8275' 5989' 2-7/8" J-55 8275'-8302' 5989'-6010' Packers and SSSV(type,measured and true vertical depth) Baker FHL packer 8064'MD 5829'TVD Baker FB-1 packer 8283'MD 5995'TVD Baker FVL safety valve 1863'MD 1741'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: NA NA NA NA NA Subsequent to operation: NA NA NA NA NA 14.Attachments(required per 20 PAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development❑ Service ❑✓ Stratigraphic H Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas H WDSPL H Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP❑ SPLUG H 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: 317-324 Authorized Name: Rachel Kautz Contact Name: Rachel Kautz/Travis Smith Authorized Title: Well Integrity Supervisor Contact Email: n2549Aconocophillips.com Authorized Signature: / Date: f//7/ 1- Contact Phone: 907-659-7126 Form 10-404 Revised 4/2017 �/ v.-a, t 0 Ii 1 1 I Submit Original Only 4 f7/7 P'RDMS WEA - 62017 • • ConocoPhilhps RECEIVED Alaska SEP 0 6 2017 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC September 1, 2017 Commissioner Hollis S. French Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French, Enclosed please find the 10-404 Report of Sundry Operations for injector KRU 3A-02 (PTD 185-205) for a retrievable patch set in the tubing above the packer. The integrity of the patch was confirmed with mechanical integrity tests. Please call Travis Smith or myself at 659-7126 if you have any questions. Sincerely, Rachel Kautz Well Integrity Supervisor ConocoPhillips Alaska,Inc. • DATE OPERATION DETAILS KRU 3A-02 was reported for suspect IA pressure increase and a failed diagnostic MIT. Executive Subsequent diagnostics suggested a tubing leak, and an acoustic leak detect log confirmed a Summary tubing leak at 7743'. The leak was subsequently patched and passed the required post initial injection MITIA. 3/5/2017 (AC EVAL)T POT PASS.T PPPOT PASS. IC POT PASS. IC PPPOT PASS. MITIA FAILED TO 3000 PSI. ESTABLISH LLR OF 0.16 GPM @ 3000 PSI.MITOA PASSED TO 1800 PSI. 6/26/2017 LOGGED ARCHER LEAK DETECTION TOOL FROM PLUG AT 8296'TO SURFACE. DETECTED LEAK AT TOP OF PATCH 7743' PULLED 2.25 CII SLEEVE @ 8271' RKB. BAILED SMALL AMOUNT OF INJ DEBRIS FROM 1.81 CA- 2 @ 8295' RKB. BRUSH n' FLUSH PATCH @ 7743' RKB. RAN MODIFIED 2.75 STANDING VLV W/2.375" STINGER IN PATCH @ 7743' RKB. CMITTxIATO 2500 PSI PASSED. PULLED 1.81 CA- 2 PLUG @ 8295' RKB. IN PROGRESS. 8/15/2017 LRS CMITTxIA, WITH DIESEL, PASS: PRE-MIT T/1/O: 1350/1339/0 INITIAL T/I/0: 2500/2535/0 15-MIN T/I/O: 2500/2500/0 30-MIN T/I/0: 2500/2490/0 SET 2.25 CIC SLEEVE @ 8271' RKB. BRUSH n' FLUSH TBG TO TOP OF PATCH @ 7743' RKB. BRUSH THROUGH PATCH @ SAME FLUSH TBG WI 70 BBLS DIESEL.SET 2.72" PIIP PACKER (CPP35099) W/ 10.62' SPACER & 2.375" STINGER (OAL 19' 6") @ 7730' RKB W/STINGER STUNG INTO PERM PATCH TOP @ 7743' RKB. MITIA TO 3000 PSI, PASS. COMPLETE. 8/16/2017 LRS MITIA, PRESSURE UP WITH DIESEL (PASS) PRE-MITT/I/O: 1250/980/10 INITIAL T/I/O: 1275/3050/15 15-MIN T/1/0: 1250/3000/15 30-MIN T/I/O: 1260/2980/20 (SW) STATE WITNESSED (CHUCK SCHEVE) MIT-IA PASS TO 2500 PSI. Initial T/I/0 = 1820/870/220. IA FL @ SF. Pressured IA to 2500 psi w/ 1.5 bbls diesel. 8/26/2017 Initial T/I/O= 1820/2500/400 15 min T/I/O= 1820/2450/400. (-50 psi) 30 min T/I/O = 1820/2450/400. (+/-0 psi) Bled IA to 600 psi. (1.4 BBLS back) Final T/I/O= 1820/600/200. s KUP INJ • 3A-02 a ConocoPhillips ° Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Ccract;Philtve 500292143100 KUPARUK RIVER UNIT INJ 56.13 3,100.00 8,690.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 3A-02,8/29/20173:51:33 PM SSSV:LOCKED OUT Last WO: 35.19 9/8/1985 Vertical schematc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .................... Last Tag:SLM 8,360.0 2/2/2017 Rev Reason:SET PATCH pproven 8/29/2017 Casing Strings tinDescription CONDUCTOR OD(in) ID(in) Top(ftKB) Set Depth(ft(B) Set Depth(TVD)... Wt/Len(I...Grade Top Thread HANGER;28.7 ,. ,Q 16 15.062 31.0 105.0 105.0 62.50 H-40 WELDED 1 I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread rllIJJJI 1 SURFACE 95/8 8.921 30.6 4,112.1 3,110.1 36.00 J-55 BTC mCasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD(...Wt/Len(I...Grade Tap Thread lllaL • PRODUCTION 7 6.276 23.7 8,677.8 6,294.2 26.00 J-55 BTC Tubing Strings -.Tubing Description String Ma...I ID(in) Top(ftKB) Set Depth(ft..f Set Depth(TVD)(...Wt(Ib/ft) (Grade Top Connection CONDUCTOR;31.0-105.0 TUBING 31/2 2.992 28.7 8,301.71 6,009.6 9.30 J-55 EUE 8RD 3.5"x2.875"@ 8274' Completion Details SAFETY VLV;1,863.0 IrtJ Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) II 28.7 28.7 0.12 HANGER FMC GEN III TUBING HANGER 3.500 GAS LIFT;2,707.6III 1,863.0 1,740.7 40.50 SAFETY VLV BAKER FVL SAFETY VALVE(LOCKED OUT 2.810 11/11/2010) 8,050.1 5,819.0 41.03 PBR BAKER PBR 3.000 8,063.8 5,829.3 40.92 PACKER BAKER FHL PACKER 3.000 8,139.1 5,886.4 40.67 BLAST RINGS CARBIDE RINGS(4) 2.867 SURFACE;30.6-4,112.1-- e- 8,271.1 5,986.4 40.77 NIPPLE AVA BPL PORTED NIPPLE 2.296 GAS LIFT;4,884.68,280.6 5,993.6 40.77 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.438 8,282.7 5,995.2 40.77 PACKER BAKER FB-1 PERMANENT PACKER 3.000 GAS LIFT;5,855.1 r`. 8,295.6 6,004.9 40.78 NIPPLE CAMCO D NIPPLE NO GO 2.250 ® 8,301.0 6,009.1 40.78 SOS CAMCO SHEAR OUT SUB 2.441 GAS LIFT;8,297.5 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) 7) Des Com Run Date ID(in) GAS LIFT;8,708.2 • 7,726.0 5,576.8 42.26 PATCH 2.72"PIIP PACKER(CPP35099)W/10.62'SPACER •8/16/2017 2.375 &2.375"STINGER(OAL 19'6") ■ 7,743.0 5,589.4 42.18 PATCH SET PATCH ACROSS#8 MANDREL w/10'SPACER 4/20/2002 2.375 GAS LIFT;7,056.3 PIPE 8,271.0 5,986.3 40.77 SLEEVE-O 2.25 CII SLEEVE 8/16/2017 1.875 GAS LIFT;7,401.1 8,271.1 5,986.4 40.77 NIP AVA PORTED NIPPLE REDUCER 3/13/2002 2.250 REDUCER 8,295.6 6,005.0 40.78 NIP NIPPLE REDUCER 2.25"OD X 1.81"1 ID 3/13/2002 1.810 PATCH;7,726.0 �. REDUCER Perforations&Slots Shot GAS LIFT;7,750.4, Dens PATCH;7,743.0 II Top(TVD) Btm(TVD) (shats/f Top(ftKB) Ben(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,108.0 8,208.0 5,862.8 5,938.6 C-4,C-3,C-1, 11/13/1985 12.0 IPERF 120 deg.ph;5"Hyper UNIT B,3A- Jet II 02 GAS LIFT;6,003.5 8,319.0 8,344.0 6,022.7 6,041.6 A-3,3A-02 11/13/1985 4.0 IPERF 90 deg.ph;4"Hyper Jet II 8,357.0 8,397.0 6,051.4 6,081.6 A-2,3A-02 11/13/1985 4.0 IPERF 90 deg.ph;4"Hyper Jet II FOR;8,050.1 1 PACKER;8,083.8 Mandrel Inserts Sl II ati on Top(TVD) Valve Latch Port Size TRO Run INJECTION;6,101.4 , - N• Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn i _ 1 2,707.6 2,290.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/25/1996 (PERF;8,108.0-8,208.0- 2 4,884.7 3,603.5 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/25/1996 a 3 5,855.1 4,252.1 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/25/1996 4 6,297.5 4,556.7 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/25/1996 mi SLEEVE-0;8,271.0 5 6,708.2 4,843.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/23/1996 NIPPLE;8,271.1 _III 6 7,056.3 5,089.8 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/23/1996 NIP REDUCER;E,271.1 7 7,401.1 5,338.3 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/2017 Ai.I;�i t 8 7,750.4 5,594.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/23/1996 ll9 8,003.5 5,783.9 MERLA TPDX 1 1/2 GAS LIFT DMY RM 0.000 0.0 5/26/1995 SEAL ASSY;8,280.6 = 1 8,101.4 5,857.8 CAMCO KBUG 0 1 INJ DMY BK 0.000 0.0 9)4/1991 • Notes:General&Safety PACKER;8,282.7 End Date Annotation 4/26/1996 NOTE:11.4 ppg Brine in 7"Csg 2/20/2002 NOTE:LEAK FOUND IN BOTTOM OR PIN-END;MANDREL PATCHED 4/20/2002 NIPPLE;8,295.5 1/10/2011 NOTE:View Schematic w/Alaska Schematic9.0 NIP REDUCER;8,295.61 10/12/2012 NOTE:RIG RKBs PROD CSG vs TUBING ACCOUNTS FOR CSG/TBG TOPS I 4/11/2017 NOTE:WSR from 4/22/2002 states top of patch set at 7691'RKB when correlated using 1994 log. SOS;8,301.0 4/11/2017 'NOTE:Patch depth aligned to tubing tally with 52'adjustment. IPERF;8,319.0-8,344.0 IPERF;8,357.0-8,397.0- PRODUCTION;23.7-8,877.8 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Wednesday,August 30,2017 P.I.Supervisor 1 6(3°117 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 3A-02 FROM: Chuck Scheve KUPARUK RIV UNIT 3A-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprvd00-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3A-02 API Well Number 50-029-21431-00-00 Inspector Name: Chuck Scheve Permit Number: 185-205-0 Inspection Date: 8/26/2017 ." Insp Num: mitCS170827081707 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3A-02 Type Inj W TVD 5829 ' Tubing 1820 • 1820 - 1820 - 1820 PTD 1852050 Type Test SPT Test psi 1500 - IA 870 2500 2450 - 2450 BBL Pumped: 1.5 " BBL Returned: 1.4 OA 220 400 400 400 Interval 4YRTST P/F P ✓ Notes: -1�t Ir SCANNED r LB 2 t r�,5 Wednesday,August 30,2017 Page 1 of 1 LAS-?..$)5 2W o WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. July 11, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED DA1/2P/2017 TA LOGGED M K.BENDER JUL 192017 RE: Leak Detect Log with ACX: 3A-02 AO G C C Run Date: 5/29/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3A-02 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-21431-00 Leak Detect Log with ACX (Processed Log) 1 Color Log 50-029-21431-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 AUS 2.017, Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:st47✓a v I3.4U1Cté • S ti OF Tye g \����y/��� THE STATE Alaska Oil and Gas - esKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAl‘l.' Fax: 907.276.7542 www.aogcc.alaska.gov Rachel Kautz Well Integrity SupervisorM145 J U L 3 12.°17' ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3A-02 Permit to Drill Number: 185-205 Sundry Number: 317-324 Dear Ms. Kautz: 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, Hollis S. French Chair 4 i DATED this (e) day of July, 2017. RBDMS L L .SUE. L 7 2017 • • RECEIVED STATE OF ALASKA JUL 1 2 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 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: _Tubing patch 2. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 185-205 • 3.Address: ❑ Service E. 6.API Number: Stratigraphic P.O.Box 100630 Anchorage,Alaska 99510 50-029214310000 . 7.If perforating: N/A 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? V-.. -k-) 3A-02 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025632 • 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): g 0 c 6294 8678 6294 3000 Casing 41.5.f7 Length Size MD TVD Burst Collapse Structural Conductor 74' 16" 105' 105' Surface 4081' 9-5/8" 4112' 3110' 3520 2020 Intermediate Production 8654' 7" 8678' 6294' 4980 4320 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8108'-8208',8319'-8344', 5863'-5939',6023'-6042', 3-1/2" J-55 8275' 8357'-8397' 6051'-6082' 2-7/8" J-55 8275'-8302' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker FHL packer,Baker FB-1 packer,Baker FVL safety valve 8064'MD/5829'TVD,8283'MD/5995'TVD, 1863'MD/1741'TVD 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 2. 14.Estimated Date for 15.Well Status after proposed work: 7/14/2017 Commencing Operations: OIL ❑ WINJ ❑✓ - WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 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: Rachel Kautz Contact Name: Rachel Kautz/Travis Smith Authorized Title: Well Integrity Supervisor Contact Email: n2549conocoohillips.com Contact Phone: 659-7126 Authorized Signature: _,-.2 _ Date: 4/////1"II COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 t-7— 3 22{ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes No ❑ RBDMS ‘ —JUL z 7 2017 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /o --40 4) APPROVED BY , Ito{t Approved by: p// COMMISSIONER THE COMMISSION Date: ` (� �,�� ��//v" /� R4cE nnForm 10-403 Revised 4/2017 0 f P valid for 12 months from the date of approval.7/Pr/ Attachments in • • N.- ConocoPhillips ConocoPhillips Alaska P.O. BOX 100360 RECEIVED ANCHORAGE,ALASKA 99510-0360 JUL 12 2017 AOGCC July 11, 2017 Commissioner Hollis S. French Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 3A-02 (PTD 185-205) for a proposed retrievable tubing patch. . Please contact Travis Smith or myself at 659-7126 if you have any questions. Sincerely, Rachel Kautz Well Integrity Supervisor ConocoPhillips Alaska,Inc. • KRU 3A-02 DESCRIPTION SUMMARY OF PROPOSAL Tubing Patch for KRU 3A-02 KRU 3A-02 (PTD 185-205) is an injector that was reported to the AOGCC on March 6, 2017 for a failed diagnostic MITIA and suspect IA pressurization. A subsequent LDL identified a tubing leak near the existing permanent tubing patch set at —7743' RKB. CPAI proposes the following repair plan: 1. Set retrievable tubing patch across the leak. 2. MITIA to AOGCC requirements. 3. Return the well to injection. 4. AOGCC witnessed MITIA once thermally stabilized. 5. Submit 10-404 post-repair. NSK Well Integrity Supervisor CPF3 &WNS KUP INJ 3A-02 ConocoPhillips ° Well Attributes Max Angle&MD TD Al:lah.1111 , + Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Film(ftKB) coriocow+npc 500292143100 KUPARUK RIVER UNIT INJ 56.13 3,100.00 8,690.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 3A-02,5123/20174:33'.20 PM SSSV:LOCKED OUT Last WO: 35.19 9/8/1985 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .......................... Last Tag:SLM 8,360.0 2/2/2017 Rev Reason:PULL CIC SLEEVE,SET 01 pproven 5/23/2017 SLEEVE,GLV C/O Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WVLen(I...Grade Top Thread HANGER;28.7 Ii ,= CONDUCTOR 16 15.062 31.0 105.0 105.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 30.6 4,112.1 3,110.1 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread 111111111111111111911111111111111110911111111111•91011laotK nu,PRODUCTION 7 6.276 23.7 8,677.8 6,294.2 26.00 J-55 BTC Tubing Strings .N Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection CONDUCTOR;31.0-105.0-4 TUBING 3 1/2 2.992 28.7 8,301 76,009.6 9.30 J-55 EUE BRD 3.5"x2.875"@ 8274' Completion Details Nominal ID SAFETY VLV;1,863.0 i.., ' Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) 28.7 28.7 0.12 HANGER FMC GEN III TUBING HANGER 3.500 1,863.0 1,740.7 40.50 SAFETY VLV BAKER FVL SAFETY VALVE(LOCKED OUT 2.810 GAS LIFT;2,707.6 I f 11/11/2010) ■■■ 8,050.1 5,819.0 41.03 PBR BAKER PBR 3.000 8,063.8 5,829.3 40.92 PACKER BAKER FHL PACKER 3.000 8,139.1 5,886.4 40.67 BLAST RINGS CARBIDE RINGS(4) 2.867 SURFACE;Sas-a,1I2.1-.7 8,271.1 5,986.4 40.77 NIPPLE AVA BPL PORTED NIPPLE 2.296 8,280.6 5,993.6 40.77 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.438 GAS LIFT;4,864.6P 8,282.7 5,995.2 40.77 PACKER -BAKERFB-1 PERMANENT PACKER 3.000 8,295.6 6,004.9 40.78 NIPPLE CAMCO D NIPPLE NO GO 2.250 GAS LIFT;5,855.1 8,301.0 6,009.1 40.78 SOS CAMCO SHEAR OUT SUB 2.441 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top mel GAS LIFT;6,297.5 Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 7,743.0 5,589.4 42.18 PATCH SET PATCH ACROSS#8 MANDREL w/10'SPACER 4/20/2002 2.375 1.875 PIPE GAS LIFT;8,708.2 8,271.1 5,986.4 40.77 NIP AVA PORTED NIPPLE REDUCER 3/13/2002 2.250 REDUCER 8,271.1 5,986.4 40.77 SLEEVE-0 2.25 CII SLEEVE 5/19/2017 GAS LIFT;7,056.3 8,295.6 6,005.0 40.78 NIP NIPPLE REDUCER 2.25"OD X 1.81"I ID 3/13/2002 1.810 REDUCER GAS LIFT;7,401.1 • Perforations&Slots Shot I Dens Top(TVD) Bim(TVD) (shots/f GAS LIFT;7,750.4, Top(ftKB) Btm(ftKB) (ftKB) (MB) Zone Date t) Type Com PATCH;7,743.0 II8,108.0 8,208.0 5,862.8 5,938.6 C-4,C-3,C-1, 11/13/1985 12.0 IPERF 120 deg.ph;5"Hyper UNIT B,3A- Jet II 02 8,319.0 8,344.0 6,022.7 6,041.6 A-3,3A-02 11/13/1985 -4.0 (PERF 90 deg.ph;4"Hyper Jet GAS LIFT;8,003.5 II 8,357.0 8,397.0 6,051.4 6,081.6 A-2,3A-02 11/13/1985 4.0 IPERF 90 deg.ph;4"Hyper Jet II Mandrel Inserts PBR;8,050.1 Sl ati PACKER;8,083.5 on Top(TVD) Valve Latch Port Size TRO Run 'I Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type ((n) (psi) Run Date Com 1 2,707.6 2,290.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/25/1996 INJECTION;8,101.42 4,884.7 3,603.5 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/25/1996 I3 5,855.1 4,252.1 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/25/1996 (PERF;8,106.0-8,208.0 4 6,297.5 4,556.7 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/25/1996 5 6,708.2 4,843.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/23/1996 6' 7,056.3 5,089.8 CAMCO KBUG 1 GAS LIFT DMY BK 0.000' 0.0 4/23/1996 NIPPLE;8,271.1 7 7,401.1 5,338.3 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/2017 SLEEVE-0;8,271.1 I_ 8 7,750.4 5,594.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/23/1996 NIP REDUCER;8,271.1 1.I I�' 9 8,003.5 5,783.9 MERLA TPDX 11/2 GAS LIFT DMY RM 0.000 0.0 5/26/1995 1 8,101.4 5,857.8 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 9/4/1991 0 SEAL ASSY;8,260.6 F. NB Notes:General&Safety End Date Annotation " PACKER;8,282.7 4/26/1996 NOTE:11.4 ppg Brine in 7"Cog - 2/20/2002 NOTE:LEAK FOUND IN BOTTOM OR PIN-END;MANDREL PATCHED 4/20/2002 1/10/2011 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE;8,295.5, ,r p, 10/12/2012 NOTE:RIG RKBs PROD CSG vs TUBING ACCOUNTS FOR CSG/TBG TOPS NIP REDUCER;8,295.8 ,' '` 4/11/2017 -NOTE:WSR from 4/22/2002 states top of patch set at 7691'RKB when correlated using 1994 log. '!!i 4/11/2017 NOTE:Patch depth aligned to tubing tally with 52'adjustment. SOS;8,301.0 (PERF;8,319.0-8,344.0 IPERF;8,357.0-8,397.0 I I PRODUCTION;23.7-8,877.8 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Monday, March 06, 2017 3:53 PM To: Wallace, Chris D (DOA) Subject: KRU 3A-02 (PTD# 185-205) Attachments: 3A-02 90-day TIO.jpg Hello Chris— KRU injection well 3A-02 (PTD# 185-205)was observed with indications of rising IA pressure. Yesterday, diagnostics were performed and the well failed an MITIA. The well was shut-in and we will begin to perform diagnostics to determine the source of the communication. We will notify you if a fix is found, or if a plan of action is planned that requires 10-403 approval. Attached is a 90-day TIO plot. Please let me know if you have any questions or disagree with the plan. Thank you, Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED MAR 0 9 201Z • 1 • I I I I I I I It rel." .7 si I. 0 41) M CO C :i N. (113E E o L rigas Mom IC:t Upe— v di CLD r Cid i coi GOM 0- pi, i Oi I I I rt, CDI ;- E °' a) 1 0 0 1.7.1 1.-Jt-J 1.-J C J r ] r ] J Z C) 05 to CJ 1J 1.7,31.-.JL7 U, U1 I1.-JWIt-J U, t c4 V-.0 L t T I MI MI ISd 4 5 0W ConocoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: ~ ~EC~I~lEL APR n 5`2010 ~laskaAil & Gas Cons. Commission And~q~ ~s- ~,os 3f~_aa- ~.~~'~~ ~.: A F ~ ~ '~ f~ 0' Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet .serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 2 and 21, 2010. The corrosion inhibitor/sealant was pumped March 27, 28 and 29, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, MJ 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 3/31/10 3A_ 3B_ 3C_ 3(~_ 3H_ 31. 3.1 3M ~A R 3R POn's Weli Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-02 50029214310000 1852050 Surface n!a 26" n/a 4.25 3/29/2010 ' 3A-04 50029214330000 1852070 SF n/a 26" n/a 4.25 3/29/2010 3A-07 50029214440000 1852230 SF n/a 25" n/a 4.25 3/29/2010 3A-16 50029214920000 1852840 SF n/a 23" n/a 3.4 3/29/2010 3B-10 50029213660000 1851140 6'6" n/a 6'6" n/a 25.5 3/28/2010 3C-11 50029213570000 1851020 SF n/a 25" n/a 4.25 3/27/2010 3G-08 50103201280000 1900650 SF 0.65 27" 3/2/10 5.52 3/28/2010 3G-09 50103201290000 1900670 SF 0.60 22" 3/2/10 4.67 3/28/2010 3G-22 50103201470000 1901420 SF n/a 22" n/a 4.25 3/28/2010 3H-01 50103200840000 1871100 SF n/a 21" n/a 4.25 3/28/2010 3H-03 50103200850000 1871110 17" 0.40 8" 3/21/10 1.7 3/28/2010 3H-146 50103200920200 2050210 SF n/a 23" n/a 3.4 3/29/2010 31-02 50029215150000 1853080 SF n/a 22" n/a 2.97 3/29/2010 31-10 50029219340000 1890370 39' 3.50 24" 3/21/10 3.4 3/29/2010 3J-04 50029214000000 1851650 SF n/a 23" n/a 3.4 3/28/2010 3J-14 50029214960000 1852880 SF n/a 25" n/a 4.67 3/28/2010 3J-15 50029214970000 1852890 SF n/a 22" n/a 3.4 3/28/2010 3M-05 50029217060000 1870250 SF n/a 21" n/a 3.4 3/29/2010 3M-07 50029217080000 1870270 SF n/a 22" n/a 4.25 3/29/2010 30-09 50029218250000 1880610 SF n/a 23" n/a 4.25 3/27/2010 30-16A 50029217960100 1880430 SF n/a 22" n/a 3.52 3/27/2010 3R-10A 50029222530100 1920310 SF n/a 21" n/a 4.25 3/27/2010 3R-11 D 50029222480000 1920160 SF n/a 17" n/a 3.25 3/27/2010 3R-15 50029222580000 1920340 SF n/a 24" n/a 3.82 3/27/2010 3R-19 50029222690000 1920460 1" n/a 21" n/a 5.1 3/27/2010 3R25 50029226220000 1951810 SF n/a 21" n/a 5.52 3/27/2010 ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor K~q{lZjDÇ DATE: Monday, September 12,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3A-02 KUPARUK RIV UNIT 3A-02 'J,b5 \CfjS/ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :3ßf!- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3A-02 Insp Num: mitJJ050909120207 ReI Insp Num API Well Number 50-029-21431-00-00 Permit Number: 185-205-0 Inspector Name: Jeff Jones Inspection Date: 8/30/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. r--3A-02 ~TYÎ>-~-·Inj.l-w I TVD '- I I I -'-T--- Well 5830___1 IA 670 3020 2960 2950 I -..-L--.-- --- r 1852050 -ITypeTest-1 SPT I Test psi I P.T. 1457.5 I OA 120 270 270 270 I .__l____._._ ..' _.__. I ._ ._,- Interval 4YRTST P/~._. P Tubing 2250 2250 2250 2250 I I 1______._.__-L-_.__.____. Notes 1.9 BBLS diesel pumped. 1 well house inspected; no exceptions noted. " .: ~l'-'"' (. E'" \i') i,,';;;,¡(.',!.i' \t',"~ W\.~ 1\- ~:) ..,'i' - ~. \.;.)I'-~I..'}-...!J \.'u\i~...'>;t... ,-1 c~ (11 2005 c~? u Monday, September 12,2005 Page I of I DAY I April 30, 1994 Well 3A-02 Alternate MIT Engineering Sequence of Events T. J. Walker Written May 1, 1994 0930 O94O 0945 Velocity 368.5 FPM. 0950 RIH to 8020' Well injection rate stable at 3810 BWPD, pressure 2250 psi, temp. 60° F. Pressure on 7" 2620 psi, 10" 450 psi. Contacted plant to request no SW changes. 