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191-141
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2M-03 (PTD 191-141) OA exceeded OPL Date:Tuesday, July 1, 2025 2:47:39 PM Attachments:AnnComm Surveillance TIO for 2M-03.pdf From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Tuesday, July 1, 2025 2:45 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Automation, AK Wells <akwellsautomation@conocophillips.com> Subject: KRU 2M-03 (PTD 191-141) OA exceeded OPL Well Name: 2M-03 Facility: CPF2 PTD: 191-141 Well Type: Inj AA Number (if applicable): Internal Waiver (Yes/No if applicable): Type of Issue: OA Exceeded OPL Maximum Pressure (if applicable): 1100 Date of Occurrence (if applicable): 6/30/2025 Hi Chris, KRU 2M-03 (PTD 191-141) is an WAG injection well currently on MI injection. The OA was cemented to 8 ft from surface during a rig work over in 2024. The operator found the OA at 1100 psi on 6/30/2025. The operator bled the OA to 100 psi. The cause of the high pressure on the OA is thermal. CPAI does not intend to conduct diagnostics or additional monitoring at this time. Please let me know if you have any questions or disagree with the plan. The TIO, schematic, and bleed log are attached. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2M-03 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2M-03 2025-06-22 1800.0 1000 -800.0 IA 2M-03 2025-06-30 1100.0 100 -1000.0 OA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:RKB (Est. 87' of Rathole) 7,365.0 2M-03 5/15/2020 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Swapped out SOV, pulled RHC, pulled plug 2M-03 5/6/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE:11/10/2010 condijw 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 42.0 123.0 123.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 41.5 3,323.2 2,913.9 36.00 J-55 BTC Tie-Back String 7 6.28 40.6 1,804.4 1,733.3 26.00 L-80 HYD 563 Production 7 6.28 41.8 7,516.2 26.00 J-55 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 7,058.4 Set Depth … 5,934.4 String Max No… 3 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection HYD 563 ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 40.3 40.3 0.13 Hanger 6.982 3.5" FMC Gen 4 tubing hanger, H- BPV, EUE Lift threads FMC GEN IV 2.952 6,969.2 5,861.2 34.97 Mandrel – GAS LIFT 5.640 3.5" x 1.5" SLB MMG, GLM (SN#: 24384-09) SLB MMG 2.920 7,028.7 5,910.0 34.86 Nipple - X 4.506 3.5" HES 2.81" X-Nipple (SN#: 4792263702-01-001) HES 2.81" X 2.813 7,045.7 5,924.0 34.85 Locator 4.240 Baker Locator (4.24" No-Go) Baker 2.990 7,046.5 5,924.6 34.85 Seal Assembly 3.990 Baker GBH-22, 80-40 Seal Assembly (2' space out), (SN#: 453010065) Baker GBH-22, 80-40 2.990 Top (ftKB) 7,048.5 Set Depth … 7,089.8 Set Depth … 5,960.2 String Max No… 5.41 Tubing Description Tubing – Completion Lower Wt (lb/ft) Grade Top Connection ID (in) 2.97 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,048.5 5,926.3 34.85 PBR 5.410 OTIS PBR w/ 10' STROKE & 4" SEAL BORE OTIS 2.970 7,064.4 5,939.3 34.84 PACKER 6.000 OTIS HVT RETRIEVABLE PACKER OTIS HVT 3.250 7,079.7 5,951.9 34.84 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 7,089.2 5,959.7 34.83 WLEG 4.500 OTIS RH BALL SEAT SUB/WIRELINE ENTRY GUIDE, NO ELMD LOG AVAILABLE OTIS 2.875 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) 40.6 40.6 0.13 EMERGENCY SLIPS 11" x 7" C-21 Emergency Slips 4/5/2024 7.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 6,969.2 5,861.2 34.97 1 GAS LIFT DMY RK 1 1/2 0.0 4/28/2024 SLB MMG 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 1,788.7 1,720.6 35.67 Collar - Stage 8.250 CMTR,TYPE H ES-II, HYD 563 L- 80, S/N#: 5031046-03 Halliburto n HES II CMTR 6.125 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,183.0 7,203.0 6,036.8 6,053.2 C-4, 2M-03 11/8/1992 4.0 IPERF 180 deg. phasing; Oriented 105 deg. CCW, 2 1/2" Titan 7,214.0 7,224.0 6,062.3 6,070.6 A-4, 2M-03 2/22/1992 4.0 IPERF 180 deg. phasing; Oriented 84.25 deg. CCW, 4 1/2" HJ II Csg Gun 7,238.0 7,258.0 6,082.1 6,098.6 A-3, 2M-03 2/21/1992 4.0 IPERF 180 deg. phasing; Oriented 172 deg. CCW, 4 1/2" HJ II Csg Gun 7,258.0 7,278.0 6,098.6 6,115.2 A-3, 2M-03 2/21/1992 4.0 IPERF 180 deg. phasing; Oriented 166 deg. CCW, 4 1/2" HJ II Csg Gun 2M-03, 5/7/2024 10:07:42 AM Vertical schematic (actual) Production; 1,800.9-7,516.2 IPERF; 7,258.0-7,278.0 IPERF; 7,238.0-7,258.0 IPERF; 7,214.0-7,224.0 IPERF; 7,183.0-7,203.0 PACKER; 7,064.4 Nipple - X; 7,028.7 BALL & ROD; 7,021.0 Mandrel – GAS LIFT; 6,969.2 SURFACE; 41.5-3,323.2 Tie-Back String; 40.6-1,804.4 Production String 1 Cement; 240.0 ftKB CONDUCTOR; 42.0-123.0 EMERGENCY SLIPS; 40.6 Hanger; 40.3 KUP INJ KB-Grd (ft) 41.01 RR Date 1/3/1992 Other Elev… 2M-03 ... TD Act Btm (ftKB) 7,512.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032016000 Wellbore Status INJ Max Angle & MD Incl (°) 40.75 MD (ftKB) 2,400.00 WELLNAME WELLBORE2M-03 Annotation Last WO: End Date 4/11/2024 H2S (ppm) DateComment SSSV: TRDP MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 25, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2M-03 KUPARUK RIV UNIT 2M-03 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2024 2M-03 50-103-20160-00-00 191-141-0 W SPT 5938 1911410 1500 2131 2142 2147 2147 20 150 90 90 4YRTST P Sully Sullivan 6/22/2024 tested to 2800 for 500 psi dp 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 2M-03 Inspection Date: Tubing OA Packer Depth 880 2810 2720 2710IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240624174535 BBL Pumped:1.9 BBL Returned:1.5 Thursday, July 25, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 99 9 9 9 9James B. Regg Digitally signed by James B. Regg Date: 2024.07.25 14:39:34 -08'00' Originated: Delivered to:5-Jul-24 Alaska Oil & Gas Conservation Commiss 05Jul24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED CD4-586 50-103-20857-00-00 223-046 Colville River WL TTiX-PPROF FINAL FIELD 3-Mar-24 CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX-PPROF FINAL FIELD 7-Mar-24 2M-12 50-103-20181-00-00 192-090 Kuparuk River WL SCMT FINAL FIELD 8-Mar-24 1B-16A 50-029-22457-01-00 218-155 Kuparuk River WL RST FINAL FIELD 9-Mar-24 CD4-588 50-103-20853-00-00 223-029 Colville River WL TTiX-PPROF FINAL FIELD 22-Mar-24 CD5-23 50-103-20761-00-00 217-155 Colville River WL Packer Setting FINAL FIELD 24-Mar-24 3F-08 50-029-21464-00-00 185-246 Kuparuk River WL SCMT FINAL FIELD 30-Mar-24 2M-03 50-103-20160-00-00 191-141 Kuparuk River WL SCMT FINAL FIELD 31-Mar-24 2B-14 50-029-21143-00-00 184-111 Kuparuk River WL WFL FINAL FIELD 3-Apr-24 2T-41 50-103-20675-00-00 213-146 Kuparuk River WL PPROF FINAL FIELD 7-Apr-24 MT7-03A 50-103-20830-01-00 223-084 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 22-May-24 MT7-01 50-103-20832-00-00 221052 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 27-May-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39122 T39123 T39124 T39125 T39126 T39127 T39128 T39129 T39130 T39131 T39132 T39133 2M-03 50-103-20160-00-00 191-141 Kuparuk River WL SCMT FINAL FIELD 31-Mar-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.05 10:30:21 -08'00' 191-141 T38907 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.12 12:58:18 -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 7512'feet None feet true vertical 6309' feet None feet Effective Depth measured 7365'feet 7064'feet true vertical 6187'feet 5939'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)3-1/2" 3-1/2" L-80 J-55 7058' 7090' 5943' 5960' Packers and SSSV (type, measured and true vertical depth)7064' 5939' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: 3323'2914' Burst Collapse Production 1763' 7475' Casing 1733' 6306' 1804' 7516' 3282' 123'Conductor Surface Tie-Back 16" 9-5/8" 82' measured TVD 7" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 191-141 50-103-20160-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025586 Kuparuk River Field/ Kuparuk Oil Pool KRU 2M-03 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 MDSize 123' Well Shut-In 324-052 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: Otis PBR SSSV: None James Ohlinger james.j.ohlinger@conocophillips.com (907) 267-1102Staff RWO/CTD Engineer 7183-7203', 7214-7224', 7238-7278' 6037'-6053', 6062-6071', 6082'-6115' Fra O s 6. A PG , C g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E= James.J.Ohlinger@cop.com Reason: I am the author of this document Location: Date: 2024.05.09 14:33:56-08'00' Foxit PDF Editor Version: 13.0.0 James J. Ohlinger RBDMS JSB 051524 DSR=5/13/24 Page 1/17 2M-03 Report Printed: 5/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/25/2024 03:00 3/25/2024 09:00 6.00 MIRU, MOVE MOB P Move off 2M-12 // Prep 2M-03 for backing over well // Spot well head equipment in cellar // Back over 2M-03 0.0 0.0 3/25/2024 09:00 3/25/2024 14:30 5.50 MIRU, MOVE RURD P Rig up and safe out over well // Spot cuttings tank and HL trailer //Complete pre-accept checklist // prep to bring on seawater // Spot tiger tank and open top tank // Rig accepted 14:30 0.0 0.0 3/25/2024 14:30 3/25/2024 17:00 2.50 MIRU, WELCTL RURD P Take on seawater // Rig up for well kill operations // 0.0 0.0 3/25/2024 17:00 3/25/2024 18:00 1.00 MIRU, WELCTL PRTS P Flood lines to tiger tank and open top // PT lines 2500 psi good test // Blow down line to tiger tank 0.0 0.0 3/25/2024 18:00 3/25/2024 20:45 2.75 MIRU, WELCTL DISP P PJSM // Verify tank straps and confirm deep clean pill made // Circulate well w/ 390 bbls 8.5+ seawater @ 5 bbls/min @ 360 psi // Pump 320 bbls clean seawater back shut down for flow check 0.0 0.0 3/25/2024 20:45 3/25/2024 21:15 0.50 MIRU, WELCTL OWFF P Flow check well // no flow // 0.0 0.0 3/25/2024 21:15 3/25/2024 22:15 1.00 MIRU, WELCTL MPSP P Blow down lines // Install ISA BPV // Test BPV 1000 psi 10 min // Good test 0.0 0.0 3/25/2024 22:15 3/26/2024 00:00 1.75 MIRU, WHDBOP NUND P Rig down circulating lines // ND production tree 0.0 0.0 3/26/2024 00:00 3/26/2024 01:00 1.00 MIRU, WHDBOP MPSP P Set test plug 0.0 0.0 3/26/2024 01:00 3/26/2024 04:30 3.50 MIRU, WHDBOP NUND P NU Adapter flange ad DSA. Set stack. Torque up 0.0 3/26/2024 04:30 3/26/2024 07:00 2.50 MIRU, WHDBOP RURD P Rig up BOPE testing equipment 0.0 0.0 3/26/2024 07:00 3/26/2024 09:00 2.00 MIRU, WHDBOP RURD P Fill stack. Purge air from stack 0.0 0.0 3/26/2024 09:00 3/26/2024 17:00 8.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested annular, UVBR's, LVBR’s w/ 3 1/2" test joints. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½” EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3000 PSI, after closure=1600 PSI, 200 PSI attained =19 sec, full recovery attained =121 sec. UVBR's= 4 sec, LVBR’s= 4 sec. Annular= 16 sec. Simulated blinds= 4 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =2100 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Brian Bixby. 0.0 0.0 3/26/2024 17:00 3/26/2024 18:30 1.50 MIRU, WHDBOP RURD P Pull slip over blanking plug. B/D, R/D testing equipment. Suck out stack. 0.0 0.0 3/26/2024 18:30 3/26/2024 19:30 1.00 MIRU, WHDBOP MPSP P Pull ISA BPV 0.0 0.0 3/26/2024 19:30 3/26/2024 20:00 0.50 COMPZN, RPCOMP PULD P M/U landing joint. BOLDS. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/11/2024 Page 2/17 2M-03 Report Printed: 5/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/26/2024 20:00 3/26/2024 20:30 0.50 COMPZN, RPCOMP PULL P Pull hanger T/ RF F/ 7027' T/ 6997'. Pipe free @ 125K. Heave weight swigs F/ 120-110K. 7,027.0 6,997.0 3/26/2024 20:30 3/26/2024 21:00 0.50 COMPZN, RPCOMP PULD P L/D landing joint & hanger. 6,997.0 6,997.0 3/26/2024 21:00 3/26/2024 21:15 0.25 COMPZN, RPCOMP RURD P R/U HES spooling unit. 6,997.0 6,997.0 3/26/2024 21:15 3/26/2024 21:30 0.25 COMPZN, RPCOMP SFTY P PJSM w/ HES spooler & rig crew on L/D 3 1/2" completion. 6,997.0 6,997.0 3/26/2024 21:30 3/26/2024 23:30 2.00 COMPZN, RPCOMP PULD P Cont L/D 3 1/2" completion F/ 6997' T/ 6069', PUW=120K. Brought SSSV 948' up hole. Leaving 794' below wellhead. 6,997.0 6,079.0 3/26/2024 23:30 3/27/2024 00:00 0.50 COMPZN, RPCOMP RURD P Mobilize BHA #1 drift mill T/ RF. 6,079.0 6,079.0 3/27/2024 00:00 3/27/2024 00:30 0.50 COMPZN, RPCOMP RURD P Mobilize BHA #1 drift mill T/ RF. 6,079.0 6,079.0 3/27/2024 00:30 3/27/2024 01:30 1.00 COMPZN, RPCOMP BHAH P M/U BHA #1 5 7/8" sting mill on top of 3 1/2" EUE joint #29. 6,079.0 6,079.0 3/27/2024 01:30 3/27/2024 03:00 1.50 COMPZN, RPCOMP PULD P RIH w/ BHA #1 attempt to drift wellhead. Could not pass with mill @ 30.63'. Pull mill and inspect. Visible damage to mill face on 5 of the 6 blades ~ 5.25" OD. 6,079.0 6,079.0 3/27/2024 03:00 3/27/2024 03:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #1 5 7/8" sting mill. 6,079.0 6,079.0 3/27/2024 03:30 3/27/2024 05:30 2.00 COMPZN, RPCOMP PULL P Cont L/D 3 1/2" completion F/ 6069' T/ 5856' PUW=94K. SOW=64K. Brought SSSV 1170' up hole. Leaving 575' below wellhead. No control of SS control line. 6,079.0 5,856.0 3/27/2024 05:30 3/27/2024 06:00 0.50 COMPZN, RPCOMP RURD P P/U tools through beaver slide 5,856.0 5,856.0 3/27/2024 06:00 3/27/2024 07:30 1.50 COMPZN, RPCOMP RUNL P C/O elevators from tubing to drill pipe. Shuffle stands for tally alignment 5,856.0 5,856.0 3/27/2024 07:30 3/27/2024 08:30 1.00 COMPZN, RPCOMP BHAH P M/U BHA #2, GS spear and joint of drill pipe 5,856.0 5,856.0 3/27/2024 08:30 3/27/2024 12:00 3.50 COMPZN, RPCOMP PULD P Attempt to travel down. Unable to travel past 5854. Hanging up in well head. Manipulate pipe with rig floor winches and tongs - No success 5,856.0 5,856.0 3/27/2024 12:00 3/27/2024 14:00 2.00 COMPZN, RPCOMP PULD P L/D drill pipe working joint, Swap elevators back to tubing. PUH 5854 to 5824. Recovered two SS clamps no control line from top of joint #38. Inspected bottom of coupler. Observed dent where it was setting down. Set slips low. Remove coupler. Replace with special clearance coupler 5,856.0 5,824.0 3/27/2024 14:00 3/27/2024 15:30 1.50 COMPZN, RPCOMP BHAH P Swap elevators tubing back to drill pipe. Make up BHA #3 GS to completion on DP. Work into well 5,824.0 5,860.0 3/27/2024 15:30 3/27/2024 19:30 4.00 COMPZN, RPCOMP TRIP P RIH w/ 3 1/2" EUE completion sting with GS spear on DP T/ 6689'. PUW=102K, SOW=64K. Tagged up hard @ 865' GS spear depth. Set TD weight down on string, unable to pass. P/U clean 115K. SSSV @ ~1432'. 5,860.0 6,689.0 3/27/2024 19:30 3/27/2024 20:00 0.50 COMPZN, RPCOMP COND P Mix 35 Bbls 2.5% low torque lube pill. 6,689.0 6,689.0 3/27/2024 20:00 3/27/2024 21:00 1.00 COMPZN, RPCOMP CIRC P Close UPR. Reverse circ 27 Bbls lube pill @ .5 BPM, 100 PSI. 6,689.0 6,689.0 Rig: NORDIC 3 RIG RELEASE DATE 4/11/2024 Page 3/17 2M-03 Report Printed: 5/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/27/2024 21:00 3/27/2024 22:00 1.00 COMPZN, RPCOMP PULD P P/U 30' PUW=120-115K. SOW=70K. Tagged hard in same spot @ 865' spear depth. Set down T/ 35K. Pump @ 1.5 BPM, 500 PSI. Attempt to release from tubing w/ GS spear multiple times. Unsuccessful. 6,689.0 6,689.0 3/27/2024 22:00 3/28/2024 00:00 2.00 COMPZN, RPCOMP TRIP P B/D TD. Called out string of 3 1/2' IBT SC collars. POOH F/ 6688' T/ 6138', PUW=112K. 6,689.0 6,138.0 3/28/2024 00:00 3/28/2024 00:30 0.50 COMPZN, RPCOMP TRIP P POOH F/ 6138' T/ 5860', PUW=95K. Loading 3 1/2" IBT tubing into shed. 6,138.0 5,860.0 3/28/2024 00:30 3/28/2024 01:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA #3 GS spear on DP. T/ 5824'. 5,860.0 5,824.0 3/28/2024 01:00 3/28/2024 03:00 2.00 COMPZN, RPCOMP RURD P R/U tubing handling equipment. Process 3 1/2" IBT SC tubing. 5,824.0 5,824.0 3/28/2024 03:00 3/28/2024 03:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #4 GS spear T/ IBT tubing. F/ 5824 T/ 5840. 5,824.0 5,840.0 3/28/2024 03:30 3/28/2024 05:00 1.50 COMPZN, RPCOMP PULD P RIH w/ 3 1/2" EUE completion sting with GS spear on IBT tubing F/ 5840', T/ 6403'. 579' GS depth. 5,840.0 6,403.0 3/28/2024 05:00 3/28/2024 09:00 4.00 COMPZN, RPCOMP PULD P Continue in 1199' GS set down. Kelly up, PUW=97K, RIW=75K. Bring pumps online 2.5 BPM @ 2400 PSI. Set down 40 K, Lift off completion, PUW=45. Kelly down, Blow down top drive 6,403.0 7,028.0 3/28/2024 09:00 3/28/2024 11:00 2.00 COMPZN, RPCOMP TRIP P Trip out of well 7,028.0 18.8 3/28/2024 11:00 3/28/2024 11:30 0.50 COMPZN, RPCOMP BHAH P Lay down BHA #4 18.8 0.0 3/28/2024 11:30 3/28/2024 12:00 0.50 COMPZN, RPCOMP BHAH P P/U BHA #5 IBP 0.0 32.7 3/28/2024 12:00 3/28/2024 12:30 0.50 COMPZN, RPCOMP RGRP P Replace broken gauge on tongs 32.7 32.7 3/28/2024 12:30 3/28/2024 15:00 2.50 COMPZN, RPCOMP TRIP P RIH BHA #5, RIW=40K. Fill string with hose. Make up head pin and hose to sensator. PUW=43K, RIW=40K. Pressure up to 1000PSI. Hesitate 5 minutes. go up in 500 PSI increments 5 minute hesitation. See tool shift @ 2800PSI. Able to circulate. Plug set 680' COE. TOP=673 32.7 686.0 3/28/2024 15:00 3/28/2024 17:00 2.00 COMPZN, RPCOMP PULD P POOH sideways with 3 1/2" IBT tubing T/ 32' 686.0 32.0 3/28/2024 17:00 3/28/2024 17:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #5 32.0 0.0 3/28/2024 17:30 3/28/2024 18:00 0.50 COMPZN, RPCOMP PRTS P PT IBP T/ 1000 PSI for 10 Min. 0.0 0.0 3/28/2024 18:00 3/28/2024 19:30 1.50 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. 0.0 0.0 3/28/2024 19:30 3/28/2024 21:15 1.75 COMPZN, RPCOMP NUND P N/D BOP. Strip equipment off of TBG head. 0.0 0.0 3/28/2024 21:15 3/28/2024 22:00 0.75 COMPZN, RPCOMP RURD P R/U Hydratight equipment on TBG head & CSG head flanges. 0.0 0.0 3/28/2024 22:00 3/28/2024 22:15 0.25 COMPZN, RPCOMP SFTY P PJSM w/ PESI and rig crew on growing 7" CSG. 0.0 0.0 3/28/2024 22:15 3/29/2024 00:00 1.75 COMPZN, RPCOMP NUND P Grow 7" CSG w/ Hydratight. 0.0 0.0 3/29/2024 00:00 3/29/2024 00:45 0.75 COMPZN, RPCOMP NUND P Grow 7" CSG w/ Hydratight. Total growth of 31.75". Allow 7" to relax for 30 Min. 0.0 0.0 3/29/2024 00:45 3/29/2024 01:15 0.50 COMPZN, RPCOMP NUND P Remove TBG head. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/11/2024 Page 4/17 2M-03 Report Printed: 5/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/29/2024 01:15 3/29/2024 04:00 2.75 COMPZN, RPCOMP CUTP P Make initial cut on 7" CSG w/ Whacks saw to remove bottle neck top @ 5.25" ID. M/U 7" spear. Engage stub. Pull 125K tension in 7". Re-land in emergency slips. Install original pack off. Total stretch of 20.5". Over all growth of 52.25". A 3/4" X 6" extension and Allen head socket were dropped into hole. Make final cut on 7" w/ Whacks saw; 0.0 0.0 3/29/2024 04:00 3/29/2024 07:00 3.00 COMPZN, RPCOMP RURD P Mobilize 11" 3K x 11" 5K DSA w/ test ports to cellar. Mobilize SL unit to fish extension and socket in well. NU DSA with test ports 0.0 0.0 3/29/2024 07:00 3/29/2024 10:00 3.00 COMPZN, RPCOMP NUND P N/U BOPE. Test 3K flange via test ports and testable API rings 250 / 3000PSU. Test 5K flange 250 / 3500 Good test. R/U slick line to fish tools in well 0.0 0.0 3/29/2024 10:00 3/29/2024 17:00 7.00 COMPZN, RPCOMP SLKL P Continue NU BOP. M/U slick line tool string with magnets. RIH to retrieve tools dropped in well 0.0 0.0 3/29/2024 17:00 3/29/2024 19:00 2.00 COMPZN, RPCOMP SLKL P Run 9, Recover 3/4" drive X 8" extension from 671' . Continue w/ 1 additional magnet run for Allen head socket. No joy. 0.0 0.0 3/29/2024 19:00 3/29/2024 19:30 0.50 COMPZN, RPCOMP SLKL P R/D & release slick line. 0.0 0.0 3/29/2024 19:30 3/29/2024 20:30 1.00 COMPZN, RPCOMP NUND P Install riser & hook up trip tank hose. Align BOP stack. 0.0 0.0 3/29/2024 20:30 3/29/2024 21:00 0.50 COMPZN, RPCOMP RURD P R/U testing equipment. 0.0 0.0 3/29/2024 21:00 3/29/2024 21:15 0.25 COMPZN, RPCOMP PRTS P Shell test BOP, choke & kill lines. 0.0 0.0 3/29/2024 21:15 3/29/2024 21:30 0.25 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. 0.0 0.0 3/29/2024 21:30 3/29/2024 22:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #7 Modified lower extension w/ 5 3/4" overshot. T/ 5'. 0.0 5.0 3/29/2024 22:00 3/29/2024 23:00 1.00 COMPZN, RPCOMP TRIP P RIH w/ BHA #7 T/ 653', PUW=45K, SOW=45K. 5.0 653.0 3/29/2024 23:00 3/30/2024 00:00 1.00 COMPZN, RPCOMP MPSP P Wash down @ 5 BPM, 115 PSI T/ 671'. Engage IBP top. P/U 15K shift IBP. P/U additioal 1'. Allow elements to relax for 30 Mn. 653.0 671.0 3/30/2024 00:00 3/30/2024 00:45 0.75 COMPZN, RPCOMP TRIP P POOH F/ 671' T/ 30'. PUW=45K. 671.0 30.0 3/30/2024 00:45 3/30/2024 01:15 0.50 COMPZN, RPCOMP BHAH P L/D BHA #7 & IBP; Inspect overshot no Allen head socket. 30.0 0.0 3/30/2024 01:15 3/30/2024 01:45 0.50 COMPZN, RPCOMP RURD P R/U TBG handling equipment. 0.0 0.0 3/30/2024 01:45 3/30/2024 02:30 0.75 COMPZN, RPCOMP TRIP P RIH w/ 5 stands of 3 1/2" IBT tubing T/ 480'. 0.0 480.0 3/30/2024 02:30 3/30/2024 03:00 0.50 COMPZN, RPCOMP SVRG P Service rig 480.0 480.0 3/30/2024 03:00 3/30/2024 04:00 1.00 COMPZN, RPCOMP PULD P L/D 3 1/2" IBT tubing F/ 480'. 480.0 0.0 3/30/2024 04:00 3/30/2024 04:30 0.50 COMPZN, RPCOMP RURD P R/D TBG handling equipment. 0.0 3/30/2024 04:30 3/30/2024 05:30 1.00 COMPZN, RPCOMP BHAH P M/U BHA #8 tandem 5 7/8" & 6 1/16" string mill T/ 17' 0.0 17.0 3/30/2024 05:30 3/30/2024 07:30 2.00 COMPZN, RPCOMP TRIP P Trip in to 1200', tight @ 219-233, 3 to 5K, tight 355 to 386. 3 to 5K. Tight 520 to 540 17.0 1,200.0 Rig: NORDIC 3 RIG RELEASE DATE 4/11/2024 Page 5/17 2M-03 Report Printed: 5/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/30/2024 07:30 3/30/2024 08:00 0.50 COMPZN, RPCOMP TRIP P 1200', POOH, PUW=54K 1,200.0 17.0 3/30/2024 08:00 3/30/2024 09:00 1.00 COMPZN, RPCOMP BHAH P Lay down drift. P/U RCJB 17.0 39.3 3/30/2024 09:00 3/30/2024 10:00 1.00 COMPZN, RPCOMP TRIP P Trip in hole to 1150. Kelly up, 54K up and down 39.3 1,180.0 3/30/2024 10:00 3/30/2024 11:30 1.50 COMPZN, RPCOMP CIRC P Break circulation Circ BU 8 BPM @1167 PSI, Pump 20 BBl Hi Vis sweep 1,180.0 1,198.0 3/30/2024 11:30 3/30/2024 12:00 0.50 COMPZN, RPCOMP TRIP P Shut down pump. Pull one stand. Kelly down, Blow down top drive. TOOH F/1198 1,198.0 39.0 3/30/2024 12:00 3/30/2024 13:00 1.00 COMPZN, RPCOMP BHAH P Lay down BHA #9 RCJB, Recover one SS band. No Allen head socket. M/U BHA #10- 5 3/4" overshot. 39.0 34.3 3/30/2024 13:00 3/30/2024 15:30 2.50 COMPZN, RPCOMP TRIP P Trip in hole, KU 1170, Break circulation. PUW=54K, RIW=54K, 1 BPM @ 52 PSI with returns. Ease in hole set down @ 1200'. PUH no latch, Index 1/4 turn. Set down 1202. PUH to 66K. Set back down 10K. PUH weight break over @ 105K. Circ BU @ 1174' 34.3 1,202.0 3/30/2024 15:30 3/30/2024 17:00 1.50 COMPZN, RPCOMP TRIP P POOH racking back DP F/ 1202' T/ 34' 1,202.0 34.0 3/30/2024 17:00 3/30/2024 18:00 1.00 COMPZN, RPCOMP BHAH P At overshot. Lay down BHA #10 34.0 0.0 3/30/2024 18:00 3/30/2024 18:30 0.50 COMPZN, RPCOMP RURD P R/U tubing handling equipment. 0.0 0.0 3/30/2024 18:30 3/30/2024 20:00 1.50 COMPZN, RPCOMP PULL P L/D 3 1/2" completion F/ 5824' T/ 5225'. PUW=82K. Balled up control on collar of joint #51, #52, #54. Recovered Allen head socket inside SSSV on hold open sleeve. 0.0 5,225.0 3/30/2024 20:00 3/30/2024 23:30 3.50 COMPZN, RPCOMP PULL P Cont L/D completion F/ 5225' T/ 2006', PUW=70K. 5,225.0 2,006.0 3/30/2024 23:30 3/31/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service rig. Change dies on power tongs. 2,006.0 2,006.0 3/31/2024 00:00 3/31/2024 01:45 1.75 COMPZN, RPCOMP PULL P Cont L/D 3 1/2" completion F/ 2006' T/ surface. 15.43' cut joint was flared on 1 side 3.75" OD Heavy corrosion on collars F/ joint #176 bottom 1400' of hole. 2,006.0 0.0 3/31/2024 01:45 3/31/2024 03:15 1.50 COMPZN, RPCOMP CLEN P Clean and clear RF and pipe shed. Send out HES spooling unit. Spot E- Line unit. Mobilize E-Line tools T/ RF. 0.0 0.0 3/31/2024 03:15 3/31/2024 03:45 0.50 COMPZN, RPCOMP SFTY P PJSM w/ SLB E-line on R/U and run CBL. 0.0 0.0 3/31/2024 03:45 3/31/2024 05:15 1.50 COMPZN, RPCOMP ELNE P R/U SLB E-Line w/ CBL & CCL 0.0 0.0 3/31/2024 05:15 3/31/2024 08:30 3.25 COMPZN, RPCOMP ELNE P RIH W/CCL and CBL tools. Zero at rig floor. Log 3000' to surface 0.0 0.0 3/31/2024 08:30 3/31/2024 09:00 0.50 COMPZN, RPCOMP ELNE P Rig down E-line 0.0 0.0 3/31/2024 09:00 3/31/2024 10:30 1.50 COMPZN, RPCOMP BHAH P Clear and clean rig floor, M/U BHA #11 RBP 0.0 47.8 3/31/2024 10:30 3/31/2024 12:00 1.50 COMPZN, RPCOMP TRIP P Trip in well At 2240 PUW=67. SOW=65K 47.8 2,262.0 3/31/2024 12:00 3/31/2024 12:45 0.75 COMPZN, RPCOMP MPSP P Perform plug set. Top of plug @ 2252.8, COE=2256.8. Lift off. 2,262.0 2,236.0 3/31/2024 12:45 3/31/2024 13:45 1.00 COMPZN, RPCOMP MPSP P Rig up and fluid pack to PT RBP, PT 1000PSI - 10 minutes 2,236.0 2,236.0 3/31/2024 13:45 3/31/2024 14:15 0.50 COMPZN, RPCOMP RURD P Pull stand, Lay down single, Rig up to dump sand 2,236.0 2,143.0 Rig: NORDIC 3 RIG RELEASE DATE 4/11/2024 Page 6/17 2M-03 Report Printed: 5/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/31/2024 14:15 3/31/2024 23:30 9.25 COMPZN, RPCOMP OTHR P Dump 25 bags = 65' of sand on top of RBP. Let sand settle. 2,143.0 2,143.0 3/31/2024 23:30 4/1/2024 00:00 0.50 COMPZN, RPCOMP RURD P B/D, R/D circ equipment. 2,143.0 2,143.0 4/1/2024 00:00 4/1/2024 00:45 0.75 COMPZN, RPCOMP TRIP P POOH F/ 2143' T/ 6'. PUW=65K. 2,143.0 6.0 4/1/2024 00:45 4/1/2024 01:00 0.25 COMPZN, RPCOMP BHAH P L/D BHA #11 RBP running tool. . 6.0 0.0 4/1/2024 01:00 4/1/2024 02:45 1.75 COMPZN, RPCOMP NUND P C/O LPR T/ 7" fixed. 0.0 0.0 4/1/2024 02:45 4/1/2024 03:30 0.75 COMPZN, RPCOMP RURD P R/U testing equipment. 0.0 0.0 4/1/2024 03:30 4/1/2024 04:00 0.50 COMPZN, RPCOMP PRTS P PT LPR w/ 7" TJ T/ 250/3000 PSI for 5 min each. 0.0 0.0 4/1/2024 04:00 4/1/2024 04:30 0.50 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. 0.0 0.0 4/1/2024 04:30 4/1/2024 04:45 0.25 COMPZN, RPCOMP BHAH P M/U BHA #12 MSC. 0.0 5.0 4/1/2024 04:45 4/1/2024 05:30 0.75 COMPZN, RPCOMP TRIP P RIH w/ BHA #12 tag sand top @ 2190'. 5.0 2,190.0 4/1/2024 05:30 4/1/2024 06:30 1.00 COMPZN, RPCOMP TRIP P PUH, rack back 4 stands, Locate collars, 1 BPM @ 80 PSI, 1861 and 1819. PUH make cut @ 1790., 90 RPM TQ @ 8.7K, 5 BPM @ 936 PSI 2,190.0 1,790.0 4/1/2024 06:30 4/1/2024 07:30 1.00 COMPZN, RPCOMP CIRC P Circ BU for slight gas, 2 BPM @ 198 PSI 1,790.0 1,790.0 4/1/2024 07:30 4/1/2024 08:00 0.50 COMPZN, RPCOMP TRIP P Blow down top drive, Trip out F//1790 1,790.0 4.7 4/1/2024 08:00 4/1/2024 08:30 0.50 COMPZN, RPCOMP BHAH P Lay down cutter and working joint 4.7 0.0 4/1/2024 08:30 4/1/2024 12:00 3.50 COMPZN, RPCOMP CIRC P PJSM, R/U LRS to test spool. Line up returns from OA to OT tank. Pump 70 BBls Hot Diesel. Pump 280 BBls hot water. Arctic pack in open top 0.0 0.0 4/1/2024 12:00 4/1/2024 13:00 1.00 COMPZN, RPCOMP RURD P Blow down all lines, R/D LRS 0.0 0.0 4/1/2024 13:00 4/1/2024 13:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #12 7" casing spear 0.0 12.0 4/1/2024 13:30 4/1/2024 14:00 0.50 COMPZN, RPCOMP FISH P Latch spear into 7" tubing. Pull free @ 110K 12.0 0.0 4/1/2024 14:00 4/1/2024 14:30 0.50 COMPZN, RPCOMP NUND P PJSM, Nipple down stack, remove air boot, R/D trip tank line, Break bolts on DSA. P/U stack high enough to retrieve casing slips 0.0 0.0 4/1/2024 14:30 4/1/2024 15:00 0.50 COMPZN, RPCOMP RURD P FMC pulling casing slips 0.0 0.0 4/1/2024 15:00 4/1/2024 16:00 1.00 COMPZN, RPCOMP NUND P Install stack. Nipple up DSA. TQ Nuts 0.0 0.0 4/1/2024 16:00 4/1/2024 16:30 0.50 COMPZN, RPCOMP SEQP P Surface test DSA flange to 3000PSI 0.0 0.0 4/1/2024 16:30 4/1/2024 17:00 0.50 COMPZN, RPCOMP RURD P Install riser and air boot 0.0 0.0 4/1/2024 17:00 4/1/2024 18:00 1.00 COMPZN, RPCOMP PULD P Pull 7" cut joint to floor. Cut joint =30.48. Set slips. Back out working joint and lay dow. M/U 4' Pup joint. Mouse joint. Disengauge spear. 