0700 MIRU Schlumberger E-Line 0800 Hold Safety meeting 0830 Pressure test to 3500 psi 0850 RIH to 100' w/CCL/WFL. WFL has 2', 6' and 20' detectors with Minitron (neutron activator) above. Tool OD 1-11/16", 38' total length. 0905 Perform Measurement w/10 Second burst w/six'cycles. 0915 Check well data. Rate 3830 BWPD, pressure 2252 psi, temp. 59° F 0925 Velocity 193.6 FPM. Calculate rate using following equation: Rate = (Area tbg - Area t°ol) * 1.7808*FPM Rate = (7.031-2.237)* 1.7808* 193.6 Rate = 1653 BWPD No good. Determine 10 sec. burst to long. Not using 0.83 correction factor. Perform Measurement w/2 second burst w/six cycles. Check well data. Rate 3800 BWPD, pressure 2247 psi, temp. 59° F. Last surface turbine meter calibration in 1988! Rate = 3146 BWPD 1035 Tie in to tubing tally 1048 Perform Measurement w/2 second burst w/six cycles. 1055 Check well data. Rate 3820 BWPD, pressure 2246 psi, temp. 59° F 1100 Velocity 323.9 FPM. Rate = 2765 BWPD. Delta top-bottom = 381 BWPD 1105 Perform Measurement w/2 second burst w/six cycles. 1110 Check well data. Rate 3825 BWPD, pressure 2243 psi, temp. 59° F ~¢ANNE~ DEC ! ~ 2002 ' Page 1/5 Well 3A-02 Alternate MIT Engineering Sequence of Events (continued) T. J. Walker Written May 1, 1994 1115 Velocity 387.4 FPM. Rate = 3307 BWPD. Delta top-bottom = -161 BWPD 1120~ Perform Measurement w/2 second burst w/six cycles. Tool failed, not making neutrons. Try again. No good. 1228 POOH f/another tool. . 1340 RIH to 100' w/CCL/WFL. Same configuration. 1345 Park tool at 100' 1350 Perform Measurement w/2 second burst w/six cycles. 1355 Check well data. Rate 3856 BWPD, pressure 2238 psi, temp. 59° F 1403 Velocity 382.2 FPM. Rate = 3263 BWPD. Delta topi-top2 = -117 BWPD. 1410 RIH to 8020' 1450 Tie in to tubing tally 1500 Perform Measurement w/2 second burst w/six cycles. 1508 Check well data. Rate 3843 BWPD, pressure 2241 psi, temp. 60° F 1515 Velocity 353.2 FPM. Rate = 3015 BWPD. Delta top-bottom = 248 BWPD 1520 Perform Measurement w/2 second burst w/six cycles. 1525 Velocity 324.9 FPM. Rate = 2773 BWPD. Delta top-bottom = 490 BWPD 1533 Perform Measurement w/2 second burst w/six cycles. 1-540 Check well data. Rate 3847 BWPD, pressure 2240 psi, temp. 60° F 1545 Velocity 378.3 FPM. Rate = 3230 BWPD. Delta top-bottom = 33 BWPD 1550 RIH to 8244' for A/C split determination. 1552 Perform Measurement w/2 second burst w/six cycles. Bad reading; Can't see reading on 6' detector and 20' out in 7" Page 2/5 Well 3A-02 Alternate MIT Engineering Sequence of Events (continued) T. J. Walker Written May 1 ,'1994 1612 RIH to 8260' in 7". 1615 Perform Measurement w/2 second burst w/six cycles. 1620 Check well data. Rate 3820 BWPD, pressure 2245 psi, temp. 59° F. Check KDGS trend, OK. 1630 Velocity 9.4 FPM. Calculate rate using fOllowing equation: Rate = (Area csg - Area tool) * 1.7808*FPM Rate = (7.031-2.237)'1.7808'193.6 Rate = 480 BWPD Repeat 3 times.' 8.0, 7.5 and 9 FPM. Rates, 408, 383, 460 BWPD Calculate A/C Split average total rate 30.70 BWPD & average A rate 433 BWPD. A/C split 14%/86%. 1730 POOH to flip tool. 1745 Call DeWayne Schnorr in Anchorage to discuss job progress. Indicated tool should calculate almost identical flow rates in same spot. The error he estimated should be +/- 10/15 FPM. We saw +/- 50 FPM difference. DeWayne felt this was strange and couldn't explain problem. Discussed 20' detector length. We thought distance might need to be longer at these higher rates. DeWayne felt it was adequate and should handle rates to 450 FPM. We saw velocity from 330 to 380 Discussed running spinner to determine flow rates in tubing. He concurred and recommended at least one long (20 min.) stop to verify well stability. 1750 1830 1845 1847 RIH with CCL/WFL with deteCtors above Minitron looking for upward flow behind pipe. Tie in to tally. Park tool at 7976' (above top packer). Perform Measurement w/2 second burst w/six cycles. SCANNED DEC 1 9 2002 Page 3/5 Well 3A-02 Alternate MIT Engineering Sequence of Events (continued) T. J. Walker Written May 1,1994 1850 Check well data. Rate 3780 BWPD, pressure 2232 psi, temp. 60° F. 1859 No flow detected. 1900 RIH to 8045' (to check up flow below top packer). 1904 Perform Measurement w/2 second burst w/six cycles. 1915 No flow detected. 1916 POOH 1930 Call town to discuss job. Ron Marquez not home. Discussed job with Jim Zernell. Plan to run spinner to determine tubing integrity. All agree with plan. 1940 Check well data. Rate 3793 BWPD, pressure 2225 psi, temp. 60° F. 1945 OOH, RDMO. Estimated job cost $17M DAY 2 May 1, 1994 Well injection rate stable at 3880 BWPD, pressure 2232 psi, temp. 60° F. 0800 MIRU Schlumberger E-Line 0930 Hold Safety meeting, Pressure test 0940 RIH with CCL/GR/Temp/Pres/Cont. Spinner. Decide not to run centralizer to assure tools will go through AVA choke. 1030 Tie in with tally 1036 Start up passes at 40, 80, 120 from across C Sand (8250' to 7950') 1.101 Stop count at 8235'. See data on attached calculation sheet. 1103 Check well data. Rate 3860 BWPD, pressure 2237 psi, temp. 60° F. Stop count at 8020' for 20 minutes. Well stable within 1 RPS. 1115 POOH to 220' 1216 Check well data. Rate 3878 BWPD, pressure 2232 psi, temp. 60° F. Start up passes at 40, 80, 120 from 220' to 100'. Page 4/5 Well 3A-02 Alternate MIT Engineering Sequence of Events (continued) T. J. Walker Written May 1, 1994 1240 Stop counts at 100' 1300 POOH for bow spring centralizer to check well rates. Well has 41 ° deviation in Kuparuk. Likely cause of flow measurement error in bottom of hole. 1330 RIH with same tools and bow spring centralizer to 8020' 1404 Check well data. Rate 3852 BWPD, pressure 2239 psi, temp. 63° F. 1410 Tie in 1415 Stop count above and below packer show 30 RPS. 1420 Log up at 80 FPM same location as previous. 39 counts. Make stop counts above mandrels on way OOH. 1450 Check well data. Rate 3861 BWPD, pressure 2238 psi, temp. 64° F. Make stop counts above mandrels on way OOH. 1549 Check well data. Rate 3906 BWPD, pressure 2233 psi, temp. 65° F. Make stop counts above mandrels on way-OOH. 1558 Shut-in well for threshold readings. 1630 OOH. RDMO Estimated cost $10M, Total $27M. Confirm flow constant down tubing within 2%. See attached calculation sheet for details. Page 5/5 Well 3A-02 Alternate MIT Calculation Sheet T. J. Walker Readings with no centralizer for AJC Split Line Speed (FPM) Total Flow @ 100' (RPS) Total Flow @ 8020' (RPS) A Sand Flow @ 8235' (RPS) Threshold (RPS) 0 33 25 40 80 120 39 43.5 48 32 36 40 15 19 25 3.4 7.4 11.9 Determine Intercept Total Flow @ 100' (FPM) 312 Total Flow @ 8020' (FPM) 246 A Sand Flow @ 8235' (FPM) 9 8 Threshold (FPM) 8 In 2-7/8" tubing Calculate Flow rate Rate = (FPMintercept - FPMthreshold) * 1.4 * (ID)^2 * 0.83 Total Flow @ 100' (BWPD) 3162 Total Flow @ 8020' (BWPD) 2476 Delta 687 BWPD Total Flow @ 8020' (BWPD) ** 2983 Delta 1 7 9 BWPD A Sand Flow @ 8235' (BWPD) 67 9 ** Wiihout 0.83 correction factor because tool on Iow side of hole. A/C Split 21% 79% Using 100' flow Readings with centralizer (can't pass AVA sleeve) Line Speed (FPM) 0 Total Flow.w/cent. @ 100' (RPS) 32 Total Flow w/cent. @ 8020' (RPS) 30 40 80 120 41 39 Previous flow within 7 RPS or 687 BWPD Thus one RPS equals approximately 98 BWPD Centralized spinner flow within 2 RPS or -196 BWPD Difference is 196/3162=6% Decide to iog well with centralizer Spinner Stop counts with centralizer Depth (FT) ~ 70 32,0 1790 3O.3 2200 29.8 2630 29.8 4805 30.3 5700 30.2 5775 31.3 5785 31.7 623O 30.5 6640 30.3 6985 31.0 7300 31.0 7310 31.0 7650 31.0 7710 31.0 79OO 30.O 8030 30.3 Average 30.7 Median 30.5 Standard Dev. 0.6 Deviation is 0.6 RPS * 98 BWPD/RPS or 59 BWPD Difference is 59/3162=2% Conclusion from spinner logging: Fiow top and bottom equal within 2% SCANNED DEC ! 9 2002 TJW 5-1-94 Well 3A-02 Alternate MIT · Total Flow @ 100' (RPS) ~,- [] Total Flow 8020' (RPS) 45 ~..." -- * Threshold (RPS) · ~ A Sand Flow 8235' (RPS) .,/~'"/' .. ~.~' ,) .... /'~ ~ 0 ~,-~ ~ ......... / ..-"/'~"' .~., . ./ . 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ 0 0 0 0 0 0 0 0 I I I I I I I ! I I ! I Line speed (FPM] TJW 5/1/94 Well 3A-02 Alternate MIT Z m ! Total Flow w/cent. @ 8020' (RPS) [] Total Flow w/cent. @ 100' (RPS) · Total Flow @ 100' (RPS) ~ Total Flow @ 8020' (RPS) · Threshold (RPS) /~ A Sand Flow @ 8235' (RPS) O O CD O O O O O O O O O O O O O O ~ t.O ~' Od O {~0 t.O ~' Od O ~0 t~O ~1' Od O I I I I I I I I I ! I I I Line ~peed (F~M) I I I TJW 5-1-94 GUIDELINES WATER INJECTION PROFILES OBJECTIVE OF SPINNER SURVEYS IN WATER INJECTORS · TO OBTAIN A/C SPLIT (PERCENTAGE OF INJECTED WATER FLOWING INTO THE A SAND VERSUS THE PERCENTAGE FLOWING INTO THE C SAND). · THIS DATA IS NEEDED TO MAXIMIZE OIL RECOVERY I1. PRE-JOB PREPARATION A. CHECK PROCEDURE, REVIEW WELL FILE, AND DISCUSS OBJECTIVES WITH DRILL SITE ENGINEER IF NECESSARY · CHECK TOOL STRING OD WITH MINIMUM ID B. ENSURE ADEQUATE STABLE FLOW/INJECTION PERIOD C. CONSIDER RUNNING SL GAUGE RING TO CHECK FILL, IDENTIFY TIGHT SPOTS, AND CHECK FOR THICK FLUIDS IN RATHOLE D. SET UP KDGS PRINTOUT USING "DSPVlD" PANEL. · DSPVID WILL PRINT THE FLOW RATE AND PRESSURE III. ON-SITE QUALITY CONTROL A. BRING TO JOB SITE: · CBL/CET OR TUBING COLLAR LOG FOR TIE IN · GRAPH PAPER FOR CROSS PLOT · CALCULATOR FOR CALCULATIONS · SPINNER DATA SHEET · PROCEDURE FROM DRILL SITE 'ENGINEER B. NOTE ON WSR FLOW RATE, PRESSURE, AND TEMPERATURE FROM KDGS JUST BEFORE SPINNER RUNS C. DISCUSS PROCEDURE WITH SERVICE COMPANY OPERATOR TO: · VERIFY THAT EVERYONE IS WORKING OFF THE SAME PROCEDURE · EXPLAIN ANY UNUSUAL STEPS OF THE PROCEDURE D. TIE-IN TO CASING COLLARS WITH UP PASS, SUBSEQUENT PASSES CAN BE DEPTH SHIFTED AFTER THE PASS E. MAKE PASSES AT LINE SPEEDS SPECIFIED, ADJUST LOGGING SPEED SLIGHTLY IF NEEDED TO GET BE'r'i'ER READING F. PLOT DATA TO VERIFY SPINNER IS WORKING PROPERLY G. CALCULATE FIELD ESTIMATE OF A/C INJECTION SPLIT IV. DISTRIBUTION OF DATA A. THE CROSS PLOT, CALCULATIONS, AND SPINNER DATA SHEET ARE DISTRIBUTED AS SHOWN IN THE UPPER CORNER OF THE SPINNER DATA SHEET. THE KDGS PRINTOUT IS SENT TO THE DRILL SITE ENGINEER. B. THE LOG IS DISTRIBUTED TO THE: CPF Well Files NSK Central Files KOE File Clerk ATO-1119 Drill Site Engineer FIELD ANALYSIS PLOTTING A. PLOT ALL UP AND DOWN PASSES AND STATIC STOPS (IE LINE SPEED EQUALS ZERO) USING STATIC STOP DEPTHS FOR THE DYNAMIC PASS SPINNER DATA POINTS. MAKE SURE STOP DEPTHS ARE MIDWAY BETWEEN COLLARS AND NOT ON CHANGES IN ID SUCH AS "D" NIPPLES OR PBR'S - 1) IF THE LINES AREN'T ON A STRAIGHT LINE AND PARALLEL VERIFY ID'S ARE THE SAME OTHERWISE ADDITIONAL PASSES MAY BE REQUIRED · DATA POINTS LESS THAN +/- 2 RPS MAY BE SUSPECT DUE TO THE EFFECTS OF FRICTION AND FLUID VISCOSITY AT LOW RPS · NEGATIVE RPS MAY NOT BE PARALLEL TO POSITIVE RPS AND USUALLY WILL NOT LINE UP 2) EXTEND THE LINES FOR TOTAL FLOW, A SAND ONLY, AND NO FLOW UNTIL THEY INTERCEPT THE X-AXIS AND OBTAIN A FPM VALUE FOR EACH. LOG II. CALCULATIONS A. CALCULATE THE THRESHOLD VELOCITY OF THE SPINNER · THE INTERCEPT OF THE NO FLOW LINE WITH THE X AXIS IS THE THRESHOLD VELOCITY IN FEET PER MINUTE B. CALCULATE THE TOTAL RATE (ABOVE C SAND) AND' A SAND ONLY (BETWE~ THE A AND C SANDS) MAXIMUM VELOCITIES BY ADDING THE THRESHOLD VELOCITY (ADD ABSOLUTE VALUES) C. CORRECT THE MAXIMUM VELOCITIES TO AVERAGE VELOCITIES AVERAGE VELOCITY--CORRECTION FACTOR* MAX. VELOCITY CORRECTION FACTOR= FOR 7" AND 5" CASING IS 0.84 FOR 3.5", 2.875" TUBING IS 0.85, FOR 2.375" IS 0.84 D. USING THE AVERAGE VELOCITY OF THE TOTAL RATE, CALCULATE THE TOTAL RATE IN BPD WITH THE FOLLOWING FORMULA: BPD=(AVERAGE VELOClTY)*(ID)2*I.4 AVERAGE VELOCITY= FEET PER MINUTE ID= INSIDE DIAMETER IN INCHES AT THE TOTAL RATE STOP DEPTH FOR NORMAL GRADES OF CASING AND TUBING THE ID'S ARE 7" = 6.276", 5" = 4.408", 3.5" = 2.992", 2.875" = 2.441" 2.375"= 1.995" 1.4= UNITS CONVERSION FACTOR E. COMPARE THE CALCULATED TOTAL RATE WITH THE SURFACE READINGS TO GIVE A LEVEL OF CONFIDENCE TO THE SPINNER LOG. IT SHOULD BE WITHIN 15%. F. CALCULATE THE A SAND ONLY RATE USING THE A SAND ONLY AVERAGE VELOCITY G. RATIO THE TOTAL RATE TO THE A SAND ONLY RATE TO GET THE A/C SAND SPLIT. A SAND %-- (A SAND RATE/TOTAL RATE)*100 C SAND %= 100- A SAND % AIC SPLIT is the A SAND % followed by the C SAND % GUIDELINES HEADER INFORMATION A. BPD RATE B. TEMPERATURE AT THE TREE (WHIT OR WHT) C. PRESSURE AT THE TREE (WHIP OR WHP) D. "TAGGED FILL @ XXXX', BOTTOM PERF @ XXXX'". E. TOOL DIAGRAM: 1) TOOL SCHEMATIC (INCLUDE ROPE SOCKET, WT. BARS) 2) SHOW SENSING DISTANCES (IE, HP TO CCL TO SPINNER) 3) HP SERIAL NUMBER AND LATEST CALIBRATION DATE 4) TEMP SERIAL NUMBER AND LATEST CALIBRATION DATE 5) SPINNER DIAMETER AND PITCH 6) IF COUNTS ARE USED, HOW MANY COUNTS EQUALS ONE RPS F. IF INJECTION SPLIT IS NOTED ON THE LOG, LABEL IT AS "FIELD ESTIMATE" I1. LOG PRESENTATION A. TIE-IN PASS 1) LOGGING DIRECTION IS UP 2) LOG ACROSS SHORT JOINTS UP TO GLM ABOVE TOP PACKER 3) RECORD LOG USED TO TIE-IN (FOR EXAMPLE: GEARHART CBL DATED 5-05-83) B. DYNAMIC & STATIC PASSES 1) PRESENT CCL WITH SPINNER PASSES AND LOGGING SPEED. 2) OVERLAY SUCCESSIVE SPINNER PASSES 3) SCALE RPS ON LOG TO MINIMIZE WRAPPING 4) DEPTHS ON LOG ARE THE DEPTH OF THE SPINNER C. DYNAMIC & STATIC STOPS 1) ON THE LOG RECORD: DEPTH OF STOP RPS OR SPIN COUNTS PRESSURE AND TEMP AT DEPTH TIME OF STABILIZED PRESSURE AND TEMP GENERAL INFORMATION I. THREE TYPES OF SPINNERS ARE USED AT KUPARUK: A. CONTINUOUS SPINNER 1 ) MOST COMMON 2) MOST VERSATILE 3) MOST RELIABLE 4) HARD TO INTERPRET FALLBACK B. FULL BORE SPINNER 1) LOW RATES 2) FOLD DOWN BLADES 3) USED ONLY IN CASING 4) SENSITIVE TO FALLBACK C. BASKET FLOWMETER 1) EXTREME LOW RATES 2) VERY FRAGILE 3) USED ONLY IN CASING 4) CAN ELIMINATE FALLBACK II. THE DIRECTION OF THE FLOW IS DOWN -'SO EXPECT THE BEST DATA FROM THE UP PASSES. II1.THE MORE STABLE THE WELL, THE BETTER THE RESULTS - VERIFY WITH KDGS AND ONSITE READINGS (IE, MANIFOLD BUILDING AND WELLHEAD). SCANNED DEC 9 IV. SPINNER PASSES IN EXCESS OF 180-200 FPM LOSE RESOLUTION AND NEED TO BE AVOIDED. V. THE SPINNER IS LOCATED ON THE BOTTOM OF THE TOOL STRING - DO NOT TAG FILL UNTIL ALL THE SPINNER WORK IS COMPLETE. SCANNE~ DEC ! ~ 2002 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 _X Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 72 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Kuparuk Unit 4. Location of well at surface 8. Well number 47¢4' FNL, 742' FEL, Sec. 7, T12N, R9E, UM (asp's 507706, 5996884) 3A-02 At top of productive interval 9. Permit number / approval number 1340' FSL, 3332' FEL, Sec. 18, T12N, R9E, UM 185-205/ At effective depth 10. APl number 50-029-21431 At total depth 11. Field / Pool 4296' FNL, 3486' FEL, Sec. 18, T12N, R9E, UM (asp's 504983, 5992082) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8690 feet Plugs (measured) true vertical 6303 feet Effective depth: measured 8389 feet Junk (measured) true vertical 6076 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 105' 16" 193' sx AS II 105' 105' SUR. CASING 4040' 9-5/8" 1100 sx AS III, 340 sx Class G 4112' 3110' PROD. CASING 8605' 7" 4O0 sx C~ass G, 250 sx AS ~ 8677' 6294' Perforation depth: measured 8108'- 8208', 8319' - 8344', 8357'-8397' ~ ~. ¢.L,,..... .... 'i "".:, _ . .._.[ ~'~.,~' ;¢ ~, ''~'~i.,~ true vertical 5863' - 5939', 6023'- 6042', 6051'- 6082' /!~.,p~-~, i) 0. o.J~'~. ., Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tbg @ 8275' MD; 2-7/8",6.5#, J-55 Tbg @ 8302' MD. ~!~S~(~- 0ii i."; ~.~;.;U (.',,i ;.!,, (.;i-,i'~,iiiti;;~;[[~' Packers & SSSV (type & measured depth) BAKER 'FHL' @ 8064' MD; BAKER 'FB-I' @ 8283' MD; BAKER 'FVL' @ 1863' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubinq Pressure Pdor to well operation 908 2700 2829 Subsequent to operation 1117 300 2486 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signedjerr)/Deth/efs ~-¢'~~~ Title: Problem Well Supervisor Date .~//.~~~ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Phillips Alaska, Inc. Kuparuk Well 3A-02 SUNDRY NOTICE 10-404 04/27/02 Phillips Kuparuk injection well 3A-02 tubing was patched 04/22/02 to repair a leak at the bottom of GLM #8. The well exhibited slow T x IA communication, although not bad enough to fail an MIT. A video log run on 2/20/02 identified the thread leak at 7754' md, the bottom of gaslift mandrel #8. The patch is a Merla 3-1/2", 20-feet long, non-retrievable permanent style. The patch set depths are: Top: 7691' md (5551' tvd) Bottom: 7711' md (5566' tvd) A passing MIT was performed 04/25/02 (submitted to AOGCC). The test was waived by the Field Inspector. The test results are: TVD/MD Pre test Initial 15 minute 30 minute PTD: 1852050 5,830 Tubing 2,400 2,400 2,400 2,400 Well #: 3A-02 8,064 Casing 100 3,050 3,000 3,000 NSK Problem Well Supervisor 04/27/02 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 27, 2002 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-404 Report of Sundry Operations for Phillips Alaska, Inc., well 3A-02. The report is a summary of a robing patch on the injection well. Please call Pete Nezaticky or me at 907-659-7224 if you have any questions. Sincerely, .~l~rry Dethlefs Phillips Problem Well Supervisor Attachments Re: Kuparuk well 3A-02 injector repair Subject: Re: Kuparuk well 3A-02 injector repair Date: Mon, 04 Mar 2002 16:06:30 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: NSK Problem Well Supv <n1617@ppco.com> Jerry, Thanks for the notice. ! do not think you are remiss on anything. Your work of 2/20/02 served to positively identify the problem you suspected. Your proposal to effect repair using a patch is one that has been used before. By copy of this email, you have approval to proceed with the planned patching operation. You can send in the 403 by fax (please remember to sign it). Good luck. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: > Tom: Phillips Kuparuk we//3A-02 (PTD 1852050) water injector has quite a > long history of slight but constant T x fA communication, dating back to > about 1991 by my records. I believe the AOGCC has been informed of this > before due to an alternate MIT (tracer) ran on 3/14/92. The well has > consistently passed MIT's but the IA slowly charges up. Recently Engineering has asked us to investigate repairs for consideration for gas injection (WAG). We ran a video log on 2/20/02 that clearly shows a thread leak in the bottom connection of GLM #8. Our intent is to repair the leak with a 20' permanent patch. After the patch is set we arrange for one of the Inspectors to witness an MIT in preparation for conversion to gas injection. There is a couple of items we need to catch up on: We did not notify you immediately upon finding the leak on 2/20/02; I hope this emaii will suffice for that. We need to submit a '!0-403 for approval to patch; we have an opportunity to patch the well this week. Can we get verbal (or emaii) permission to do so, followed with the paperwork? We will need to submit a '10-404 after the patch is set. We need to submit a 10-404 with conversion information for WAG injection. Please let me know if this plan sounds OK, or if you need additional information. Thanks/. Jerry Dethlefs Phillips Problem Weft Supervisor Tom Maunder <tom maunder~.admin,state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 2 3~4~02 4:07 PM ll:$Zpm From-KUP ~LL$ ~'T PROJ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1,Type ofraquest AbandOn_ Suspend_ Operational shutdown _ Re.enter suspended well _ Alter caaing _ Repak well _X Pluggh3g _ 'l-]me extension _ ~,fl mulat~ _ Change approved program_ Pull tubing _ Variance _ Per/orate _ OIlmr _ 2, Name of Opera!or .... Phill!ps ~la~,a,,mc..r. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4774' FNL, 742' FEL, Sec. 7, T12N, R~E, UM At top o! productive interval 1340' FSL, 3332' FEL, Sec, 18, T12N, RgE, UM At effec~ve dep~l At total depth 4296' FNL, 3486' FEL, Sec. 18, T12N, RgE, UM 12. Present well condition ~urnmary Total depth; measured true verttcet Type of Well: Development Exploratory ~ Stratigraphlc ~ Servlce__X (asp's 507706, ~996~84) 8690 feet Plugs (measured) 6303 !eel 6, Datum elevation (DF or KB feet) RKB 72 feet 7. Unit or Property n~me Kuparuk Unit ~ Well number 3A-02 9. Permit number / epproWl numb.r 18B.205 10, APl number 50-029-21431 11. Field / Pool Kuparuk Oil Pool Effective depth: measured true vertical Ca~lng Length CONDUCTOR 105' SUR, CASING 4040' PROD. CASING 8605' 8389 feat Junk (measured) 6076 met 16" 193' ~A$ II 1 9-5/~," 1100 ~x AS III, 340 7" 400 sx Class G, 2.~0 sx AS 11 8677' 6294' Perforation depth; measurect 8108' - 8208', 8319' - 8344', 8~57'.8397 RECEIVED tr~e ve~i¢~l ~B53'-5939',6023'-6042',6051'-6082' MAR ! ! 2oo2 Tubing (.size, grade, and rneas~Jred depth Packers & SSSV (type & measured depth) BAKER 'FHL' ~ 8064' MD; 13AKER 'FB.I' ~ 8283' MD; I~AKER 'FVL' ~ 1863' MD, 13. Attachments Description summary of proposal Detailed oper?ons program 14. Estimated date for commencing operation ~// I l& $tatu~ of well classification March 20, 2_002 I 16, If proposal was verbally approved Oil __ Name of approver D~te, approved .... ,, service 17. I hereby ~tl~ that the foregoing is true and correct to the best of my knowleqge, ~,~rN~,~,~/ , ~//__ ./ FOR.COMMISOION USI~ ONLY Conditions of approval: Notify Commission so repmsent?:"e may witness Mech~nlc.~f Integrity Test ..~:~, ~]3sequent form required '10- BOP sketch_ .Water Iniector Sqspended __ Approval no, ~_Ap_pr~oye_d by order of the Commission Original Signed By Commissioner Form 10.403 Rev o6/1~)/88 ' - SUBMIT IN TRIPIJC^TF~ F-,uparuk' 10-403 request 3A-02 & 30-17 Subject: Kuparuk 10-403 request 3A-02 & 30-17 Date: Men, 11 Mar 2002 23:17:29 -0900 From: "NSK Problem Well Supv" <n1617@ppco.com> To: tom_maunder@admin.state.ak.us CC: "CPF3 Prod Engrs" <n1223@ppco.com> Tom I have attached the 10-403 applications and the supporting documents for 3A-02 and 30-17. I have also faxed you the signed 403 copies as timing for approval is getting tight. 