0.0 0.0 4/1/2024 18:00 4/1/2024 18:30 0.50 COMPZN, RPCOMP PULD P Lay down spear and cut joint to shed 0.0 0.0 4/1/2024 18:30 4/1/2024 19:00 0.50 COMPZN, RPCOMP RURD P RD spinners and tongs, RU GBR power tongs 0.0 4/1/2024 19:00 4/1/2024 21:00 2.00 COMPZN, RPCOMP PULL P PJSM, Pull 7" casing. 40 Jts and 14.58" cut joints, 14 centralizers 1,760.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/11/2024 Page 7/17 2M-03 Report Printed: 5/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/1/2024 21:00 4/1/2024 22:30 1.50 COMPZN, RPCOMP BHAH P Clear and clean rig floor, C/O floor equipment from GBR tongs to spinners and rig tongs, P/U YJ tools to floor. 0.0 0.0 4/1/2024 22:30 4/1/2024 23:00 0.50 COMPZN, RPCOMP BHAH P P/U BHA #14 8 3/8" string reamr 0.0 48.9 4/1/2024 23:00 4/2/2024 00:00 1.00 COMPZN, RPCOMP TRIP P RIH w/ BHA #14 T/ 850'. 48.9 850.0 4/2/2024 00:00 4/2/2024 01:00 1.00 COMPZN, RPCOMP TRIP P RIH w/ BHA #14 F/ 850', tagged top of 7" @ 1791'. PUW=60, SOW=60K. Very minimal drag RIH w/ 8 3/8" drift. 850.0 1,790.0 4/2/2024 01:00 4/2/2024 02:00 1.00 COMPZN, RPCOMP CIRC P CIrc Bbls hi vis sweep aorund @ 5 BPM, 225 PSI. Taking contaminated returns to cuttings tank. 1,790.0 1,790.0 4/2/2024 02:00 4/2/2024 03:00 1.00 COMPZN, RPCOMP TRIP P POOH F/ 1790' T/ 49'. PUW=60K. 1,790.0 49.0 4/2/2024 03:00 4/2/2024 03:45 0.75 COMPZN, RPCOMP BHAH P L/D BHA #14 F/ 49'. 49.0 0.0 4/2/2024 03:45 4/2/2024 05:15 1.50 COMPZN, RPCOMP CLEN P Clean & clear RF. Mobilize 6 1/4" DC to shed and process. 0.0 0.0 4/2/2024 05:15 4/2/2024 06:00 0.75 COMPZN, RPCOMP RURD P Install wear bushing. 0.0 0.0 4/2/2024 06:00 4/2/2024 06:30 0.50 COMPZN, RPCOMP SVRG P Service rig. 0.0 0.0 4/2/2024 06:30 4/2/2024 07:30 1.00 COMPZN, RPCOMP BHAH P M/U BHA #15 tandem 8 3/8" & 8 1/2" mills w/ DC's T/ 125', SOW=48K. 0.0 125.0 4/2/2024 07:30 4/2/2024 10:30 3.00 COMPZN, RPCOMP TRIP P RIH F/ 125' T/ 1791', PUW=67K, SOW=65K. 5K bobble @ 250' & 390' & 555' & 605'. 125.0 1,791.0 4/2/2024 10:30 4/2/2024 11:30 1.00 COMPZN, RPCOMP DISP P Displace well w/ vis seawater @ 5 BPM, 120 PSI. 1,791.0 1,791.0 4/2/2024 11:30 4/2/2024 12:00 0.50 COMPZN, RPCOMP COND P Suck out neat seawater from trip tank. Fill trip tank w/ vis seawater. 1,791.0 1,791.0 4/2/2024 12:00 4/2/2024 13:15 1.25 COMPZN, RPCOMP TRIP P POOH F/ 1791' T/ 125'. PUW=67K. 1,791.0 125.0 4/2/2024 13:15 4/2/2024 14:30 1.25 COMPZN, RPCOMP BHAH P L/D BHA #15 F/ 125'. PUW=45K. 125.0 0.0 4/2/2024 14:30 4/2/2024 15:00 0.50 COMPZN, RPCOMP CLEN P Clean and clear RF & Pipe shed. 0.0 0.0 4/2/2024 15:00 4/2/2024 15:45 0.75 COMPZN, RPCOMP MPSP P Pull wear bushing. Set test plug. 0.0 0.0 4/2/2024 15:45 4/2/2024 16:30 0.75 COMPZN, RPCOMP RURD P R/U testing equipment. 0.0 0.0 4/2/2024 16:30 4/2/2024 18:00 1.50 COMPZN, RPCOMP MPSP P Attempt T/ shell test. Test plug leaking, Drain stack. Pull test plug. Change out seal. Reinstall test plug. Fill stack w/ fresh water. 0.0 0.0 4/2/2024 18:00 4/3/2024 00:00 6.00 COMPZN, RPCOMP BOPE P Begin weekly BOP test w/ 3 1/2' and 7" Test Joints to 250/3000 psi. Approval granted by AOGCC to lower sundry test pressure to 3,000 psi due to casing flange rating. Witness waived by Sean Sullivan.. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/11/2024 Page 8/17 2M-03 Report Printed: 5/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/3/2024 00:00 4/3/2024 04:00 4.00 COMPZN, RPCOMP BOPE P Complete weekly BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular and UVBR's w/ 3 1/2" test joint. Test fixed LPR's w/ 7" test joint. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½” EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 2000 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 3075 PSI, after closure = 1625 PSI, 200 PSI attained = 25 sec, full recovery attained = 127 sec. UVBR's = 4 sec, LVBR’s= 4 sec. Annular= 19 sec. Simulated blinds= 4 sec. HCR choke & kill= 2 sec each. 4 back up nitrogen bottles average = 2175 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Sean Sullivan. 0.0 0.0 4/3/2024 04:00 4/3/2024 06:30 2.50 COMPZN, RPCOMP BOPE T F/P during Test #5. CMV #13 leaked. Redressed and re-tested. 0.0 0.0 4/3/2024 06:30 4/3/2024 07:30 1.00 COMPZN, RPCOMP RURD P B/D, R/D pressure testing equipment. 0.0 0.0 4/3/2024 07:30 4/3/2024 08:00 0.50 COMPZN, RPCOMP MPSP P Pull test plug. Set wear ring. 0.0 0.0 4/3/2024 08:00 4/3/2024 08:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #16 (7" dress off shoe). 0.0 11.0 4/3/2024 08:30 4/3/2024 09:30 1.00 COMPZN, RPCOMP TRIP P TIH w/ 7" dress off shoe. Tagged up @ 230'. K/U push through w/ 5K. Set down @ 528', could not pass set 15K. PUW=48K, SOW=46K. 11.0 528.0 4/3/2024 09:30 4/3/2024 10:00 0.50 COMPZN, RPCOMP TRIP P POOH F/ 528' T/ 11', PUW=48K. 528.0 11.0 4/3/2024 10:00 4/3/2024 10:15 0.25 COMPZN, RPCOMP BHAH P L/D BHA #16. 11.0 0.0 4/3/2024 10:15 4/3/2024 10:45 0.50 COMPZN, RPCOMP RURD P Mobilize tools & collars T/ RF & pipe shed. 0.0 0.0 4/3/2024 10:45 4/3/2024 12:45 2.00 COMPZN, RPCOMP BHAH P M/U BHA #17, tandem 8.5" mills w/ DC's T/ 126', SOW=48K. 0.0 126.0 4/3/2024 12:45 4/3/2024 13:00 0.25 COMPZN, RPCOMP TRIP P RIH T/ 226' took weight. PUW=49K, SOW=49K. 126.0 226.0 4/3/2024 13:00 4/4/2024 00:00 11.00 COMPZN, RPCOMP REAM P K/U obtain parameters. PU = 51K. SO = 48K. Pump @ 5 BPM, 30 PSI. ROT @ 60 RPM, 4.5K free Tq. ROT=47K. Mill w/ work Tq 4.5-6.5K, 2-3K WOB. F/ 226' T/ 256'. Mill w/ work again F/ 338' T/ 355'. Mill w/ work again F/ 393 T/ 401'. Attempt to slide through tight spot @ 340'. Unable. Continue to work string mills F/ 340' T/ 393'. 226.0 393.0 Rig: NORDIC 3 RIG RELEASE DATE 4/11/2024 Page 9/17 2M-03 Report Printed: 5/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/4/2024 00:00 4/4/2024 04:45 4.75 COMPZN, RPCOMP REAM P Maintain Parameters. PUW = 51K. SOW = 48K. 60 RPM. 5 BPM @ 40 psi. Torque Range = 6.5K-7.3K. Continue to work 8 1/2" tandem string mills across tight spots F/ 340' T/ 554'. Set 15K down @ 554'. Worked string mills at tight spot. Cleaned up @ 560'. Back Ream up through trouble depths to 219'. Blow Down Top Drive. Drift from 219' down to 408' clean. 1-2K Wt bobbles. Found cut mark on Joint #11. Replace joint and update Tally. Cont. drift to xxx'. 393.0 408.0 4/4/2024 04:45 4/4/2024 05:30 0.75 COMPZN, RPCOMP TRIP P TIH F/ 408' T/ 1,783', no pumps or ration PUW=105K, SOW=65K 408.0 1,783.0 4/4/2024 05:30 4/4/2024 06:30 1.00 COMPZN, RPCOMP CIRC P Pump 25 bbl hi-vis pill. Circ out @ 5 BPM, 120 PSI. 1,783.0 1,783.0 4/4/2024 06:30 4/4/2024 07:00 0.50 COMPZN, RPCOMP OWFF P B/D TD. OWFF. 1,783.0 1,783.0 4/4/2024 07:00 4/4/2024 07:30 0.50 COMPZN, RPCOMP TRIP P POOH F/ 1783' T/ 405', PUW=105K. @ 405' pulled 15K over. RIH through problem area 5-6K drag. 1,783.0 395.0 4/4/2024 07:30 4/4/2024 08:15 0.75 COMPZN, RPCOMP REAM P K/U ream problem area PUW=50K, SOW=45. Pump @ 5 BPM, 30 PSI. Rot @ 60 RPM, Free Tq = 4.5K. Work w/ 1-2K WOB. TQ = 6-7K. Make several passes up and back down F/ 395' T/ 415'. Kill pump & Rot. Drift down w/ little to no drag. Drift up 3-5K drag. 395.0 415.0 4/4/2024 08:15 4/4/2024 08:30 0.25 COMPZN, RPCOMP TRIP P POOH F/ 415' T/ 126. PUW-50K. 415.0 126.0 4/4/2024 08:30 4/4/2024 09:15 0.75 COMPZN, RPCOMP BHAH P L/D BHA #17 F/ 126'. 126.0 0.0 4/4/2024 09:15 4/4/2024 09:30 0.25 COMPZN, RPCOMP BHAH P M/U BHA #18 dress off Assy T/ 11' 0.0 11.0 4/4/2024 09:30 4/4/2024 10:30 1.00 COMPZN, RPCOMP TRIP P RIH F/ 11' T/ 527'. PUW=45K, SOW=45K. Took weight @ 527'. Attempt to orient - no go. Attempt to ROT no-go. Unable to pass 527'. 11.0 527.0 4/4/2024 10:30 4/4/2024 10:45 0.25 COMPZN, RPCOMP TRIP P POOH F/ 527' T/ 11', PUW=45K. 527.0 11.0 4/4/2024 10:45 4/4/2024 11:00 0.25 COMPZN, RPCOMP BHAH P L/D BHA #18. 11.0 0.0 4/4/2024 11:00 4/4/2024 12:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #19 Stacked 8 3/8" & 8 1/2" mills w/ DC's T/ 115' 0.0 115.0 4/4/2024 12:00 4/4/2024 12:15 0.25 COMPZN, RPCOMP TRIP P RIH T/ 234'. PUW45K, SOW=45K. Tagged up hard. 115.0 234.0 4/4/2024 12:15 4/4/2024 16:00 3.75 COMPZN, RPCOMP REAM P Obtain parameters. Pump @ 5 BPM, 30 PSI. Rot @ 60 RPM, Free Tq = 4.5K. ROT=45K. Ream F/ 234' T/ 255' & F/ 390' T/392' & 542' T/ 545'. Work w/ 1-2K WOB. TQ = 6-9K. RIH T/ 575' 234.0 575.0 4/4/2024 16:00 4/4/2024 17:00 1.00 COMPZN, RPCOMP TRIP P RIH F/ 575' T/ 1773' PUW = 67K, SOW = 67K. 575.0 1,775.0 4/4/2024 17:00 4/4/2024 18:30 1.50 COMPZN, RPCOMP CIRC P Pump hi-vis pill. Circ out pill @ 8 BPM and 226 psi. 1,775.0 1,775.0 4/4/2024 18:30 4/4/2024 18:45 0.25 COMPZN, RPCOMP OWFF P Blowdown Top Drive OWFF 1,775.0 1,775.0 4/4/2024 18:45 4/4/2024 20:00 1.25 COMPZN, RPCOMP TRIP P TOOH w/ BHA #19 (Stacked 8 3/8" + 8 1/2" string mills) F/ 1775' T/ 115'. Found another joint of 3 1/2" DP with cut marks on OD. Replaced. 1,775.0 115.0 Rig: NORDIC 3 RIG RELEASE DATE 4/11/2024 Page 10/17 2M-03 Report Printed: 5/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/4/2024 20:00 4/4/2024 20:45 0.75 COMPZN, RPCOMP BHAH P L/D BHA #19. 115.0 0.0 4/4/2024 20:45 4/4/2024 21:30 0.75 COMPZN, RPCOMP BHAH P MU BHA #20 (8 1/4" dress off shoe). 0.0 10.4 4/4/2024 21:30 4/4/2024 22:30 1.00 COMPZN, RPCOMP TRIP P TIH w/ 8 1/4" OD dress off shoe to 1,766'. 10.4 1,766.0 4/4/2024 22:30 4/5/2024 00:00 1.50 COMPZN, RPCOMP MILL P Tag top of 7" stump @ 1,791'. PUH. Kelly up. Obtain parameters. PUW = 62K, SOW = 62K. Free Torque = 4.4K. Pump Rate = 3 BPM @ 44 psi. TIH. Rotate over stump. Clear backside and swallow stump to 1,796'. Saw pump pressure increase to 260 psi. Torque Range to clear backside = 5.5-6.0K. Fully swallowed stump to inner mill. Wash backside of stump. PU off stump. Reduce pump rate to 1 BPM @ 110 psi. TIH. Set 5-7K down and dress off 7" stump from 1,791.0' to 1,791.3' (bottom of dress off shoe @ 1,796.3'). 1,766.0 1,796.3 4/5/2024 00:00 4/5/2024 01:00 1.00 COMPZN, RPCOMP MILL P Continue to dress off 7" stump from 1,791.3' to 1,791.5' (bottom of dress off shoe @ 1,796.5'). 60 RPM. 6.3K Torque. 1,766.0 1,796.5 4/5/2024 01:00 4/5/2024 01:30 0.50 COMPZN, RPCOMP CIRC P Pump 30 bbl hi-vis pill. Circ out w/ vis Seawater @ 8 BPM / 220 psi pump pressure. 1,796.5 1,790.0 4/5/2024 01:30 4/5/2024 01:45 0.25 COMPZN, RPCOMP OWFF P Install wiper rubbers. OWFF 1,790.0 1,790.0 4/5/2024 01:45 4/5/2024 03:30 1.75 COMPZN, RPCOMP TRIP P TOOH w/ BHA #20. L/D 7 scarred joints of 3 1/2" DP. Replaced with new. 1,790.0 10.4 4/5/2024 03:30 4/5/2024 05:00 1.50 COMPZN, RPCOMP BHAH P L/D BHA #20. L/D Drill Collars. 10.4 0.0 4/5/2024 05:00 4/5/2024 05:30 0.50 COMPZN, RPCOMP RURD P B/D choke & kill lines. Suck out stack. Pull wear bushing. 0.0 0.0 4/5/2024 05:30 4/5/2024 08:00 2.50 COMPZN, RPCOMP RURD P Clean and clear rig floor. R/U GBR 7" casing equipment. M/U 7" HYD563 XO to floor valve. 0.0 0.0 4/5/2024 08:00 4/5/2024 08:30 0.50 COMPZN, RPCOMP SFTY P PJSM. w/ GBR & rig crew on running 7" tieback Verify 7" jewelry and run order. 0.0 0.0 4/5/2024 08:30 4/5/2024 12:30 4.00 COMPZN, RPCOMP PUTB P Run 7", 26#, L-80, Hyd 563 casing as per tally T/ 1795' Nordic 3 RKB. 1804.4' ORKB. PUW=85K, SOW=70K. Set down 25K. Pull 50K over, confirm grapple on patch is bit. Slack back off T/ PUW. 0.0 1,804.4 4/5/2024 12:30 4/5/2024 12:45 0.25 COMPZN, RPCOMP RURD P R/U testing equipment, 1,804.4 1,804.4 4/5/2024 12:45 4/5/2024 13:00 0.25 COMPZN, RPCOMP PRTS P PT 7" casing patch T/ 2500 PSI for 10 Min. 1,804.4 1,804.4 4/5/2024 13:00 4/5/2024 14:00 1.00 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. Suck out stack 1,804.4 1,804.4 4/5/2024 14:00 4/5/2024 15:00 1.00 COMPZN, RPCOMP NUND P N/D BOP & lift stack. Pull 30K tension on patch set 11" x 7" emergency slips. 1,804.4 1,804.4 4/5/2024 15:00 4/5/2024 16:00 1.00 COMPZN, RPCOMP NUND P N/U BOP. Install riser. Offload contamination pill in cuttings tank, pill pit & trip tank. 1,804.4 1,804.4 4/5/2024 16:00 4/5/2024 16:15 0.25 COMPZN, RPCOMP PRTS P PT break on stack & CSG head T/ 3000 PSI. Install riser. 1,804.4 1,804.4 Rig: NORDIC 3 RIG RELEASE DATE 4/11/2024 Page 11/17 2M-03 Report Printed: 5/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/5/2024 16:15 4/5/2024 19:15 3.00 COMPZN, RPCOMP RURD P Blow air through return line manifold. R/U cement equipment. Crew C/O. PJSM w/ HES Cementers and Nordic. PT hard line out to cuttings tank and open top tank to T/ 3000 PSI. PT cementers line to 4,000 psi. 1,804.4 1,804.4 4/5/2024 19:15 4/5/2024 21:30 2.25 COMPZN, RPCOMP CMNT P HES cementers pressured up to 3,050 psi to shear ES cementer open. Pump 175 bbls of 140 deg F Fresh Water at 4 BPM/410 psi, 10 bbls Fresh Water w/ Red Dye, Batch up first tub of cement (Cement Wet) @ 20:00. Pump 109 bbls of 15.3# cement and see red dye in OA returns. On schedule per hole volumes. Swapped to cuttings tank. Finish pumping a total of 123 bbls of 15.3# cement. OA returns slowed down approx. 3 bbls after seeing initial red dye. SD Pump. Drop Closing Plug. Pump 5 bbls Fresh Water spacer behind. Minimal returns from OA. Slight drip. SD Pumps. Swap to rig pumps. Displace cement with 62 bbls of 8.6# SW. See pump rates/pressure chart below: 8:50PM: 13 bbls away, 3 BPM @ 355 psi Minimal OA returns. Slow drip. Slow rate to 2 BPM. 8:55PM: 18 bbls away. 2 BPM @ 300 psi. No OA returns. 9:00PM: 26 bbls away. 2 BPM @ 394 psi. No OA returns, but seeing lift pressure. 9:11PM: 47 bbls away. 2 BPM @ 576 psi. Still no OA returns. Slow rate to 1 BPM @ 565 psi. 9:16PM: 52 bbls away. 1 BPM @ 630 psi. No returns. 9:23PM: 58 bbls away: 1 BPM @ 688 psi. No returns. 9:27PM: 62 bbls away. 1 BPM @ 714 psi. No returns. Bumped plug @ 62 bbls. Est. TOC based on 3 bbls of red dye returns = 240'. Bump closing plug. Cement in place @ 21:30. Hold 2,200 psi for 15-min. Bleed off to ensure ES cementer is closed. 