3A-02 is an injector that has a tubing leak. You gave Jerry an email approval to proceed with the patching procedure. Initial plans were to run ./ the patch this week, but the job needed to be bumped and should be run sometime next week. (See attached file: 3A-02 Sundry Discussion 03-11-02.doc)(See attached file: 3A-02 Sundry 03-08-02.xls)(See attached file: 3A-02.pdf) 30-17 is an injector that was thought to have tbg x IA communication. After extensive diagnostics and AOGCC permission to inject MI for 1 month there is no indication of communication. The approval for temporary MI injection ends on Thursday (3/15). We are asking to place this well on normal status with no restrictions. Instead of going through the process of converting everything back to water injection we would like to continue MI injection until the 403 is reviewed and a decision is made. (See attached file: 30-17 Sundry Discussion 03-11-01 .doc)(See attached file: 30-17 Sundry 10-403 03-08-02.xls)(See attached file: 30-17.pdf) Peter Nezaticky Phillips Problem Wells 1F -~3A-02 Sundry Discussion 03-11-02.doc;! Type: WINWORD File (application/msword) !I Encoding' base64 Name: 3A-02 Sund~ 'Dis'cus~,ion 03-11-02.doc :! ~-~3A-02 Sundry 03-08-02.xls Name: 3A-02 Sundry 03-08-02.xls Type: EXCEL File (application/msexcel)i Encoding: base64 ................ ~'~'~ } 3A-02.pdf i/ I j~_~ 3A_02.pdfi Name: Type: Acrobat (application/pdf)i/ !~Encoding: base64 ~._~30-17 Sundry Discussion 03-11-01.docli Type: WINWORD File (application/msword) i.... iEncoding' base64 Name: 30-17 Sundry 10~403 03-08-02.xls Type: EXCEL File (application/msexcel) ~30-17 Sundry 10-403 03-08-02.xlsi:!Enc°ding: base64 i,_ ii Name: 30-17.pdf I ~130-17.pdfii Type: Acrobat (application/pdf) i, , :i Encoding' base64 1 of 2 3/12/02 7:32 AM Phillips Alaska, Inc. Kuparuk Well 3A-02 SUNDRY NOTICE 10-403 REPAIR REQUEST 03/11/02 The purpose of this Sundry Notice is to notify the AOGCC of Phillips Alaska, Inc., intent to repair the tubing on Kuparuk well 3A-02 injector. The well has had a history of the IA slowly charging, but has consistently passed MIT' s. Diagnostics showed that the charging was due to a leak in the tubing, but the leak rate was too small for traditional logging tools. A video log was performed on 2/20/02, which showed the leak in a gas lift mandrel #8 collar connection at 7754' md. No other leaks were found and the tubing appears to be in good condition. A 3-1/2" patch (2.37" ID, permanent) will be set over the mandrel and collar leak ~ 7754' md. An MIT will be performed on the casing to verify the repair integrity. -/ Near-term plans for this well include conversion from water to gas injection (WAG service). J PROPOSED ACTION PLAN Phillips proposes to use the following action plan for operation of this injector: 1. The well may be used for either gas or water injection (WAG); 2. Tubing / casing integrity must be maintained by installation and maintenance of a patch or other repair over the known tubing leak ~ 7754'md to meet AOGCC MIT criteria; Successfully MIT the casing / tubing after installation of the patch. ~ Notify the AOGCC should MIT's or injection rates and pressures indicate further problems. o NSK Problem Well Supervisor 06/23/01 ARCO Alaska, Inc. A PKR (8064-8065, OD:6.151) PKR (8283-8284, OD:6.151) Perf (8319-8344) Perf (8357-8397) 3A-02 GKA 3A-02 APl: 500292143100 SSSV Type: Baker 'FVL' Annular Fluid: Reference Log: Last Tag: 8389 Last Tag Date: 6/18/99 Casing String CONDUCTOR Size Top 16.000 0 Casing String - SURFACE Size I T°P I 9.625 0 Casing String - PRODUCTION Size I T°P I 7.000 0 Tubing String - TUBING Size I Top 3.500 0 2.875 8275 Perforations Sum mary Well Ty pe:]lNJ Orig Completion: [9/8/85 Last W/O:} Ref Log Date:} TD: [8690 ftKB Max Hole Angle:156 deg @ 3100 Angle @ TS:141 deg @ 8107 Angle @ 'rD: }41 de9 @ 8690 Rev Reason:}JEWELRY BY VG Last Update: |7/3/99 / Bottom TVD I Wt IGrade I Thread 105 105 Bottom TVD Wt IGrade I Thread 4112 3110 36.00 J J-55 Bottom I TVD Wt I Grade Thread 8677 I 6294 26.00 I J-55 Bottom J TVD Wt Grade I Thread 8275 I 5989 9.30 I J-55 } 8RD EUE 8302 6010 6.50 ] J-55 ] 8RD EUE Interval TVD I Zone ~Status FeetlSPF1 Date / Type I Comment 8319- 8344 6023-6042 I A-3 [ I 251 4[I1/13/8~IPERF [9O deg. phasing; 4" Hyper Jet II 8357 - 8397 6051 - 6082 I A-2 I I 40~ 4]11/13/8~IPERF 190 deg. phasing; 4" Hyper Jet II Gas Lift MandrelsNalves StnI MD I TVDI Man I Man I VMfr I VType IVODILatchlPortITROI Date / Vlv 1 I 27081 22911 Camc~l KBUG I I DMY I 1.0 I BK 10.000l 01 4/25/96 / 2I 4885}3604} Camco } KBUG I } aW I 1.0 I BK 10.0001 014/25/96/ 3I 58551 4252} Camco I KBUG J I aw I 1.0 I BK 10.0001 01 4/25/96 } 4I 62981 4557J Camco I KBUG J J DMY I 1.0 I BK 10.0001 01 4/25/96 [ 5I 67o81 48431 Camcol EBUe I I DW I 1.0 I BE 10.0001 0/4/23/96/ 6I 7O561 5O9OIcamool ~<BUe I I DW I 1.0 I BE 10.0001 01 4/23/96 / 7I 74011 53381 Camcol KBUG I I DW I 1.0 I BE 10.0001 0/4/24/96/ 8/ 77501 5595} Camco I KBUG I I DW I 1.0 I BK 10.0001 01 4/23/96 / 9} 8003/ 5784} Merla } TPDX } J DMY / 1.5 I BM /0.0001 0/ 5/26/95 / 10 / 81011 5857/camc° I KBUG I I DMY / 1.o / aK /o.oooI Ol 9/4/91 / Description ,tc.) - JEWB. RY ID 2.810 3.000 3.000 2.296 2.310 3.000 2.250 2.441 2.441 Baker 'FVL' Other (plugs, equip., Depth ITVDI Type 18631 17401 sssv 80501 58191 PER 80641 58301 PKR 8271] 59861 NiP 82711 59861 SLEEVE 8283} 59951 PKR 8296J 6005J NIP 8301[ 6009} SOS 83021 6010/ -i-FL General Notes Baker Baker 'FHL' AVA'BPL' Landing Nipple w/ 2 7~8" XO (Drift ID=2.296'3 AVA; TPI (New Sty le) set 7/2/99 Baker 'FB-I' Camco 'D' Nipple NO GO Camco Date J Note 4/25/96 INote on Schematic: Leak Detection on 4/25/96 failed to locate a leak; Note on } WSR -'bad test'. IALSO: 11.4 ppg Brine in 7" Csg ., MEMORANDUM TO: Julie Heusser Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 21, 2001 THRU: Tom Maunder [. P.I. S uperv isor/.di.~)~ ¢~J.~ FROM: John Crisp ~'~\"[ ~'~ ~3 ~t'~\ GKA Petroleum Inspector Kuparuk River Field NON- .CONFIDENTIAL SUBJECT: Mechanical Integrity Tests Phillips Alaska 3A Pad 3A-02,04,06,07,10 Packer Depth Pretest Initial .15 Mi.ri. 30 Min,. . ! ' 'WellI 3A-02 I Typelnj. I S I T.V.D. I 5830 ITubingi 2~J00 ! 29001 29001 2900,,l~.tew, a~! 4 I P.T.D.I ~S5~o5o,ITyPete~l"' ." ITestpsiI 445e l Casingi' 2700, I 3350 i 3320 ! 33~0. I. P/F I --P ! 'WalI "3A-04 'iType~nj.I S IT-~'-D- I 5877 I'Tubingl' 295o1 298o I' 2~0 1':;980 'l~nterVaq~i4 1 .... ,i ~'s52070 IT.y~.testl P. ITest~l ~,~.l'c~;,.I ~2~ !' 1980 ,I 195O1194° [ P~ I P Wall! 3A-06 p'.T.D.I No'ms: Weill, 3A-07 'P, .I.D.I 1852230 Notes: WellI 3A-10 P.T.D.I 1852370 Notes: i Type~nj.! S I T.v.D. i ~'lTu~ngl 2~751 26ool 2~1 26~'.1!.~e~1 4 Type't~l'. P. IT~'~il ~'~ lca~,gi '.2r,5o I~-o I a,°°l ~ .I "": I __" IT ypelnj, i S I T.V.D. I ~' i~ut"ngi 3000 I' 3000"i 300013000 I~nt~a~l 4 ~:;W~"I '. I~e"..~'l ~.4~0 lcasingI .~o75 I ~! 482°1,482° I' P/F ! -P l,,e,nj, i' S I ~.v.,. I~ i~u~n,I ~ooo I ~0oo '1-~°, i ~ I'"'e'v~'il'~" 'i:ypetest! P I Testpsil 1477 ICasingI 4500 I ,2050 !' 2020 ,i 2020 I. P/F I _P Type INJ. 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 These wells passed the Standard Annulus Pressure tests. 2 annulus pressures were high considering they were bled down the previous day. 5 MIT's no failues witnessed. M.I.T.'s performed: Attachments: Number of Failures: 0_ Total Time during tests: 3 HRS. CC: MIT report form 5/12/00 L.G. MIT KRU 3Aa 7-21-01jc.xis 7/23/01 Mr. P. S. White Page 2 November 27, 1994 surveyed or logged every other year and wells which demonstrate mechanical integrity every fourth year. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests or the application of alternative methods. BY ORDER OF THE COMMISSION David ~/'c-,~ohnston, ~"ai~~ Alaska O~servation Commission Russell A. Douglass, Commissa/oner Alaska Oil and Gas Conservation Commission Tfckerman Babcock, Commissioner Alaska Oil and Gas Conservation Commission ARCO Aleake, Inc. Date: Apdl 21, 1994 Subject' From/Location: Fac ood~: Well File 3A-02, T, TR, 12/95 Telephone: To/Locat io n: Alternate MIT w/Water Flow Log - Injection Well 3A-02 T. J. Walker 263-4124 H. Scherffius/W. Wilder The following well work is recommended' WELL: PRIMARY OBJECTIVE: SECONDARY OBJECTIVE(S): ESTIMATED COST: CHARGE CODE OR AFC NUMBER: TYPE OF WORK REQUESTED: TAG FILL ATO-1256 NSK-69 (Plus 2 Copies) 3A-02 Alternate MIT w/ Water Flow Log - State Reporting - Rule 6 Determine A/C split. $5400 for 7 hours of logging 230DS36AL SCA CODE: E-Line X WELl. INFORMATION ATTACHED: X 40222 OTHER (Describe in Comments)_ YES NO Comments- A water flow log (WFL) is recommended to satisfy AOGCC alternate mechanical integrity testing (MIT) for Injection Well 3A-02. A radioactive tracer survey was performed in March 1992 to satisfy these requirements which must be repeated every two years. Ple_as_e notify_ the AOGCC at least 24 hours in advance of logging to enable .a re.oresentative to witness the ;an.DliCation of alternative methods. Please see attached memo and AOGCC administrative aoDroval for information on WFL MIT's. - . Past diagnostic work has indicated an upper packer leak and recently tubing x 7" casing communication has been suspected. However, if a tubing leak exists, it is small as shown on the attached bleed log. The attached procedure calls for a WFL to be used to assure water is entedng only the Kuparuk formation. In addition, determination of the A/C split is requested. Please call if you have any questions on the attached procedure. Please note this orocedure is new for KuDaruk. Therefore. ole~e advise enoineednn of lob fimino so I carl be on-site. Enulneer Kuparuk Petroleum Engineering R. B. MarquezN~" J. O. Golden/M. C. Vincent M. F. Jerling/R. B. Kay DS 3A Operators D. R. Schnorr (Schlumberger) ATo-1270 NSK-22 NSK-22 NSK-22 ATO- 1158 AR~O Aleed~ Int. ~ a ~dmldle~ ~ A~iemi~ql~dleidC~nlee~ Alternate MIT w/Water Flow Log Recommended Procedure Well 3A-02 Charge Code' 230DS36AL SCA Code: 40222 An alternate MIT is required tb vedfy all injected water is entering the Kuparuk Formation. Please notify_ the AOGCC at least 24 hours in advance of logging to enable a representative to witness the ap.olication of alternative methods. Pdor to Running Survey 1. Establish a stabilized injection rate at full header pressure (approximately 4500 BWPD) for a minimum of one day pdor to running survey. . Contact CPF-3 Production Engineer pdor to performing logging to ensure that minute values for injection rate and pressure are recorded on KDGS. ., WFL Procedure (to as,sure tubing is not. leaking) Maintain constant injection rate while logging. See attached WFL info 1. MIRU Schlumberger E-line and PT lubricator. Conduct safety meeting. . RIH with CCLANFL. The detectors should be located below the "source" at 2', 6' and 20' to record downward flow. Assure tools will pass through AVA choke. . Park source at 100' MD-RKB (avoid tubing collar). . Perform measurement with WFL to .calculate flow rate. The measurement will take about 15 minutes with a 10 sec. burst and 6 cycles of data. 0 Log tie-in pass from tubing tail to bottom 1" GLM. Tie-in to tubing jewelry from schematic and/or CET dated 10-01-85. Note' Last tag 8445' MD-RKB on 7/30/93. 6. Park source below top packer at 8020' MD-RKB (avoid tubing collar). . Perform measurement with WFL to calculate flow rate". The measurement will take about 15 minutes with a 10 sec. burst and 6 cycles of data. . Compare flow rates (while checking KDGS to assure constant surface flow rate). If flow rates are neady identical (+/-100 BWPD), proceed with following work. If rate found in step 7 is less that found in step 4, repeat measurements up tubing to determine leak location. Contact Anchorage to discuss options. Schlumuerger Water r-,ow Log Information Sheet Tool Configuration for tubing log Source (top) 2' Detector 6' Detector 20' Detector Tool Configuration for 7" annulus log 20' Detector 6' Detector 2' Detector Source (bottom) General Tool Info 1) RA activation has a 7 Sec 1/2 life 2) Water will stay radioactive for about 1 minute 3) Tubing metal will stay radioactive 4 to 8 hours 4) Avoid radioactive spots in tubing on repeat measurements 5) Approximate tubing accuracy +/- 20 BWPD 6) Approximate 7" annulus accuracy +/- 70 BWPD 7) WFL will not activate diesel. Rate formula in tubing BWPD = (Area Tubing-Area WFL) * 1.7808 * 0.83 * Fluid Velocity (fpm) Area = 0.7854 * D^2 Area 3.5" J-55 9.3# tubing (ID) = 0.7854 * 2.992^2 = 7.031 Sq In. Area 2.875" J-55 6.58 Tbg (ID) = 0.7854 * 2.441^2 = 4.680 Sq In. Area WFL (OD) = 0.7854 * 1.6876^2 = 2.237 Sq In. Rate formula in 7" annulus BWPD = (Area casing-Area tubing) * 1.7808 * 0.90 * Fluid Velocity (fpm) Area = 0.7854 * D^2 Area 7" J-55 casing (ID) = 0.7854 * 6.275^2 = 30.926 Sq In. Area 3.5" J-55 9.3# Tbg (OD) = 0.7854 * 3.5^2 = 9.621 Sq In. T. J. Walker 4/21/94 Alternate MIT w/Water Flow Log Recommended Procedure Well 3A-02. (continued) Charge Code' 230DS,36AL SCA Code' 40222 NC SDlit determination, 1. Park source directly above D nipple at 8240' MD-RKB (in 2-7/8" tbg) (avoid tubing collar). . Perform measurement with WFL to determine A Sand flow rate. The measurement will take about 15 minutes with a 10 sec. burst and 6 cycles of data. 3. Calculate A/C Split. Repeat measurement to confirm value. 4. POOH to change tool configuration. WFL Procedure (.to assure no flow u.~ from u.m:), er .Dacker in 3.5" x 7" annulus ) Maintain constant injection rate while logging. . RIH with CCL/WFL. The detectors should be located above the "source" at 2', 6' and 20' to record upward flow. Assure tools will pass through AVA choke. 2. Tie-in to tubing jewelry from schematic and/or CET. 3.- Park source above PBR at 7970" MD-RKB (avoid tubing collar). . Perform measurement with WFL to assure no flow behind pipe. The measurement will take about 15 minutes with a 10 sec. burst and 6 cycles of data. . Calculate flow upward in 3.5" x 7" annulus. If water is found to be moving up. Make additional stops to determine location water is leaving the 7". 6. RDMO Kur"RUK WELL 3t-'12 WATER INJECTION WELL · APTf: 50-029-21431-00 ADL LFASE: 25632 ~: 85-205 SPtD DATE: 09/02/85 SURFACE LOCATIC~I: TOP OF KUPARUK: TD ~ICt~: (I~4~~~: 11/13/85 CASING and TUBING DETAILS 16" 62.5 H-40 105' 9.625" 36.0 J-55 4112' 503' FSL, 743' FEL, SEC 7, T12N, R9E, ~4 ORIGINAL RKB: 72 1340' FSL, 3332' FEL, SEC 18, T12N, R9E, ~4 TUBING SPOOL: 29 984' FSL, 3471' FEL, SEC 18, T12N~ RgE, ~4 PAD ELEVATION: 42 FMC GEN III 3-1/8" H(~ ..I ,J J ..J I I '///////x 1809': BAKER FVL ~ ~x.~ '~ ~ ) (2. 812' I .D. ) 2651 ': 600' 4831 ': 3100' ~ ~ '; 5801 ': 6242 ': 57~' 58~' 6655': ~ ~ 1" ~ (D~ ~23 ' 7002': ~ ~G 1" ~ (D~ 71.6 ~ 2.5 ~ 7347': ~ ~G 1" ~ (D~ 210.8 ~ 7697': ~ ~G 1" ~ (D~ 7951': ~ ~DX 1.5" ~ (D~ 799~': ~ ~ - 3-1/2" x 2-7/8" X~ 8235': ~ ~-1 ~ 824~': ~ D ~~ (2.25" I.D.) ~253': ~O ~ ~ ~ 4" ~ 4" ~ 8445': ~ ~ (07/30/93) 8592': ~ (61563 ~-~) 7" 26.0 J-55 3.5" 9.3 J-55 MISC. DATA DESCRIPTION KICK ~ POINT: ANGLE THRU KUP: 41° TVD TO UPPER PKR: TVD TOTC~ C SD PERF TVD TO TC~ ASD PERF VOLUME TOTT VOLUME TT TO TC~ PERF VOLUME 7" ANNULUS PERFORATION DATA 8108-8208 C3 12 120e 5" CG 8319-8344 A3 4 90~ 8357-8397 A2 4 90e REVISI~DATE: 07/30/93 I~.AS(~: TAG FILL BY: TJN WELL 3A'02 i. ;3S BLEED EVENT HISTORY WELL DATE TIME ANNULUS B?.k'~.D PRIMARY CASING STARTING ENDING TIME FLUID BLED PRESSURE PRESSURE MINUTES BLED 3A-02 '12/09/93 0001 3A-02 03/26/93 0001 7 2900 1600 30 D 7 2375 1925 30 D ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL 3A-02 DATE 5/1/94 DAY 2 DESCRIPTION OF WORK SPINNER SURVEY i CONTRACTOR / KEY PERSON SCHLUMBERGER/GERARD JOHNSON PBTD (RKB) ]LAST TAG (RKB) - DATE 8592' ! 8445'/7-30-93 SITP=2330g 7"CP=2600g 9-5/8"CP=500g TIME LOG ENTRY 0800 MIRU SCHLUMBERGER E LINE KUPARUK RIVER UNIT WELL SERVICE REPORT ]AFC/CC# - SCA# I 230DS36AL/40222 IFIELD COST EST. IACCUMULATED COST [ $10,000 ] $27,217 ISSSV TYPE / STATUS IBAKER FVL/IN SERVICE 0915 PT LUB TO 3800g-OK! HELD SAFETY MEETING 0930 RIH W/l-11/16" HEAD, 6'WT BAR, CCL, ATC/GR, PTS & CONTINUOUS SPINNER 1020 MADE TIE-IN LOG FROM 8280' TO 7900'-TIED INTO GLM @ 8049' 1030 RIH TO 8255'-MADE UP PASSES TO 7950' @ 40, 80 & 120 FPM-TOTAL FLOW RATE= 315O BWPD 1115 MADE 15 MIN STOP COUNT @ 8030'-STOP COUNT 25-POOH 1215 MADE UP PASSES FROM 220' TO 100' @ 40, 80 & 120 FPM- 1300 RIH W/l-11/16" TOOL STRING W/BOW SPRING CENTS ON BTM OF CONT SPINNER- 1400 SET SPINNER @ 8030' FOR STOP COUNT-STOP COUNT 30 (PREVIOUS STOP COUNT 25) 1515 MADE STOP COUNTS FROM 7900', ABOVE EACH MANDREL TO 1790'-AVG STOP COUN~I 30.5 RPS 1530 MADE STOP COUNT @ 105'=33.2-STOP COUNT @ 190'=31.5 1535 1600 1630 1730 R1H TO 400'-MADE PASS FROM 400' TO 70' @ 80 FPM- SI WELL TO RUN VELOCITY PASS FROM 200' TO 70' @ 40, 80 & 120 FIgM WELL OPENED BACK UP TO WI RDMO WHTP=2200 7"CP=2500# 9-5/8"CP=480g SUMMARY RAN SPINNER SURVEY WO BOW SPRING CENT ON SPINNER-READINGS ON SURFACE WERE SIGNIFIC~TLY DIFFERENT-(600 BWPD) RERAN SPINNER SURVEY W/BOW SPRING CENT-READINGS WERE WITHIN 175 BWPD VERIFIED READINGS @ 8030' AND 100' BY RUNNING 16 STOP COUNTS BETWEEN I BOTH POINTS FIELD ESTIMATED A/C SPL1T WAS 20%/80%-TOTAL RATE 3250 BWPD SPINNER CONFIRMS NO LEAK FROM TUBING TO CASING ABOVE PAKER I CHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK Weather ]Temp. ]Chill Factor Ivisibility milesrWind Vel.] Report mph[ I I I INCOMPLETE Signed REMARKS CONTINUED: SERVICE COMPANY SCHLUMBERGER DAILY $10,000 ACCUM. TOTAL · $27,217 Diesel TOTAL FIELD ESTIMATE $10,000 Signed: $27,217 3A-02 ALT MIT FLOW AT 8020' FLOW AT 100' FF~ 40 80 120 F-PM 40 80 120 A FLOW 1 5 1 9 2 5 A FLOW TOTAL FLOV 3 2 3 6 4 0 TOTAL FLOV~ 3 9 4 3 4 8 · A 50: FLOW 45 -' ~] TOTA 3 5 ~ ~ ~_ow 2 .o/o~ o o o o 2 l...._ ....... _8~o~__ o ~ o · .... 'q ................................... F .......................................... --I ............................ 1- ........................ Page 1 3A-02 ALT MIT Chart I 50 45 4O -= A FLOW , : ~ TOTAL FLOW100 ~ ou T~ -300 -60 -30 0 30 60 90 120 Page 1 ARCO Alaska, Inc. ,~r KUPARUK RIVER UNIT Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT ~WELL DESCRIPTION OF WORK IAFC/CC# SCA# 3A-02 ALTERNATIVE MIT [ 230DS36AL/40222 DATE CONTRACTOR / KEY PERSON IFIELD COST EST. IACCUMULATED COST 4/30/94 SCHLUMBERGER/GERARD JOHNSON I $17,217 I $17,217 I DAY PBTD (RKB) ILAST TAG (RKB) - DATE ]SSSV TYPE / STATUS 1 8592' I 8445'/7-30-93 IBAKER FVL/IN SERVICE HTP=2247# 7"CP=2620# 9-S/8"CP--450ff TIME LOG ENTRY 0700 MIRU SCHLUMBERGER E LINE 0800 HELD SAFETY MEETING 0830 PT LUB TO 3500~-OK! 0850 RIH W/l- 11/16" X 38' CCL/WFL(SOURCE ON TOP)-PARK MINITRON @ 100'- 0915 FLOW RATE FROM FLOW METER 3800 BWPD-MINITRON READING W/10 SEC BURST READING 1653 BWPD (TOO LOW) 0930 DECREASE BURST RATE TO 2 SEC-VELOCITY READING 368.5 CORR. TO 3146 BWPD 0945 RIH TO LOG TIE-IN PASS FROM TBG TAIL TO BTM 1" GLM @ 8049' 1030 TIE-IN W/GLM @ 8049'-CORRECTED COUNTER BY 7'-LOGGED FROM TT TO GLM @ 795 i'-LOG ON DEPTH 1045 PARKED MINITRON @ 8020' 1100 READING W/2 SEC BURST 2765 BWPD (KDGS 3800 BWPD) 1115 REPEAT READING W/MINITRON @ 8020' 1120 READING W/2 SEC BURST 3307 BWPD (KDGS 3800 BWPD) 1200 MINITRON NOT READING-DROPPED TOOL STRING DOWN TO TT-S~T MINITRON @ 824 ,MINITRON NOT READING-POOH 1345 CHANGED OUT TOOL STRING-RIH AND SET MINITRON @ 100'- 1415 MINITRON READING 382.2 (3263 BWPD)-RIH TO TIE-IN W/BTM GLM @ 8049' 1500 FIED IN TO GLM @ 8049'-SET MINITRON @ 8020' 1515 MINITRON READING 353.2 (3015 BWPD) 1520 REPEAT MINITRON READING @ 8020'=324.9 (2774 BWPD) 1540 REPEAT MINITRON READING @ 8020'=378..3 (3230 BWPD) 1545 RIH TO 8244' FOR "A" SAND INJECTIVITY-UNABLE TO PU READINGS 1600 RIH TO 8306' & LOGGED TO CSG TO CK FOR COLLARS-NO COLLARS IN TOOL AREA-SE MINITRON @ 8260'-2' READING=7.5/6' SEC READING 9.0 (AVG 421 BWPD) 1620 REPEAT-2' READING 8.0/6' READING 9.4 (AVG 444 BWPD) 1730 POOH TO REVERSE TOOL STRING ~CHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK I I COMPLETE ~ INCOMPLETE ReportWeather ITemp' IChillFact°r Visibility miles WindVel' ISignedmphI ~~.. ,~ ~~ REMARKS CONTINUED: 1750 1830 RIH W/TOOL STRING IN REVERSE (DETECTORS @20', 6' & 2' W/SOUI~'CE ON BTM) RAN TIE-IN LOG FROM 8070'-7908'-MADE REPEAT PASS FROM 8070'-7900' 1845 RIH TO 7976'-MINITRON @ 7970'-42' ABOVE PACKER @ 8012' (KDGS RATE 3800 BWPD) 1900 DETECTOR READINGS INDICATED NO FLOW ABOVE PKR RIH & SET MINITRON @ 8045'-DETECTOR READINGS INDICATE NO FLOW ABOVE PKR 1945 POOH 2045 RDFN WHTP= 22508 7"CP=26208 9-5/8" CP--4808 SUMMARY RAN WFL PER PROCEDURE. FLOW READINGS WERE INCONSISTENT (SEE ATTACHED WORK SHEET)-A/C SPLIT W/AVAILABLE DATA=14%/86%-433/2637 BWPD- TOTAL OF 3070 BWPD. WFL ABOVE & BELOW PKR @ 8012' RKB INDICATED NO WTR FLOW PLAN TO RUN SPINNER SURVEY TO CONFIRM FLOW RATES IN AM. SERVICE COMPANY SCHLUMBERGER DAILY $17,217 ACCUM. TOTAL $17,217 $17,217 Diesel TOTAL FIELD ESTIMATE Signed: $17,217 3A-02 WK SHT JTABLE I TABLE 2 Minitron Tool Velocities Conversion Best Flowrate Time Depth Depth 2' 6' 20' Factor T,ubing Casing 0915 100' 129' 193.6 8.537 1652.8 WELL: 0930 100' 129' 368.5 3145.9 11 00 8020' 8049' 323.9 2765.1 11 20 8020' 8049' 387.4 3307.2 1 400 100' 129' 382.2 3262.8 1 51 5 8020' 8049' 353.2 3015.3 1 525 8020' 8049' 324.9 2773.7 1 540 8020' 8049' 378.3 3229.5 TABLE 3 1 620 8260' 8289' ~7.5 9 AVERAGE OF 2'&6' VELOCITIES 421.0 1 630 8260' 8289' 8 9.4 AVERAGE OF 2'&6' VELOCITIES 444.0 1 850 7970' 7950' NO FLOW 1 900 7945' 7951' NO FLOW ! Page I 'TREND PV~D 14759 14761 ANALOG/ACCUMULATOR TRENDING - 8 HOUR PLOT NAME DESCRIPTION AI-P3A5000-02 DS3A WELL-02 WATER INJ ~ At-F3A1103-02 DS3A WELL-02 H20 IIkU FLOW SA 0 13:17 ~--ADJUSTABLE--~ CURRENT ---PLOT RANGE-- VALUE MINIMUM MAXIMUM 2235.00 0.00 0.00 3870.31 0.00 0.00 2340.00W 3910~00W 2320.00W A I 2300.00w P 3 A 2280.00w 5 0 0 0 2260.00w 0 2 2240.00w 2220.00w 2200.00w INST. SHIFT KEYS ~ TIME FORWARD 3 ~ TIME BACKWARD 4 AA i aF a3 A al a0 3 gt0 a2 3880,00w 3850.00w 3820.00w 3790.00w 3760.00w 3730.00w 3700.00w BRD ~NST. MULTIPLE PLOT ~ uaaaaaaaaauaaaaaaaaauaaaaaaaaauaaaaaaaaa 05'16 07:16 09'16 05:16: 56 MINUTES PRINT GRDS ,PC'E{ SPAN,PVI ,PV2,PV3,PV4 SPAN,PV1 ,PV2,PV3, PV4 11'16 O4/3O/94 5 ~ WELL PLOT 01,1A-01 ALASKA OIL AND GAS CONSERVATION COMMISSION January 27, 1994 / / WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-14,~ TELECOPY: (~T/) 276-7542 ADMINISTRATIVE APPROVAL AIO NO. 2.6 Re: Amend Rule 6 to allow additional means for demonstrating mechanical integrity of injection wells Paul S. White, Senior Engineer Kuparuk Petroleum Engineering ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK. '99510-0360 Dear Mr. White: .. ARCO Alaska, Inc. (ARCO), as operator of the Kuparuk River Unit, by letter dated January 20, 1994 requested the Commission modify Rule 6 of Area Injection Order No. 2. The modification would allow use of a variety of logging devices to demonstrate mechanical integrity of injection wells. The commission has determined that alternative means for demonstrating mechanical integrity of injection wells is appropriate. This approval supersedes Area Injection Order No. 2 Rule 6, and Administrative Approval AIO No. 2.4. Therefore Rule 6 of Area Injection Order No. 2 is amended to read: Rule 6 Demonstration of Tubing/Casing Annulus Mechanical Imegrity A schedule must be developed and coordinated with the Commission which ensures that the _tullin$/~ annulus for each .injection well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi, or 0.25 psi/fi multiplied by the vertical depth of the packer, whichever is greater; but not to exceed a hoop stress greater than 70°/$ of the casing's minimum yield strength. The test pressure must be held on the tubing/casing for 30 minutes with no more than a 10% decline. Alternative EPA approved methods may also be used with Commission approval, including but not limited to timed-mn radioactive tracer surveys, oxygen activation logs, temperature logs and noise logs. Wells with tubing-to-casing communication must be ARCO Alaska, Inc Date: Subject: January 29, 1994 Alternative MIT's Internal Correspondence File Code:F, P From/Location: P.S. White ATO-1210 Telephone. 