1,804.4 1,804.4 4/5/2024 21:30 4/5/2024 23:00 1.50 COMPZN, RPCOMP RURD P Cement in place @ 21:30. Blow Down cement lines. RD Cement Head. Close bag. Open LPR. Flush lines with rinsate pill out to cuttings and open top tank. Flush and clean cement out of BOP's. Blow Down lines. 1,804.4 1,804.0 4/5/2024 23:00 4/5/2024 23:30 0.50 COMPZN, RPCOMP OWFF P Perform 30-min NFT on OA. 1,804.0 1,804.0 4/5/2024 23:30 4/6/2024 00:00 0.50 COMPZN, RPCOMP NUND P Change out LPR from 7" fixed to VBR's. Unload excess 7" casing from pipe shed. 1,804.0 1,804.0 4/6/2024 00:00 4/6/2024 05:30 5.50 COMPZN, RPCOMP NUND P Cont. change out LPR from 7" fixed to VBR's. ND Stack. Cut 7" casing. Cut Joint Length = 28.45'. Break out 6' pup. L/D and kick out cut joint. 1,804.0 1,804.0 4/6/2024 05:30 4/6/2024 07:00 1.50 COMPZN, RPCOMP NUND P Clean out wellhead. Install packoffs. NU Tubing head. 1,804.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/11/2024 Page 12/17 2M-03 Report Printed: 5/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/6/2024 07:00 4/6/2024 07:15 0.25 COMPZN, RPCOMP PRTS P Test pack-offs to 3,000 psi for 15-min. 0.0 0.0 4/6/2024 07:15 4/6/2024 12:30 5.25 COMPZN, RPCOMP NUND P Install secondary IA valve. N/U DS & BOP. Install riser. 0.0 0.0 4/6/2024 12:30 4/6/2024 13:30 1.00 COMPZN, RPCOMP WWWH P Jet BOP stack. 0.0 0.0 4/6/2024 13:30 4/6/2024 14:00 0.50 COMPZN, RPCOMP MPSP P Install test plug. 0.0 0.0 4/6/2024 14:00 4/6/2024 15:30 1.50 COMPZN, RPCOMP RURD P R/U testing equipment. Fill stack w/ fresh water. 0.0 0.0 4/6/2024 15:30 4/6/2024 20:30 5.00 COMPZN, RPCOMP BOPE P Weekly BOPE test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested annular, UVBR's, LVBR’s w/ 3 1/2" test joints. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½” EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure= 3000 PSI, after closure= 1750 PSI, 200 PSI attained =19 sec, full recovery attained = 118 sec. UVBR's= 4 sec, LVBR’s= 3 sec. Annular= 21 sec. Simulated blinds= 3 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average = 2250 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Adam Earl. 0.0 0.0 4/6/2024 20:30 4/6/2024 20:45 0.25 COMPZN, RPCOMP MPSP P Pull test plug. 0.0 0.0 4/6/2024 20:45 4/6/2024 23:00 2.25 COMPZN, RPCOMP RURD P Attempt to feed 5/8" hose through OA casing port into annulus. Able to feed 5/8" OD hose about 4" into port. Very tight. RU to PT OA. Hardline and sensator in cellar. Set wear ring. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/11/2024 Page 13/17 2M-03 Report Printed: 5/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/6/2024 23:00 4/7/2024 00:00 1.00 COMPZN, RPCOMP PRTS P PT OA to 500 psi. Charted for 10-min (x3). Double blocked on last attempt. Slow leak off. Failed. >5% pressure loss in 10-min on each test. See data below: Intial Test: 11:08: Fluid Packed w/ charge pump. Took 0.8 BBLS. 11:10: Press. up to 520 psi. Took 5 strokes (0.3 BBLS). 11:15: Pressure @ 460 psi 11:20: Pressure @ 360 psi. Lost 160 psi/10min Failed Repeat test: 11:27: Press up to 580 psi. Took 0.3 BBLS 11:32: Pressure @ 460 psi 11:37: Pressure @ 420 psi. Lost 160 psi/10min Failed Final Test (double blocked at OA): 11:43: Pressure up to 580 psi. Took 0.3 BBLS 11:48: Pressure @ 480 psi 11:53: Pressure @ 420 psi. Lost 160 psi/10min Failed. 0.0 0.0 4/7/2024 00:00 4/7/2024 01:00 1.00 COMPZN, RPCOMP RURD P R/D OA testing equipment. Install mouse hole. Load YJ tools and DC's. 0.0 0.0 4/7/2024 01:00 4/7/2024 02:00 1.00 COMPZN, RPCOMP BHAH P MU BHA #21 (5-bladed junk mill). 0.0 318.0 4/7/2024 02:00 4/7/2024 04:00 2.00 COMPZN, RPCOMP TRIP P TIH to 1,704'. Screw in Top Drive. Lightly tag TOC @ 1,747'. 318.0 1,747.0 4/7/2024 04:00 4/7/2024 09:15 5.25 COMPZN, RPCOMP DRLG P PUH. Obtain parameters. PUW = 68K. SOW = 65K. RPM = 70, Free Torque = 5.5K. Pump Rate = 4 BPM @ 132 psi. TIH and mill green cement from 1,747' to 1,768'. Set 3-5K down. Milling hard cement @ 1,768'. Continue milling through plug @ cementer T/ 1783'.. Pumping hi vis sweeps after milling though plug & after milling through cementer. Mill through green cement & stringers T/ 2195'. Tagged sand top. 1,747.0 2,195.0 4/7/2024 09:15 4/7/2024 10:00 0.75 COMPZN, RPCOMP CIRC P P/U T/ 2168'. PUW=76K, SOW=70K. Circ 18 Bbls hi-vis pill around @ 8 BPM, 525 PSI. 2,186.0 2,168.0 4/7/2024 10:00 4/7/2024 11:00 1.00 COMPZN, RPCOMP DRLG P Dry drill on sand top # 60 RPM, 5K Tq. PUW=76K, SOW-70K. 2,168.0 2,195.0 4/7/2024 11:00 4/7/2024 11:30 0.50 COMPZN, RPCOMP TRIP P POOH F/ 2195' T/ 318'. PUW=76K. 2,195.0 318.0 4/7/2024 11:30 4/7/2024 13:00 1.50 COMPZN, RPCOMP BHAH P L/D BHA #21 F/ 318' T/ surface. PUW=48K. 318.0 0.0 4/7/2024 13:00 4/7/2024 14:00 1.00 COMPZN, RPCOMP WWWH P Jet BOP stack. 0.0 0.0 4/7/2024 14:00 4/7/2024 14:15 0.25 COMPZN, RPCOMP RURD P R/U testing equipment. 0.0 0.0 4/7/2024 14:15 4/7/2024 14:45 0.50 COMPZN, RPCOMP PRTS P PT 7" CSG down to RBP T/ 3000 PSI for 10 Min. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/11/2024 Page 14/17 2M-03 Report Printed: 5/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/7/2024 14:45 4/7/2024 15:00 0.25 COMPZN, RPCOMP RURD P B/D, R/D testing equiment. 0.0 0.0 4/7/2024 15:00 4/7/2024 15:30 0.50 COMPZN, RPCOMP CLEN P Clean RF. 0.0 0.0 4/7/2024 15:30 4/7/2024 16:30 1.00 COMPZN, RPCOMP BHAH P M/U BHA #22 RCJB T/ 325', SOW=48K. 0.0 325.0 4/7/2024 16:30 4/7/2024 17:30 1.00 COMPZN, RPCOMP TRIP P RIH T/ tag @ 2,195'. Set 4K down. PUW=75K, SOW=70K 325.0 2,295.0 4/7/2024 17:30 4/7/2024 18:30 1.00 COMPZN, RPCOMP CIRC P Dry drill on sand top. Kick on pumps. Obtain parameters. 5 BPM @ 1,100 psi. 15 RPM. Circ out from 2195' to 2207'. Saw pressure drop. Progress slowed. 2,195.0 2,207.0 4/7/2024 18:30 4/7/2024 20:00 1.50 COMPZN, RPCOMP TRIP P TOOH w/ RCJB. 2,207.0 325.0 4/7/2024 20:00 4/7/2024 21:00 1.00 COMPZN, RPCOMP BHAH P L/D RCJB. Inspect and clean out. Recovered substantial metal shavings on magnets and chunks of metal/rubber. 325.0 0.0 4/7/2024 21:00 4/7/2024 21:30 0.50 COMPZN, RPCOMP BHAH P MU BHA #23 (RCJB Run #2). 0.0 325.0 4/7/2024 21:30 4/7/2024 22:30 1.00 COMPZN, RPCOMP TRIP P TIH w/ RCJB Run #2 to 2207'. 325.0 2,172.0 4/7/2024 22:30 4/8/2024 00:00 1.50 COMPZN, RPCOMP SLPC P Slip and cut drill line. 2,172.0 2,172.0 4/8/2024 00:00 4/8/2024 01:00 1.00 COMPZN, RPCOMP SLPC P Finish slip and cut drill line. 2,172.0 2,172.0 4/8/2024 01:00 4/8/2024 02:00 1.00 COMPZN, RPCOMP WASH P Screw in Top Drive. Obtain parameters. 5 BPM @ 800 psi. Circulate to clean debris off top of sand plug from 2207' to 2217' (35' of sand plug left above RBP). Set 4K down. Progress slowed. Acting like RCJB is full. 2,207.0 2,217.0 4/8/2024 02:00 4/8/2024 03:00 1.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #23 (RCJB Run #2). Load and measure 3 1/2" jewelry and pup joints. 2,217.0 325.0 4/8/2024 03:00 4/8/2024 04:00 1.00 COMPZN, RPCOMP BHAH P L/D RCJB. Inspect and unload. Recover metal shavings on magnets, metal pieces in boot basket, and cement flakes in RCJB. 325.0 0.0 4/8/2024 04:00 4/8/2024 04:30 0.50 COMPZN, RPCOMP BHAH P MU BHA #24 (RCJB Run #3). 0.0 325.0 4/8/2024 04:30 4/8/2024 05:30 1.00 COMPZN, RPCOMP TRIP P TIH w/ RCJB to 2217'. PUW=75, SOW=70K. 325.0 2,217.0 4/8/2024 05:30 4/8/2024 06:30 1.00 COMPZN, RPCOMP WASH P Wash/Clean debris from top of sand @ 2217' T/ 2236'. 2,217.0 2,236.0 4/8/2024 06:30 4/8/2024 06:45 0.25 COMPZN, RPCOMP CIRC P Circ BU @ 8 BPM, 1250 PSI. 2,236.0 2,236.0 4/8/2024 06:45 4/8/2024 07:30 0.75 COMPZN, RPCOMP TRIP P POOH F/ 2236' T/ 325', PUW=75K 2,236.0 325.0 4/8/2024 07:30 4/8/2024 08:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA #24 F/ 325' T/ surface. PUW=48K. Inspect baskets & magnets. Very minimal returns. 325.0 0.0 4/8/2024 08:30 4/8/2024 08:45 0.25 COMPZN, RPCOMP CLEN P Clean & clear RF & pipe shed. 0.0 0.0 4/8/2024 08:45 4/8/2024 09:15 0.50 COMPZN, RPCOMP SVRG P Service rig. 0.0 0.0 4/8/2024 09:15 4/8/2024 09:45 0.50 COMPZN, RPCOMP BHAH P M/U BHA #25 RBP retrieval tool T/ 124'. SOW=42K. 0.0 124.0 4/8/2024 09:45 4/8/2024 10:45 1.00 COMPZN, RPCOMP TRIP P RIH F/ 124' T/ 2236', PUW=70K, SOW=67K. 124.0 2,236.0 4/8/2024 10:45 4/8/2024 11:00 0.25 COMPZN, RPCOMP WASH P Wash sand of top of plug F/ 2236' T/ 2247'. @ 7 BPM, 400 PSI 2,236.0 2,247.0 Rig: NORDIC 3 RIG RELEASE DATE 4/11/2024 Page 15/17 2M-03 Report Printed: 5/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/8/2024 11:00 4/8/2024 11:45 0.75 COMPZN, RPCOMP DISP P Pump 30 Bbls hi-vis pill @ 8 BPM, 700 PSI. Displace well over to neat seawater. 2,247.0 2,247.0 4/8/2024 11:45 4/8/2024 12:15 0.50 COMPZN, RPCOMP COND P Offload neat seawater into pits. Fill TT. 2,247.0 2,247.0 4/8/2024 12:15 4/8/2024 12:45 0.50 COMPZN, RPCOMP MPSP P Wash T/ plug top. Engage RBP. @ 2252'. Open equalizer. P/U & release plug. RIH past set depth. 2,247.0 2,254.0 4/8/2024 12:45 4/8/2024 13:00 0.25 COMPZN, RPCOMP OWFF P OWFF 2,254.0 2,254.0 4/8/2024 13:00 4/8/2024 14:30 1.50 COMPZN, RPCOMP TRIP P POOH F/2254' T/ 124', PUW=70K. 2,254.0 124.0 4/8/2024 14:30 4/8/2024 15:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA #25 & RBP. PUW=42K. 124.0 0.0 4/8/2024 15:00 4/8/2024 15:30 0.50 COMPZN, RPCOMP CLEN P Remove YJ tools from pipe shed. Mobilize tools for BHA #26. 0.0 0.0 4/8/2024 15:30 4/8/2024 16:00 0.50 COMPZN, RPCOMP PRTS P PT 7" against CA2 plug T/ 3000 PSI for 10 Min. 0.0 0.0 4/8/2024 16:00 4/8/2024 16:30 0.50 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. 0.0 0.0 4/8/2024 16:30 4/8/2024 17:00 0.50 COMPZN, RPCOMP SVRG P Service rig. Adjust service loop. 0.0 0.0 4/8/2024 17:00 4/8/2024 18:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #26 Dress off Assy T/ 310', SOW=50K. 0.0 310.0 4/8/2024 18:00 4/8/2024 21:15 3.25 COMPZN, RPCOMP TRIP P RIH T/ 6881', PUW=149K, SOW=104K. 310.0 6,881.0 4/8/2024 21:15 4/8/2024 22:00 0.75 COMPZN, RPCOMP PULD P PUDP F/ 6881' T/ 7000', PUW=149K, SOW=104K. 6,881.0 7,000.0 4/8/2024 22:00 4/8/2024 23:00 1.00 COMPZN, RPCOMP MILL P Obtain parameters. Pump @ 3 BPM, 370 PSI. Rot @ 35 RPM, 7K Free Tq. ROT=125K. Swallow tubing stub @ 7006'. Dress stub off F/ 7006' T/ 7007. 7.4-7-6K Tq. 644 PSI. P/U off T/ 7000'. Retag. P/U 7,000.0 7,007.0 4/8/2024 23:00 4/8/2024 23:30 0.50 COMPZN, RPCOMP CIRC P Cir hi-vis pill around @ 8 BPM, 2000 PSI. 7,007.0 6,881.0 4/8/2024 23:30 4/9/2024 00:00 0.50 COMPZN, RPCOMP OWFF P OWFF. Blowdown Top Drive. 6,881.0 6,881.0 4/9/2024 00:00 4/9/2024 03:00 3.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #26 (3 1/2" dress off shoe). 6,881.0 310.0 4/9/2024 03:00 4/9/2024 03:45 0.75 COMPZN, RPCOMP BHAH P L/D BHA #26. 310.0 0.0 4/9/2024 03:45 4/9/2024 04:30 0.75 COMPZN, RPCOMP BHAH P M/U BHA #27 (3 1/2" overshot) 0.0 316.0 4/9/2024 04:30 4/9/2024 09:30 5.00 COMPZN, RPCOMP TRIP P TIH w/ 3 1/2" overshot to 2,344'. Crew C/O, Cont. TIH w/ overshot to 7.007'. 316.0 7,007.0 4/9/2024 09:30 4/9/2024 11:00 1.50 COMPZN, RPCOMP FISH P Obtain parameters. PUW = 145K. SOW = 110K. Swallow stub to 7,012'. Pressure up to 500 psi. Confirm latched. Set 25K down to confirm fully located. PU to 155K (10K over). Open Jars. Straight pull to 185K (40K) over. Hit 5 jar licks down to attempt to break free downward before jarring up. PU to 165K (20K over). Light jar lick. Straight pull to 185K. No movement. Reset Jars. PU to 175K (30K over). Hit jar lick. No movement. Hit jar lick up @ 40K over. Seals moved uphole 1'. Set back down and stung seals back into PBR. Press up to 200 psi. PUH and watched pressure fall off @ 6,995'. 7,007.0 7,012.0 Rig: NORDIC 3 RIG RELEASE DATE 4/11/2024 Page 16/17 2M-03 Report Printed: 5/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/9/2024 11:00 4/9/2024 11:45 0.75 COMPZN, RPCOMP CIRC P Park @ 6,995'. Pump 15 bbl hi-vis sweep. Circ STS @ 6 BPM / 1417 psi. 7,012.0 6,995.0 4/9/2024 11:45 4/9/2024 12:15 0.50 COMPZN, RPCOMP OWFF P OWFF for 30-min. Blowdown Top Drive. 6,995.0 6,995.0 4/9/2024 12:15 4/9/2024 15:15 3.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #27 6,995.0 316.0 4/9/2024 15:15 4/9/2024 17:00 1.75 COMPZN, RPCOMP BHAH P L/D BHA #27 (3 1/2" overshot) w/ cut tubing and seal assembly. Cut Joint Length = 11.00'. Multiple holes and external corrosion in tubing below cut joint down to top of seal assembly. One section of odd ballooned tubing as well (see pictures). R/D OA fluid swapping hardware. Loaded 10 bbls of 11.3# NaCl/NaBr into OA, displacing 10 bbls of 8.4# FW spacer/red dye. Re-install OA nipple. 316.0 0.0 4/9/2024 17:00 4/9/2024 18:00 1.00 COMPZN, RPCOMP CLEN P Clean rig floor prep for TIH with clean out assembly 0.0 0.0 4/9/2024 18:00 4/9/2024 18:30 0.50 COMPZN, RPCOMP SVRG P Replace unloader valve on TD 0.0 0.0 4/9/2024 18:30 4/9/2024 20:00 1.50 COMPZN, RPCOMP BHAH P MU BHA #28 (PBR cleanout assembly) 0.0 311.0 4/9/2024 20:00 4/9/2024 22:00 2.00 COMPZN, RPCOMP TRIP P TIH to just above PBR @ 7,033'. 311.0 7,033.0 4/9/2024 22:00 4/9/2024 22:30 0.50 COMPZN, RPCOMP WASH P Screw in Top Drive. Obtain parameters. PUW = 143K. SOW = 110K. Tag top of PBR @ 7029', Make up TD rotate 1/4 turn , Wash down to top of PBR @ 6 BPM / 1250 psi. Continue in PBR T/ 7032' Lower pump rate 1 bpm @ 70psi, Continue to wash down into PBR to clear potential debris. No-Go inside PBR @ 7,041'. 7,033.0 7,041.0 4/9/2024 22:30 4/9/2024 23:30 1.00 COMPZN, RPCOMP CIRC P PUH. Pump hi-vis pill. Circ STS @ 6 BPM / 1,180 psi to clear debris from wellbore. 7,041.0 7,041.0 4/9/2024 23:30 4/10/2024 00:00 0.50 COMPZN, RPCOMP OWFF P OWFF // Blow down TD 7,041.0 7,041.0 4/10/2024 00:00 4/10/2024 06:00 6.00 COMPZN, RPCOMP PULD P TOOH w/ BHA #28 (PBR clean out) laying down drill pipe. 7,041.0 312.0 4/10/2024 06:00 4/10/2024 06:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #28. 