263-4241 To/Location: KPE Engineers & Supervisors AOGCC approval has recently been received to use a vadety of logging techniques for alternative mechanical integrity tests (MIT's). Use of oxygen activation logs (water flow logs), temperature logs, and noise logs are now approved. Radioactive tracer surveys may still be used, but in most cases the other logs (and especially the water flow log) will be preferred due to cost and regulatory constraints. Attached is a copy of the new rule. If you have any questions or need further interpretation, please call me at 4241. P. S. White . Senior Engineer M. Eck/W. Ford V. L Ferguson D. A. Grove F. E. Komin K. M. Lake D. Schnorr W. Stdcklancl/J. Mclnnes W. Wilder/H. Scherffius NSK-38 ATO- 1228 ATO-1276 ATO-1120 ATO-1251 ATO- 1158 NSK-69 NSK-69 ARCO Ala~ct, Inc. is · Subsidiary of AtlanticRichfieldCompany The foliowing sepia logs were requested to be sent to AOGCC' ~ F TM ~- "~" 3A-02 ~ RA TRACER SURVEY 3-12-92 ~ .~-- 2, ~ ~ 3A-11 RA TRACER SURVEY 3-15-92 If you have any questions please contact me at 265-6835. Maria Trevithick Kuparuk Records Clerk ARCO, Alaska Inc. JUN 0 8 Alaska Oil & Gas Cons. Commission ARCO Alaska, Inc. April 10, 1992 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Report of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION WELL ACTION 3A-02 Alt. MIT 3A-11 Alt. MIT If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Operations Engineer cc: J.D. Bolling ATO-1196 KOE1.4-9 (w/o attachments) (w/o attachments) k ECEI'VE D Alaska Oii& Gas Cons. Anchorage ,".F[C:C, /'.iaska, inc. is a Subsidiary of At[cidic','.ici~ii~l:;, l:.''i';.~:;; STATE OF ALASKA AI.Ao,,,A OIL AND GAS CONSERVATION C.,C~MIb,.~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate m Pull tubing Alter casing Repair well 2. Name of Operator 5. Type of Well: Development ~ ARCO Alaska. Inc. Exploratory _ 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service ~ 4. Location of well at surface 503' FSL, 743' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1340' FSL, 3332' FEL, Sec. 18, T12N, R9E, UM At effective depth 1042' FSL, 3446' FEL, Sec.18, T12N, RgE, UM At total depth 984' FSL, 3471' FWL, Sec. 18, T12N, R9E, UM , , 12. Present well condition summary Total Depth: measured 86 9 0' true vertical 6 3 0 2' Plugging feet Plugs (measured) feet None Perforate Other ~ , 6. Datum elevation (DF or KB) RKB 72 feet 7. Unit or Property name Ku@aruk River Unit 8. Well number 3A-02 9. Permit number 85-205 10. APl number so-02~-21431 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 8 5 9 2' true vertical 6 2 2 8' Length Size 109' 16" 41 1 2' 9 5/8" 8678' 7" feet Junk (measured) feet Norle Cemented 193 Sx AS II 1100 Sx AS III & 340 Sx Class G 400 Sx Class G & 250 Sx AS II measured 8108'-8208', 8357'-8397', 8319'-8344' true vertical 5863'-5939', 6051 '-6081', 6022'-6041' Tubing (size, grade, and measured depth) 3 1/2" J-55 W/ tbg tail at 8254' Packers and SSSV (type and measured depth) Baker FHL @ 8016', Baker FB-1 @ 8235', Baker FVL @ 1815' Measured depth True vertical depth 105' 109' 4112' 3110" 8677' 6293" 13. 14. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Alaska. 0il & Gas Cons. Commiss~o,~ X X ~,llonora,,]e Re_oresentative Daily Average Production or Irljection Data OiI-Bbl Gas-Mci Water-Bbl Casing Pressure 2000 2000 Service - - 2000 2000 16. Status of well classification as: Water Injector ~ Oil _ Gas Suspended Tubing Pressure 1600 1600 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SiEIned ~'. ~/. ~ Form 10-404 Rev 09/12/90 Title SUBMIT IN DUPLICATE R( rt of Sundry Well Opel ons Kuparuk River Unit Well 3A-02 April 9, 1992 On November 27, 1991, the AOGCC granted ARCO Alaska, Inc. a waiver to continue water injection into Well 3A-02 in the presense of tubing by casing communication. Due to a probable upper packer leak, an alternative MIT is required to verify that all of the injected fluid is entering the approved Kuparuk interval. A radioactive tracer survey was performed on March 13, 1992_~, and both the tracer log and the results of this tracer work ~are attached. The AOGCC was notified 24 hours prior, but did not witness the survey. Results from the radioactive tracer survey indicate that all water is entering the A and C Sands. Both the tracer log and a detailed evaluation are attached. Changes in the velocity profile through the tubing are insignificant, and are within tool accuracy. Hot spots shown in secondary runs are indicative of tracer hold-up above doglegs, in mandrels, or adhering to scale. The speed of secondary indications from tracer movement after shots were fired indicates gamma movement must be within tubing, while no movement was detected behind pipe. All tracer measurements and previous leak detection diagnostics indicate the well has casing integrity with no indication of injected water going anywhere except into A and C Sands as intended. As per the A~trative Approval, A_rea_ Injection_Order__N~ 7 (December 20,~this survey will be repeated every two years to confirm that injection is still being maintained within the Kuparuk interval. Alaska Oil & Gas Cons. Commission KUPARUK WELL 3A-02 APl #: SPUD DATE' 500292143100 09/02/85 ADL LEASE: 25632 COMPLETION DATE: 11/13/85 PERMIT #: WORKOVER DATE: SURFACE LOCATION: 503'FSL,743'FEL,SEC7,T12N,RDE TOP OF KUPARUK: 1340'FSL,3332'FEL,SEC18,T12N,R9E TD LOCATION: 984'FSL,3471'FEL,SEC18,T12N,RDE NI deplfls am MD-RKB to lop of equipment unless otherwise noted ORIGINAL RKB: 72 CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16' 62.5~ H-40 105 9.625" 36# J-55 4112 7" 26# J-55 8677 3.5" 9.3~ J-55 EUE 8254 LINER DETAILS SIZE WEIGHT GRADE TOP TUBING SPOOL: 29 WELLTYPE: WATER INJECTOR BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV BAKER FVL 2.812' 1809 SBR BAKER PBR 3' 7998 PKR BAKER FHL 8012 AVA AVA 'BPL' NIPPLE 8223 PKR BAKER FB-1 8235 NOGO CAMCO 'D' NIPPLE 2.25' 8248 SHROUT CAMCO 8253 ' L PAD ELEVATION: 42 STN 1 2 3 4 5 6 7 8 9 lO INTERVAL 8108-8208 8319-8344 8357-8397 GAS UFT and FLOW INFORMATION VALVE DEPTH MANDREL SIZE 2651 CAMCO KBUG 1 · 4831 CAMCO KBUG 1" 5801 CAMCO KBUG 1" 6242 CAMCO KBUG 1' 6655 CAMCO KBUG 1" 7002 CAMCO KBUG 1" 7347 CAMCO KBUG 1' 7697 CAMCO KBUG 1" 7951 MERLA TPDX 1.5" 8049 CAMCO KBUG 1' PERFORATION DATA ZONE FT SPF PHASE C3 100 12 120 A3 25 4 90 A2 40 4 90 85-205 PORT SIZE .DV .DV .DV .DV .DV .DV .DV .DV .DV .DV COMMENTS SOS 5" CSG GUN SOS 4" CSG GUN SOS 4" CSG GUN MISC. DATA DESCRIPTION DEPTH KICK OFF POINT: 600 MAX HOLEANGLE: 56 deg 3100 HOLE ANGLETHRU KUP: 41 deg LAST TAG DATE: ~ ! RATHOLE: 28 ft FISH/OBSTRUCTION: PBTD: 8592 PBTDSS: 6156 REVISION DATE: 02/05/90 REASON: UPDATE 3A-02 Radioactive Tracer Survey Evaluation and Summary March 13, 1992 1, RA Tracer In!ectlon velocity check through entire tubin_a: Velocity profile measured peak-to-peak is: From Time To Time Velocitv 196' 14:43:34 1996.2' 15:00:55 1.73 fUsec 1996.2 15:00:55 4877.2' 15:34:04 1.45 ft/sec 4877.2' 15:34:04 5996.2' 15:46:51 1.45 ft/sec 5996.2' 15:46:51 8206.2' 16:12:52 1.42 ft/sec KDGS Rate (bwod) 1130 1130 1130 1130 Result: Except for above 1996', velocity ranges are within +/- 2%. No Leakage detected. Note' The velocity calculated between 196' and 1996' is considered an anomaly because the maximum velocity possible in 3.5" O.D. tubing at the measured injection rate is 1.5 ft/sec. Baseline Vs. Secondary_ Gamma Rav Log The secondary gamma ray log shows four new hot spots in the tubing which are washed away by the time of the third GR log. Hot Spot ToD Hot SDot BoSom Dogleg 6540' 6840' @6800 7060' 7240' @7300 7560' 7710' none 7950' 8230' none Note: Hot spots are an indication of either tracer adhering to scale build-up in tubing, tracer hold-up in mandrels, or tracer settling above severe doglegs in tubing. There are severe doglegs as detected in the Gyro survey occurring at the upper two hot spots which make it possible the tracer material to settle out. 3. Check for movement below Too Packer: Procedure: Inject Ra tracer slug at 8060' (below upper packer) and monitor flow down tubing and wait for secondary kick to indicate movement up behind pipe. Result: Kick travels down tubing and passes detectors, then is detected 18.8 minutes later. The top detector is receiving the RA signal prior to the bottom detector which indicates the tracer is moving down relative to the detector. The time between detectors is 15 sec and if the tracer is in the annulus this means it is going 0.61 ft/sec which corresponds to an annular velocity of 1400 bwpd. This is impossible because the well is only injecting 1130 bwpd, therefore the tracer can not be coming down annulus. The second detection may be break away tracer that had been held up in the tubing. Velocity indicates it must be in the tubing. Therefore, no movement behind pipe. RECEIVED 4. Check for Leakaoe above UDDer Packer: -- - - Procedure: Inject Ra tracer slug at 7962' (above upper packer) and monitor flow down tubing and wait for secondary kick to indicate movement up behind pipe. Result: Kick travels down tubing and passes detectors, then is detected 40 minutes later. is moving down relative to the detector. The time between detectors is 15 sec and if the tracer is in the annulus this means it is going 0.61 fi/sec which corresponds to an annular velocity of 1400 bwpd. This is impossible because the well is only injecting at 1130 bwpd, therefore the tracer can not be coming down annulus. The second detection may be break away tracer that had been held up in the tubing. Velocity indicates it must be in the tubing. Therefore, no movement behind pipe. 5. Final Gamma Ray Loo A third gamma ray log was run after all shots were taken which showed that all of the above hot spots were gone except for the following: 7954'-7960' 8008'-8012' 8106'-8116' At GLM ~9 (1.5") At Upper Packer At Upper C Sand Peals Result: Previous leak detection diagnostics indicates that there may be a minor leak across the upper packer as well as the1.5" mandrel. The tracer log and leak detection diagnostics show that there is casing integrity above that point. ~ummarv No indication of injected water going anywhere except into C and A Sands as intended. 1. Operations Performed: 2. Name of Operator REPORT OF SUNDRY WELL OPERATIONS ....... . Operation Shutdown __ Stimulate __ Plugging Perforate _ Pull tubing Alter casing Repair well ~ Other ~ 5. Type of Well: 6. Datum elevation (DF or KB) Developme~ ~ Exploratory Stratigraphic 8 6 9 0' feet Plugs (measured) 63 0 2' feet None 8 5 g 2' feet Junk (measured) 8 2 2 8' feet None Size Cemented ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorac~e, AK 99510 4. Location of well at sudace 503' FSL, 743' FEL, Sec. 7, T12N, R9E, UM At top of productive Interval 1340' FSL, 3332' FEL, Sec. 18, T12N, R9E, UM At effective depth 1042' FSL, 3446' FEL, Sec. 18, T12N, R9E, UM At total depth 984' FSL~ 3471' FWL~ Sec. 18~ T12N~ R9E~ UM 12. Present well condition summery Total Depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 1 0 9' Surface 41 1 2' Intermediate Production 8 6 7 8' Liner Perforation depth: measured 1 6" 193 Sx AS II 9 5/8" 1100 Sx AS III '& 340 Sx Class G 7" 400 Sx Class G & 250 Sx AS II RKB 72 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3A-02 9. Permit number 85-205 10. APl number 50-029-21 431 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 105' 109' 4112' 3110" 8677' 6293" 8108'-8208', 8357'-8397', 8319'-8344' true vertical 5863'-5939', 6051'-6081', 6022'-6041' 13. 14. Tubing (size, grade, and measured depth) 3 1/2" J-55 w/ tbg tail at 8254' Packers and SSSV (type and measured depth) Baker FHL (~ 8016'~ Baker FB-1 ~ 8235'~ Baker FVL ~) 1815' Stimulation or cement squeeze summery Intervals treated (measured) Treatment description Including volumes used and final pressure Rooresentative Daily Averaae Production or Iniecfion Data OiI-Bbl Gas-Mcf Water. Bbl Casing Pressure Tubing Pressure Prior to well operation 32OO 22OO 1700 Subsequent to operation .... 3 2 0 0 2 2 0 0 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run ~ I Water Injector ~ Daily Report of Well Operations X Oil = Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1700 =orrn 10-404 Rev 09/12/90 Title SUBMIT IN DUPLICATE Kuparuk Well 3A-02 -- On August 30, 1991, ARCO received verbal approval from AOGCC to continue operating Kuparuk Well 3A-02 while performing diagnostic work to determine the source of pressure communication between the tubing and seven inch casing (see Application for Sundry Approval submitted 8/30/91). This diagnostic work is complete (pertinent Well Service Reports attached) and has indicated that the source of the pressure communication is the upper packer (see attached wellbore schematic). ARCO will request permission to continue operating this well as is while periodically performing alternative MITs in a separate Sundry Application. KUPARUK WELL 3A-u z APl #: SPUD DATE: ORIGINAL RKB: 500292143100 ADL LEASE: 25632 PERMIT #: 09/02/85 COMPLETION DATE: 11/13/85 WORKOVER DATE: SURFACE LOCATION: 503'FSL,743'FEL,SEC7,T12N,RgE TOP OF KUPARUK: 1340'FSL,3332'FEL~SEC18,T12N,R9E TD LOCATION: 984'FSL,3471 'FEL,SEC18,T12N,R9E NI del:~hs are MD-RKB to t~p of equipment unless olf~erwise noted 72 TUBING SPOOL: 29 PAD ELEVATION: WELLTYPE: WATER INJECTOR CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16' 62..5~ H-40 105 9.625' 36# J-55 4112 7' 26# J-55 8677 3.5' 9.3~ J-55 EUE 8254 LINER DETAILS SIZE WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV BAKER FVL 2.812" 1809 SSR BAKER I:~R 3' 7998 PKR BAKER FI-IL 8012 AVA AVA 'BPL' NIPPLE 8223 PKR BAKER FB-1 823~ NOGO CAMCO 'D' NIPPLE 2.25' 8248 SHROUT CAMCO 8253 ''L 42 GAS UFT and FLOW INFORMATION VALVE STN DEPTH MANDREL SIZE 1 2651 CAMCO KBUG 1' 2 4831 CAMCO KBUG 1" 3 5801 CAMCO KBUG 1 ' 4 6242 CAMCO KBUG 1' 5 6655 CAMCO KBUG 1' 6 7002 CAMCO KBUG 1' 7 7347 CAMCO KBUG 1' 8 7697 CAMCO KBUG 1' 9 7951 MERLA TPDX 1.5' 10 8049 CAMCO KBUG 1 ' PERFORATION DATA INTERVAL ZONE FT SPF PHASE 8108-8208 C3 100 12 120 8319-8,344 A3 25 4 90 8357-~g7 Ag. 4O 4 90 85-205 PORT SIZE .DV .DV .DV .DV .DV .DV .DV .DV .DV .DV COMMENTS SOS 5' CSG GUN SOS 4" CSG GUN SOS 4' CSG GUN MISC. DATA DESCRIPTION DEPTH KICK OFF POINT: 600 MAX HOLE ANGLE: 56 deg 3100 HOLE ANGLE THRU KUP: 41 deg LAST TAG DATE: 05/25/87 8425 RATHOLE: 28 ft FISH/OBSTRUCTION: PBTD: 8592 PSTD~: 6156 ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ,..:,:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:. :.:.:.;-;.;.:.:.:.:.:.;.:.:.:,:.:.:.:.:.:.:.:.:,:.:.:,;.:.:.:.:.:. :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ,;,:.:,:.:.:.:.:.;.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.;.:.:.:.:,:.:.. :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~.:.:.:.:.;.:.;.:.:.:.;.;.:.:.;.:.:.:.:.;.:.:.:.:.:.:.:.:.;.:.;.:.: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ........ I ' 'l'" REVISION DATE: 02/05/90 REASON: UPDATE " 5uDs~Olary of AIlanhc R~cnhelO Company WELL SEHVICE REPOR'I REMARKS CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor Visibility Wind Vel. Report °F °F miles knots /~Hk,,,k/~,a~, ~nC. ~vl~ SuDs~chary of Atlantic RJ¢l~field Cornl3any TRACTOR ~ o REMARKS WELL SERVICE REPORT ~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weathe~ ~ Temp, i Chill FIcto~ I Villblllty I WInd Vel, Report · I mile~I , r Suos~d~ar'y of Atlantic ~c~helcI ComDan¥ Weather Report - CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK (~ ~ '~ Factor ' ;' gn~' ~~ } ~ Temp. Chill Visibility Wind Vel. ; °F ~ ,Si APPLICATION FOR SUNDRY APPROVALS 1. Type of Requeat: Abandon Suapex~ Alter casing _ Chan~le approved i~o~ram _ Repair well_ Plugging _ Pull tubir~l _ 5. Type of Well: Exploratory _ Stratigraphic _ Operation Shutdown _ Re-enter suspended well_ Time extension Stimulate Variance _~_ Perforate _ Other_ 6. Datum elevation (DF or KB) 2. Name of Operator feet Plugs (measured) feet Norle RKB 72 feet 7. Unit or Property name Kuparuk River Unit 8. We~l number 3A-02 9, Permit number 85-205 10. APl number so-029-21 431 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool ,ARCO Alaska. Inc. 3. Address P. O. Box 100360, 'Anchora~le, AK 99510 4. Location of well at surface 503' FSL, 743' FEL, Sec. 7, T12N, R9E, UM At top of productive Interval 1340' FSL, 3332' FEL, Sec. 18, T12N, R9E, UM At effective depth 1042' FSL, 3446' FEL, Sec.18, T12N, R9E, UM At total depth 984' FSL~ 3471' FWL~ Sec. 18~ T12N~ R9E~ UM 12. Present well condition summery Total Depth: measured 8 6 9 0' true vertical 6 3 0 2' 8 5 9 2' feet Junk (measured) 8228' feet None 13. Effective depth: measured true vertical SEe Cerr~ 1 6" 193 Sx AS II 9 5/8" 1100 Sx AS III & 340 Sx Class G 7" 400 Sx Class G & 250 Sx AS II Casing Length Structural Conductor 1 0 9' Surface 41 1 2' Intermediate Production 8 6 7 8' Liner Perforation depth: measured 8357'-8397', 6051'-6081', 8319'-8344' 6022'-6041' 8108'-8208', true vertical 5863'-5939', Measured depth True vertical depth 105' 109' 4112' 3110" 8677' 6293" KELI:IV U NOV 21 !991 Alaska 0il & Gas Cons. Commission Anchorage Description summary of proposal .2[. Detailed operation program_ BOP sketch_ Tubing (size, grade, and measured depth) 3 1/2" J-55 w/ tbg tail at 8254' Packers and SSSV (type and measured depth) Baker FHL (~ 8016'r Baker FB-1 ~) 8235'r Baker FVL ~ 1815' Attachments Status of well classification as: _ Suspended i Iniector ! IApprov_al No..._ 14. Estimated date for commencing operation 115. A~AP I Oil I Gas 16. If proposal was verbally approved Name of approver Date approved Service Water 17. I hereby certify that the foregoing is true and correct to the beat of my knowledge. Sic~ned ~'.bJ. ~FOR~USEONLyTitle Conditions of approval: Notify Commission so representative mey witness Plug integrity i BOP Test I Location clearance__ Mechanical Integrity Test i Subsequent form require ORIGINAL SIGNED BY L%'"IE C, SMITH U', -'t~ .. 11 -.o,q ' cii Commissioner Date SUBMIT IN TRIPLICATE Approved by order of the Commission Form 10-403 Rev 09/12/90 Kuparuk Well 3A-02 ARCO Alaska, Inc. requests permission to continue operating Kuparuk Well 3A-02 as is. This water injection well has experienced tbg. by 7" casing pressure communication over the last several months and recently failed an in-house MIT. Diagnostic work was done in September 1991, which identified the source of the leak as the top packer (the well has a selective single completion as shown in the attached schematic). ARCO would periodically perform alternative MITs (using radioactive tracer logging techniques) to verify that there is no ground water contamination ocurring. N OV 2 1 1991 Alaska 0il & Gas Cons. Commissio~ Anchorage KUPARUK WELL 3A-02 APl #: 500292143100 SPUD DATE: 09/02/85 ADL LEASE: 25632 COMPLETION DATE: 11/13/85 PERMIT #: WORKOVER DATE: 85-205 SURFACE LOCATION: 503'FSL,743'FEL,SEC7,T12N,RgE TOP OF KUPARUK: 1340'FSL,3332'FEL, SEC18,T12N,RgE TD LOCATION: 984'FSL,3471 'FEL,SEC18,T12N,R9E All deplhs am MD-RKB to top of equipment unless otherwise noted ORIGINAL RKB: 72 ITEM SSSV SBR PKR AVA PKR NOGO SHROUT CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16' 62.5~ H-40 105 9.625' 36# J-55 4112 7' 26# J-55 8677 3.5' 9.3~ J-55 EUE 8254 LINER DETAILS WEIGHT GRADE TOP TUBING SPOOL: 29 WELLTYPE: WATER INJECTOR SIZE BTM TUBING JEWELRY TYPE ID DEPTH BAKER F"VL 2.812' 1809 BAKER I:~R 3' 7998 BAKER FHL 8012 AVA 'BPL' NIPPLE 8223 BAKER FB-1 8235 CAMCO 'D' NIPPLE 2.25' 8248 CAMCO 8253 MISC. DATA DESCRIPTION DEPTH KICK OFF POINT: 600 MAX HOLE ANGLE: 56 deg 3100 HOLE ANGLETHRU KUP: 41 deg LAST TAG DATE: 05/25/87 8425 RATHOLE: 28 ft FISH/OBSTRUCTION: PAD ELEVATION: 42 STN 1 2 3 4 5 6 7 8- 9 10 INTERVAL 8108-8208 8357-8397 PBTD: 8592 PBTDSS: 6156 :.