312.0 0.0 4/10/2024 06:30 4/10/2024 09:30 3.00 COMPZN, RPCOMP RURD P Pull wear ring. Clean and clear rig floor. Load and RU GBR equipment. Verify 3 1/2" HYD563 joint count and jewelry run order. 0.0 0.0 4/10/2024 09:30 4/10/2024 16:30 7.00 COMPZN, RPCOMP PUTB P PJSM. Run 3 1/2" HYD563 Completions as per Tally. Bury Joint #223. MU Joint #224 to #225 in mousehole. Install XO on top of #225 for Top Drive screw in. MU double to #223. 0.0 7,011.0 4/10/2024 16:30 4/10/2024 17:30 1.00 COMPZN, RPCOMP WASH P Screw in Top Drive on Joint #225. Obtain parameters. PUW = 96K. SOW = 75K. Pump Rate = 0.5 BPM / 40 psi. Wash down to find top of PBR. See 300 psi pressure indicator @ 7,033'. SD Pumps. Open Bleeder. Fully locate seals in PBR @ 7040.3'. Set 10K down. 7,011.0 7,040.3 Rig: NORDIC 3 RIG RELEASE DATE 4/11/2024 Page 17/17 2M-03 Report Printed: 5/8/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/10/2024 17:30 4/10/2024 18:15 0.75 COMPZN, RPCOMP HOSO P PU 2' off no-go. Mark Pipe. Measure partial joints pulled. Joint #224 partial pulled = 27.0'. Joint #223 pulled = 30.95'. Total pulled = 57.95'. Need 31.33' for RKB + Hanger + Hanger Pup. Space out pups for 2' space out = 26.62' L/D Joint #222. MU space out pups: 9.73' + 9.70' + 6.06'. Total pups = 25.49'. FInal Space out 3'. MU last full Joint #222. 7,040.3 6,947.0 4/10/2024 18:15 4/10/2024 19:00 0.75 COMPZN, RPCOMP PULD P MU hanger w/ pup. MU landing joint. Pu. Wt 95K So Wt. 75K 6,947.0 6,947.0 4/10/2024 19:00 4/10/2024 20:00 1.00 COMPZN, RPCOMP CRIH P Reverse circulate 134 bbls of 8.6# CI down the backside. Displace w/ 52 bbls of neat Seawater. SD Pumps. 4 bbls/min @ 251 psi 6,947.0 6,947.0 4/10/2024 20:00 4/10/2024 21:00 1.00 COMPZN, RPCOMP THGR P Land Hanger. 28.3' // Pressure up on tubing 500psi w/ IA open confirm in seals good test // RILDS. Drop Ball and Rod. 6,947.0 7,040.0 4/10/2024 21:00 4/10/2024 22:00 1.00 COMPZN, RPCOMP RURD P RU testing equipment and manifold on rig floor. 7,070.0 7,040.0 4/10/2024 22:00 4/10/2024 23:45 1.75 COMPZN, RPCOMP PRTS P PT Tubing to 3,500 psi. Chart for 30- min. Bleed to 2,000 psi. PT IA to 3,000 psi. Chart for 30-min. Dump tubing pressure to shear out SOV. 7,040.0 7,040.0 4/10/2024 23:45 4/11/2024 00:00 0.25 COMPZN, RPCOMP RURD P Rig down test equipment 0.0 0.0 4/11/2024 00:00 4/11/2024 01:00 1.00 COMPZN, WHDBOP MPSP P Pull landing jt // Install BPV in hanger // test BPV 1000 psi 10 min 0.0 0.0 4/11/2024 01:00 4/11/2024 05:00 4.00 COMPZN, WHDBOP NUND P Blow down surface lines // Nipple down BOPs // Nipple up Production Tree and tree adapter // test void 5000 psi 15 min 0.0 0.0 4/11/2024 05:00 4/11/2024 07:00 2.00 COMPZN, WHDBOP RURD P RU 1502 Companion to wing valve on tree. Crew C/O. RU LRS for freeze protect and tree test. 0.0 0.0 4/11/2024 07:00 4/11/2024 08:30 1.50 COMPZN, WHDBOP PRTS P Pressure test production tree 5000psi w/ LRS. Pull test dart and BPV. 0.0 0.0 4/11/2024 08:30 4/11/2024 10:30 2.00 DEMOB, MOVE FRZP P Freeze protect well w/ 71 bbls Diesel. U -Tube for 1 hour. RU LRS and attempt to squeeze diesel into OA. Pressured up to 500 psi @ 9:45AM. Very little leak off/injection. 0.0 0.0 4/11/2024 10:30 4/11/2024 11:30 1.00 DEMOB, MOVE FRZP P Bump pressure back up to 500 psi repeatedly. Held OA pressure at 500 psi for 1.5 hours, slowly squeezing diesel into OA. Squeezed approx. 0.2 BBLS diesel into OA. Swap to rig generators at 11:00. Disconnect high-line. 0.0 0.0 4/11/2024 11:30 4/11/2024 14:00 2.50 DEMOB, MOVE RURD P B/D hardline to tanks. R/D hardline. R/D 1502 nipple from OA. RU nipple w/ gauge to OA. Secure tree and cellar. Prep for rig move to 2M-37. Final Pressures: T/IA/OA = 0 / 0 / 0 psi. Rig Release @ 14:00 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/11/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:RKB (Est. 87' of Rathole) 7,365.0 2M-03 5/15/2020 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Swapped out SOV, pulled RHC, pulled plug 2M-03 5/6/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE:11/10/2010 condijw 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 42.0 123.0 123.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 41.5 3,323.2 2,913.9 36.00 J-55 BTC Tie-Back String 7 6.28 40.6 1,804.4 1,733.3 26.00 L-80 HYD 563 Production 7 6.28 41.8 7,516.2 26.00 J-55 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 7,058.4 String Max No… 3 1/2 Set Depth … 5,934.4 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection HYD 563 ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 40.3 40.3 0.13 Hanger 6.982 3.5" FMC Gen 4 tubing hanger, H- BPV, EUE Lift threads FMC GEN IV 2.952 6,969.2 5,861.2 34.97 Mandrel – GAS LIFT 5.640 3.5" x 1.5" SLB MMG, GLM (SN#: 24384-09) SLB MMG 2.920 7,028.7 5,910.0 34.86 Nipple - X 4.506 3.5" HES 2.81" X-Nipple (SN#: 4792263702-01-001) HES 2.81" X 2.813 7,045.7 5,924.0 34.85 Locator 4.240 Baker Locator (4.24" No-Go) Baker 2.990 7,046.5 5,924.6 34.85 Seal Assembly 3.990 Baker GBH-22, 80-40 Seal Assembly (2' space out), (SN#: 453010065) Baker GBH-22, 80-40 2.990 Top (ftKB) 7,048.5 Set Depth … 7,089.8 String Max No… 5.41 Set Depth … 5,960.2 Tubing Description Tubing – Completion Lower Wt (lb/ft) Grade Top Connection ID (in) 2.97 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,048.5 5,926.3 34.85 PBR 5.410 OTIS PBR w/ 10' STROKE & 4" SEAL BORE OTIS 2.970 7,064.4 5,939.3 34.84 PACKER 6.000 OTIS HVT RETRIEVABLE PACKER OTIS HVT 3.250 7,079.7 5,951.9 34.84 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 7,089.2 5,959.7 34.83 WLEG 4.500 OTIS RH BALL SEAT SUB/WIRELINE ENTRY GUIDE, NO ELMD LOG AVAILABLE OTIS 2.875 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) 40.6 40.6 0.13 EMERGENCY SLIPS 11" x 7" C-21 Emergency Slips 4/5/2024 7.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 6,969.2 5,861.2 34.97 1 GAS LIFT DMY RK 1 1/2 0.0 4/28/2024 SLB MMG 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 1,788.7 1,720.6 35.67 Collar - Stage 8.250 CMTR,TYPE H ES-II, HYD 563 L- 80, S/N#: 5031046-03 Halliburto n HES II CMTR 6.125 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,183.0 7,203.0 6,036.8 6,053.2 C-4, 2M-03 11/8/1992 4.0 IPERF 180 deg. phasing; Oriented 105 deg. CCW, 2 1/2" Titan 7,214.0 7,224.0 6,062.3 6,070.6 A-4, 2M-03 2/22/1992 4.0 IPERF 180 deg. phasing; Oriented 84.25 deg. CCW, 4 1/2" HJ II Csg Gun 7,238.0 7,258.0 6,082.1 6,098.6 A-3, 2M-03 2/21/1992 4.0 IPERF 180 deg. phasing; Oriented 172 deg. CCW, 4 1/2" HJ II Csg Gun 7,258.0 7,278.0 6,098.6 6,115.2 A-3, 2M-03 2/21/1992 4.0 IPERF 180 deg. phasing; Oriented 166 deg. CCW, 4 1/2" HJ II Csg Gun 2M-03, 5/8/2024 10:23:04 AM Vertical schematic (actual) Production; 1,800.9-7,516.2 IPERF; 7,258.0-7,278.0 IPERF; 7,238.0-7,258.0 IPERF; 7,214.0-7,224.0 IPERF; 7,183.0-7,203.0 PACKER; 7,064.4 Nipple - X; 7,028.7 BALL & ROD; 7,021.0 Mandrel – GAS LIFT; 6,969.2 SURFACE; 41.5-3,323.2 Tie-Back String; 40.6-1,804.4 Production String 1 Cement; 240.0 ftKB CONDUCTOR; 42.0-123.0 EMERGENCY SLIPS; 40.6 Hanger; 40.3 KUP INJ KB-Grd (ft) 41.01 RR Date 1/3/1992 Other Elev… 2M-03 ... TD Act Btm (ftKB) 7,512.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032016000 Wellbore Status INJ Max Angle & MD Incl (°) 40.75 MD (ftKB) 2,400.00 WELLNAME WELLBORE2M-03 Annotation Last WO: End Date 4/11/2024 H2S (ppm) DateComment SSSV: TRDP CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Jake Henry To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Company Man, Nordic 3 Subject:N3 BOPE test 3-26-24 Date:Friday, March 29, 2024 8:00:17 AM Attachments:Nordic 3 BOP AOGCC 03-26-24.xlsx Some people who received this message don't often get email from jake.henry@nordic-calista.com. Learn why this is important Nordic rig 3 initial BOPE test form 3-26-24 on 2M-03 Jake Henry Nordic Calista Dog House 670-6144 907-414-0962 Cell This information is intended only for the use of the individual (s) or entity (ies) named above and may contain confidential or privileged information. Any unauthorized disclosure, copying, distribution or the taking of any action in reliance on the contents of this transmitted information is strictly prohibited. If you are not the intended recipient or have received this transmission in error, please immediately delete it and any attachments from your system and send me an email confirming that you have not disclosed, copied, or distributed this message and that you have deleted this message and any attachments from your system. .580 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:3 DATE: 3/26/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1911410 Sundry #324-052 Operation: Drilling: Workover: xxx Explor.: Test: Initial: xxx Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:3136 psi MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 1P BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8"P Pit Level Indicators PP #1 Rams 1 2 7/8" X 5 1/2"P Flow Indicator PP #2 Rams 1 CSO Rams P Meth Gas Detector PP #3 Rams 1 2 7/8" X 5 1/2"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"P System Pressure (psi)3000 P Kill Line Valves 1 3 1/8"P Pressure After Closure (psi)1600 P Check Valve 0NA200 psi Attained (sec)19 P BOP Misc 2 2 1/16" 5000 P Full Pressure Attained (sec)121 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4 @ 2100 P No. Valves 12 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 1P Annular Preventer 16 P #1 Rams 4 P Coiled Tubing Only:#2 Rams 4 P Inside Reel valves 0NA #3 Rams 3 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:8 hrs HCR Choke 1 P Repair or replacement of equipment will be made within 0 days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3-26-24/03:08 Waived By Test Start Date/Time:3/26/2024 9:00 (date) (time)Witness Test Finish Date/Time:3/26/2024 17:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Brian Bixby Nordic Test BOPE with 3 1/2" test joint Henry/Twedt CPAI Newell/Barr KRU 2M-03 Test Pressure (psi): gmanager.rig3@nordic-calista.com ic3.Companyman@conocophillips Form 10-424 (Revised 08/2022) 2024-0326_BOP_Nordic3_KRU_2M-03 9 9 9 999 9 9 9 9 9 -5HJJ Operations shutdownRepair WellFracture StimulatePlug PerforationsAbandon1. Type of Request: Change Approved ProgramPull TubingOther StimulatePerforateSuspend Alter CasingPerforate New Pool Re-enter Susp WellPlug for Redrill 5. Permit to Drill Number:4. Current Well Class:2. Operator Name: DevelopmentExploratory 3. Address:ServiceStratigraphic 6. API Number: 8. Well Name and Number:7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? NoYes 10. Field:9. Property Designation (Lease Number): Kuparuk River Field 11. Junk (MD):Effective Depth TVD:Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: None7512' CollapseCasing Conductor Surface Production Packers and SSSV MD (ft) and TVD (ft):Packers and SSSV Type: 13. Well Class after proposed work:12. Attachments: Proposal Summary Wellbore schematic ServiceDevelopmentExploratory StratigraphicDetailed Operations Program BOP Sketch 15. Well Status after proposed work: WDSPLOIL WINJ Suspended SPLUGGSTORWAGGASDate:16. Verbal Approval: AOGCC Representative: GINJ AbandonedOp Shutdown Contact Name:James Ohlinger Contact Email: Contact Phone: 907-267-1102 Authorized Title: Sundry Number:Conditions of approval: Notify AOGCC so that a representative may witness Location ClearancePlug Integrity BOP Test Mechanical Integrity Test Other Conditions of Approval: Post Initial Injection MIT Req'd? NoYes APPROVED BY Date:THE AOGCCCOMMISSIONERApproved by: Sr Res EngSr Pet GeoSr Pet EngComm.Comm. KRU 2M-03 Other: Replace Tubing N/A Kuparuk River Field james.j.ohlinger@conocophillips.com CTD Engineer Size Kuparuk River Oil Pool 6309' Plugs (MD): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length AOGCC USE ONLY Tubing MD (ft):Tubing Grade: Packer: 7036'MD/5916'TVD Packer: 7046'MD/5924'TVD Packer: 7064'MD/5939'TVD SSSV: 1793'MD/1724'TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 25586 191-141 50-103-20160-00-00P.O. Box 100360, Anchorage, AK 99510 ConocoPhillips Alaska, Inc Proposed Pools: J-55 BurstTVD 7090' MD 123' 2914' 123' 3323' 16" 9-5/8" 82' 3282' 7475' 6306'7" None6187'7365' 3-1/2" Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: OTIS HVT Retrev Packer SSSV: Camco TRDP-4A 7516' Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 3136 14. Estimated Date for Commencing Operations: 2/20/24 Perforation Depth MD (ft): 7183-7203' 7214-7224' 7238-7278' 6037-6053 6062-6071' 6082-6115' By Samantha Coldiron at 12:05 pm, Feb 06, 2024 324-052 Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E=James.J.Ohlinger@ cop.com Reason: I am the author of this document Location: Date: 2024.02.06 10:47:54-09'00' Foxit PDF Editor Version: 13.0.0 James J. Ohlinger BOP test to 3500 psig Annular preventer test to 2500 psig X 10-404 SFD 2/7/2024 DSR-2/13/24 X X VTL 02/21/2024*&:JLC 2/21/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.21 15:23:50 -09'00'02/21/24 RBDMS JSB 022324 2M-03 RWO Procedure Kuparuk Injector RWO PTD #191-141 Page 1 of 5 General Well info: Wellhead type/pressure rating: FMC Gen IV (5000 psi) Production Engineer: Adam Becia Reservoir Development Engineer: Kevin Wiggs Estimated Start Date: 2/26/24 Workover Engineer: James Ohlinger (265-1102/ James.J.Ohlinger@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Injector Scope of Work: Pull the existing 3-1/2” completion down to the pre-rig tubing cut. Install a new 7” casing to regain all OA needed for WAG injection. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Pre-Rig Work 1. SBHP 2. Lockout SSSV 3. Open lowest GLM ~6996’ RKB, dummy valves in remaining GLM 4. Set RBP ~7030’ RKB in 3-1/2” tubing above the patch a. MIT-T & DDT tubing 5. Cut the tubing at ~7017’ RKB Rig Work MIRU 1. MIRU Nordic 3 on 2M-03 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500 psi. Retrieve Tubing – Part 1 of 2 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to the cut ~7017’ RKB a. If tubing gets detained on POOH around the known tight spot depth ~243’ RKB b. Cut the control line and secure to the tubing for extraction later c. Then set IBP through tubing. Pressure test IBP to confirm set. d. Dump sand on top of IBP. e. Then gently set remaining tubing back on sand with GS profile on top of tubing 7” Surface Casing Grow & Stretch 6. If KWF has been static at surface or 1 barrier already exists in the well, then set RBP or IBP at ~200’ RKB. 7. Swap lower rams to 7” fixed rams and test to prepare for 7” casing removal. 8. ND BOPEs 2M-03 RWO Procedure Kuparuk Injector RWO PTD #191-141 Page 2 of 5 9. RU Hydratight per Hydratight procedure. ND tubing head and allow 7” production casing to grow per Hydratight procedure recording pressure and growth through each cycle. 10. Remove casing slips. Cut off excess with Wachs Cutter. 11. NU BOPE to casing head with necessary adapters and spacer spools. Test break to 3000 psi against RBP. 12. If shallow IBP/RBP was set, then RIH and pull RBP or IBP. TOOH and LD plug. Retrieve Tubing – Part 2 of 3 13. Pull remaining 3-1/2” tubing from top of sand/IBP 14. RU E-line: Run caliper & RCBL and log from ~3300’ MD back to surface. Confirm top of cement behind 7” casing; Estimated TOC ~ 6600’ MD (SLB CBT Log 01/27/92) 7” Surface Casing Subsidence Repair 15. Set RBP in 7” casing below TOC, pressure test or perform 30 min NFT, dump 50’ of sand on top of RBP. 16. RIH with multistring cutter on DP, cut 7” casing above the TOC, POOH and stand back DP 17. Circulate out the Arctic Pack from the OA 18. Spear the 7” casing. POOH and lay down the 7” casing 19. RIH w/ tandem string mills to gauge the 9-5/8” casing for the ES cementer & Sealing Overshot 20. RU casing crew and RIH w/ new 7” casing, ES Cementer, and Sealing Overshot, PT casing to 2500 psi 21. RU cementer and cement 7” x 9-5/8” annulus to surface 22. ND BOPE, pull 7” casing in tension and land in the slips. Cut excess 7” casing with Wachs cutter. 23. NU new tubing head and BOP stock. Test break 24. RIH w/ 6-1/8” bit/mill to TOC, mill through cement. POOH standing back drillpipe. 25. Pressure test the casing to 2500 psi, chart for 30 minutes 26. RIH w/ wash string assembly and circulate out sand on top of RBP that was set below TOC 27. Pull RBP 28. RIH w/ wash string assembly and circulate out sand on top of IBP that was set below the pre-rig tubing cut 29. Pull IBP Retrieve Tubing – Part 3 of 3 30. Perform a Cleanout run if necessary, based on tubing condition and dress off 3.5” tubing stub if necessary. 31. Pull remaining 3-1/2” tubing down to the Otis PBR. a. Has a 10’ patch inside the tubing & RBP. Install 3-½” Tubing Injection String 32. MU 3 ½” completion with seals, nipple profile, packer, and GLMs. RIH to stab into PBR. 33. Once on depth, circulate CI brine, space out as needed, land hanger, RILDS, drop B&R, and set packer. 34. Pressure test tubing to 3,000 psig for 5 minutes. 35. Pressure test inner annulus to 2,500 psig for 30 minutes on chart. ND BOP, NU Tree 36. Confirm pressure tests, then shear out SOV with pressure differential. 37. Install BPV. 38. ND BOPE. NU tree. PT tree. 39. Pull BPV, freeze protect well, and set BPV if necessary. 40. RDMO. 2M-03 RWO Procedure Kuparuk Injector RWO PTD #191-141 Page 3 of 5 Post-Rig Work 41. Swap out SOV with a DV. 42. Pull any plugs ball and rods. Following subject to change/be updated with pre-rig work: MIT results: MIT-T N/A, known tubing leak ~7042’ MD, patched 9/22/20 MIT-IA Passed 10/13/20 CMIT-TxIA Passed 9/21/20 IC POT & PPPOT Failed – 12/10/23 T POT & PPPOT PASSED – 12/10/23 MPSP: 3136 psi using 0.1 psi/ft gradient Static BHP: 3727 psi / 5912’ TVD measured 2/10/23 2M-03 RWO Procedure Kuparuk Injector RWO PTD #191-141 Page 4 of 5 2M-03 Completion (KUP INJECTOR) Pr i m a r y C e m e n t Pr i m a r y C e m e n t 9-5/8" Surface Casing 7" Production Casing 16" Conductor A-sand perfs 7214' - 7224' RKB 7238' - 7278' RKB C-Sand Perfs 7183' - 7203' RKB D KOP @ 700' RKB Otis SA (4" PB) Stripped OR Cut Joint Production Packer (7064' RKB) 7" TOC Good Cement (6600' RKB) Weaker Cement (6600' - 6210' RKB) Last Tag (7365' RKB) Packer 7036' Packer 7046' Tight Spot (2.72") 243' 6996' Pre-Rig Tubing Cut 7017' SC Leak ~528' Leak 7042' RBP 7030' 21' 2M-03 RWO Procedure Kuparuk Injector RWO PTD #191-141 Page 5 of 5 COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in)Grade Thread (top) Conductor 123 123 16 H-40 Surface 3323 2914 9-5/8 J-55 BTC Production 7516 J-55 BTC-MOD Tubing 7090 5960 3-1/2 L-80 Hyd. 563 2M-03 Proposed RWO Completion (KUP INJECTOR) Pr i m a r y C e m e n t Pr i m a r y C e m e n t PROPOSED COMPLETION 3-1/2" 9.3# Hyd.563 Tubing to surface GLM 3-1/2" x 7" Premier Packer X-Nipple (ID - 2.813") Seals REMAINING COMPLETION LEFT IN HOLE Otis PBR @ 7049' RKB Otis Retrievable Packer @ 7064' RKB Camco D Nipple @ 7080' RKB (2.75" ID) Otic WLEG @ 7089' RKB 9-5/8" Surface Casing 7" Production Casing 16" Conductor A-sand perfs 7214' - 7224' RKB 7238' - 7278' RKB C-Sand Perfs 7183' - 7203' RKB D KOP @ 700' RKB CO N T I N G E N C CO N T I N G E N C X Otis SA (4" PB) Stripped OR Cut Joint Production Packer (7064' RKB) 7" TOC Good Cement (6600' RKB) Weaker Cement (6600' - 6210' RKB) Last Tag (7365' RKB) Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:RKB (Est. 87' of Rathole) 7,365.0 2M-03 5/15/2020 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Recover LIH tools. 2M-03 7/15/2023 appleha Notes: General & Safety Annotation End Date Last Mod By NOTE:11/10/2010 condijw 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 42.0 123.0 123.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 41.5 3,323.2 2,913.9 36.00 J-55 BTC Production 7 6.28 41.8 7,516.2 26.00 J-55 BTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 39.0 Set Depth … 7,089.8 Set Depth … 5,960.2 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 39.0 39.0 0.12 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 1,793.4 1,724.4 35.81 SAFETY VLV 5.250 CAMCO TRDP-4A-RO MODIFIED SAFETY VALVE CAMCO TRDP- 4A 2.812 2,821.7 2,527.4 39.34 GAS LIFT 5.540 OTIS WB OTIS WBD 2.897 4,885.9 4,156.7 35.44 GAS LIFT 5.540 OTIS WB OTIS WBD 2.897 6,223.1 5,254.5 35.59 GAS LIFT 5.540 OTIS WB OTIS WBD 2.897 6,995.9 5,883.1 34.89 GAS LIFT 5.960 OTIS LB OTIS LBX 2.907 7,048.5 5,926.3 34.85 PBR 5.410 OTIS PBR w/ 10' STROKE & 4" SEAL BORE OTIS 2.970 7,064.4 5,939.3 34.84 PACKER 6.000 OTIS HVT RETRIEVABLE PACKER OTIS HVT 3.250 7,079.8 5,951.9 34.84 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 7,089.2 5,959.7 34.83 WLEG 4.500 OTIS RH BALL SEAT SUB/WIRELINE ENTRY GUIDE, NO ELMD LOG AVAILABLE OTIS 2.875 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) 243.0 243.0 0.33 TIGHT SPOT NOTICED TIGH SPOT IN TBG @ 243' RKB (ABLE TO TAP 2.72" DMY RBP BY & PULL UP HOLE THRU AREA W/ NO PROBLEMS) 5/4/2022 0.000 7,036.0 5,916.0 34.86 PATCH - PACKER 2.72" P2P PATCH ASSEMBLY, ANCHOR LATCH, OAL 10.85' CPP3 5294 9/22/2020 1.620 7,040.0 5,919.3 34.85 SPACER PIPE 2-1/16" P110 SPACER PIPE CPAL 35136 9/22/2020 1.590 7,042.0 5,920.9 34.85 LEAK Tubing Leak @7042' 6/28/2020 2.992 7,046.0 5,924.2 34.85 PATCH - PACKER 2.72" P2P, OAL 4.01' CPP3 5288 9/21/2020 1.620 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) 2,821.7 2,527.4 39.34 1 GAS LIFT DMY BK 1 0.0 2/22/1992 0.000 4,885.9 4,156.7 35.44 2 GAS LIFT DMY BK 1 0.0 2/22/1992 0.000 6,223.1 5,254.5 35.59 3 GAS LIFT DMY BK 1 0.0 2/22/1992 0.000 6,995.9 5,883.1 34.89 4 GAS LIFT DMY RM 1 1/2 0.0 12/1/1992 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,183.0 7,203.0 6,036.8 6,053.2 C-4, 2M-03 11/8/1992 4.0 IPERF 180 deg. phasing; Oriented 105 deg. CCW, 2 1/2" Titan7,214.0 7,224.0 6,062.3 6,070.6 A-4, 2M-03 2/22/1992 4.0 IPERF 180 deg. phasing; Oriented 84.25 deg. CCW, 4 1/2" HJ II Csg Gun7,238.0 7,258.0 6,082.1 6,098.6 A-3, 2M-03 2/21/1992 4.0 IPERF 180 deg. phasing; Oriented 172 deg. CCW, 4 1/2" HJ II Csg Gun7,258.0 7,278.0 6,098.6 6,115.2 A-3, 2M-03 2/21/1992 4.0 IPERF 180 deg. phasing; Oriented 166 deg. CCW, 4 1/2" HJ II Csg Gun 2M-03, 7/15/2023 12:44:11 AM Vertical schematic (actual) Production; 41.8-7,516.2 FLOAT SHOE; 7,514.7-7,516.2 FLOAT COLLAR; 7,429.8-7,431.1 IPERF; 7,258.0-7,278.0 IPERF; 7,238.0-7,258.0 IPERF; 7,214.0-7,224.0 IPERF; 7,183.0-7,203.0 WLEG; 7,089.2 NIPPLE; 7,079.7 PACKER; 7,064.4 PBR; 7,048.5 PATCH - PACKER; 7,046.0 SPACER PIPE; 7,040.0 LEAK; 7,042.0 PATCH - PACKER; 7,036.0 GAS LIFT; 6,995.9 GAS LIFT; 6,223.1 GAS LIFT; 4,885.9 SURFACE; 41.5-3,323.2 FLOAT SHOE; 3,321.2-3,323.2 FLOAT COLLAR; 3,241.3-3,243.1 GAS LIFT; 2,821.7 SAFETY VLV; 1,793.4 TIGHT SPOT; 243.0 CONDUCTOR; 42.0-123.0 HANGER; 41.5-46.0 HANGER; 39.0 KUP INJ KB-Grd (ft) 41.01 RR Date 1/3/1992 Other Elev… 2M-03 ... TD Act Btm (ftKB) 7,512.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032016000 Wellbore Status INJ Max Angle & MD Incl (°) 40.75 MD (ftKB) 2,400.00 WELLNAME WELLBORE2M-03 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP ! " # $! % " & ' $ (" " ) *$ +, *# - # ./$ 0/ 1 $ $ " # # ! 2 ,2 3 $ 4* 56 $ 7 8&5 7 * 9*5 7 * :*5 7 + #* 9* + #* :* 9 5 7 59*7 ; <59*7 0)'=$ " / 6 < : < :9*5 7:*5 7 ' - " !< * > < +, *# # (+ * ) !< " /6 /$; * 6 .:# * ? ? ? 6@? ?"" #?/$; ! "$ "+ " A " #$ ?"" # ! $ / > 9 / 6" //B9/ =23 $ +, 23 $ :+*>3 # " 99/ / $+ C+ ?"" * " " + ? + 0/ # !# ! !# A$ * ! * / * D 54807.)4%0''( ? 9*5 7 <08-.=9*)4.=:* <08(.=9*)4'(=:* <08.(=9*)4-4=:* :04-=9*0'(=:* * :*5 7 A + 6 E 6 E /6$*? " $ + :/ $" 99/ / $ '8"')'18 !" #$#%#&# >,88-.8F FE44)8 %# '% #" % % " <F/ ( % '$& () *)+ , * -. () *)+ , * /0 1 ;%)) 2)*/ 0818= '-= '4(= '-= --'-= 0G .G 4%)&1G 1= -'1'= * 9*5 7 01-%0'8-=F0'(%0''(=F0'-1% 0'01= .8-0%.8)-=F.8.'%.80=F.81'% .)= ".#. -%&'G <// < <// < < C: #< :" *%( :# .-84= 0-.)= .10= $ 8%(8- # 8&'8' *, - 3/ ,- 4* # 5/0 4*5 /0 -/ 4 *,6 0(.4= 0)81= .-8.= By Meredith Guhl at 1:34 pm, May 16, 2022 322-306 Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Anchorage, Alaska Date: 2022.05.16 10:27:38-08'00' Foxit PDF Editor Version: 11.2.1 Dusty Freeborn DLB 05/16/2022 X 10-404 X X VTL 5/18/2022 DSR-5/16/22 JLC 5/18/2022 Jeremy Price Digitally signed by Jeremy Price Date: 2022.05.18 14:12:49 -08'00' RBDMS SJC 052322 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 16 May 2022 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 application for sundry approval for ConocoPhillips Alaska, Inc. well KRU 2M-03 (PTD 191-141) to pull the existing tubing patch and replace it with a large bore retrievable tubing patch and nipple reducer. During the most recent subsidence surveillance drift, what is believed to be a subsidence induced tubing restriction was identified at approximately 243’. The larger inner diameter patch and nipple reducer will allow for a reduce sized diameter plug to be used to secure the well below the packer. Please contact me at 907-265-6218 if you have any questions. Sincerely, Dusty Freeborn Senior Well Integrity Specialist ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Anchorage, Alaska Date: 2022.05.16 10:26:39-08'00' Foxit PDF Editor Version: 11.2.1 Dusty Freeborn ypp p pull the existing tubing patch and,()pggp replace it with a large bore retrievable tubing patch and nipple reducer. During the mostp g g p pp g recent subsidence surveillance drift, what is believed to be a subsidence induced tubing, restriction was identified at approximately 243’. The larger inner diameter patch and pp y gp nipple reducer will allow for a reduce sized diameter plug to be used to secure the wellpp below the packer. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:RKB (Est. 87' of Rathole) 7,365.0 5/15/2020 2M-03 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Noted Tight Spot in Tubing 5/4/2022 2M-03 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 42.0 Set Depth (ftKB) 123.0 Set Depth (TVD) … 123.0 Wt/Len (lb… 62.50 Grade H-40 Top Connection WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 41.5 Set Depth (ftKB) 3,323.2 Set Depth (TVD) … 2,913.9 Wt/Len (lb… 36.00 Grade J-55 Top Connection BTC Casing Description Production OD (in) 7 ID (in) 6.28 Top (ftKB) 41.8 Set Depth (ftKB) 7,516.2 Set Depth (TVD) … Wt/Len (lb… 26.00 Grade J-55 Top Connection BTC-MOD Tubing Strings: string max indicates LONGEST segment of string Tubing Description TUBING String … 3 1/2 ID (in) 2.99 Top (ftKB) 39.0 Set Depth (ft… 7,089.8 Set Depth (TVD… 5,960.2 Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model 39.0 39.0 0.12 HANGER 3.500 8.000 1,793.4 1,724.4 35.81 SAFETY VLV 2.812 5.250 CAMCO TRDP-4A 2,821.7 2,527.4 39.34 GAS LIFT 2.897 5.540 OTIS WBD 4,885.9 4,156.7 35.44 GAS LIFT 2.897 5.540 OTIS WBD 6,223.1 5,254.5 35.59 GAS LIFT 2.897 5.540 OTIS WBD 6,995.9 5,883.1 34.89 GAS LIFT 2.907 5.960 OTIS LBX 7,048.5 5,926.3 34.85 PBR 2.970 5.410 OTIS 7,064.4 5,939.3 34.84 PACKER 3.250 6.000 OTIS HVT 7,079.8 5,951.9 34.84 NIPPLE 2.750 4.540 CAMCO D 7,089.2 5,959.7 34.83 WLEG 2.875 4.500 OTIS Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 243.0 243.0 0.33 TIGHT SPOT NOTICED TIGH SPOT IN TBG @ 243' RKB (ABLE TO TAP 2.72" DMY RBP BY & PULL UP HOLE THRU AREA W/ NO PROBLEMS) 5/4/2022 0.000 7,036.0 5,916.0 34.86 PATCH - PACKER 2.72" P2P PATCH ASSEMBLY, ANCHOR LATCH, OAL 10.85' 9/22/2020 1.620 CPP35294 7,040.0 5,919.3 34.85 SPACER PIPE 2-1/16" P110 SPACER PIPE 9/22/2020 1.590 CPAL35136 7,042.0 5,920.9 34.85 LEAK Tubing Leak @7042' 6/28/2020 2.992 7,046.0 5,924.2 34.85 PATCH - PACKER 2.72" P2P, OAL 4.01' 9/21/2020 1.620 CPP35288 Mandrel Inserts : excludes pulled inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,821.7 2,527.4 39.34 1 GAS LIFT DMY BK 0.000 0.0 2/22/1992 2 4,885.9 4,156.7 35.44 1 GAS LIFT DMY BK 0.000 0.0 2/22/1992 3 6,223.1 5,254.5 35.59 1 GAS LIFT DMY BK 0.000 0.0 2/22/1992 4 6,995.9 5,883.1 34.89 1 1/2 GAS LIFT DMY RM 0.000 0.0 12/1/1992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,183.0 7,203.0 6,036.8 6,053.2 C-4, 2M-03 11/8/1992 4.0 IPERF 180 deg. phasing; Oriented 105 deg. CCW, 2 1/2" Titan 7,214.0 7,224.0 6,062.3 6,070.6 A-4, 2M-03 2/22/1992 4.0 IPERF 180 deg. phasing; Oriented 84.25 deg. CCW, 4 1/2" HJ II Csg Gun 7,238.0 7,258.0 6,082.1 6,098.6 A-3, 2M-03 2/21/1992 4.0 IPERF 180 deg. phasing; Oriented 172 deg. CCW, 4 1/2" HJ II Csg Gun 7,258.0 7,278.0 6,098.6 6,115.2 A-3, 2M-03 2/21/1992 4.0 IPERF 180 deg. phasing; Oriented 166 deg. CCW, 4 1/2" HJ II Csg Gun Notes: General & Safety End Date Annotation 11/10/2010 NOTE: 2M-03, 5/10/2022 11:07:42 AM Vertical schematic (actual) Production; 41.8-7,516.2 IPERF; 7,258.0-7,278.0 IPERF; 7,238.0-7,258.0 IPERF; 7,214.0-7,224.0 IPERF; 7,183.0-7,203.0 PACKER; 7,064.4 PATCH - PACKER; 7,046.0 SPACER PIPE; 7,040.0 LEAK; 7,042.0 PATCH - PACKER; 7,036.0 GAS LIFT; 6,995.9 GAS LIFT; 6,223.1 GAS LIFT; 4,885.9 SURFACE; 41.5-3,323.2 GAS LIFT; 2,821.7 SAFETY VLV; 1,793.4 TIGHT SPOT; 243.0 CONDUCTOR; 42.0-123.0 KUP INJ KB-Grd (ft) 41.01 RR Date 1/3/1992 Other Elev… 2M-03 ... TD Act Btm (ftKB) 7,512.