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:. :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :!:!:i:i:i:i:i:~:!:~:!:!:i:i:i:i:!:i:!:~:!:i:i:i:i:i:i:i:i:i:i:!:!:i i:i:i:i:!:!:i:i:i:i:i:i:i:i:i:i3!:!:i:i:!:i:i:i:!:i:!:i:i:!:!:i:!: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ,..............................-,....-.*............................ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .:.:.:.:.:.:.:.:.:.:.:.:.:.:.:,:.:.:.:-:.:.:.:.:-;-:.:.:.:.:.:.:... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: GAS UFT and FLOW INFORMATION VALVE DEPTH MANDREL SIZE 2651 CAMCO KBUG 1' 4831 CAMCO KBUG 1" 5801 CAMCO KBUG 1" 6242 CAMCO KBUG 1' 6655 CAMCO KBUG 1' 7002 CAMCO KBUG 1' 7347 CAMCO KBUG 1' 7697 CAMCO KBUG 1' 7951 MERLA TPDX 1.5' 8049 CAMCO KBUG 1' PORT SIZE .DV .DV .DV .DV .DV .DV .DY .DV .DY .DV PERFORATION DATA ZONE FT SPF PHASE C3 100 12 120 A3 25 4 90 A2, 40 4 90 COMMENTS SOS 5' CSG GUN SOS 4' CSG GUN SOS 4" CSG GUN RECEIVED NOV 1 19It 0il & Gas Cons. CommissiO Anchorage REVISION DATE: 02/05/90 REASON: UPDATE ARCO Alaska, Inc. Post Office ,__,, "100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 April 30, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Subject' Kuparuk River Field Water Injection Surveys In compliance with Rule 4 of Conservation Order No. 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk water injection wells for the First Quarter, 1990. The data is provided in the form of separate zone surveys or as spinner logs listed in Attachment 1. Injection rates determined by separate zone surveys are also listed in Attachment 1. The blue line and sepia-copies of the spinner logs are also included. If you have any questions concerning the information reported, please contact me at 263-4978. Sincerely, S. E. Schmidt Operations Engineer SES:LLP Attachment ARCO Alaska. Inc. is a Subsidiar'., ~f Atlan,.icRicn!ietdCompan'/ ATTACHMENT 1 WELL APl NUMBER NUMBER 50- KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE q - INJECTIVITY PROFILES FIRST qUARTER 1990 SUBMITTAL DATE OF DATE OF DATA TYPE REASON FOR INITIAL PROFILE/ PROFILE/ PROFILE/ INdECTION SURVEY SURVEY SURVEY 1F-lO 02920984 10/28/85 02921025 08/16/8q ilF- 15 /' lO-02 03/31/90 1G-03 03/31/90 WELL COMPLETION SEP ZONE FOLLOWUP A&C SS SEP ZONE FOLLOWUP A&C SS 02920813 10/11/85 03/16/90 SEP ZONE FOLLOWUP A&C SS 0292082q 10/25/85 03/30/90 SEP ZONE FOLLOWUP A&C SS 1G-09 02921001 09/15/8q 10-16 02921031 08/2q/8q 1R-03 02921q06 11/19/85 1R-15-, 02921387 11/10/8~ 2B-07 02921080 07/12/86 2B-08 02921079 11/07/85 2B-lO 0292108q 11/09/86 02/06/89 03/30/90 SEP ZONE FOLLOWUP A&C SS SEP ZONE FOLLOWUP ,,, A&C SS 03/0q/90 SEP ZONE FOLLOWUP A&C SS 03/07/90 SEP ZONE FOLLOWUP A&C SS 03/06/90 03/25/90 2U-03 02921269 11/19/85 2U-lq 02921262 11/10/85 2U-16 0292126q 01/lq/86 ";3A-02 02921q31 01/27/87 .,~ 3A-11 02921lt58 .. SEP ZONE FOLLOWUP A&C SS SPINNER FOLLOWUP A&C SS SEP ZONE FOLLOWUP A&C SS 07/02/89 03/29/90 SEP ZONE FOLLOWUP A&C SS 0q/09/90 SEP ZONE FOLLOWUP A&C SS 03/29/90 SEP ZONE FOLLOWUP A&C SS 03/lq/90 SEP ZONE FOLLOWUP A&C SS 03/25/90 SEP ZONE FOLLOWUP A&C SS 03/18/90 SEP ZONE FOLLOWUP A&C SS 03/10/90 SPINNER FOLLOWUP A&C SS SPINNER FOLLOWUP A&C SS 01/21/87 01/1~/90 ZONES TAKING WATER A C A C A C A C A C A C c A C A C A C A C A C A A C A A C A A C A INJECTION BWPD q.08 MMSCFD 2.00 MMSCFD 3.qq MMSCFD 1.55 MMSCFD 8OO 5000 8O0 3600 1000 3000 ~120 5qO0 2250 1775 2150 1650 2500 28O0 115o 2350 .~. 1500 2200 ~ 22oog_ 2000 21o3 24bO 1375 1652 1374 235 5665 ~50 00010000 0O020OO0 00030000 O00qO000 OO050000 OO060000 00070000 00080000 00090000 00100000 00110000 00120000 00130000 O01q0000 001ql000 00lq2000 00lq2100 001q2200 001q2300 00lq3000 00150000 00160000 00170000 00180000 00190000 00200000 00210000 00220000 00230000 O02qO000 00250O0O 00260000 00260102 00260202 00260302 00260q03 00260503 0026060q 0026070q 0026080q 00260903 0026100q 00261104 0026120q 0026130q O0261qOq 0026150q 00261600 00261700 00261800 00261900 00262000 00262100 00262200 00262301 00262q01 00262501 00262601 00262700 00262800 00263000 0026q000 00265000 ATTACHMENT 1 PAGE 2 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE 4 - INJECTIVITY PROFILES SECOND QUARTER 1987 SUBMITTAL WELL APl DATE OF NUMBER NUMBER INITIAL 50-029 INJECTION DATE OF DATA TYPE REASON FOR WELL ZONES PROF ILE/ PROFILE/ PROF ILE/ COMPLET ION TAK I NG SURVEY SURVEY SURVEY WAT ER 2B-11 21089 11/19/85 2H-01 20033 03/15/86 2H-04 20027 03/15/86 06/16/87 SPINNER FOLLOWUP ARC S ARC 06/05/87 SPINNER FOLLOWUP ARC S ARC 06/07/87 SPINNER FOLLOWUP ARC S ARC 50-103 2T-04 20074 03/30/87 2T-09 20071 03/30/87 2T-11 20075 03/30/87 2T-15 20062 03/30/87 2T-16 20063 03/30/87 50-029 3A-02 21431 01/21/87 i' 3A-04 211;33 01/21/87 3A-10 21457 01/21/87 ~~ 21458 01/21/87 06/13/87 SPINNER INITIAL ARC SS ARC 06/16/87 SURVEY INITIAL A S A 06/21/87 SPINNER INITIAL ARC SS ARC 06/16/87 SURVEY INITIAL ARC SS A 06/16/87 SURVEY INITIAL ARC SS A 3A-14 21490 04/14/87 05/25/87 SPINNER INITIAL ARC SS ARC 05/87 SURVEY INITIAL ARC SS A 05/87 SURVEY INITIAL A S A 05/27/87 I~~ INITIAL ARC SS ARC 05/87 SURVEY INITIAL A S A "' INJECTION BWPD RECEIVED 3485 1833 59O A'JG /, i ¢7 ~' ~' ~.r Alaska 0il & Gas Cons. Commission Anchorage 2500 1200 1650 .RECEtYED c,/I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM .... 3SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator ARCO Alaska., Inc Operation shutdown [] Stimulate .Fl, Plugging ~ Perforate .r-! Pull tubing Alter Casing ~ Other [] 5. Datum elevation (DF or KB) RKB 72' 3. Address PO Box 100360: Anchorage: AK 99510 4. Location of well at surface 503' FSL, 743' FEL, Sec. 7, T12N, RgE, UM 6. Unit or Property name K~J,nar~J~ ~iv~r Ilnif_ 7. Well number 3A-2 Feet At top of productive interval 1340' FSL, 3332' FEL, Sec. 18, At effective depth 1042' FSL, 3446' FEL, Sec. 18, A~lC:~t~ 3471' FWL, $ec.18, T12N, R9E, UM T12N, R9E, UM T12N, R9E, UM 8. Approval number #85-205 9. APl number 5o-- 029-21431 10. Pool Kuparuk River Oil Pool 11. Present well condition summary~;c~r~, ND Total depth: measured .... true vertical6302' TVD feet feet Plugs (measured~lOne Effective depth: measured 8592' ND true vertical8228' TV[} feet feet Junk (measured)None Casing Structural Conductor Surface XX X ~:K~X~ ¢t~t e Production xxx~r~Xxxxx Perforation depth: Length Size 109' 16" 4112' 9-5/8" 8678' 7" measured Cemented Measured depth True Vertical depth 193 SX ASII 105' MD llOOSX ASIII 4112' MD & 340SX Class G 400SX Class G 8677' MD & 250SX ASII 8108'-8208' MD, 8357'-8397' MD, 8319'-8344' MD 109' TVD 3110' TVD 6293' TVD true vertical5863'-5939' TVD, 6051'-6081' TVD, 6022'-6041' TVD Tubing (size, grade and measured depth) 3½", J-55, 9.41b/ft, Tail @ 8254' MD Packers and SSSV (ty. pe and measured depth) Baker FHL @ 8016'; Baker FB-1 @ 8235'; Baker FVL @ 1815 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2265 (Injection started on 1/21/87. Subsequent to operation 6000 0 650 410 Rates shown are 1/31/87) 7549 120 120~ 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run '~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-~.~ TitleSr. Operations Engineer Submit in Duplicate ARCO Alaska, Inc. S WELL T Z PRODUCTION WELL STATUS GAS LIFT STATUS NO. A O -. T N - U E FTP TEMP CHOKEI 7"CSG 10"CSG GAS INJ METER WELL S PSI F BEAN PSI PSI TEMP HCF TOTAL SI/HR REMARK 5-, P ~ 1~,5--' .~- loft /~'.~o ~ TOTAL ~ ~ ~ MAXIMUM INJECTION WELL STATUS WELL I Z ALLOWABLE NO. N O J N I,.,N~J, ,....~, ,, , CHART TOTAL TOTAL E TEMP CHOKE 7"CSG 10"CSG METER CALC INJ INJ WELL F BEAN PSI PSI TOTAL MMSCF BBLS MMSCF SI/HR GASOORRFAeTOR = HEAOER P~ESS = TOTAL FOR O.S. DRILL SITE PROD TEST PROD TEST BATH BLANKET RUN TIME HEATER TEMP TEMP PSI PSI TEMP GAS PSI OUT /~0 CHEMICALS TYPE GAL,'DAY COMMENTS: OPERATORS SIG NATU REi %/¢~~ .~/~ S WELL T Z PRODUCTION WELL STATUS GAS LIFT STATUS NO. A O T N TEMP U E FTP ,CHOKE 7"CSG 10"CSG GAS INJ METER WELL S PSI F , BEAN PSI PSI TEMP HCF TOTAL SI/HR REMARK I P g /50 fi'So I~ T ~ ~DD / 7 /03~ ~ ~ /.~.~ .~/~ ,, MAXIMUM WELL I Z ALLOWABLE INJECTION WELL STATUS NO. N O ~ J N CHART TOTAL TOTAL E TEMpIcHoKE 7"CSG 10"CSG METER CALC INJ INJ WELL F BEAN PSI PSI TOTAL MMSCF BBLS MMSCF SI/HR I/ GAS CORR FACTOR = ~~ HEADER PRESS = TOTAL FORD.S. DRILL SITE PROD TEST PROD TEST BATH BLANKET '~UN TIME HEATER TEMP TEMP PSI PSI TEMP GAS PSI OUT COMMENTS: CHEMICALS TYPE GAL/DAY OPERATORSSIGNATURE: ./~ ~/~ -. ~ 0~-01-87 15 T-65977~? NSK ARCO Alaska, Inc. . DRILL$1TE STATUS REPORT DATE: !-~ [-~:~'~ TIME: ~-,~..~O~'3 DRILLSITE_~ ~ ~/(~.LL T .~. PRODUCTION WELL STATUS GAS LIFT STATUS , . ~ ~ ~ ~-~ ~o ~' ~~ ~ .....f ....."' ., , , ,.. ~ ~ '' IE P ~ I~ o / ~o, ~o ...... - . , . , ..:= _ _ _.. -,, , , ,, . , _ t_ ,. .,. _ ........ TOTAL MAXIMUM WELL IN ZO ALLOWABLE INJECTION WELL STATUS J ~ ~ CHART TOTAl' TOTAL TEMPCHOKE 7"CSG 10"CSG METER CALC INJ INJ WELL F BEAN PSI PSI TOTAL MMSCF BBLS MMSCF SI/HR ..... G..A$,C,ORR FACTOR = .~. _ II ~' !,,~ HEADER PRESS = ~-, 3'~.-.~ TOTAL FOR D.S. , , : , , , , DF~ILL~'I:I;~ .... 15ROD TEST PR6D TEST ' BATH BL/[N'KET RUN TIME HEATER TEMP TEMP PSI PSI TEMP GAS PSi .......... ,N ~ 3~ Io~ !No, Z~ Zo zq OUT iqO I~0 . ~0 .1~0 ... CHEMICALS TYPE GAL/DAY too/o E. O~E.^TORS S'aN~,TU,E: m'"'~.'O COMMENTS: STATE OF ALASKA ALAS,-.,r, OIL AND GAS CONSERVATION COMI~:¢SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon © Suspend ~ Operation Shutdown [] Re-enter suspended well [] Alter casing '~ Time extension FZ Change approved program ~ Plugging [] Stimulate ~ Pull tubing r~ Amend order ~ Perforate [] Other 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100560. Anchorage, AK 99510 4. Location of well at surface 503' FSL, 743' FEL, Sec. 7 T12N RgE UN At top of productive interval ' ~ ~ 5. Datum elevation (DF or KB) / RKB 72 feet 6. Unit or Property name Ku~aruk River IJnii-. , 7. Well number 3A-2 8. Permit number Permit #85-205 9. APl number 5o- 029-21431 1340' FSL, 3332' At effective depth 1042' FSL, 34.46' At total depth 984' FSL, 3471' 11. Present well condition summary Total depth: measured 8690' MD true vertical 6302' MD FEL, Sec.18, T12N, R9E, UM FEL, Sec.18, T12N, R9E, UM FWL, Sec.18, T12N, R9E, UM 10. Pool I<~Jnar~Jk River flil Ponl feet feet Plugs (measured)None Effective depth: measured 8592' MD feet true vertical 8228' MD feet Casing Structural Conductor Surface X X X Production xxx,~L~xxxx Perforation depth: Junk (measured) None Length Size Cemented Measured depth 109' 4112' 8678' measured 16" 193 SX ASII 105' MD 9-5/8" 1100 SX ASIII 4112' MD & 340 SX Class G 7" 400 SX Class G 8677' MD & 250 SX ASII 8108'-8208' MD, 8357'-8397' MD, 8319'-8344' MD ~ue Vertical depth 109' TVD 3110' TVD 6293' TVD true vertical5863'-5939' TVD, 6051'-6081' TVD, 6022'-6041' TVD Tubing (size, grade and measured depth) -'-" J-55 9 4 lb/ft Tail ¢. 8254' 2 ~ ~ · ~ Packers and SSSV (type and measured depth) BakPr FHI @ Rl'llt~~. RRL,~ FR-1 r~ R2q,c;'. ~ = L, ,-, ,,., J~/I ~ 1~11:;' 12.Attachments Description summary of proposal ,~ Detailed operations program Convert well from oil producer to water i n~Pctnr 13. Estimated date for commencing operation January 10, 1987 BOP sketch r 14. If proposal was verbally approved /I/ ; Date approved Name of approver / 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~7 /''' ./~' C 't ' . . OC.r--~ Z ¢~ Title Sr. Operations Engineer Signed ..:( Dat&2/23/86 CommiSsion Use Only Conditions of approval Notify commission so representative may witness J ApprovalNo. ~ Plug integrity [] BOP Test [] Location clearance - . . / _.,...;:.~,'~..'.-,:.;~? ~j.,~.. ,.~.. .... ........... '~;:"~- ~i:.......~ .:~.,,' ]':':~'3~' ,.. Approved by ....... , ....,, ,~...; Form 10-403 Re¥-~12,4--85 .... '_" Commissioner Subsequen~ X,¥orl~ ! by order of the commission Date Submit in triplicate ARCO Alaska, Inc. Post Office Bc 3360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 31, 1986 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-11!9 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal =5806 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: --~iR-14 CET/CEL ~1R-14 CET/CEL 2A-14 CET/CEL ~u-~3A-1 CET/CEL -~f3A-2 CET/CEL -JJ.3A-3 CET/CEL --3A-15 CET/CEL 3A-16 CET/CEL 3C-15 CET/CEL ~a~3C-16 CET/CEL '~J3F-1 CET/CEL 3F-10 .CET/CEL --J~.3F:11 CET/CEL --3J-4 CET/CEL ~3J-6 CET/CEL 10-12-85 Run ~2 8600 10-13-85 Run =3 85.50 10-02-85 Run #1 6795 10-01-85 Run ~1 7550 10-01-85 Run #1 6680 10-01-85 Run #1 6080 12-30-85 Run #2 6400 12-30-85 Run ~2 7300 10-!5-85 Run ~1 5887 10-15-85 Run ~1 3995 ~1 700O 10-!7-85 Run ~ 12-19-85 Run #1 5166 12-19-85 Run ~1 6950 10-05-85 Run #1 6860 10-19-85 Run ~1 7000 - 9120 - 8894 - 7763 - 9467 - 8570 - 8256 - 8038 - 9030' - 7730 - 6753 - 8488 - 6483 - 8322 - 8410 - 8487 ~3J-9 CET/CEL 12-18-85 Run ~1 36 - 6678 Receipt Acknowledged:.~/, ...... / oo, . State of.Alaska(+ 1 sepi;a)~K Drilling Vault(1 film) ARCO AlasA=. /nc. is a Subsidiary of AlianlicRichfi~.idCompany STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COFvnvllSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG ' 1. Status of Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-205 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21431 Classification of Service Well 4. Location of well at surface 503' FSL, 743' FEL, Sec.7, T12N, RgE, UN At Top Producing Interval 1340' FSL, 3332' FEL, Sec.18, T12N, R9E, UN At Total Depth 984' FSL, 3471' FEL, Sec,18, T12N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) 72 ' RKB 6. Lease Designation and Serial No. ADL 25632 ALK 2565 9. Unit or Lease Name Kupaurk River Unit 10. Well Number 3A-2 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Date Spudded 09/02/85 17. Total Depth (MD+TVD) 8690' ND ,6302 'TVD 13. Date T.D. Reached 09/07/85 18.Plug Back Depth (MD+TVD) 8592 'MD ,6228 'TVD 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 09/08/85* I N/A feet MSL 1 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost YES ~X NO [] 1863 feet MD 1550' (approx) 22. Type Electric or Other Logs Run D IL/SFL/CR/SP, FDC/CNL~ CCT 23. CASING, LINER AND CEMENTING RECORD l SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 109' 24" 193 sx AS I1 9-5/8" 36.0# J-55 Surf 4112' 12-1/4" 1100 sx AS Ill & 340 sx Class "G" Top job performed w/100 sx AS 1 7" 26.0# J-55 Surf 8678' 8-1/2" 400 sx Class "G" & 250 sx AS II 25. TUBING RECORD 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 8357' - 8397' w/4 spf 8319' - 8344' 8108' - 8708' w/12 spf SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 8302' 8064' & 8283' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD)/AMOUNT& KIND OF MATERIAL USED See attached Add4ndum, dated 2/27/86. 27. N/A Date First Production PRODUCTION TEST IMethod of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested Flow Tubing Press. Casing Pressure PRODUCTION FOR OIL-BBL TEST PERIOD I~ CALCULATED , O L-BBL 24-HOUR RATE ~1~ GAS-MCF WATER-BBL GAS-MCF 28. CORE DATA WATER-BBL CHOKE SIZE IGAS-OIL RATIO OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED APR 0 3 i986 Alaska Oil & Gas Cons. Commissio~ Anchorage Form 10-407 Rev. 7-1-80 * NOTE: Tubing was run & well perforated 11/13/85. GRU1/WC01 CONTINUED ON REVERSE SIDE Submit in duplicate ' 30. 29. ( ; GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8104' 5859' N/A Base Kuparuk C 8202i 5933' Top Kuparuk A 8306' 6012' Base Kuparuk A 8464' 6131' 31. LIST OF ATTACHMENTS Addendum (dated 2/27/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · Signed ~:/~ ~)/,_,, ~<~~t._~, 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 23' Attached. s'U'pl~lementa'l :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-e21alain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 3A-2 Frac well w/297 bbls diesel, 1000# 100 mesh & 7480# 20/40 sand @ avg rate of 21BPM, 3300 psi. Turn well over to Production. Drilling ~uperintendent z Da~e ARCO Alaska, Inc. Post Office 00360 Anchorage, A~ar~ka 99510-0360 Telephone 907 276 1215 February 19, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton- Enclosed are the Well Completion Reports for the following wells' lA-14 1H-4 3A-2 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L147 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~,~'~ AND GAS CONSERVATION COmiVIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL _r~X. X GAS '~ SUSPENDED ~ ABANDONED ~--, SERVICE J 2. Name of Operator / ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 Classification of Service Well 4. Location of well at surface 503' FSL, 743' FEL, Sec.7, T12N, R9E, UN At Top Producing Interval 1340' FSL, 3332' FEL, Sec.18, T12N, R9E, UN At Total Depth 984' FSL, 3471' FEL, Sec.18, T12N, R9E, UN 7. Permit Number 85-205 8. APl Number $0- 029-21431 9. Unit or Lease Name Kupaurk River Unit 10. Well Number 3A-2 11. Fieldand Pool Kuparuk River Fi eld 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 72' RKB I ADL 25632 ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 09/02/85 09/07/85 I 09/08/85* I , N/A feet MSL 1 18.Plug Back Depth (MD+TVD) I ~ 17. Total Depth (MD+TVD) 19. Directional Survey 20. Depth ,vhere SSSV set 21. Thickness of Permafrost 8690'MD,6302'TVD 8592'MD,6228'TVD YES ~_--~X NO ~ I 1863 feetMD 1550' (approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP, FDC/CNL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE 16" WT. PER FT. 62.5# GRADE H-40 TOP Surf BOTTOM Surf 109' 9-5/8" 36.0# J-55 4112' 7" 26.0# J-55 Surf 1 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 8357' - 8397' W/4 spf 8319' - 8344' 8108' - 8708' w/12 spf 8678 ' HOLE SIZE 24" 12-1/4" CEMENTING RECORD 'AMOUNT PULLED 193 sx AS II I 1100 sx AS III & 340 sxJ Class "G" Top job performed w/100 sx AS 1 400 sx Class "G" & 250 ~x AS II 8-1/2- 25. TUBING RECORD SIZE I DEPTH SET (MD) 3-1/2" J 8302' PACKER SET (MD) 8064' & 8283' 26, ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST ', Date First Production I Method of Operation (Flowing, gas lift, etc.) ~FlowTubing Casing Pressure OIL-BBL GAS-MCF WATER-BBL !OIL GRAVITY-APl (corr) ; ICALCULATED I ', Press. !24-HOUR RATE ~ I 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SUbmit core chips. N 0N E Form 10-407 w NOTE: Tubing was run & well perforated 11/13/85. DAM/WC36 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH FORMATION TESTS · Include inter,~al tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 8104' 5859' N/A 8202i 5933' 8306' 6012' 8464' 6131' 31. LIST OF ATTACHMENTS Well History (completion details) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer 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 10407 AtlanticRichfieldCompany '~' Daily weli'History- Initial Report Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Dally work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska county or Parish Field Lease or Unit Kuparuk River Auth. or W.O. no. T t e AFE AK0243 North Slope Borough ADL 25632 Completion IState Alaska IWell no. 3A-2 Nordic 1 API 50-029-21431 Operator ARCO Alaska, Inc. Hour 11/11/85 2200 hrs. A.R.Co's W.I. Prior status if a W.O.. I Date Complete Spudded or W.O. begun Date ~nd depth as of 8:00 11/12/85 11/13/8'5 Complete record for each day reported 7" @ 8678' 8'592' PBTD, Prep to RIH w/3½" compl 10.2 ppg NaC1/NaBr Accept rig @ 2200 hrs, 11/11/85. NU & tst BOPE. scrprs & 3½" tbg. RIH w/7" csg 7" @ 8677' 8592' PBTD, POOH w/6-1/8" JB & GR 10.2 ppg NaC1/NaBr RIH w/scrprs, filter brine, POOH. Perf w/4" guns, @ 4 SPF, f/8357'-8397', & 8319'-8344'. Perf w/5" guns, 12 SPF f/8108'-8708'. RIH w/6-1/8" gage ring & JB. Drilling Superintendent 56.24% The above is correct Signature For form preparation a~l~ distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Oil and Gas ComPany Daily Well History-Final Report instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official-,est is not required upon completion, report completion and representative test data in bJocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ~County or Parish Alaska I North Slope Borough Field J Lease.or Unit Kuparuk River ADL 25632 Auth. or W.O. no. ~Title AFE AK0243 I Completion Nordic 1 Operator ARCO Alaska, Inc. IAccounting State cost center code Alaska IWell no. 3A-2 Spudded or W.O. begun API 50-029-21431 Complete Date and depth as of 8:00 a.m, 11/14/85 A.R.Co. W.I. 56.24% Date 11 / 11 / 8 5 Complete record for each day reported Iotal number of wells (active or inactive) on this est center prior to plugging and I bandonment of this well I our ~ Prior status if a W,O. 2200 hrs. I 7" @ 8677' 8592' PBTD, RR 6.8 ppg diesel in tbg & ann Fin POOH w/6-1/8" gage ring & JB. RIH, set Bkr FB-1 pkr assy w/top @ 8235' WLM. RD Schl. ND riser. RU & RIH w/3~" tbg & compl equip. PU SSSV & ts, to 5000 psi. Fin RIH w/3½" tbg, stab into pkr, drop ball, space out & lnd tbg. Set FHL pkr @ ±8056' WLM. Ts, tbg to 2500 psi. Shear off PBR. Re-lnd tbg. Tst ann & pkr to 2500 psi. Ts, SSSV; OK. Shear out ball. ND BOPE, NU & ts, tree to 5000 psi. Displ well to diesel. Ts, tbg & orifice vlv. Set BPV. RR @ 2400 hfs, 11/13/85. Note: SSSV @ 1863', EHL pkr @ 8064', FB-1 pkr @ 8283', TT @ 8302'. Old TD Released rig 2400 hrs. Classifications (oil, gas, etc.) New TO I PB Depth , 8592 PBTD I Date ~Kind of rig 11/13/85 I Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Dale Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR . Gravity - Allowable Effective date corrected The above is correct Signature For form preparation an(~distribution, see Procedures Manual, Section 10, 13ril~ing, Pages 86 and 87. Drilling Superintendent ~UB.~URFACE DIRECTIONAl. ~URVEY [~UIDANCE ~.ONTINUOUS [-+'] OOL Company , Well Name Field/Location ARCO AT,A~SKA I,NCORPORATEp , 3A-2 (503' FSL. 743' FEL, S7. T12N. R9E, LTM~ KUI~ARLTK. NORTH SLOPE. ALASKA Jol~ Reference 70913 i~: ~o_g~ed LESNIE Oate 31' -OCTOBER-85 Computed BOLA~ ~CT DIRECTIONAL SURVEY LISTING FOR ARCO ALASKA. INC. 3A-2 I<UPARUK NOI~TH SLOPE,AbASKA · · . ENGINE ,F.R ~ [,ESNIE ,. ~ETHr~L.)S OF cr)~PUI'A?IInN ' 'rO~L boCA'l.'!nN; '¥A'~!GFNT1A{~- averaqed devl.~tlo~ T i,.j'r E p Pn I~ A ? T ~]~; l,Ilk!EA~ and azimuth 3A-2. C¢'}l. iP UTAT I r)N D~'rE: 1-NOV-~5 PAGE DATE or SURVEYI 02 OCT 85 KELbY RUSHTNG EbEVATIONI ENGINEERI bESNZE I.NT~RPOt.,ATED VALUF...S FOR EVEN 1,00 FEF.,T OF MEA${IRED DEPTH 'CRIjF Si,JR-SEA COUPSE MEASIIRFD VFRTICAI, VEPTTCAL DEVTATION A.7.,I,~UTH DEPTH [)EP'r~i DEPTH DEG MIN PEG H.TN 0.00 0,00 100.00 IO0.UO 200.00 199,90 300.00 2q9.99 400.00 399 90 500.00 499~97 600.00 509,'1R 70n. O0 6q9.01 RO0.O0 7q7.,35 qO0.Oo 8o4,91 39 lg W 4.7 27 W 4-1 33 W S 41 5 w 35 54 W VERTICAL DOGbEG RECTANGUbRR COORDINATES SFCTION SEVERITY NORTH/SOUTH EAST/WEST FEET DEG/IO0 FEET FEET 0.00 0.00 '0,42 0,50 '1,13 0,94 '1.04 '0,58 0,46 0,77 2.9! 6.51 3 97 18.54 36.32 2,91 58.1.4 2,04 -7~.00 ~0 0 28 O0 0 25 ~27 9g 0 32 227 99 0 27 ]27 99 0 2~ 427 07 I 44 ~27,78 5 1] 627,01 9 2 725,]5 11 28 ~27.9! I3 48 [~4,~1 ?0 ~ ~107,~5 23 27 1 oOO, oO 991. bO l~OO,nU 1096.31 l~On.n{~ ! 179,05 1300 O0 1269 09 1197.69 26 27 1400:00 i358: 18, 1786.18 28 53 1~0o.00 1444:75 1377,75 31 1] {600.00 15~9 28 1457,98 ]3 13 1800.~(') ~ bq~ [9] 16lO,gl ]8 30 1900.o0 1768'~0 169~.40 41 4! 2nO0.O0 !841.17 1760,17 45 5 2100,n0 1909,5~ ln37,56 48 35 2200 O0 1974 21 1007.?1 gO lg 2300]00 ?037~51 io6S.Sl, ~i n 24On,nO ~100.27 202~.22 51 ~6 2~O0.nO 2162.5~ 209o.55 5! Jq 2600 oo ~2~.28 2152.78 52 o 2~OO.n{) ~3d5.34 2?7].]4 53 4~ 2o0o.o0 ~4n].54 2~31.54 55 2 3000.00 2460.24 2]~8.24 55 45 310o.00 ~516.13 2444.13 56 ~ 320~.00 2571.86 2490,g6 5u 6 3]0n.00 96~7.86 2555,~ 55 4& 3400.00 70R4.44 2&17.44 55 16 3500,00 ~741,77 266Q.77 54 40 3600.00 77q9.65 2727.65 K4 24 370o.00 ~858,35 2786.35 53 44 3800.00 ~917.90 2845,o0 5]{ 11 ]qO0,O0 ?978,26 2g06,~5 52 3! s ]4 24 w 83.97 S 34 17 w 115.65 S B1 4~ w 153'01 S 32 2 w 195.21 $ ]4 29 w ~41:73 $ 34 51 w 791.73 $ 34 58 w ]45.07 $ ]4 4] w 401,09 S 34 40 w 4b1,16 s ~5 ~ w 525.48 S 35 3~ w 59].ql $ ]5 41 w 666,69 $ ]6 10 w 74~.80 S 36 46 w 819.o7 s 37 ~ w 897.55 S ]b 56 w 975.44 ~ ]b 40 W t053.g] $ ~6 2~ W 1132,~ S ~b 20 W 1212.B $ ]6 30 W 129].60 S ]b 34 W 1375,]0 S ]6 3q W 1458.]5 ,, $ ]b 4a W 1541.09. $ ]6 35 W 162].65 S ]6 14 W i705.86 $ ]6 25 W 1787,55 S 36 18 W 1868,85 g ~5 58 W 1949.59 S ]5 45 W 2029.73 S 35 37 W 2109.29 3,81 3 4~ 2 73 3 20 2 28 2 27 1 69 3 36 3.13 2,96 3,59 3,29 1,22 0,64 0,26 0,50 0,55 0.54 1,47 1,16 0.71 0,20 0,29 0.69 0.83 0,54 0,72' · 0,65 '.~0,75 · ..,.. ,.%:... !'. .: ; ,. .' ~ ,v'. 72,00 FT ,.' ADI~'ARTURE MU?H ;',:",',DEG MIN 0,00 0,43 0 79 N 0 28 N 0 40 S I 52 S 5 60 S 1.4 57 28 05 45 25 0,00 E 0,09 E 0,87 E 1,51 E 1 73 E 0 99 E 37 31 W 0 0 E 12 8 E 3 3' $ 39 30 W 66 47 S 92 123 159 198 239 283 3~9 379 431 52 61 $ ?0 91 $ 90 98 $ 75 8 138 90 S 166 69 $ 197 71S 229 16 S 263 93 S 300 10 W 05 w 46 w 116 ~8 W 62 W ~45 22 W 26 W 40~ 49 w 46~ 43 W 526 487 82 S 340 14 W 594 547 608 671 733 795 858 922 986 1052 04 $ 382 84 $ 427 07 $ 4?3 24 $ 520 62 8 567 62 $ 6i4 26 S 661 6O $ 7O9 07 S 757 72 w 667 44 W 743 50 W 821 41W 899 57 W 977 70 W 1055 91W 1135 39 W 1215 61 w 1296 S 34 W 90 $ 30 S 35 !2 W 97 S 35 3f 20 $ 3S 4O 46 S 35 45 W 1710 95 S 124;,.:<6 W 2114 54 S 35 59 W Cr~PUTATiON DATE: 1 -NOV,-85 PAGB ARCh ALASKA, TNt. DATE OF SURVEY: 02 OCT 85 3A-? KELbY BUSHING EbEVATIONI K[IPARI!K NnRTH $l. OPg, ALASKA ENGINEER I IUT~RPO[,A~f;n VA~,UE;~ FnR EVEN ~00 FfJET OF ~EASURED DEPTH TRUE SU.-SEA COURSe.: VERTTCAb OGLEG RECTA.GUbRR COORDiNAtES HOR~'~ DEPARTURE D~C; M~N FFET DEG/100 FE~T FEET F~ nE?T? DFPTH DgPTH DEG M[N 4000,00 ]039,56 2067,56 51, 51 4100,00 31Ol,79 302g,79'> 51 4700.~() ]i64,~5 309~.85 50 5n 4~()0.00 ~278,45 3156,4~' ~'0 15 4400.~0 ~2q2 15 3720.15 50 31. 4500,n0 ~.355~S~ 3~83,88 50 4~0o,o0 ~4~9,9n ]~47,90 50 470A,oO ]484.00 3417,00 50 4 4800,00 ~54~,2Q 347b,29 49 55 4900.o0 ~612.87 3540,~7 ~9 5000,00 3677.8o 3605,89 49 510~.00 ]743,19 367~,18 49 7 5~0o,0o ~8OB.87 3736.P7 48 40 5Son Oo ]875 2n 3n03,20 5400~00 3942~03 3R70,03 47 55 5~00,00 dO09 36 3037,36 ~7 26 5600,00 4077~24 4005,74 5700,00 41.{5.40 go'/3,~O 5~00 oO 4213 73 4141,7..% a~ 52 5g00:Oo 4292~24 4210,24 6o(.)o,o0 4391.27 477~,72 46 2~ 6100,00 .~.~?O,o~ 4~4~.05 46 24 6200,00 44. gg,11 44.17,11 d6 29 6]0o,nO 4557.64 4485.64 ao 4~ 6400.00 4696,57 4~54.~7 4b 6500 O0 46q6,17 4~2~,17 45 45 6600:00 47&0,04 4694,04 6700,OO 48~6,27 470a,77 44 6R00,OG d907.41 4935,41 ~4 47 6900.00 4978°32 4006.32 44 50 7000.00 ~049,03 4077,03 44 7100.00 5190,1~ 504~,12 44 31 7?00.00 519~.69 5~lq.&9 43 5& 7~0o O0 5263.9& 519~.9b ~3 36 740o:n0 53~6.~7 5?64.67 43 6 770~.o0 ~556.8~ 5484.~3 A2 27 7gOO,OO 57o5,6o 5633,60 S 35 20 w 2188.15 S 35 17 W 2266,28 S 34 39 W 234],78 $ 34 14 W 2420.87 $ 33 12 W 2497.92 S 32 4 w 2574.97 S ]0 59 w 265~.79 S 30 ~ W 272~.5~ S ~9 n W 2805.05 S ~8 15 W S 97 2~ W 2957.05 S 96 37 w ]032,51 S ~5 4~ w 3107,53 S ~4 54 W S 23 57 W 3255 60 S ~4 ~ w 332¢:78 S 75 27 W S ?5 2~ w 3474,38 S ~4 19 W 3546,83 S 23 17 w 361R,94 S 23 54 w ]$9n 53 $ ~4 5 W $ ~4 ~7 W ]90~,18 S ?4 lq W ~978,d4 $ ?3 44 W 4040.15 S 23 3~ W 4~5q ~5 S 94 5! w 432~ 75' · 5 75 46 w 460,7 $ 25 37 w 453o.71 $ 74 ~! w 4607.84 S 93 37 w 4A75.84 $ 22 10 W q810.32 $ ?1 25 V! 4976,R5 S 20 5~ W 494~,84 S 90 26 W 5flOR,04 0,84 1,11 0,59 0,63 I 04 0:93 0,65 0,79 0,82 0,76 O,b7 0,64 0,82 0,85 0,75 1,09 1,30 0.81 0,73 0,68 0.76 0 71 1:54 0,40 0,86 0,42 0,21 0,98 1.02 0,15 0,44 0 83 ,90 0 54 0 58 0 41 0 80 0 31 · 1902 60 S 1378 1966 20]0 2005 2160 2226 2293 2360 2427 2495 2562 2630 2698 2765 22 S 1422 29 $ 146~ 17 S 150 67 S 1,546 79 S 1585 39 S 1.623 38 S 1660 38 W 2349 04 W 2421 W 256 6~ W 2651 59 W 271 42 W ~809 05 W 2885 72,00 let 56 S i695 54 W 296} 06 S 34 55 W 70 S 1763,21 W 3110, 4 ]l N 34 S 1.795 21W 3184 57 S 34 !8 N 07 S 1825 97 W 3257 87 S 34 5 N 74 S 1855 75 W 3330 $ 33 2832 44 S 1886 2898 46 W 3403 547 32 W 3619 3097 68 S 2007 10 W 3691 08 3163 98 S 2036 55 W 3762 3230 48 W 3834 3296 O0 W 3906 3362 49 3493 3558 3623 3687 26 $ 206 38 8 209~ 20 S 2126 82 $ 2155 41S 218 67 $ 2211 13 $ 2240 36 S 2269 99 W 4119 45 W 4190 4~ W 4259 54 W 4329 75 S 46 W 16 S 35 W 32 S 2 27 W }~ S 32 , AO 92 $ 32 0 35 $ 31 52 88 S 3t 43 W 83 $ 31 36 W. 3751 48 $ 2299 33 w 4400.06 $ 31 30 W 3815 12 S 2329 27 W 4469,97 S 31 24 W W 4539,49 3877 3940 4003 4065 4128 4191 4254 4316 94 $ 2359 51 S 2389 21 S 2417 8q 8 2443 68 S 2470 45 8 2495 10 S 2519 30 S 2542 78 S 31 19 W 13 W 4608,21 S 31 13 W 10 W 4676.33 S 31 7 W 97 W 4743 89 S 31 0 W 03 W 4811 14 S 30 53 W 11 W 4877 89 S 30 45 W 36 W 4944 14 $ 30 38 W 83 W 5009 63 S 30 30 N DEG MIN 3s se w 4 N 13 $ 17 N iS $ 7 w ARCO ~[jaSKA, TNC. 3~,-? KIIp~NI. IK NORTH ST.OPE, AT,A~KA PAGE 3 CObiPUTAT Ir~N L) ~.~ TE: 1-NOV-B5 DATE OF SURVEY i 02 OCT 65 KELLY BUSHIN~ EbEVATIONi INTERPOI,ATED VAI,,UE$ FOR EVEN 100 FE~T OF MEASURED DEPTH TRUF SUB-SEA ' COURSE ~£~$))HFD VFRTICA[, VEPTTCAL DE'V)ATION ~ZIMUTH DEPT. DFPTH DEG MTN VERTTCAL DOGbEG RECTANGUbAR COORDTNATE$ G~CTION SEVERITY NORTH/SOUTH EAST/WEST FEET DEG/IO0 FEET FEET 0,55 4378 0,90 4440 0 42 4501 0:78 4562 0,28 4623 7,39 4684 0,00 4745 0,00 4799 46 S 2565 79 W 507 25 $ 2566 16 W 51 37 $ 2610 59 W 5 77 $ 2633 06 W 90 $ 2656 )2 W ~ e4 $ 2680 12 W ~$9; 17 S 2705 33 W ,4.2 4' S 2728 04 W $520' 8000.00 57~0,5n 8100,00 5855.87 8200.00 8~00 nO 6007.44 8400:00 60~3.0~ 8500.00 fi158,71 8~00,o0 ~234.3~ 8690.00 6302.4~ 5859 ),:::: 4'0' 45 " "40 ~7 60115g]5:~ 4:50 0 6086,71~ 40 40 615~,38' 40 50 6~30,46 4050 $ ~O 4 w 5072.9] S 19 55 W 5137.20 $ ?(,) 6 w 5200,93 S ~0 28 w 5264.92 S 20 5.4 W 5329.09 $ 72 3~ w 5393.40 $ 22 ~1. W 5457.03 S 22 4~ W 5516,03 72,00 FT ~ DEPARTURE, AZIMUTH :':~ DEG NZN '8 2~ ARCO 3/', "" ? NI3RTH 'aEASIJRF[;' V!!"RTICA!, VET~'rTCAb DEV:rAT].OI~ DEPTH D~PTH DEPTH DEG DATE DP' SURVEY I 02 OCT 85 KELLY BUSHING EbEVAT~ON~ ENGTNEER ~ ~ESNfE INTFRPOT,ATED VAL~JES FOR i~.:VEN !000 FEET Of' MEASURED DEDT VgR'r~cA[, D;3GbF. G RFCTANGIlbAR COORDINATES HORIZ,.' ~EPARTURE ~EC~ION ~EVERITY NORTH/~OUTH EA~T/~EST DX'ST,~ Z~MUTH f'E~:T DEG/~ O0 FE~T FEET F~T '~, D~O MXN O.uO 3.81 3,59 487 0.71 1.118 0,84 ~775 0,67 2427 0,76 3097 0,44 375~ 0.55 4378 0,00 4799 n.oO 0,0o -72.00 ... 0 o l~O0.Ou 901.50 919.50 16 37 2000.00 ,841.t7 176g 17 455 3nod no ~46(,.2~ 23~:2~ 55 45 4000"0(; ]0~9 56 2967, ~5 51 5~ 5o00,o0" 3677~8o 3605,89 49 20 6000 DO ~35!,22 4~7~,22 46 25 700o~0() 5049.0~ 4077,0] 44 5] 8o00.o(, g7flO.bo 57og.50 41 27 8~9o.00 &302.46 ~73o,46 40 50 0 O0 N 0 O0 E ~' 66 47 $ 52 lO W 8 72,00 FT 82 $ 340 14 W 59 25 S 806 64 W 1.37 24 S 1288 48 W 56 S 1.6 95 68 S 2007 10 W 369 48 5 229933 W 440 46 $ 2565 79 W 5074 4~ S 2728,04 W 5520 ARCh ALASKA, T. NC. 3A-~. KIIpRR[IK NnRTII SLOPE,At.,AAKA CONPUTAT[ON DATE: 1-NOV'85 'rpuP SUB-SEA COURSE ~EAS!IRF.,D VERTICAl, V£~'rTCA[, 'DEVTATION AZIMUTH DEPT!! DRPTH nEPTH DEG M~N O~G ~I~N , , 0'0'0 0 22 100 O0 0 3~ ~0000' 0 27 ~On 0'0 0 23 0.00 72,0() 72.00 ~77,~0 172 O0 77~.01 272~00 ]77,01 372 On 47~,02 472:0n 579,13 572,00 67~,&9 774.15 772,00 R76,43 872.0~ 07~.70 972.0o 108.4.76 1072,0o 119~.34 1172,00 t~O? 58 ~272 O~ 1415~78 1372!00 1531.98 1472 O0 1651.~5 1572.0n 177a ~q 1672,00 1004'fl3 1772.0n 2044:32 ~872.0n , . PAGE 5 DATE OF SURVEY I 02 OCT 85 KELLY BUSHTNG ELEV'ATIONI 72,00 FT ENGINEER) LE~NIE INTERPOI,ATED vA~,UES FDR EVE~ 100 F~ET OF SUB-SEA DEPTH VERTTCAL DOGLEG RECTANGULAR COORDINATES SECTION SEVEPITY NORTH/SOUTH EAST/WEST 400 O0 1 2 500.00 4.12 600.00 7 53 700'00 10 56 ~00,00 13 20 21.96.~5 1972,00 2354.94 2072,0o 2515.93 ?172.00 2678.14 ~272,00 2845.47 2372.0o 3020.o6 2472.00 ]?00.95 ?572.00 337P,]3 ?b72,0n 3552.~2 ~772,00 3723,0~ ?872,00 FEET DEC/lO0 FEET FEET -0.73 -0.97 -0,73 0.09 4.31 14.54 31.40 52,61 ~ 34 30 w 78.31 S 3~. 26 w 110.44 S 31 54 W 150,02 S 32 6 w !96.36 S 34 3~ W 749.34 S 34 55 W 30R.44 S 34 50 W 3'13.51 $ 34 44 W 445.50 c 35 1n W 52870 S )5 43 W 625:69 g00.00 15 48 1000,00 ~9 46 1100.00 ?3 14 1200.n0 ~o 3~ 140o.o0 3t 57 lEOn,no 34 1600.00 ~7 43 170n. OO 41 49 [ROO,O0 46 40 1000,00 g0 17 2oOn,oo 51 lO 210o.o0 51 47 2900,00 52 3? 2lb0.oO q4 21 2du,.nO 55 53 2~oo,no 56 6 2600.00 ~5 2~ 27uo,On 54 37 2PO0,O~ 5] 34 5 t7 4 W 862.57 S 3b 53 w 987.34 S 36 30 W 1115.51 $ ~6 2~ w 1749.95 $ 36 35 W ~ ]6 4g W 1541,29 S 3b 14 w 1687.q2 ~ ]o 24 W 1830.12 S ]5 5~ W lgs~.~t S 35 38 W S 35 27 W S 34 36 W $ 31 46 W ~ 30 17 W ~ 28 46 W $ ?7 30 w S 76 13 w F 94 57 W 2101.12 2229.10 235~.54 2473.42 2594.39 2714.15 2833.14' 2q5n.22 3065,59 3178,]0 0.00 0,54 0.78 0 21 0 37 2 19 3 14 5 12 1.87 2,62 3,27 3,57 2 87 3 18 2 26 2 40 2,97 97 ~'55 '1 18 0 41 0 36 '.0 51 66 29 . ~9] 0,80 0.50 0.70 1,21 0,99 0,7] 0,81 0,66 0,89 % s.s ., ~ . 0,26 N 0,01 0'76 0 46 4 08 11 54 S ~ 98 3889,69 2972.0o 2qon.o0 52 36 4057.]1 3072,00 3000,00 51 30 4211.32 3172,00 3100,00 ~0 4F 4368.~8 ~272.00 .)?OO,nO ~¢) 31 452~.74 ~372.00 3]0o.00 ~0 14 4681,97 3472,00 3400,00 qO 6 4~36,79 3572.0n 3KOO,O0 49 4R 514],o9 ]772,0n 3700.0{~ dB 57 5795.?0 ]872.0o ]~Uo.nO ~8 14 DEPARTURE AZIMUTH :DEG 606,70 88 499,20 864 805.17 74 908,30 ~ 574, ~ 989 651,58 ]016,28$ 731,18 ~ 1117251 132,18 S 816,98 396 1251,49 905, ~ 544 369,58 903.64 692 1484,46§ 1078.16 W 1834 596 18 , 1159,87 W 1973 98 44 96 57 68 09 ~ 35 36 ~ 1704,29 237,79 2106 35 35 59 18086 312.3, 2234.59 35 , , ,75 ~ 2599,92 578,36 2719,31 ~ 35 28 ~ ' 637,04 ~ 2837,79 35 13 Cnl, iP{~TA'TI ON U A'].'F..,: 1 ,,,NUV-g 5 ARCO AL.,A~KA, Ti~C. NOR'TH ~I,OP~, AI,ASKA £NG.TN~gR: INTERPOI.,A'~ED' VAI,LtE$ FOR EVEN 100 FEF..T OF' 5U.P,.-SEA DEPTH ']PR U F SURT~EA C 0 [J R L-, ~ VER'~'[CAB DOGL~C RECTANGUDAR COORDINATES WL'AStlHKI'; VW. RTICAI. VER ICAb DEVIATION AZ1)4U~H SFCTION SEVERITY NORTH/SOUTH EAST/WEST DEPTH I)FPTH D~PTH DEG MIN PEG i~N FEET DEG/100 FEET ~EET s 73 39 w 3288.39 S 25 20 w 3396,05 S 74 57 w 3502,63 $ 73 25 W 36('38,24 R 24 ~ W 3712.22 $ 23 41 W 3616.14 S 23 52 w 4024.54 $ 23 25 W 4]25.96 ~{ 23 26 W 4225.25 1,59 0.83 2924 0,87 3021 0,30 3117 1.11, 321,3 0.69 3310 0,43 3405 0,40 3499 0.84 3591 PAGE 6 PATE Or SURVE¥I 02 OC~ 85 KEbbY BUSHING EbEVATIQNI 72,00 FT 2728 j8 S 18~ 2827 36 $ 18 5444.6'7' )972.00 3qO0,O0 47 42 5592,!2 4072.00 4000,00 ": 47 ~ 5738,95 4172,00 4100,00. :46 53 5~85.10 4272.00 4900,00 46 37 &n30.19 4372,00 4~00,00 46 30 617~.~O 4472.00 4400,00 46 10 6320.~5 4572.0o 4500,00 46 40 646~.]2 4672 OO 460n.00 45 51 660, 54 4772:00 ~700.00 45 40 6750:~2 4872,0o 4~00.O0 44 36 10 $ 1930 33 5 1974 68 S 201 84 8 205~ 22 $ 2 02 S 2166 O0 8 2226 DEPARTURE AZIMUTH .PEG MIN 03 w 35 w 33 2 03 W 360! 33 9 21 w) 42 W 41 6 S 1 5'9 W 56 W 4225 27 S I 48 W 6~91.O7 4972.00 400n.00 44 5P 7032.39 5072.0n 5000.00 44 45 7172.61 5172.00 510n. O0 44 9 73~1,~3 5272.0n 5200.00 ~3 ]] 7446.~9 5372.00 5t00.00 42 5~ 7584.~5 ~472.00 5400.00 42 45 7720.~3 K572.00 5~0o.~0 a2 ~ 7955,~0 5072,0~ 5&OO.OO 41 ~7 7988 65 K772.00 5700.n0 ~1 .{o 8~21:21 5872.00 5900.o0 40 3~ 6253.16 5972.00 5qO0.O0 40 50 8385.30 6072.(30 OO00.O0 d(3 57 8517 54 6172 O0 6100.00 40 50 864g~74 g272:00 6900.00 40 50 8690.00 6302.4~ 0930.46 40 50 $ 2g 4q W 4323.4.8 S 24 59 W 4422.59 g 25 50 w 4520.29 S 24 23 W ~61~,47 S 23 10 w 4708,40 $ 22 17 w 4800,19 S ~ lg W 4~90,45 S ?0 36 W 4978.86 ~ 90 P W 50~5.58 $ ~0 4 W 5~50.67 S, ?(') 3 w 5234.q3 $ ~o 53 w 531g,62 S 22 41 w 5404,70 S 22 4~ W 54.90',~4~ $ 22 4] W 5516,03. ~' ~3 .. ¢ ,. . 0.29 0,65 1,00 3860 1,27 3941 0,60 403 0.60 4119 0 61 4204 0i59 4268 0 50 4371 0 73 4453 0 46 0:44 0.00 0,00 0,00 36~1 63 8 2266 88 W 4323 55 S 31 37 W 3772 94 W 4422 74 S 31 28 W S31 20 W 51 8 2392 42 $ 2430 16 $ 2466 33 S 250 42 $ 253~ 2O ~ 25 52 W 4520 32 W 4615 16 W 4706 16 W 4800 16 W 4691 39 W 4990 22 W 5067 86 W 5153 54 95 S 4 w 99 S 54 w 54 S 30 44 W 32 $ 30 33 W 46 $ 30 23 W 05 S 30 12 W ARCO A[.,/~SKA~ TNC, KIIPJ~RIIK NnRTH ,SI',OPE,AI',ASKA ~'~ A R K F R Tnp KIIPAR~K C HA,.5~ WJlPARIJ~ C TnP KUPAR~K A BASF~ ~I,.lPARUK A P~TD Tn IN'rWRPO[,ATED VA[,OMS Ft~R CHDSEN HOPlZONS ~202.00 ~300.00 ~592. OO 8OqO, O0 DATE OF SURVE¥~ 02 OCT 85 KELhY BUSHZNG EIoEVATZON~ 72,00 FT ENGINEERt LFSNXE ORIGIN= 503' FSL, TVD FRO~ KB SUB-SEA 5858.~1 5786 91 6011.98 5939,98 6!31.44 6059,44 6229.33 6156.33 6302°46 6230.46 RECTANGU~A~'.~!~ NORTH/SOU,~OI~'RDINATE$ 4 02. 0 ,',~:C.,' 4566.44 ~'",,' :,,,2~34.44 APCD Ak, ASKA, TNt, KIIPARI!K NORTH ,ST,~OPE,AI,ASKA TOP KUP~,R~IK C BAB~ KUPA~U~ C TnP KIIpARIIK A BA~F KUPAI~UK A CD/-lPUTAq'ION DATF,: ************ ST~ATIGRAPHIC ,, g202,00 '8306,00 R46~.00 8592.0n goqo,o0 1-NOV-85 SUMMARY DATE DF SURVEY I 02 OCT 85 KELLY BUSHING ELEVATIONI ?2,00 ENGTNEER~ ORIGIN= FRO~ KB SUB-SEA 5858.ql 5786,91 5933.29 5861,29 b0~.98 59]9,98 6131.44 6059,44 6228.]3 6156'33 6302.40 ~230,46 SURFACE FE~. ~ RECTANG NORTH/SO 4502, 45~.44 46 ,0~ 4740,]4 4799,48 FT :ON N. RgE, UH 'r/#EST MF, ASI.J PEn DEPTH T~. VFRmlrAT.. DFPmH 6]07.46 AT TD: SUB-SEA VERT~iCA[, DEPTF! 62"~0.46 HOR.T ZflNTAL, DEPARTURE DISTANCE AZIMUTH FE~T DF, G MIN 5~20.62 ~ 29 36 W SCHLUMBERGER O I REC T I ONAL SURVEY COMPANY ARCO ALASKA I NC B-2 WELL 3A-2 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOED REFERENCE O000?OBI3 WELL NAME: 3A-2 SURFACE LOCATION: · ' FSL, 743' FEL, S7, T12N, R9E. ! t~I~IZONTAL PROJECTION SCl:L;'. 1/]000 ]H/FT -40(X) - ~l(:l:l -;g~(:~ - 1 ~ 0 ! 0(:30 ~>000 3000 £~ST WltLL NAME: 3A-2 SURFACE LOCATION: 503' ~ gL, 743' FEL, S7, T12N, R9E, U1v. VERTICAL PROJECTION 91. -ICI:lO 0 0 1 ,_ ~Vi'~ 2CX~ 3(XIO 4000 ~.+~-r~~.:+~+~+~ ~ i ~ ~i ~ ~.[.~4~-->-,:--~4-+-H--¢~-.~i-~.,.~4.+.H--,:'.4+..+,"4+~.-~-+.~-.~.- ..~--~-..~...~,..~4..~-..~.. ..~..~4..~..~..~..~.. -~~..~4~4, ,~ ~ ' ~ ' ' ' ', ~ ~ ~ ' ' ~ ~ ~ ~: ~ ~ ~ ~ ~ ~ ~,, ~ ' ~ ~ ..F~...~..-Fk~.~..~..~....F~...~..~..~..FF~4.. ~.-4 .~*--~- ~-~-~?-~?. ,-.~--*--*-.*..4.-t-.?----?- -.~--*-~-.-..{--*..*.-,-.*... --t.~--~.T- ~-~ ~ ~ ~..74 ....... ~---.~:.-~?+-,t-r-?:--~-?-??-?.t,-??-~-?.- "~'r'??-"??-~"~-' ..?-r.r?,~--?-t-.??.. ~-?r't-.:"~"?.~.-~--t.. .,~.~..-~ ~ ~.._~.~;~.~_~ ~+.~.f_~..~..~-,.~.f~.~_~..~...~..~..~.f... ~?~. "~"~-~+'t'?'f"~"~" ~'~"~"+"~"*"f"+"?'~- -~4~~.~ ~ .~. ~-L.~-~..~4~ ..~.4-~..~=~-;..~4-~.~..;..;..;..~.~..~.~-~....~..~.~..~.....~..~..~..~....~.;..~..~..,-~..;..~..~.. ~.~..~..~..~-~..;..~.4..~.. 4.4...~.,~..~.~...,..~..~..~..~..~;..;..~..~4. ~-:.,-~..-~..~.-s..~ ..... :-:~"~"~ .................. ......~ ~;~~.-~ .... ' '-.~---:..~-.~ ....... ;--~.-;--;..~,-;..~--~ ....... ;: ~::: ]. :~--;--~-.~.-.--~--;..~ ~-....~..;...~-.;..}..~-.~..~..,-.] ........... ;.-;-.;..~..~..{ ....... ;::~..~.. ~.~s~.~-~.444~4~;~4.~.~.~L.~.~4-1~s.~.~~..~.s~.~ ..~..:..~..~..~ ...... ~..:....,~-~..~.4..t..~..~..~..~.. L.:-.:..~.;,.~..;..~.4..:.. : : : : . : ; I : ~ : : ; : : : : : : : : : : : : : : : : : : I : : : : ~ : : : : : : : : : : : : : : : : : ; : : : : : : : : I : : : : -.~-e..e.-~-~.~-e~-- -.~=~.~.e..e-e.- ~.~..e..e..~.4.e.~.e-d .~..e-e.-e-~-~e-.~.--~-.. ~-~--.,..+.-~..~..e.e.. --~-~-.~.-e..~--e--e..e-.~....e-~-..~.- -.*-.~--e-.~.. ,,4.-~..;.,.p-~--~-4--;-~- ";"~$"$--~--$.'$--s--~-.' ,'-~..-~-.,b-~-.~..-;--~--s--s"~ "$--~";"$" p'~"*"?" ~"~'""-~"$~-~-';~ ~;-$-~.-~...]...~-.s--$-.- --$--$-.s-.$..--~'4..~ ......... -.~..~..~.,~.~.~..~..:..~.. ~.~.~$~..~4~.~L~4~4~..~.:.~4~.~..~F~u~ ......... ~.4.. ~.-~ ~.~..~..~..~.:..~..L.L...~..;..~...~ ...... ~..~..~..; ...... ~..~.4..;,.~..:..:..L.;.. --~..?f.+.~-?+- --~.~.f.+.~..s..f..f.4,..-.f~..~.4.4..~-~.~s- ..$.~-f..~..~.~..f..~......f..f..f..~L~-+~ ~_~_~4.4.+.~..~.~...s.+.f.4......~..;..~..f...-.;..s..~...;...F.,..;..;..;.. -.~.~.~.~.;-~.-~.4.. -.~.~.;..~..~-~.~..~.4.-.-~..~.-~..~..~.-~.-.~4..~- ..~-~..~-~;..;..~......~..~..~..;...p~..~.3..~.. ~..~..~..~..~..~.-~..: ..~.4..~.4..,...~..~..~..;., ,..~..;..~...~-~..~..~..~.,~-. ..~ ....... :...~-L.~.~..~-4 ..... ~--~.~.4..~..~..-k.;---~-.....~.--~..~-.$..$..;---~--.k.~,- -.~.4 .......... ,--*-~-.~-., ...... ~.-~..-~..S.. p~..~..;..~.. ~4..~ .-,-.~...k.~.....~.,~-.~.-~ ...... P.~..~.4-...~..;.-:...;.-,.-.;.-;..k-;.. ., .:...~..$..+L;...~ .~...~..~. ~. ~..L~..L.;.. F-.L4.....$.-~.-~-.;..~..+-..;...F.~,..4..~ ,i..$.. L,$..~...;.4.. -.~...L..; .~.+..~..~..~.-;... ~.. ;..~..$..L~4.. i. :..4...L. ;..~ · ~ ........ ~-4.....~.-;-.:. L. ~.. ~..-:. ~.. '.. : ; : : : : ; : ; : : : I : : . : : : ~ : : : : : : · : : · : ; : : . · · . . ; : , . · . : : , , ' : : : , ; : : : · , : ~ : : ........ ~ .......... ~ ..... ~..~.., ............... · ........... ~ ................. ~--~-~ .......................... ~ ...... , ..... ~ ........... 14..;..~..~.,,~.~ ...... . ....... · ...................... ~ : : : : : ; : : : : : : : : : : : : : , : : : : : : : : /: : : : : : : : : : : : : : : : I ~ :- · : : : : : ; : : : I : : : : ........... ~.~.g ..-~ ............... ~ ................................. ~ ......................... 1.4 ........ k. .............................. ~.~ .......................................... .............. ~ ............. 4 ........................ [ ....................... ~ .......................... L ........... [ ............ , ........ , .............. ~ .... ~ ........... ,4 ~ I I I · ~ ; I i : ; · : I ; I , ; : I I I : I : : : I I [ : , I ' I I : : I ~' : : 1 - : · -- .-,..~-.~-+~.~.~-...,.-~.~,~-.~..,.,+...>--~ ...... ,.-~--T..~....~.-~....~-- ..~.-~--~--,--,-.~-~--v.-...~..~--~--~..~..~.~..,.-,.. -.~.-~--.--~-4-~..~..,-~-. -.~..,..~--.... --..-~--~..,.- ,-.,,.~.-,-.,--~.....-~..~..~.. ~ ~ : : ~ : ; : ; -: : : : . ; : : : : : : : : : : ; : : : ; · : : : ; ; ; : : ~ : ; ; t ; ; ; : i : : : t , : , : : : : ; : : : : . : ; ; : ; ..a.~.¢..;-.~-¢-~.-~ .... F.¢--~..¢..~..~..4.-.~..~..,-¢..~..¢..~.. ;.4..~..~..~....~..~..~.4..~.~...$..¢..~...-.~..~..~..~.+.;..~..~..~.. :..~..~-:..~-.1.-~.-~-.;..~-~4-.~4-4 ..... ~..~..~..~.. ~.~4..~..~.i...L;..:..;.. · .~..~.4..~..~..~.~ .... ~..~.~.-~.-~..~.4-..$.4...,..~..~.4..i.. L4..~.~.4....~.-~..~..~..~-~.~.-;--~.....~..~4..~..~4.4.4..;.. ~..~.4..~..~..{..;.4..~..~..:..~..~.4..~ .... i. ~..~..~.. ,. ~..~..~.~..~...~..~..~.. 4-4.4-.~-,-.~.~4~.- -4-.~-~.~$..~-4.4.--.~..$..~..$.. ;-$-.$..$.4-- --$-.~-~.~.-~-~e--~..$--,-.~..~-~..$..f-~..~.~.. ,.i.~4..~..$..i,.i.-~ --~..~--~.-,--~.4..~.-i--.-.$.-~-~--4--~-$..$--~-- ~ ~ I : · : ~ : : : : ~ : : : : : : : ; , : : : : : : : : : : : : : ~ : : ; : : : : : : : : : ~ : : : ; : : : : : i I : : , : : : : ....... ~ ....... ~...~ ..................................................... ~ ......................... ~ .................. ~ .................................................. ~ .............. : : ~ ~ I ~lllJIJI : : ~ : : i : : : : · i : ~ : : ' · -~.,4.4.~-~ -~-.~--~-. 4-. -.~-~.$--~-. .-~-4-4--4--..-.4-4--~-$-- ,-4-.~-4--~- ,4-~-.~..4. -4-4-.4.-~ ...... : : : : f : : : :P'~"4"4'- -~--~-4--~.- ~--~--$.-~. .~.-~ .~.~--...4.4.-4.-4-. ~.4..~.-~- .-~--$-.~.-$,. : : : : /.~_~.: : : : : : ; ; : : : : ; : : : : : : : : ~ : : : ; : : : · · : · ~ : I : I : : : : : : : : : : : .?..?.?.? ....... ?.,..,..?...74.,..,..,..,.. ..~.4.&4..~.~4....~..~.4..~.4..g..~4.4.....~..&.~44..~.~.~ ~.4-~4-~.~44..~...-.~..~..~..~.-L~..~..~.~....4..~..~..,..1-~..~ ..~.~-...~..~..~..*...-~..¢..~.4-.F.~.4..~..~.. ~ ~ ~ i ~ ' ' ; ~ ; ; i ' ~ :: : I r ; ; i ; ~ i ; ; : ~ ! I: r ; T , : ~ : ~ T ~ ~ ~ . : : : ; : ~: ; : r : : : : : : : : : i ; : : : -.,..,-.-,-.~--1--~-.~.-4 ..... ,--,-.,.-,-4..,..,..~-.,... --i..~..~--i--1-~-..--~-.$-- ~i---~-----~-.~.~-.i-i--i--~ --~-.-P-~--$..l-.~-.4.-i-.i.-,..~..i--~-.i..l..i-.$..i..i-...~..~.-$.4.-~ -.i-.i.-$.-.--. -i!+5-~--f.a-j-..i+H--f.f.i..f{--. "i"i"i:~~ ~...:S~-~0~ ~f.~--~-?'"~'"i"i" ~''* +'i {"{+ ++-4.-? .-~-+-+.-~ ..... ~..¢.i--i--r-?.H. ~- ".. '?', '~". ~ffi'. .... ~'~'?'?'.'-. '?". '~ ..... .'- .