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032016000 Wellbore Status INJ Max Angle & MD Incl (°) 40.75 MD (ftKB) 2,400.00 WELLNAME WELLBORE2M-03 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP ! "##$"#%&'() $"#* + ! "# # # $$% & # # '( # ,!(-%$ % + ) * "+ , -./ 0 1 - 2 "2#%# , "3 " 3 . # / ( %* 0#" ""#%12 3# 0 ""$/#% " "#%4 5 + 678 #$ #% ,5 #% 2 ( "# , 4=# 562 789: 8 ' , 4 ; / "#// / "#// < 1 #(# "= " "> > , "># 2 "2##%# 1 #(# "= 3 , 2 "2# 1' &'8> % ;2> '7 < ' , 4 ; 4 8 '1' &'8 ;2 "2# < '1' &'8 ; " , " , " > 52 : = , , 1' &'8> % ;2> '7 8 '1' &'8 ; < '1' &'8 ; ? , ; , " 2 / ' '8> % ;2> 8 '' '8 ; 0 ,$' '8 2 ! < '' '8 ; Originated:Delivered to:3-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 1Y-27 50-029-22379-00 n/a Kuparuk River Packer Setting Record Field- Final 8-Sep-20 0 1 2 2B-02 50-029-21154-00 906718091 Kuparuk River Packer Setting Record Field- Final 20-Sep-20 0 1 3 2F-05X 50-029-22730-00 906726469 Kuparuk River Packer Setting Record Field- Final 28-Sep-20 0 1 4 2H-09 50-103-20050-00 n/a Kuparuk River Plug Setting Record Field- Final 6-Sep-20 0 1 5 2M-03 50-103-20160-00 906439276 Kuparuk River Packer Setting Record Field- Final 21-Sep-20 0 1 6 2M-24 50-103-20171-00 906726590 Kuparuk River Leak Detect Log Field- Final 23-Sep-20 0 1 7 2M-24 50-103-20171-00 906726590 Kuparuk River Packer Setting Record Field- Final 23-Sep-20 0 1 8 2T-209 50-103-20281-00 906722868 Kuparuk River Water Flow Log Field & Processed 28-Sep-20 0 1 9 3B-03 50-029-21322-00 906711627 Kuparuk River Leak Detect Log Field- Final 15-Sep-20 0 1 10 3B-03 50-029-21322-00 906711627 Kuparuk River Packer Setting Record Field- Final 16-Sep-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/04/2020 PTD: 1911410 E-Set: 34334 12/08/2020 Abby Bell MEMORANDUM TO: Jim Regg -�jj I P.I. Supervisor FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, October 20, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2M-03 KUPARUK RIV UNIT 2M-03 Ste: Inspector Reviewed By: P.I. Supry Comm Well Name KUPARUK RIV UNIT 2M-03 API Well Number 50-103-20160-00-00 Permit Number: 191-141-0 Insp Num: mitBDB201013160310 Rel Insp Num: Inspector Name: Brian Bixby Inspection Date: 10/13/2020 - Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2M-03 ITypelnj W'TVD 5938 ITubing 1380 ,i 1380 - 3ao 380 PT L 1911410 -'Type Test SPT Test psi soo IA 610 zloo "i 2060 zoso" BBLPumped: i 1J "BBL Returned: 1.2 OA no 370 320 370 ' P Interval OTHER P/F Notes: MITIA Per SUNDRY 320-283 Post Patch Tuesday, October 20, 2020 Page I of I 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well ConocoPhillips Alaska, Inc.Development Exploratory 3. Address: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 7512 feet N/A feet true vertical 6309 feet N/A feet Effective Depth measured 7365 feet 7064 feet true vertical 6187 feet 5940 feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth)3.5 J-55 7090' MD 5960' TVD Packers and SSSV (type, measured and true vertical depth)Packer Otis HVT 7064' MD 5939' TVD SSSV Camco TRDP 4A-RO 1793' MD 1727' TVD 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 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: Contact Name: Authorized Title: Contact Email: 10/20/2020 Contact Phone: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name 4. Well Class Before Work:5. Permit to Drill Number: Other: Tubing patch Junk measured Burst Collapse 191-141 50103201600000 ADL0025586 KRU 2M-03 P.O. Box 100630, Anchorage, Alaska 99508 N/A Kuparuk River Field/Kuparuk River Oil Plugs measured Packer measured true vertical Casing Length Size MD TVD N/A N/A N/ASurface32829 5/8 3323 2914 N/A Conductor 81 16 123 123 7183'-7203', 7214'-7224', 7238'-7258', 7258'-7278' 6037'-6053',6062'-6070',608'2-6099', 6099'-6115' N/AProduction7469775086306N/A N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Senior Engineer:Senior Res. Engineer: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283 WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Jan Byrne / Dusty Freeborn n1617@conocophillips.com 659-7224 Well Integrity & Compliance Specialist 320-283 Authorized Name: Authorized Signature with date: ----- ----- t Fra O 6. A G L PG R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:32 pm, Oct 20, 2020 Dusty Freeborn Digitally signed by Dusty Freeborn Date: 2020.10.20 12:59:15 -08'00' SFD 10/20/2020 VTL 11/02/20 DSR-10/20/2020 RBDMS HEW 11/10/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 20, 2020 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set across a known tubing leak in KRU 2M-03 (PTD 191-141). Please contact Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Dusty Freeborn Digitally signed by Dusty Freeborn Date: 2020.10.20 12:58:26 -08'00' Date Event Summary Executive Summary Leak detect log identified a tubing leak at 7042'. A tubing patch was set from 7036'-7046' and a SW MIT-IA was perfromed to prove integrity. 06/28/20 PERFORMED LEAK DETECT LOG FROM 7080' RKB TO SURFACE, FOUND LEAK @ 7042' RKB. JOB COMPLETE 07/17/20 RECIEVED APPROVED SUNDRY 320-283 FOR TUBING PATCH INSTALLATION. 09/21/20 EQUALIZED & PULLED 2.75" CA-2 PLUG @ 7080' RKB, SET LOWER 2.72" P2P @ 7046' RKB (ME) (OAL 4.01' / SN:CPP35288), CMIT TBG x IA 3000 PSI PASS. IN PROGRESS. PRE CMIT T/I/O= 1275/1150/100, INITIAL T/I/O= 3125/3025/120, 15 MIN T/I/O= 3100/3025/120, 30 MIN T/I/O= 3100/3025/120, BLEED BACK 09/22/20 SET UPPER 2.72" P2P SPACER & ANCHOR LATCH (OAL 10.85' / SN:CPP35294 / CPAL35136), MIT IA 3000 PSI PASSED. COMPLETE. PRE MIT T/I/O= 1275/1250/100, INITIAL T/I/O= 1275/3025/120, 15 MIN T/I/O = 1275/3000/120, 30 MIN T/I/O = 1275/2975/120, CONFER W/ CWG 45 MIN T/I/O = 1275/2975/120 ****PASS**** 10/13/20 (SW) STATE WITNESSED (BRIAN BIXBY) MIT-IA TO 2100 PSI (PASSED). Initial T/I/O = 1380/610/270. IA FL @SF. Pressurize IA to 2100 psi w/ 1.1 bbls of diesel. Monitor 30 min. Starting T/I/O = 1380/2100/370. 15 min T/I/O = 1380/2060/370 (-40). 30 min T/I/O = 1380/2050/370 (-10). Bleed IA to T/I/O = 1380/610/270 (1.2 bbls back). Final T/I/O = 1380/610/270. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:RKB (Est. 87' of Rathole) 7,365.0 5/15/2020 2M-03 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: SET PATCH 9/22/2020 2M-03 condijw Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 42.0 Set Depth (ftKB) 123.0 Set Depth (TVD) … 123.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 41.5 Set Depth (ftKB) 3,323.2 Set Depth (TVD) … 2,913.9 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description Production OD (in) 7 ID (in) 6.28 Top (ftKB) 41.8 Set Depth (ftKB) 7,516.2 Set Depth (TVD) … Wt/Len (l… 26.00 Grade J-55 Top Thread BTC-MOD Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 39.0 Set Depth (ft… 7,089.8 Set Depth (TVD) (… 5,960.2 Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 39.0 39.0 0.12 HANGER FMC GEN IV TUBING HANGER 3.500 1,793.4 1,724.4 35.81 SAFETY VLV CAMCO TRDP-4A-RO MODIFIED SAFETY VALVE 2.812 7,048.5 5,926.3 34.85 PBR OTIS PBR w/ 10' STROKE & 4" SEAL BORE 2.970 7,064.4 5,939.3 34.84 PACKER OTIS HVT RETRIEVABLE PACKER 3.250 7,079.8 5,951.9 34.84 NIPPLE CAMCO D NIPPLE 2.750 7,089.2 5,959.7 34.83 WLEG OTIS RH BALL SEAT SUB/WIRELINE ENTRY GUIDE, NO ELMD LOG AVAILABLE 2.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,036.0 5,916.0 34.86 PATCH - PACKER 2.72" P2P PATCH ASSEMBLY, ANCHOR LATCH, OAL 10.85' 9/22/2020 1.620 CPP35294 7,040.0 5,919.3 34.85 SPACER PIPE 2-1/16" P110 SPACER PIPE 9/22/2020 1.590 CPAL35136 7,042.0 5,920.9 34.85 LEAK Tubing Leak @7042' 6/28/2020 2.992 7,046.0 5,924.2 34.85 PATCH - PACKER 2.72" P2P, OAL 4.01' 9/21/2020 1.620 CPP35288 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,183.0 7,203.0 6,036.8 6,053.2 C-4, 2M-03 11/8/1992 4.0 IPERF 180 deg. phasing; Oriented 105 deg. CCW, 2 1/2" Titan 7,214.0 7,224.0 6,062.3 6,070.6 A-4, 2M-03 2/22/1992 4.0 IPERF 180 deg. phasing; Oriented 84.25 deg. CCW, 4 1/2" HJ II Csg Gun 7,238.0 7,258.0 6,082.1 6,098.6 A-3, 2M-03 2/21/1992 4.0 IPERF 180 deg. phasing; Oriented 172 deg. CCW, 4 1/2" HJ II Csg Gun 7,258.0 7,278.0 6,098.6 6,115.2 A-3, 2M-03 2/21/1992 4.0 IPERF 180 deg. phasing; Oriented 166 deg. CCW, 4 1/2" HJ II Csg Gun Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,821.7 2,527.4 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 2/22/1992 2 4,885.9 4,156.7 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 2/22/1992 3 6,223.1 5,254.5 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 2/22/1992 4 6,995.9 5,883.1 OTIS LBX 1 1/2 GAS LIFT DMY RM 0.000 0.0 12/1/1992 Notes: General & Safety End Date Annotation 11/10/2010 NOTE: 2M-03, 9/23/2020 4:53:23 AM Vertical schematic (actual) Production; 41.8-7,516.2 IPERF; 7,258.0-7,278.0 IPERF; 7,238.0-7,258.0 IPERF; 7,214.0-7,224.0 IPERF; 7,183.0-7,203.0 PACKER; 7,064.4 PATCH - PACKER; 7,046.0 SPACER PIPE; 7,040.0 LEAK; 7,042.0 PATCH - PACKER; 7,036.0 GAS LIFT; 6,995.9 GAS LIFT; 6,223.1 GAS LIFT; 4,885.9 SURFACE; 41.5-3,323.2 GAS LIFT; 2,821.7 SAFETY VLV; 1,793.4 CONDUCTOR; 42.0-123.0 KUP INJ KB-Grd (ft) 41.01 Rig Release Date 1/3/1992 2M-03 ... TD Act Btm (ftKB) 7,512.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032016000 Wellbore Status INJ Max Angle & MD Incl (°) 40.75 MD (ftKB) 2,400.00 WELLNAME WELLBORE2M-03 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP 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.Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 7512 3217 N/A Casing Collapse Conductor Surface Production Packers and SSSV Type:PKR:Packers and SSSV MD (ft) and TVD (ft):PKR: SSSV:SSSV: 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 Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:7/9/2020 Conditions of approval: Notify Commission 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 COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 659-7224 Otis HVT Retrievable packer Camco TRDP 4A-RO 7064' MD & 5939' TVD 1793' MD & 1727' TVD Size Authorized Signature: Jul-20 3.5 Perforation Depth MD (ft): J-55 N/A Tubing Grade:Tubing MD (ft): 6037-6053,6062-6070,6082- 6099, 6099-6115 Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Well Integrity & Compliance Specialist COMMISSION USE ONLY Authorized Name:Jan Byrne / Dusty Freeborn n1617@conocophillips.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025586 191-141 P.O. Box 100630, Anchorage, Alaska 99508 50103201600000 ConocoPhillips Alaska, Inc. KRU 2M-03 Kuparuk River Field/ Kuparuk River Oil 6309 7365 PRESENT WELL CONDITION SUMMARY 6187 7080' Length TVD Burst 7090 MD 2914 6306 3323 7469 123 123 7508 81 16 9 5/8 7 3282 Perforation Depth TVD (ft):Tubing Size: 7183-7203,7214-7224, 7238- 7258, 7258-7278 mm m wn ns 1 66 t y t atccctcctctctcctcctcctcctcch o c y Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 11:21 am, Jul 09, 2020 320-283 Dusty Freeborn Digitally signed by Dusty Freeborn Date: 2020.07.09 11:08:37 -08'00' N/A DLB DLB 07/09/2020 10-404 VTL 7/13/20 X X X DSR-7/15/2020Comm 7/16/2020 JLC 7/15/2020 RBDMS HEW 7/17/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 4 July 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 2M-03 (PTD 191-141) to install a retrievable tubing patch over a known tubing leak. Please contact Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Dusty Freeborn Digitally signed by Dusty Freeborn Date: 2020.07.09 11:07:20 -08'00' KRU 2M-03 (PTD# 191-141) Description Summary of Proposal Well Work Justification & Objectives 2M-03 has been identified as a well with a known tubing leak at 7042'. The well needs to have a tubing patch installed to regain TxIA integrity in order to return the well to injection. DO NOT PERFORM WORK UNTIL APPROVED 10-403 HAS BEEN RECEIVED. Steps: DSL 1. Have jumper line hooked from IA to available flow line. 2. Set catcher on CA-2 plug at 7080'. 3. Pull DMY valve from station #4 (6996'). 4. Pump 176 bbls inhibited SW and 75 bbls diesel down tubing taking returns off the IA. U-Tube to freeze protect T & IA. 5. Reset DMY valve in station #4 (6996'). 6. Pull catcher and CA-2 plug from 7080'. 7. Pump 2 bbls diesel down IA through tubing leak to clear any well bore fluids from below station #4 to leak point. 