- J'. , . "? :". ' ~'T'~w'~-*-~"?-,"~ ". '?-'?.-'1-'??' .-- ~ ..... . "~'-75"~--.-',-','-,-' '-,-'??-.-'~ "?',"~-'? ~--,-?--.'-,-' "'~'?-,'-? -.&4.-~.-&4--¢-.~.4.- ..~.~-¢.4--..--~..¢..¢..¢..&.4..&-&-¢~ ~.~-¢.4--&.~¢-.¢..¢.-: .-¢.-;..¢..¢..~..¢..&.¢..¢.....;..¢~¢..¢..~..¢-..p-¢..¢...;..¢..¢..;.....;..¢..¢..¢......,-.¢..¢.4-. · .$..LLL~.LL$~.- ..L.~..LLt..LLLL...LLLLt..LLi.~- ...~Li..!..LL.~..L...LLLLI..i..i..~..~......~..,..~..,.....;..,..~..,....~..;..~.~.....i..i..:,.i.....:..;..;.i... ~'~"~"~"t': ~..,.4..:...~.; ,.-~ , ~-,. ,- ..;..~ ....... ~ .*..:4 .-~-4-~. *"t""~4"~"~. , l · · : . : . . · : . . : ...... ; : : ~ . . : ......... "."?'??' "~'?'~"?'"'~"??'~"'"~"."t"." ~'~"?""~"?'T't ..... .'?"~". ..... ?'~".".'" '~'f'?'~'r'f'f"f'? "f'?f'f'f"f'!-i-f" "i-'f-~"f-f'i-'f-f-k '-f--~-i-f"f'i-f'f-i"~ "?"f't'f'T"f'}"~?-kf'f~' '"!"~ ~ ~"i"f" "f"i"t'f'" .~-.~,~.~..~-~.~...-~--~.~.-e.-~.-~..~.-~..e--e.-~--~.-e,.~---~.-~-. ,-.~-.~..~.-e-~--~-~--~.~-.~--~..~--~.-e--~..~: ; ~ ; ~-~.. ~- ~ ~ ! ; ~.-~.~--,--~.,~.-~..~-..-~-+..~--. : i ~ ~ i : : ~ i ~ i ~ ~ i i i ~ ! i i i ~ : : ~ i ~ i ~ t : i i~ : ! I : ~ : : : : : : : : : : : : I : : : : i : : : : : : : : : : : : -,-~..~--~--~-.~--~-~-.~--~ .... ~--~.~--~--~.-~.-~--~..~-----~..~.-~.-+-.~-.-P.~--~..~--,--~---~.-~-.~-~--~---~..~-.----P-~--~--~---~-~--~-~.;--.--$.-4-4--~ ..... ;-4--~--~ ~-.~.~.~--~-.~-~- --~..~--~..~ ...... P.~..~.-~-- ~ · : : : : : : : : : : : : : : : : , ~ : : ; ; ; ; : : : ; : : : ; : : : : : : ; : --e-- ~.-~-.~4--~--~--~-?- .'~--~--~.-~--~--~.-~--T--~.-- '-~'-~--~'-~---~-.~--+-.-~--~- .--e-~..~-.~--~-~-~-.~--~-- ~ -.~.-.~--~--~-- ~.~-- ..~.- ~ -~.~. ,-,~.~.~.. ,.~.~., -.~-.~.-~--...~-. ~..~..-~.-, -.~--?.~--~.., · -~-~.4-~.~-~4-~.4.-..~..~.~..~..~..~..~..~..~..~..~..~..~..~..~..~..~..~..-~4-~.~..~.~..~..~..~ ~ ~ ~ ~ ~i i~.-.~.-~--~-~ ~.--~-.~--~..~-....~..~..,.-~--,..~..~--~-.~-- · ~4-.4-.~-~..~.4.- ..~~.-~-~--~.-- -.~--~.-~,-~.-1-.~..$..~.4- ..-4-.~--~..~-~--~-4--4..~-.~ --~-~--~.-~.-~-...~..~--~-. ,-4-~-~ ~-~..~ .... ~.-4..~.-~.-, ..~..~..~..~-- -.~-.~..~.-~.., ................. ~ ................... ~ ........ ~ .................... L4..i-i..: .,-.~.: .i.4.-~ 4..~.4-~I..: .i..4..: ..~.~;4...i i..i.i..-4, i~4~ :.~-~ ~ ~ ~ ~ ~ : : : 1..: :. :..~ : :.4..: ~.;.;.: .4... ~.:..4..4..i..4..4..4..4.., ~ : : T~ : ~: : i ; : : : ~T ~ : ~ : : : ; : : : : : : : : : : ~/ : : : : ~ ~ ~ i }I~ ~ : TT : ! : : ? .... : : : : : ................................................ ~ .................................. ~'~ ............... ~ ................ t ......................................................... ~ ............... -.~.i..I..~.~ ..Li..i.~.., ,.,LLi..Li..Li..LL i ..LL.~A... ,..Li..Li-,..i.~.,LL L.~Li.~., ..LLi~.., ..i..i..i..i..i..i..i..i..i... ,..Li..LL L4..LLL...Li..LLi..L.LLL, : : : : : : : : : ; : : / : : : : ; : : : : : : : : : : : : : : : i : : : : : : : : : : : I : : : : : : ; : : : : : ~ : : : : : : ; ......... ~ ......................................................................................................... ~.~ .............................................. ~ .............................. 1 ............... -.;4.4..~.~..~..~..~..4...,.,4-.~4..i..1..~..~..4..4.. ,.;..~..i.4... ~.i-~4-.,..~4-~.~--.~.,4..4...,4..~i-~-..i..i..i..4..1..;..4..;..4......4..i..4.-4.. L.4..4..4-4..~ ..4..;.-4..4-1..;..4..4..;.- -4-.4..~..~.1..4..~..~.4-,..~~..~-.4.4....i..i..i..i... ,..;..~i.4- -~-i-4..,-,i-i..4..i....4..;~4-~-.4,....~..4-;..i..l..i..i..i..;-.. ,..;..i..4..i.. ~,.i..i..;-;....;..;..;..i.--I -4-~---;.-&-{..-~--4--~-4.--.-.¢--~-x--~--~ :. :. :. :--;.-4--4-4-- .i.-¢..~..¢..: { : :--; ~.4-.~-- .............. ..*--*-~--4.-.-.~-;--¢..4 ..¢-¢-;..¢--~ 4~ ........ -4 ~ ~-~ ¢--~- ...... ¢ ¢ ..... 4.-¢--;..4--: .... .¢--4.-¢--*.-: --¢-.*..¢-.;--.::. { : . : : ~-i.-4-.i.-~-~.-¢--~..4-4.~...~.--~.-¢-.~--+--i.-¢.-*-4.- .-~.¢--¢-*.-&.-¢~*-.~-¢ ¢-4-¢~--.-¢-¢~-.¢-...-¢--¢--¢..¢.4¢. ~ ~ [ ~-.~-&¢-.¢..¢..4-....4--i-.*-.¢-- -.i..4-.4..*.. -}..}..L.~-~.-g..g..g-4-...}..g.L.}..i~..}..~..g.. L.¢..¢..¢~..&..g..g..g..}__ ..}..g..~.}...~.g_¢..L.~..-g..g..g.-}..g..g.. h [ [ g.4..~-~-¢..g-.~.. --g..g..¢..-~ ..... g..4..¢..¢.. .................... i ....................................... I .... : : : : { : : : : : : : : i : : : : ~ : : : : ! : : : : : : : : : : : : : : : : : : : i ; : : : : : : : : : : : : : : : : : : : : : : : ...~.4..4..i-.i.-~.-i.4..i ..... 4..4-.4..4..1.,~..4..4..i.. ,.4..4..4.,4..1..4..$-.4..i..1..4..4-4-4.....4.4..4..i..,,..$...~..4..$..I..4..4..~;.. ..i..i~;~;.., ..;..$,,4..4-.. ,.-i..i.-i..~.1..;.-4.,4.4.-..i..i..;..4.-i..i..i-i..i.. ,.i..4..4-.4..1..4..i..i..4..1..4..i.-;,-4.....4-4..4..4..,,..~..i..4.-4..1..i-.;..4..4.. ..i..;;;..l..~....;-.4-4..4 ..... -.i..4..~.i..I-.~..4.4.4- ..;,~.4-~4.- L.i..i..4..~.-1..~.~.i..4-1..i..4..4,.4...-4-;.i..4.. ,..4..4..4..4..I..4..;..4..i.. ..i..;-4..4-.1..;..~.-~.4-i..4 ...... 70O0 211, PRO,~CTII~q ON VERT]CRL PLRNE 211. - 31. SO:LED IN VERT]CRL DEPTI-15 I'tOR]Z $CI::~E - 1/1000 IN/FT Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. 'O~KATOR, W~L-L ~!~[E J_ND NUMBER and Materials to be received by: /~ "' ~%~" Reports Date Required Date Received Remarks Completion Report Samples A<?.~- ~ ~ .................... .,.~_ ~i~ Mud Log ~ .... Core Chips Core Description Registered Survey Plat ~n~ination Sur~ey Directional Survey-~ Drill Stem Test Reports Production Test Reports ?~.~.~ _. . .. Log Run Digitized Data , . ARCO Alaska, Inc. Post Office B~._ i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 13, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3A-2 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for 3A-2. Tubing details will be submitted when the well has been completed. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU12/L124 Enclosures ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany STATE OF ALASKA ALASKAL . AND GAS CONSERVATION CO AISSION WELL COMI LETION OR RECOMI LETION REI ORT AND LOO 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED (~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-205 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21431 4. Location of well at surface ,Iq OCATIONS! 9. Unit or Lease Name 503' FSL, 743' FEL, Sec.7, T12N, R9E, UNILl Kupaurk River Unit VERIFIED t At Top Producing Interval ~ 10. Well Number 1340' FSL, 3332' FEL, Sec.18, T12N, R9E, UH jSurf..~_~ 3A-2 i _,/,~w] At Total Depth 11. Field and Pool 984' FSL, 3471' FEL, Sec.18, T12N, RgE, UH Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 72' RKB ADL 25632 ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 09/02/85 09/07/85 09/08/85I N/A feet MS LI N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD-FWD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8690'MD,6302'TVD 8592'MD,6228'TVD YES (2~X NO [] N/A feet MD[ 1550' (approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP, FDC/CNL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 109' 24" 193 sx AS II 9-5/8" 36.0# J-55 Surf 4112' 12-1/4" 1100 sx AS III & 340 sx Class Top job performed w/100 sx AS 1 7" 26.0# J-55 Surf 8678' 8-1/2" 400 sx Class "G" & 250 sx AS II 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) NONE N/A 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO TEST PERIOD OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE ~.~ ~ ..-' ~ ~' ~',~ · ~, :'~-i' Form 10~,07 TEHP3/WC11 Submit in dupJicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE - ": '- ' ~'' .'.:: '' ~t :~ Z--~ ;. ~: . ~ ~' "-] ? ,,.. ,. ':'..;' i:-:'(~EOEO'i~;[Ci~'A'Ri~-ER~ ::~-.'~_ .¢..:: . ::.:/..::i;;:'}'. ,. ';':~ ':" i']"::':; "-':';"::'::' '""' :'"¥""" '" ':'" .... ""' ' -, ' FORMATION'TESts : ',. ? ' · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8104' 5859' NIA Base Kuparuk C 8202' 5933' Top Kuparuk A 8306' 601 2' Base Kuparuk A 8464' 6131' 31. LIST OF ATTACHMENTS Gyroscopic Survey, (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge /~ ~ Associate Engineer Signed ~ ~ 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 completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 '~elephone 907 278 1215 ,,,% October 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3A-2 Dear Mr. Chatterton' Enclosed is the l,~ell Completion Report for 3A-2. The bottomhole location, TVDs, geologic markers, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU12/L25 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany · J STATE OF ALASKA ~ ALASKA( _.AND GAS CONSERVATION CO. ~IlSSIO I~ I G I N A t WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [-IXX ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-205 3. Address 8. APl Number P. 0. Box 100:~60, Anchorage, AK 99510 50- 029-21431 4. Location of well at surface 9. Unit or Lease Name 503' FSL, 743' FEL, Sec.7, T12N, RgE, UM (approx) Kupal. u)~ River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 3A-2 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 73' RKBI ADL 25632 ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 09/02/85 09/7/85 09/8/85 N/A feet MS LI N/A 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8690'MD 8592~MD YES [] NO[~]I N/A feet MD 1550' (approx) 22. Type Electric or Other Logs Run D I L/$FL/GR/EP, FDC/CNL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE' WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 109' 24" 193 sx AS II 9-5/8" 36.0# J-55 Surf 4112' 12-1/4" 1100 sx AS Ill & 340 sx Class "G" Top .job performed w/100 sx AS 1 7" 26.0# J-55 Surf 8678' 8-1/2" 400 sx 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) NONE N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. IxJl~ PRODUCTION TEST Date INi~¢[ Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ,. NONE ~._ , . , :. .... :,~- ,,, · ~ :, · Form 10-407 Submit in duplicate Rev. 7-1-80 DRH/WC37 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. To be submitted w~en gyro is run. N/A 31. LIST OF ATTACHMENTS Well Hi story 32. I hereby certify that the foregoing is true and correct to th~ best of my knowledge 0 ~ Associate Engineer Signed ~ _ Title Date lO-22-Z~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Well History - Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Kuparuk River ICounty, parish or borough North Slope Borough ILease or Unit ADL 25632 ITitle - Drill Field Auth. or W.O, no. AFE AK0251 IStale Alaska IWell no. 3A-2 Parker 141 API 50-029-21431 Operator ARCO Alaska, Inc. Date and depth as of 8:00 a.m. 8/31/85 thru 9/03/85 9/04/85 9/o5/85 Complete record for each day reported 0530 hrs. ARCO w.I. Prior status if a W.O. 16" @ 109' 2868', 2763', Drl'g Wt. 9.2, PV 10, YP 22, PH 9.0, WL 23.9, Sol 6.5 Skid rig f/3A-1, Accept rig @ 0100 hrs, 9-2-85. NU diverter ins, & 20" Bell nipple, chg out "J" hook on blocks, PU BHA, Spud in @ 0530 hrs, 9-2-85. Drl f/105'-463', Dyna drl f/463'-1528', TOH, LD DD, chg BHA, TBIH, drl f/1528'-2122', TOH, retrv surv, MU BhA, cut drlg in. TIH, drl f/2122'-2868'. 555', 3.6°, S45.7W, 554.93 TVD, 3.20 VS, S2.30, W2.36 1065', 18.2°, S32.9W, 1053.53 TVD, 119.92 VS, S81.28, W63.59 1465', 31.2°, S33.3W, 1414.39 TVD, 271.93 VS, S226.11, W153.57 2000', 45.6°, S34.6W, 1836.79 TVD, 567.28 VS, S497.26, W334.61 16" @ 109' 4132', (1264'), Circ & Cond Mud & Hole Wt. 9.6, PV 13, YP 11, PH 8.0, WL 17.4, Sol 9.5 Drl f/2868'-3045', TOH f/BHA chg. MU BHA, TIH, drl f/3045'-4132'. CBU. Pmp Hi-Vis sweep, drop single shot surv, TOH, LD BHA. Rn 100 its 9-5/8", 36#, J-55, HF ERW, BTC csg. FS @ 4112', FC @ 4026'. RU cmt head, C&C mud & hole f/9-5/8" cmt job. 2852', 54.6°, S37W, 2366.45 TVD, 1263.53 VS, S1035.00, W728.15 3349', 55.9°,S35.7W, 2649.73 TVD, 1670.67 VS, S1363.88, W970.18 3818', 53.3°,S34.7W, 2921.33 TVD, 2052.30 VS, S1675.75,Wl191.30 4092', 51.6°, S35W, 3088.31TVD, 2269.25 VS, S1854.02,W1315.43 9-5/8" @ 4112' 4850', (718'), Turbine'Drl'g Wt. 8.7, PV 9, YP 9, PH 11.0, WL 15.2, Sol 3.2 C&C mud f/cmt job, RU Dowell, tst ins to 3500 psi. Pmp wtr spacer, M&P 1100 sx AS III, + 340 sx CL "G", w/2% Si, + 0.2% D-46, @ 15.8 ppg. Bmp plug w/1500#; OK, bled press. CIP @ 1000 hrs, 9-4-85. POOH, RU Dowell, flush cln, M&P 100 sx AS I top job. RD Dowell, POOH, NU BOPE & tst to 3000#. RIH, drl 10' new hole. Rn leakoff tst, Turbine drl to 4850'. 4306', 50.5°,S32.6W,3222.84 TVD, 2435.57 VS, S1992.31,W1408.00 4620', 50.4°,S32.8W,3422.78 TVD, 2677.67 VS, S2196.05,W1538.80 56.24% The above is correct ,-~r~ W.S. CONGDO",4 Fo?form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Dat I Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until linal completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish IState North Slope Borough Alaska ILease or Unit IWell no. ADL 25632 I 3A-2 Field Alaska Kuparuk River Date and depth as of 8:00 a.m. 9/06/85 Complete record for each day while drilling or workover in progress 9-5/8" @ 4112' 8000', (3150'), Turbine Drl'g Wt. 10.2, PV 14, YP 10, PH 9.5, WL 8.0, Sol 13 Turbine drl to 5471'. Upper Kelly WO, chg out, correction & Turbine Drl to 8000'. 5150', 49.3°, S25.2W, 3764,51TVD, 3081.95 VS, S2550.02,W1735.22 5830', 47.2°, S23.1W, 4219.62 TVD, 3581.51VS, S3013.64,W1935.84 6300', 47°, S28.4W, 4539.56 TVD, 3923.67 VS, S3323.64,W2085.36 6700', 45.3°, S22.7W, 4816.66 TVD, 4210.20 VS, S3583.77,W2209.72 7213', 44.3°, S25W, 5179.35 TVD, 4569.18 VS, S3916.06,W2355.26 7735', 42.2°, S23.8W, 5559.69 TVD, 4922.69 VS, S4244.09,W2497.33 v . The above is correct Fo"~orm preparation and distribution' ' see Procedures Manual Section 10, Drilling, Pages 86 and 87 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official [est is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting District ICounty or Parish IState Alaska North Slope Borough Field ~tease or Unit Kuparuk River I ADL 25632 Auth. or W.O. no. ~Title AFE AK0251 I Drill Parker 141 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 9/2/85 Date and depth as of 8:00 a.m. 9107185 thru 9/09/85 API 50-029-21431 Complete record for each day reported cost center code Alaska JWell no. 3A-2 I otal number of wells (active or inactive) on this ost center prior to plugging and J bandonment of this well our I Prior status if a W,O. 0530 hrs. 7" @ 8678' 8690', (984'), RR Wt. 10.2, PV 14, YP 10, PH 9.5, WL 8.0, Sol 13 Turbine drl to 8177', pmp pill, POOH,. Found Trubine locked up, LD Trubine, MU new BHA assy, chg upper kelly vlv. TIH w/bit, drl to 8610', circ HI-Vis sweep, cond hole f/E logs, short trip to csg shoe, CBU, spot 106 lube pill, surv, POOH. RU SCHL, log w/DIL/SFL/GR/SP f/8602'-4112', FDC/CNL/8602'-7900', & f/6900'-5600', LD tools, RD SCHL. MU bit, RIH, wsh & ream 30', drl f/8610'-8690'. CBU, make 10 std short trip. Set back 20 std, LD DP to rn csg, std DC's, chg rams to 7", RU csg crew. Rn 200 jst 7", 26#, J-55, BTC csg w/FS @ 8678', FC @ 8592'. C&C mud, tst ins to 3500#, pmp 60 bbl spacer, followed by 400 sx CL "G" cmt w/3% KC1, + .08% D-60, + .2% D-46, @ 15.8 ppg. CIP @ 1830 hrs, 9/8/85. Displ w/diesel, RR @ 2000 hrs, 9-8-85. 8017', 41.5°,S21.2W, 5769.74 TVD, 5108.26 VS, N4417.69,E2569.32 8500', 41°, S22W, 6132.89 TVD, 5421.55 VS, N4713.99,E2686.56 Old TD Released rig 2000 hrs. Classifications (oil, gas, etc.) Oil New TD J PB Depth . Date /i '!~?~/~J,K,?d of rig 9/8/85 Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. i C.P. Water % GOR Gravity Allowable Effective dat~ corrected The above is ~rrect ~ '~ ~Si at re For'~orm preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, In,' Post Off ,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 10-22-~5 TRANSMITTAL NO: RETURN TO: ARCO ALASKA, INC. KUPARU K OPERATIONS RECORDS CLERK ATO-ill5B P.O. bOX 100360 ANCHORAGE, AK 99510 LNGI~'~LERING TRANSMITTED HEREWITh ARE ThE FOLLoWImG ITEMS. PLEASE RECEIPT AND kETU~ ONE blGNLD COPY OF THIb TR~SM!TTAL. FINAL PRINTS/ OP~NHOLE/ SCHL/ ONE * OF 1R- 2m'" 5" DIL/SFL-GR 09-04-85 ~<UN ~1 ~2" ~5~-" DIL/bFL-GR 09-04-85 RUN ~1 DEN/NED PORO 09-04-85 ~UN ~1 " DEN/NEU RAW 09-0~-85 RUN ~1 2~ DEN/NEU ~W 09-04-~5 RUN ~1 ~~ CYBE~OOK 09-04-85 RUN ~1 3 A-~ -,~5" DIL/SFL-GR 09-07-85 RUN #1 '-2" DIL/SFL-GR 09-07-85 RUN #1 2~5" DEN/NEU POt<O 09-07-85 ~<UN ~1 /%2" DEN/NLU PORO 09-07-85 RUN #1 .x,~_. %, 5" DEN/NEU RAW 09-07-85 RUN #1 ~' 2" OEN/NEU RAw 09-07-85 RUN ~1 ~ CYBE kLOOK 09-07-~5 }<UN ~1 5409 ACKNO~LLDGE 4810-9286 4810-9286 7100-9255 7100-9255 8470-9255 8470-9255 8550-9250 4105-8594 4105-8594 5600-8568 5600-8568 5600-8568 5600-8568 7900-8545 RECEIPT ACKNOWLEDGED: DISTi<IBUTION: SPAE DRiLLiNG*BL W. PASHER B. CURRIER L. JOHNbTOi, EXXON CHEVRON MOBIL PMILLiPS OIL D & M*BL NSK CLERK*BL J. RAT~LMELL*BL Ai~SK8 0ii & 0-% ~.~.:'.i :.,::.- S T A TL-,;-.,O ~,';.-, 'ALASKA* GL sOHIO /SE UNION VAULT/AND*FILM ARCO Alaska, Inc. is a Subsidiary ol AllanlicRichlieldCompan¥ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 14, 1985 Mr. C. V. Chatterton Commi ss ioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are the September monthly reports for the following wells' 3A-2 3C-3 3J-4 WSP-6I (workover) L3-5 9-29 3A-3 3C-16 3J-5 L1-2 4-21 11-8 3A-4 3F-1 3J-6 L1-14 (workover) 4-30 11-9 3C-1 3F-2 1R-3 L2-13 4-32 11-1! 3C-2 3J-3 1R-4 L2-26 9-24 15-7 16-17 If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU11/L62 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany "-' STATE OF ALASKA ' ALASKA O,- AND GAS CONSERVATION CO~v, MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-205 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21431 4. Location of Well atsurface 503' FSL, 743' FEL, Sec.7, T12N, 5. Elevation in feet (indicate KB, DF, etc.) 73' RKB RgE, UM (Approx.) 9. Unit or Lease Name Kuparuk River Unit I6. Lease Designation and Serial No. ADL 25632 ALK 2565 10. Well No. 3A-2 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. Septembe r , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0530 hfs, 9-2-85. Drilled 12-1/4" hole to 4132'. Ran, cmtd & tested 9-5/8" csg. Drilled 8-1/2" hole to 8610'. Ran logs. Continued drlg 8-1/2" hole to 8690'TD (9-7-85). Ran, cmtd & tstd 7" csg. PBTD=8592'. Secured well & RR ~ 2000 hrs, 9-8-85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 105'. Cmtd w/193 sx AS II 9-5/8", 36.0#ft, J-55, BTC csg w/shoe ~ 4112'. Cmtd w/1100 sx AS Ill & 340 sx Class "G". Performed top job w/lO0 sx AS 1 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 8678'. Cmtd w/400 sx Class "G". 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/SFL/GR/SP f/8602'-4112' FDC/CNL f/8602'-7900' & 6900'-5600' RECEIVE[.) 16. DST data, perforating data, shows of H2S, miscellaneous data NONE Alaska 0il & Gas Cons. C0rnmissi0n Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ¢ ~0/~ ~/~ TITLE ................... Associate Engineer DATE NOTE Repo~ 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 DRH/MR43 Submit in duplicate ARCO Alaska, Inc. Posl Ollice Box Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 9/26/E5 Transmittal No: 5371 RETURN TO:_ _ ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box i00360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tape and Verification Listing: ~"~lR-3j #70811 9/10/85 -~lR-4~' #70823 9/i7/85 ~3A-2./ '#70808 9/7/85 3A-3 #708i4 9/14/85 3C-3f #70807 9/6/85 ~3J-3f #708i2 9/9/85 Receipt Acknowledged: DISTRIBUTION B. Currier Drilling W. Pasher BPAE Chevron Geolog~L.Johnston Exxon Sohio Mobil Phillips Oil Union D & M NSK Drill Clerk J, Rathmell K. %ulin/Vault ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 28, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plats - 3A Pad Wells 1-16 Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU11/L22 Enclosure If RECEIVED AUG ~ 0 198 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany ? 8 18 ~7 NOTES C :CRD~NAT~S 4, RE A.S.R, ZONE 4 2. SECTION ~,NE DISTANCES ARE TRUE. 3. HORIZONTAL POSITIONS BA3EDCN THE D.B.-3A WEST ~ 3AMID ~ER LHO ~ A~SOC. ~.V~RTICAL POSITION BASED CN 3A EA$T 3A MID PER LHD 5 ASSOC. 5.O.~. ELEVATIONS iN~ERPOLATEO F~OM S/C CEO- RIXX- 3DaD rev. ~ oF ~-~ · .. .. ~ HEREBY CERTIFY THATI AMPROPERLYREGISTF'RED LISC~NSED TO PRACTICE LAND SURYEYING IN ?HF. STATE. OF ALASKA, THAT THiS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL 0E:TAILS ARE CORRECT AS OF AUGUST 14,1985 AS BUILT CONDUCTORS I- 16 1- ¥=5,996,860.05 LAT= 70°24'09.520'' X= 507,712.01 LONG= 149056, I;.020" 478' FSL, 736' FEL, 36.8' 06, ~0.8 PAO 2- Y=5,996,884.17 LAI= ?0°7~,' 09.758'' X= 507,705.57 LONG: 1~,90%6' t4.207" 503' FSL, 743' FEL, 36.8 0'3, :.0.9 Pag 3- Y=5,996,908.32 LA/-- ?Oo2a'O'). )95" X= 507,699.06 LONG: 14-J°56' la. J'J?" 527' ;$L, 749'FEL, 36.7 0G, 40.8 PAC a- Y=5,995,932.72 LAI= 70°24'10.235'' x= 507,692.55 LONG= 149°56' la.58/" 5S1' FSL, 756' FEL, 36.7 OG, ~0,8 PaL; 5- ¥=5,996,956.61 LA[= 70°24' [0.470" ×= 507,686.21 LONG= 199°56' 14 773" 575'XSL, 762'=EL, 36,5 OG, ~,0.9 P~D 0 6- Y--5,996,980.84 LAT= 70 24' 10.709" X= 507,679.66 LONG= 149°56' 14 963" 599' FSL, 768' FEL, 36.50G, 40.8 PaD 7- Y=5,gg7,004.go LAT= 70024, lO.gq~" X= .507,673.26 LONG= 149°56' 15 15[" 623' FSL, 774'FEL, 36.5 9G, ~,l. 1 P19 8- Y=5,997,029.03 LA)'= 7002~,' Il. i93" X= 507,666.81 LONG= 149°56' 15 33J" 6~+7~ FSL, 781' FEL, 36.4 06, 40.9 P. AD 9- Y=5,997,101.2t+ LAT= 70°24' 11.893'' X= 507,647.70 LONG= 149o56' 15 896" 720' FSL, 800' FEL 36 3 OG, 41. P.!P lO- Y:5,99'~, 125.66 X= 5,.; ,6~0.89 144 ' ': ~ L , 806 .' Il- Y=5,997, 149.84 X= 507,634.44 768' FSL 813 12- Y=5,997,173.97 X= 507,627.96 792' FSL 819 13- Y=5,997, 98.08 X= 507,62I.q8 .~17' ~SL 825 14- Y=5,997, 22.29 X= $07,615.0 841' FSL 832 FE FE L L FEL L [ FEL 'L FEL LAT= 70°24' i2. 134" LONG: 149°56' 16 095" L 36 30G, LAT= 0o24' 12.371" LONG= 149°56' 16 283" L 36 2 OG, Gl.2 PAO AT= 70o24' 12.509" ONG= 149°56' 16 .,; :." 36 Al'= 0°2 ONG= 1'-,g°56' 15 ':" " 36 0 OG, ~.1.3 ,qf= 70")2L,-' !3.38:." ONG= 1~.9°55' 35 8 OG, /.l.0 P:~-] 15- Y=5,997,2~6.44 LiT= 0°24' 13.322'' LOCATED IN PROTRACTED SEC.?,T. 12 N. R. 9~,,) ~'.i~, I' 1%! I- I~ I / "iL I .... ] ~ v 5,997.270.55 LAT= O)2&' 1~.55." = 5n~,b02. lO LONG= i/.9°55' !7. -" ? · . ...... ...... THIS SU "· ' co c,o. ~ ~ z, LOCATIONS August 22, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 A~nchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3A-2 T ARCO Alaska, znc. Permit No. 85-205 Sur. Loc. 503'FSL, 743'FEL, Sec. 7, T12N, R9E, LQ. Btmhole Loc. !014'FSL, 1084'FI.~, Sec. 18, T12N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Ke~zn Kuparuk River Unit 3A-2 -2- August 22, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. :~ trul, y ~ ~' ~:i,-~?~,~- .... C. V. ~atter6on ~airman of Alaska Oil and Gas Conservation Co~ission BY O~P~ER OF THE COb~ISSION be Enclosure Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office B,_ ,00360 Anchorage, Aiaska 99510 Telephone 907 276 1215 August 7, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3A-2 Dear Mr. Chatterton: Enclosed are: o An application for Permit to a $100 application fee o Diagrams showing the proposed projections of the wellbore o A proximity plot o Diagram and description of the system Drill Kuparuk 3A-2, along with horizontal and vertical surface hole diverter ° Diagram and description of the BOP equipment We estimate spudding this well on August 29, 1985. any questions, please call me at 263-4970. Sincerely, ~~~gineer JBK/TEM/tw PD/L143 Enclosures If you have ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION CO~v~MISSION "' ~ PERMIT TO DRILL 20 AAC 25.005 ATIC~_~AP ~'~ L~ k'~l DRILL [~ lb. Type of well EXPLORATORY ~ SERVICE ~ STP ~ ~, ~ REDRILL ~ DEVELOPMENT OIL ~X SINGLE ZONE ~ -,2 ~? ¢¢ DEEPEN ~ DEVELOPMENT GAS ~ MULTIPLE ZONE~ ~ ~ ~. ~ % 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 503' FSL, 743' FEL, Sec.7, T12N, PgE, UH (Approx·) At top of proposed producing interval 1257' FSL, 1236' FWL, Sec.18, T12N, PgE, UH At total depth 1014' FSL, 1084' FWL, Sec.18, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 73', PAD 42' ADL 25632 ALK 2565 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line · 0' ~ 1835'TVD feet 30 mi NW of Deadhorse miles 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8611' ND, 6132' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 450 feet. MAXIMUM HOLE ANGLE 50 oI (see 20 AAC 25.035 (c) (2) 21 Proposed Casing, Liner and Cementing Program 9. Unit or lease name Kuparuk River Unit 10. Well number 3A-2 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 15. Distance to nearest drilling or completed 3A-1 well 25' (~ surface feet 18. Approximate spud date 08/29/85 2681 psig@ 80°F Surface psig@ 5945 ft. TD (TVD) 3068 SIZE CASING AND t INER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 24:: i6:: 62.5# II-~U Weld ~0' 29' I 29' 109~ 109' + 200 cf .2J~J~¥2~ 29' I 29' ~ 3962! 3112' 890 sx AS III & i2-1/4~ ~-b/~" 36.0# J-55 BTC I i HF-ERW ..... -'~:"-.-' ! ] 340 sx Class G 8-1/2~ 7" 26.0# J-55 BTC 8F~¢3,' 28'II 28' ?. 8611'1 6132' 270 sx Class G blend ' I HF-ERW u-~',~.: I I 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Kield'' development well 'co approximately 8611' MD (6132' TVD). A 20", 2000 psi annular diverter will be ~nstalled on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak sands at approximately 3962' HD(3112' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and week]y thereafter. Test pressure will be 3000 psig. Expected maximum surface pressure is 2681 psi. Pressure ca]culations are based on virgin reservoir pressure· Surface pressure is ca]culated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed by the workover rig with 2-7/8", 6.7#, J-55, 8rd tbg. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) · 23. I hereby cert/i~C~hat the foregoing is true and correct to the best of my knowledge // SIGNED The space,~ for~/~r~sion us;/' CONDITIONS OF APPROVAL DATE Samples required I~lY ES ,~'N O Permit number Form 10-401 Mud Icg required [-]YES Directional Survey requ . /~0' E S F-iNO ired APl number 50- Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS August 22, 1985 ,COMMISSIONER DATE by order of the Commission Submit in triplicate Rev. 7-1-80 PERMIT TO DRILL (cont'd) 3A-2 installed and tested upon completion of the job. 3A-2 will be 25' away from 3A-1 at the surface. There are no other close wellbores or crossings anywhere.downhole. Top of cement for the production string will be placed at 7134'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. On completion of disposal injection, the 9-5/8" x 7" annulus will be downsqueeze Arctic packed with approximately 200 sx of Class G cement and sufficient Arctic pack to place the cement/pack interface below the permafrost. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED oH ~s (~s Cons. Commission Anch0raDe ............... ~ · __ : ..... , · ; · - _ ....... kLE]I];;IN;:= 1000 'FEET ..................... -~ .... :; ..... ,.. .................. ; '"~RCi~'--^L^SKA. I-NC.:~ ~ ..... ~ ~ .... '- ---'- PAD 3A. ~ELL NO, 2' PROPOSED . ' .-/il % ' _ KUPARUK FIELB,~"~ORTH SLOPE. ALASKA ' : ....................................: ....................... ....... ........... 4000 ' " 3000 ....... 2000 ' 1 000 0 1 000 - ....... ~'_ ............. ~000_.' I ...... I .......... I - -' I .... I I - ' .............. - .- - SURFACE LOCATION ~ . - · ......................... 503' FSL. 742' FEL ........... ............... i-.---_: ._ .....__-~--- __'_~_- ..... _'- __~_-__ . SEC. 7. T12N. RgE ' ' ' .'. ~_ -..i _--.'~ ;~_'~-_. ' .... ; --~-..- --_--_ ........ .----_- .......... 7 ...... .-T-. .......... ........... , ............... , ............................... . ................... _ ............. ................ · ........... ................... ................................................................. . ...... ......................................... .................... ; ........... . ................................ .- l 000 ..........-~ ....... ' .................... -___;2 .................................... ' ............ ~ . . ...... ~ _ .~uuu _- _ 4000 ......... " .- T,, r .. . - ' TVD 5945 ~ ............ : - .- WEST '28S8 ....... · ' ' 5000 ..... ~ ........ ~ TD'__LOcAT{~, .... -- . _- ..... ........ : SEc. ~ S,_ r~ 2N ~_'~eE.;. ~;~_.L_ ' .... . ....... ...... . _ - _. :--- . ..... -- '.: .-- -__ ~.:'_: :--t-:--;-_ S-:-31 DEG 57-'.'M I N W ..... .~:~G'Z"'~ !985:-; ....... ; ...... - '- -----;- ;-: :~ '-: :-- --- ---:----5'4 0-1 ' -' (T 0 ' T A R ¢'E ~lska oi~ a aa~ co~. cor~m~o~,'-: .... ~ ....... --' .................... ........... ~oraoe -~ ........ . . _ PAD 3A. HELL NO~ KUP6_RU_K_~._.F !ELD ,: NORTHLSLO_~EA-._A~ASKA -_-~_EASTMAN WHIPSTOCK. INC ......... --~-' ~ ]_000 BUILD 5 ..... PER !00- FT · 27'~- 33 '- - BASE PERI'IAFROST TYD=1552 TI'ID= . 45 EOC TVD=1902 TFID=2100 DEP=669 TOP -UGNU SNDS--TVD=1967 THD=2200 ,DEP=745 ]ToP W'SAK-SNDS "TVD=2632 Tl'1D=3223'DEP:1524-. ....... .--' . _ ... K-12 TVD=2912 TMD=3654 DEP=1851 ..... " -:" .~ CS(; PT TVD=3112 TI'ID=3962'DEP=2085 ......... i"- .... '-- - AV-ERAGE ANGLE- - X , :~.L_.: ....... . 49 DEG--~:29_-H-I-N ~ .... Anchorage - - --TOp UppR SNDS TVD=5822 THD=8134 DEP=5~57 _ TOP LOWR SNDS TVD~~~ DEP=5333 TARGET CNTR TV~5 ~8323 DEP=5401 -.~ -, . - ' ............. BASE KU~ SNDS . TD {LOOGINO PT) TVD=6132 TMD=8611 DEP=5620 ' ' , ~ - . . : - ........ 0 ~- - 1000 -'- -~' 2000 ..- 3000 4000 5000 6000 ............... ~ . . L..L_?_'.VERTiCAL SECTION .......................... . . ' ~00 162~ .... 16~2 ............ 1728 . _ 5O0 i 1878 2000 40O I ~ ........ - ......... 1778 1800 -.~-:: .-: -: _:- ._ _i ..-- :': :_.-- . ..................... 1832 ' 950 _ .-- '-' - ............... ' RECEIVE :.ID ....... ~ ........ . .............. :::::.:.: :. ============================ :-:: :-~-' :: : -- ' .AUG,. "--:~ ~.~5 . ............... : ........ } ....... L__~:_' -':-_~_'_ :-.- . - ' ' Naska 0il & Gas Cons. Commissi - . ::::::::::::::::::::::::::::::::::::: ....... ..... :..:._::::':..: ..... _:___~ .................. ~ : :L:.::tL~ .......... ~--L ............... _:.L:__:;.t::.]___.:L:PAD: 3A,_' ~ELL NO, .1-2-3-4. PROPOSED . _~. ::::::::::::::::::::::::::::::::::::::::::::: ::-~:------~~ ~s~oc~, ~, - · · ~ ---::-:'-:~:-~:-:~":~L:-::~:::~:~-:::::'L-tL-':~~~L~:~:ND~E' : ~ELL P'THS EXTEND BEyoND '-- ....... 5 '::: :::' === =============== ========== : ~ ::.-:--' :: -w---t-::-: - < 400_: ..::: ....... :._::_;..L .......... : ........ ~_L_:_ -. ~_.._'._. ......... _I KUPARUK R I VER T 20" -D~ VE~TER SCHEMAT I C 7 6 7 DE S CR I P T I ON I. 16 · C~CTOR. 2. TAI~O STARTER NE:AD. 3. TANKO SAVER SUB. 4. TAI~O LO~R OOICK-COt,,/~CT ASSY. 5. TANI,(O UPPER QOICK-C~CT ASSY. 6. 20' 2000 PS] DRILLING SPOOL W/lO" OUTLETS. 7. I0" NCR BALL VALVES W/I O" DIVERTER LINES, VALVES OPEN AUTOMATICALLY UPON CLOSURE OF' Ah/',&J'L AR PREVENTER. 8. 20" 2000 PSI Aht~LAR PREVENTER. 5 ,4 RECEIVED Alaska 0ii 8, 6as 0OHS. Oo~}~mi.ssion Anchorage MA:[ NTENANCE & OPERAT:[ O_N I. UPON INITIAL INSTALLATION. CLOSE PREVENTER AND VERIFY THAT VALVES HAVE- OPENED PROPERLY, 2. CLOSE ANI'~LAR PREVENTER AI'~) BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE Ah, I'~LAR PREVENTER IN TIME EVENT 'THAT AN If~FLUX OF ~IF_LL~ FLUIDS OR GAS IS DETECTED. IF NECESSARY; MAh~JALLY OVERRIDE AND CLOSE APPROPRIATE VALVE TO ACHI EVE DO~NI~I ND DIVERS I DO NOT SHUT IN ~LL UKOER A-NY CIRCUN~TANCES. i 7 6 4 ~ DIAGRAM #1 .13-5/L 5000 PSI RSRRA BOP STACK I. I G' - 2000 PSI TAN<CO STARTING 2. I1' - 3000 PSI CASING 3. t1' - 3000 PSI X 13-5/8' - 5000 PSI 4. 13-5/8' - ,5C[~ PSI PIPE 5. 13-5/8' - 5000 PSI DRILLING S{:K3CL V~/Q-W3~ KILL 6. 13-5/8' - 5000 PSI DOUBLE P-~ W/PIPE RA~ ON TCP, ?. 13-5/8' - 5000 PSI A~ ACCLNU[.ATOR CAPACITY TEST 1. Q-ECX AhD FILL AC~TCR RESERVOIR TO P~ LEVEL WITH HYDRAULIC FLUID.' 2_. A~ THAT AC~TCR P~ IS ~ PSI WITH ,3. ~ TINE, ~ CLCE~ ALL UNITS SI~U_TAhEOUSLY ALL UNITS ARE CLOSED WITH Q4ARGING PLIVP CFF. 4. RECCI~) ON NADC REP(iRT, THE ACCIB:rTABLE LOA~R LIMIT IS 45 SE~ CLOSING TINE AN:) 12_.00 PSI RE~AINING ! 2 I VED 13-5/8" F_.;;,.~ STACX TEST 1. FILL ~ STACX A~ CHCI(E k~IF6~ ~ ~IC DI~. ~ ~T ~ L~ ~ ~ IN ~ ~Y ~RA~. ~T ~ ~ IN WI~ ~I~ ~ ~ ~ IN L~ LI~ V~VES ~ TO ~ STA~ ~ 4. ~~ ~ TO ~ ~I ~ ~ F~ I0 MIN. ~ ~~ TO 5~ ~I ~ ~ F~ I0 MIN. ~ ~~ TO 0 ~I. LI~ V~VES. ~ T~ PI~ ~ ~ ~ V~VES ~ ~ ~ ~E LI~S. 6.T~T TO 2~ PSI ~ 3~ ~I ~ IN S~ 4. 7. ~I~ TESTI~ ALL V~VES, LI~, ~ ~S W[~ A ~ PSI L~ ~ ~ PSI HI~. T~T AS IN S~ 4. ~ ~T ~~ ~T ~ ~ ~T IS ~I~ ~57 ~$ ~T ~ ~ ~LY ~. 8, ~ T~ PI~ R~ ~ ~ ~~ PI~ %~ B~ PI~ ~ TO ~ ~I ~ ~ ~I. 9. ~ B~ PIPE ~, ~ ~ ~I~ ~ ~ .10. ~ ~I~ ~ ~ %ST TO ~ ~I ~ II, ~ ~I~ R~ ~ ~I~ ~ST ~. ~ ~IF~ ~ LI~S ~ ~L. ~ ~~I~ ~UID. ~ A~ VALVES IN ~I~I~ P~ITI~ I~ TEST ~~I~ VALVES, ~Y, ~Y ~S, ~I~ PI~ ~~ VALVE, ~ I~I~ ~ TO ~ PSI 3~ ~I. F~, SI~, ~ ~ TO ~[~I~ ~I~. 14. P~~ ~E B~ ~ST ~ NI~I~ ~ ~Y T~~~ ~I~LY ~~ ~ ~ILY. Alaska Oii& Gas Cons, Commission Ahchorag6-' 510084001 RFV. 2 MAY 15. I~' CHECK LIST FOR NEW WELL PERMITS Lease & Well No. Y' ~~ ITEM APPROVE DATE YES NO REMARKS 1. Is the permit fee attached .......................................... (2 thru 8) (8) (3) Admin ~/~%2~ ~-ZZ:)-~,J 9. (9 thru 12) 10. '" "~ ~" ~;/"" ,"~" ", .... 11 ~d ,e . :-'.,-'7 "" ~? '-~ ' (lO and 12) ' 12. 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... Does operator have a bond in force .................................. ~ Is a conservation order needed ........................... ........... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ (4) Casg 4,.-',rz' -.';,",~ '-~'" '~. (13 thru 21) ~. ~t.' ,-"'i~ "1 , (22 thru 26) 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 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 cement cover all known productive horizons ................ Will surface casing protect fresh water zones,.~i .i..i...i .... Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ,,~!~O' psig .. ,~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: o i-ri Geology: Engineering: HWK IC. LCS .....,,"', 'BEW ........ WVA ----- MTM ~,':'";'"'". ..... HJH .... /' '"':,,?'i ,~'/,,':"" JAL ~ rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXl ,. No special'effort has been made to chronologically - -, · .. organize this category of information. LIS T~PE V~R'~F~CAT~ON L,IST~NG bVP OlO.H02 VEP].WlCATI~N LISTING PAGE SEr~V T CF. ~TA~E :~DTT DATE :95/00/22 ORZGTN :0000 TAPE CONTTNUATI~)N PRKV TO~$ T~P~ CO~4M~NTS :LIBRARY TAPE CN ~ ARCt,) ALASKA WN : 3A-2 rN : KdPARUK RANG: gE T{,,]WN: !.,2~ SECT~ 7 COUN: BT~T: a[,,aSKA PRES: K UN,IT TYPE CATg SIZE CODE 000 000 016 065 000 000 004 065 000 000 008 065 000 000 002 06'5 000 000 004 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 004 065 UNIT TYPE CATE SIZE CODE ooo 000 0ol 065 I.,VP 0,10.~{07 VERII~"IC~TIOi~ L, TSTINt; PAGE 2 RLJP,,] ~.1., nATt~.: I.,,nc;GEh; O? SL:D T~I.)P: H.n~NA'/RD Rt'DI,A~ CASING TYPE FI,UT!) OEN$I'TY VI$CF~STTY DH Fbi!ID T~OS$ ~ATRTX=SAND [VP OlO.ItO? vERI~"iCa?lnh L, IST£~I¢; PA~E 3 ***** TH1'5 DATa N/~S Ittt]T BE~:I~ [,EPTH S~IFTED ' OVE~LA'Y$ FIF. LD PRINTS ***** ******************************************************************************* * , * * * * * * * * * * * * * , * * * * * * * * I~F,,)r~M~TTCIt'l ,r)k',NS~.rY CO,~PENSATEr) LOC (FDN) . CO~;P~,NSATED NEIITRON [,.UC, (FDN) * DATA AVAILARL~: 856~,0' TO 5600,0' * **************************** TYPE SIZE ~EPR C~DE ENTRY 2 1 6,6 0 4 1 ~6 1 ~ 4 73 60 9 4 65 .lin 16 I 66 1 0 1 66' 0 DATU~ SP~.]CTFTCAT.Tf].~! BbDCKS ~Nr~ SFWVICE SERVICE ILD nlf, OH~M GR DIL GAPI GR FDN CAPI ~ALI ~ON IN RHoB rO~ ~/C3 DRHO FON (:/C] NRAT FDN RNRA ~DN NPHI FDN DU NCNL ~DN CPS FCN[, FDN CPS ADI ~PT API AP% PILE bOG TYPE mL~SS qOD NO. O0 000 O0 0 0 O0 220 O1 0 0 O0 120 46 0 0 O0 120 4~ 0 0 O0 0~0 O1 0 O0 tlO al 0 0 O0 ]lO O1 0 0 O0 280 nl 0 0 O0 350 O2 0 0 O0 356 O! 0 0 O0 42~ 01 0 0 O0 000 O0 0 0 O0 ~90 O0 0 0 O0 330 31 0 0 O0 )30 30 0 0 4 4 4 4 4 4 4 4 4 4 4 4 4 4 E SPb REPR 1 68 1 68 1 68 I 68 1 68 1 68 PROCESS C~DE 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 DATA OBPT B~O0 ~000 31,3 SP 1 :! ~ .... 209 NPHI 4 . 070 NCNL DgDT 8500 0000 SP -,1~1850,4 GR RHOb 2,4219 DRHO NpHI 43.6035 NCNb D£D'T 8400 0000 S FI..,U RHOB ~. 3945 Dawo NPHI 31.,~359 NCNb $?. ',.4:3164 GR RHO~ ? Sl~5 DRHO NP~I 4~82~3N', CNb DB;PT SP - 10:7656 R H.O[~ 2 ' ]86'I ORHU NPPI 39., 61.72 NCNb DEDT 8!00 0000 SFI,U 2 10.!o O, 1.01~ O. :1.902. 93' O, 962. 8457 4375 0820 0000 43'5 1. 01 1 0000 ~090 ,!875 Oy, C, 1 0000 10 o 25'I 4.0 8O ;0 2004.0 22, 59... 3032. 120. 969 5OO 01.0 000 71.9 125 869 0 O0 9531 3750 0088 0000 1777 56~5 lbo ~R NRAT FCN[, NRAT FCNb ! bD NRAT FCNL l I,,D (IR NR~T PCNI,,, NR ~ T FCNL ! bD ~R 2 8340 101!4375 ~ 6973 .471 2500 ,375 697 2500 2,9336 93.1.875 3.5605 500.0000 8 179'7 85i7500 2 8828 803 0000 CAbl RNRA CALl I bM CALI RNRA CALl RNRA 2 8125 .I h ] 17 RNRA 509 0000 15.8984 52.3750 2"9414 025.0000 2,2910 120,5625 IbM CALl RNRA CALl 2,,7422 8,5000 4,03'61 2 7578 4,0361 3,0684 8. 9687 3.811.2 8.6328 ,7266 ,2273 2 7832 8~,.8984 ], 91.39 16 O15b 3, 556 2.3164 8,2656 LVP 01r~.!'O~. VEPlFIrA?ION bTSTING Pl%C.,E 5 ?. '~730 DRUU 46.7773 NCNL DKPT $000.o000 Sf'l,U SP -15.]125 NPHI q2.236.] NCNL DEPT 7900.0000 SFLU Sp -16.1250 GR RH~B ? 3594 'D°~.,~no Np~I 46~750 NCnb D~PT 7800 0000 SFLU SP 015635 GR ~HOB -g9g ~500 ~RHO NPUI -o9g ~500 NCNL DEPT 7700 0000 SFLU SP 13~750 GR RHOB '- 999.2500 DRHO NPHI -999.~500 NCNL DEPT 7~00 0000 SFLU .$P 15 [ 7813 GR RHnt,~ .-999.9.500 DRY40 ~plblI 999.2500 NCNL DEPT 7900,0000 SP -5,6075 GR RflOB -999.2500 ~PHI '99g.~500 ~}CNh DEPT ~400.0000 SP -8,6875 RHO8 999.2500 NpH! -999,2500 NCNL DEPT 73 O0. O000 $FY,U SP '.'1.5 6406 GR RHOb 999 ~ 2500 DRIqO NPHI 999. 2500 MCNb Sp -24:~87 C,,R RHnB -qgq, 2500 NP}tI -099.2500 NCNb DEPT 7~00 0000 SFLO ,SP -1,8,7188 ~R ~HOB -999,~500 DRHO NP['~I -o9g.~500 NCNb 0.0366 1061.0000 P 3945 ILD o9:75o0 0.0239 NR~T 1816,0000 FCNL 3.3730 TbD ~17.7500 GR 0.O103 NRAT 1875.0000 FCNL 4 5430 IbP 154:0000 GR -999,2500 NR~T -099.2500 FCNL 3.6875 ILD :999.2500 ~R~'I.' 999,2500 FCNL 3.0723 Ihb 113.8125 GR -090,2500 NRAT -999,:2500 3.fl672 IbD 100:0000 GR -999!2500 ~RAT -999 ~500 FCN~ 5 3672 10t:7500 -999,2500 -990.2500 FCWL 5 5430 ILO 88!9375 ~R -990 2500 NR,~T 'ggq ~500 FCNL 4,7461 ILD 90,3750 GR -n99,:2500 NRhT -999.2500 FCNb 6758 .7 :2 oo 2 112,8 !00:7500 3.5547 465.2500 2.8B67 I17.7500 3.8105 464.0000 3 1250 -990[~500 -999 2500 -999.2500 3,3477 -999.2500 -999 ~500 -999:2500 3 7344 .2500 -999.2500 -999'~500 2,5059 -999,2500 -999,2500 -999.2500 RNRA CAt, I !~NRA CAL! RNRA CAL! ~N~A CAL! RNI~A CALl RNI~A I CALI RNRA · .999:: 0 CALl -999 .500 ~NRA -990 2500 4.2578 ,~999,2500 -999. 2500 -999,2500 4,4922 -999, 2500 -99g. 2500 -999,2500 4.4727 999 2500 2,99~:2500 -990.2500 Ib~ CALl IbP CALl RNRA CA[,I RNPA 3.9.886 2 2090 3 8886 2 8965 9i8203 4 1977 3 2676 .o90: soo -999.2500 3,4082 ~999,2500 -999,2500 3,8262 -999,2500 -999.2500 2.4531 '999. 2500 -099,2500 3,6523 ' 999, '2500 ,-999,2' 500 4,2656 ~999,2500 -999.2500 . 4,7303 .99~, ~500 .99,, 500 4,4766 -999,2500 -999,2500 7000.0000 S F'T..,U .]..610'I TL, B 3,5469 Ib~ 3,5332 SP -lq %000 GR NPHI -O94.7500 ~CNL DEP'r b900,O000 SFI.U RHOB 2,5000 DRHO gPHI 3~,9379 ~CNb DEPT 6~00 O000 SFLU SP - 28:7656 NPMI 44,4316 NCNb DEPT 670~ O000 ~FI,U Sp -4n!!562 GR RHF!B 2 3301 DRHO NPHI ~q,oO~] NCN~ DEPT 6600 no00 SP -4316563 RH[1B 2 4238 BRHO NPHI, 40 7'11,5 NCNb DE:PT 6500,0000 SFLU SP -55 50~0 GR NPHI 3~,0~59 NCNL DEPT 64.00,0000 SP '3~,5938 RHOB 2,3613 NPHI 47,1191 NCN[,~ DEPT 6300. 0000 SFLU Sp -37,7188 GR RH.)E~ 2 3.41,6 ~RHO N p H I ,! g, :~ 047 N C N b D~jPT 62t)0. 0000 8FLU S P ' 43. ~ 1 ~ 7 C, R NPHI 40: 28 32 NCNL Df., I. 6100,0009 SFI,U SP '39.'7500 ~R RHOB ~.31~4 DRHO NPHI 44.5801 NCNb DEPT 6000 0000 SP -38i9062 GR RHOB ~ 3359 DRHO NPHI 44.2871 ~05.5000 -999.2509 -a9q.2500 FCNL 3.B203 TLB 99.1875 GR 0.0547 NRRT 2548.0000 FCNL 9531 !bP 0,0073 NRA1' 2.1426 114.06~5 -0 0020 4.1836 IbD 1.27,2500 GR 0.0225 NR. AT 2060.0000 FCNI., 5 6563 YLD 0,0190 NRA. T 1886,0000 rCNL 179:0000 GR 0,.0059 NR~T 1.76~,0000 FCNL 2 79~8 ,2500 GR 1935.0C)00 FCNL 3 4277 161."6250 GR O'OLO7 .~.oooo rCNb 9355 IbD 5,1250 GR 130,0054- NR,~.T 2~.1.0.0000 F'CNL 2 7676 lbo ~4~:~75o c~ -0,0005 MR~T 2023.0000 FCNI.., -099i2500 -ggg 2500 3.7793 99 ~875 311875 705 0000 2.0332 !42.1250 3.6465 542.5000 2 3223 114:0625 3 9492 440:2500 3.8008 127.2500 3.5176 536.0000 1'5, O0 3,3613 528.0000 000.0 3 8418 422,2500 ~ 2852 1.78 2500 .t 9434 460 5000 3.i055 161.6250 3,4160 536.0000 2 0957 3 ,* 6.387 529.5000 2,4531 !4~,3750 3.5977 495,~500 CALl PNRA TbM CALl RNRA CALl IbM CALl' RNRA CALl RNF~A CALI RN~A CALl Oki,, I CALl ~N~A CAB I CA[, RNRA -999.~500 -999'2500 3.8301 11.4297 3,4660 2,0723 0.4531 4.0839 2,3262 9.5000 4,1562 3,7715 1~,3203 ,7516 3,9941 10.2031 3,9089 3,1602 10,0391 4,1054 2,.~969 9. 078 4,38T0 .3 ' 08';9 g. 4063 3,7770 2,~47 9,9, 34 3, ',~ 200 2,4180 953~ 8'962 3, -52.2500 C~ 4~.~9~8 ~C~L DEPT 5~Oa 0000 SFLU SP -44, i7500 ~ ~pt.{~ 40,~809 ~CNb DEOT 5~00 0000 SFLU Sp -50:~062 GR ~HOb 2..t4]$ DRHO ~Pt~l 40,9668 ~C~b DEPT 5600 OOO0 SFLU . SP -47.~125 ~R RHDB ~,~203 DRHO NPHI 37,~906 'MCNL D~qPT 5']()0 0000 SP -40i71,.8 ~PHI -099' ~500 DEPT P~O0,OO00 SP .5~,6875 RSOS -090.2500 ~PH.[ -a90,9500 DEPT 5~00,0000 SP -55,71..88 ~HOB -990,2500 NPH1 -990.~500 DEPT .... 000. 0000 8P i'54,7188 RHOB gg9, ~500 ~HI o, 9g.25oo D~;PT 4~00.0000 SP 53,7813 RH~B -099.2500 NPHI', 4.0859 lhr~ )54.8750 ~R 1~90:0000 ~CNb ?.3281 102,1875 0.0034 ~,~IT 2~6~.0000 FCN[, 2.~289 IBm !1.9.1250 ~R 0,0015 NRAT 182~.0000 ~CNL 2.3574 101.0000 gR 0.001.5 2082,0000 2 5527 TLD 95,6875 GR -999,~500 MRRT -090,2500 FC~b 2 !.660 96~5000 090,2500 NRAT :999,2500 10 .~500 -990'25~0 -099,~500 FCM[, 3 1289 96i81~5 -999 2500 NR~T -999,~500 FCML 3 ~313 . ~,05,1875 '999,~500 '999,~500 FCNL 3.5508 It, t) -999 500 MRAT -~9912500 ~'CNb 3.7266 99,1875 GR -999,,~500 -999,~500 ~.54. 3 470: . 10~, 3, 587. 0 11.0. 3. a85, 1.01. 3. 590, , -999, -999. -099, , '999, 'ggg., '999, -gg9 -gg9 -999 3 '999, '999. '999, 999, -999, 4. -999, -999, 4. -999, -ggg, 01.56 8750 64~ 5000 3594 1875 4297 0000 ]691 1250 4629 2500 4883 0000 2773 0000 6680 2500 2500 2500 O,tO 1 '~500 2500 2500 ~773 2500 2500 2500 5156 2500 2500 ~500 2500 2500 2500 0469 2500 2500 2500 7422 500 500 2500 CALl I LM CALl Ib~ CALl RNRA CAL'I R NRA IbM CALl RNRA CALl RNRA CALl CALl RNRA CALl RNRA CabI ~N~A CAI, I ~NRA 3,9062 g 6400 4:0349 2 2695 9!5234 3 7106 2 2559 9!5234 3 ~234 2 4238 9:320.3 3,5953 2.5996 -999,2500 -999,2500 3,7~68 -999 2.500 .o9,): 2500 3,1582 -999,~500 -999.~500 ],~574 999. 500 2999,2500 3,7285 -999.~500 -999, 500 3,~71..5 -999. 500 -999,2500 4,~2.03 -999 500 -999' .2500 LVP 01no){0? VED.IFIC~vION LISTIMG PAGE 8 DEPT 4~OO.O000 SF!,U 3 NPHI -~9~.7500 ~C~L -999 DEPT 4~00 0000 SFI, O ~ SP -5~7188 GR 92 RHOB -99g.7500 nR~O -q99 DEPT 4~00.0000 SFLU 3 SP -64.2500 ~R 105 ~OB -~9~.2500 DRHO -g9q NPHI -~9q,2500 NCN[~ -999 DEPT 4500. 0000 SFT.U 3 SP -61.. 53 ~ 3 GR 97 RHOB -990 2500 DRNO -g9g WPH.I -qgg: 2500 Df]PT 4~00,0000 SFLU 4 SP -64,7500 GR 91 RHOB -~90.2500 DRHO -099 ~PHI -o99.~500 NCNh OEPT 4100.0000 SFI{,,l 2000 ~p -21.0938 ~R ~ 5~ RH, OB -999.~500 DR!40 ~99 NP[.lI -o9q.2500 NCML 999 ** F!I.,W, TRAILE SERVICF [TAr~ E FI!,E TYPE .7441 .0000 .2500 .2500 .3047 8750 :2500 .2500 .8125 .~500 .2500 i31~5 ~500 2500 .57~1 2500 i2500 ~500 0938 i~875 ~500 .~500 .0938 3750 2500 :~500 00oo )?~00 .2500 .~500 NRAT FCNL TLr) ~)RIT !*CNL Ibm, GR NRAT FC~)L ~R MRAT ~R WCNb MRhT FCNb lbo MRAT fCMb .001, 1,02d EOF' ********** 4.22~7 -999.2500 -099.2500 -990.2500 .-o99.~,5oo 999.2500 -090.2500 1836 : oo 99:~500 4 0,469 -999.2500 4.0~25 -~99,2500 -999,~500 -099.~500 ~99 2500 2500 -q99 2500 4 ,4258 -999:,,2500 -09,9,2500 -099. 2500 8.7109 -999,2500 -09:9.2500 -999.2500 CAI, I T bM CALI RN~A .! bM CALI RNRA CALl RNRA ! bM CALl RNRA CALl RNRA RNRA CALl RNRA 3.9746 -099,2500 -999.2500 3.0781 -099,2500 -999,2500 3 1660 ~999!2500 -999 2500 3,9355 -999,2500 -99q,2500 3.8867 2999,2500 999,2500 4,6719 99, O0 4,1562 ~999,2500 -999,2500 2000,0000 -999,2500 -999,2500 EOF