8. Set lower 3.5" P2P mid-element at 7046' (Just above collar at 7048') 9. Set test tool in 3.5" P2P at 7046' and perform CMIT-TxIA to 2500 psi. Record initial, 15 min and 30 min pressures. A. If CMIT-TxIA passes, pull test tool and proceed to step 10. B. If CMIT-TxIA fails, troubleshoot failure mechanism. 10. Set anchor latch, spacer pipe and upper 3.5" P2P mid element at 7036' and perfrom MIT-IA to 2500 psi. Record initial, 15 and 30 min pressures. A. If MIT-IA passes, rig down and turn well over to operations. SW MIT-IA will be required when returned to injection. B. If MIT-IA fails trouble shoot failure mechanism. Last Tag Annotation Depth (ftKB) End Date Last Mod By Wellbore Last Tag:RKB (Est. 87' of Rathole) 7,365.0 5/15/2020 zembaej 2M-03 Last Rev Reason Annotation End Date Last Mod By Wellbore Rev Reason: Leak Detect 6/28/2020 famaj 2M-03 Notes: General & Safety End Date 11/10/2010 Annotation NOTE: View Schematic w/ Alaska Schematic9.0 Wellbore 2M-03 Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Wellbore CONDUCTOR 16 15.06 42.0 123.0 123.0 62.50 H-40 WELDED 2M-03 SURFACE 9 5/8 8.92 41.5 3,323.2 2,913.9 36.00 J-55 BTC 2M-03 PRODUCTION 7 6.28 41.5 7,516.2 26.00 J-55 BTC-MOD 2M-03 Tubing Strings Des String Max Nominal OD (in)ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt (lb/ft) Grade Top Thread Wellbore TUBING 3 1/2 2.99 39.0 7,089.8 5,960.2 9.30 J-55 ABM-EUE 2M-03 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 39.0 39.0 0.12 HANGER FMC GEN IV TUBING HANGER 3.500 2M-03 1,793.4 1,724.4 35.81 SAFETY VLV CAMCO TRDP-4A-RO MODIFIED SAFETY VALVE 2.812 2M-03 7,048.5 5,926.3 34.85 PBR OTIS PBR w/ 10' STROKE & 4" SEAL BORE 2.970 2M-03 7,064.4 5,939.3 34.84 PACKER OTIS HVT RETRIEVABLE PACKER 3.250 2M-03 7,079.8 5,951.9 34.84 NIPPLE CAMCO D NIPPLE 2.750 2M-03 7,089.2 5,959.7 34.83 WLEG OTIS RH BALL SEAT SUB/WIRELINE ENTRY GUIDE, NO ELMD LOG AVAILABLE 2.875 2M-03 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) Wellbore 7,042.0 5,920.9 34.85 LEAK Tubing Leak @7042' 6/28/2020 2.992 2M-03 7,080.0 5,952.1 34.84 2.75" CA-2 Plug 2.75" CA-2 Plug (30" AOL) 5/17/2020 0.000 2M-03 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 41.5 41.5 0.13 HANGER 8.921 2M-03 42.0 42.0 0.13 CONDUCTOR 15.062 2M-03 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com Wellbore 7,183.0 7,203.0 6,036.8 6,053.2 C-4, 2M-03 11/8/1992 4.0 IPERF 180 deg. phasing; Oriented 105 deg. CCW, 2 1/2" Titan 2M-03 7,214.0 7,224.0 6,062.3 6,070.6 A-4, 2M-03 2/22/1992 4.0 IPERF 180 deg. phasing; Oriented 84.25 deg. CCW, 4 1/2" HJ II Csg Gun 2M-03 7,238.0 7,258.0 6,082.1 6,098.6 A-3, 2M-03 2/21/1992 4.0 IPERF 180 deg. phasing; Oriented 172 deg. CCW, 4 1/2" HJ II Csg Gun 2M-03 7,258.0 7,278.0 6,098.6 6,115.2 A-3, 2M-03 2/21/1992 4.0 IPERF 180 deg. phasing; Oriented 166 deg. CCW, 4 1/2" HJ II Csg Gun 2M-03 Mandrel Inserts St ati on No /S Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com Wellbore 1 2,821.7 2,527.4 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 2/22/1992 2M-03 2 4,885.9 4,156.7 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 2/22/1992 2M-03 3 6,223.1 5,254.5 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 2/22/1992 2M-03 4 6,995.9 5,883.1 OTIS LBX 1 1/2 GAS LIFT DMY RM 0.000 0.0 12/1/1992 2M-03 Comment SSSV: TRDP 2M-03, 6/30/2020 10:30:40 AM Vertical schematic (actual) PRODUCTION; 41.5- 7,516.2 IPERF; 7,258.0-7,278.0 IPERF; 7,238.0-7,258.0 IPERF; 7,214.0-7,224.0 IPERF; 7,183.0-7,203.0 WLEG; 7,089.2 2.75" CA-2 Plug; 7,080.0 NIPPLE; 7,079.7 PACKER; 7,064.4 PBR; 7,048.5 LEAK; 7,042.0 GAS LIFT; 6,995.9 GAS LIFT; 6,223.1 GAS LIFT; 4,885.9 SURFACE; 41.5-3,323.2 GAS LIFT; 2,821.7 SAFETY VLV; 1,793.4 CONDUCTOR; 42.0- 123.0 HANGER; 39.0 KUP INJ KB-Grd (ft) 41.01 Rig Release Date 1/3/1992 Annotation Last WO: End DateH2S (ppm) Date... TD Act Btm (ftKB) 7,512.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032016000 Wellbore Status INJ Max Angle & MD Incl (°) 40.75 MD (ftKB) 2,400.00 Legal Wellname 2M-03 Common Wellname2M-03 AK All Wellbores Schem Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Saturday, February 15, 2020 1:32 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 2M-03 (PTD 191-141) Report of suspect IA pressure increase Attachments: 2M-03.pdf; 21VI-03 90 day TIO trend 2-15-20.pdf Chris, KRU injection well 21VI-03 (PTD 191-141) was reported by Operations today for suspect IA pressure increase. The IA pressure was bled multiple times, but continued to re -pressurize. The well was shut in and freeze protected. DHD will be mobilized to the well to perform initial diagnostics after which a diagnostic plan will be formulated. The proper paperwork for continued injection or corrective action will be submitted once the path forward has been determined. wellbore schematic and 90 day TIO trend are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggDATE: Thursday,June 09,2016 �1 / P.I.Supervisor (41 3t LC, SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-03 FROM: Jeff Jones KUPARUK RIV UNIT 2M-03 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 1� NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2M-03API Well Number 50-103-20160-00-00 Inspector Name: Jeff Jones Permit Number: 191-141-0 Inspection Date: 6/5/2016 Insp Num: mitJJ160608091122 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ----- ------ Well 2M493 - Type Inj w TVD 5938 , Tubing 2350 2350 • 2350 - 2400 PTD 1911410 Type Test SPT Test psi 1500 IA 550 3200 3080 - 3080 L Interval 4YRTST Pte` — P OA 300 560 - 560 - 560 Notes: 1 well inspected,no exceptions noted. %WED DEC 2 9 2016 Thursday,June 09,2016 Page I of 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN D D n [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA [3 Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy Dianna~ Nathan Lowell Date: ~ -//.~ Is/ TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ Conoc ~ ' ' oPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 17, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • RE'CEIVE~ AUG2~2008 Alaska Oil & Gas Cons, Anchorage Corn~,sz,sion G~~ 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 corrosion inhibitor/sealant was pumped August 2-17, 2008. 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, Perry Kle -- ~ ~ ~ SDt C~ ~ ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off n~•e r 1 Report of Sundry Operations (10-404) Kuparuk Field -" ~/7 //LUUti Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date 2H-05 2H-17 185-168 200-019 ft SF 6" bbls N/A ft SF " N/A al 5.10 8/2/2007 2K-27 201-169 10" N/A 6 " N/A 1.27 8/2/2007 2M-03 191-141 16" N/A 10 " N/A 8.92 8/2/2007 1 B-14 194-030 SF N/A 16 N/A 2.13 8/2/2007 1 B-18 1 B-19 1B-20 194-061 194-064 203-115 9" SF 21" N/A N/A N/A SF 9" SF " N/A N/A N/A 1.70 8.07 5.10 8/13/2008 8/13/2008 8/13/2008 1 B-101 1 B-102 1 Y-05 1Y-07 1Y-17 1Y-22 1Y-26a 1Y-30 1 E-112 1 E-119 1 E-121 203-133 203-122 183-087 183-068 193-068 193-070 188-116 188-090 204-091 204-031 204-246 3" 4" 6" 6" SF SF SF SF 14" 14" 6" N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A 21 3" 4" 6" 6" SF SF SF SF 14" 14" " N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A 5.95 1.00 1.00 1.27 1.27 1.27 2.12 3.83 3.83 5.95 4.67 8/13/2008 8/17/2008 8/17/2008 8/13/2008 8/13/2008 8/13/2008 8/13/2008 8/13/2008 8/13/2008 8/17/2008 8/17/2008 1 E-123 204-074 5" N/A N/A 6 5" N/A N/A 1.00 1.00 8/17/2008 8/17/2008 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSI~JN REPORT OF SUNDRY WELL OPERATI0~1S 1. operations Pertormed: Abandon ^ Repair Well^ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhIIIIpS Alaska, InC. Development ^ Exploratory ^ 191-141 3. Address: Stratigraphic ^ Service ^/ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20160-00 7. KB Elevation (ft): 9. Well Name and Number: 14T ' 2M-03 8. Property Designation: G A L 2 ~.f gfo /~ va 4'3 ' 10. Field/Pool(s): Kuparuk River Unit ! Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7,512 feet true vertical ~ f; 3b9 ~ feet Plugs (measured) Effective Depth measured ~ Cso feet ~ ~ Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 123' 16" 123' SURFACE 3,323' 9 5/8" 3,323' PRODUCTION 7,090' 7" 7,090' ~{ }'~~ may, ¢v y `{ t~ V ~ h/bl~~ u Perforation depth: Measured depth: 7,183'-7,203' 7,214'-7,224' 7,238'-7,278' true vertical depth: 6,037'-6,053' 6,062'-6,071' 6,082'-6,115' Tubing (size, grade, and measured depth) 3 1/2", J-55, 7,090' Packers 8~ SSSV (type & measured depth) otis ~HVT~ retr. - 5,sss~ 12. Stimulation or cement squeeze summary: Intervals treated (measured) /~~q Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service^ Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAGQ GINJ^ WINJ ^ WDSPL^ 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: Contact Perry Klein / M.J. Loveland Printed Name Jon q~7ettdf erry Klein ` Title Well Integrity Project Supervisor Signature - C. Phone: 659-7043 Date 7/24/08 Pre red b Sharon Allsu Drake 263-4612 ~'~~~~I~I~L ~cc~l~- ~ ?a-ds Form 0-404 Revised 04/2006 ~ Submit Origina nl l/~ 2M-03 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 7/13/2008 7/17/2008 7/18/2008 T/I/O = 0/72/O,bleed down WHPs.Removed OA VRplug and installed jewerly for nitrogen purge.Added diesel to OA to bring FL within 30" Of weld BH weld, initial T/I/O = SI/0/0. Rig up and purge N2 across OA & conductor. Put visqueen over well to protect from rain & wind. Make 3 pass weld on starting head connection as per mechanical eng procedure. shut down N2 purge post welding ops. Final T/I/O = SI/0/0. Normal up W/H post BH weld, MITOA-Passed; Reinstall cellar grating, take down visqueen over well, Pre T/I/O = SI/0/0; Removed purge valves, and re-installed VR plugs on opposing sides of OA valve; Replaced all W/H jewelry (IA); Installed 1/2" plugs in Conductor. Pressured up OA with 1 bbls of diesel to 1800 psi, Initial T/I/O = SI/0/1800; 15 min. T/I/0=0/0/1710; 30 min T/I/O = SI/0/1680; Bled down OA; Final T/I/O = SI/0/0. Maunder, Thomas E (DOA} From: Maunder, Thomas E (DOA) Sent: Wednesday, August 06, 200812:49 PM Ta: NSK Welt Integrity Field Supv; 'NSK Problem Weii Supv' Subject: 2M-03 (199-141} All, We received a 404 for "repair work" on this well, however the wark log attached was for 1 E-04 welihead weid. Coutd you piease send in the work log for whatever was done on 2M-03? Aiso, shouid there have been a 404 for 1 E-04? Email is flne. Thanks in advance. Tom Maunder, PE AOGCC 2M-Q3 BH weld 10-404 Page 1 of 1 AIl~under, TMQmas ~ {[~C~/~j From: NSK WQIt lnXegr~ty ~ield Supv jN1~27 a~?~onQCOphiilips.comj Sent: Sunday; August 17, 2008 ~:38 FM To: Maunder, Thomas E (D~P~) Subj~+ct~ ~~lt'f~3 Bf~ uuefd 1~ 4t14 7am, I had sent to you ~ 1~-~fl4 for th~e repair of 2M-03. Found the problem..,, someone had overlaysd and sav~d a custc2m h~ader c~r~ oue fc~rrn th~tt ~lid n~~ s~tQV~ u~ on t~e print screen w~ile Q~'ing hu~ vvc3utd prinfi.. lt was nQt e~augh~, the Er-f~ ~o~ r~cieu~d ~nras i~ fia~t f4r 2M•~3 but shawecf a~ 1~-Q4. i am mail'rng a e~rrected 10=4~ ta~ay,., any questic~ns d~ n~t hesita~ tc~ eal! Thanks! ~~~ }^~~f.r~~ Vile{l tntegrity F'ield ~upenrisa~ E-mail: n1~2~@ ~c~n~c+pPhillip~.~om (so7>s~s-~~os ~' ~~~~~"` ~ r: ~ _ ~~~'~: ~ Miln'iT ~ F ~.. S yJ - T~.~~,. ~~ ~ su~ ,~ ~ ~oos STATE OF ALASKA ~~~~~~ ~~~ ~ ~ ~'; , , +, "w, ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ;. ;,~unt~,y,~~~~~ ~ REPORT OF SUNDRY WELL OPERATIONS "~ ~~a~ ~~~ 1. Operations Performed: Abandon ^ Repair Well ~^- Plug Perforations ~ Stimulate ~ Other ~~`l~g Alter Casing Pull Tubing ^ Perforate New Pooi ~ Waiver ^ Time E~ension ^ W4,~ Change Approved Program Operat. Shutdown^ Perforate ~ ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, If1C. Development ^ Exploratory ^ 191-141 - 3. Address: Stratigraphic ^ Service ~, 6. API Number: P. O. Box 100360, Anchorage, Alaska 99 0 50-103-20160-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: 14T ~ 2M-03 - 8. Property Designation: ~ 10. Field/Pool(s): Kuparuk River Unit Ad~ OO~~ ~,L , Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7,512 . feet true vertical 5,960 ~ feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 123' 16" 123' SURFACE 3,323' ' 9 5/8" " 3,323' ' r~ ~~~~ ~~~~`~"~ PRODUCTION 7,090 7 7,090 '~' " ,,.~~~,~„~,,,.-a6;,~~-~_~ _~.:..~,,. Perforation depth: Measured depth: 7,183'-7,203' 7,214'-7,224' 7,238'-7,278' true vertical depth: 6,037'-6,053' 6,062'-6,071' 6,082'-6,115' Tubing (size, grade, and measured depth) 3 1/2", J-55, 7,090' Packers & SSSV (type & measured depth) Otis'HVr' retr. - 5,939' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection D a Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N!A N/A N/A N/A Subsequentto operation N/A N/A N!A N/A N/A 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Servi ^~ Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG ~^ GINJ^ INJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Numb r or N/A if C.O. Exempt: ~ ~ Contact Perry Klein / M.J. Loveland Printed Name Jon ~Are--n-d-f-o~-r Perry Klein ~~ Title Well Integrity Project Supervisor Signature t, ' ~ ~ ~--_. ~,. Phone: 659-7043 Date 7/24/08 '-'""` """' Pre red b Sharon Allsu Drake 263-4612 ~ G ~ Form 10-404 Revised 04/2006 p~ ~~ ~~ A L Submit Original Only l~ - ~ ,R ~ ~-~ ~~. ~ : a. _ ~1 E- ~, v\ -~~ Q~ C~ C ~"~C.~` DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 7/13/2008 7/17/2008 T/I/O = 0/72/O,bleed down WHPs.Removed OA VRplug and installed jewerly for nitrogen purge.Added diesel to OA to bring FL within 30" Of weld BH weld, initial T/I/O = SI/0/0. Rig up and purge N2 across OA & conductor. Put visqueen over well to protect from rain & wind. Make 3 pass weld on starting head connection as per mechanical eng procedure. shut down N2 purge post welding ops. Final T/I/O = SI/0/0. 7/18/2008 Normal up W/H post BH weld, MITOA-Passed; Reinstall cellar grating, take down visqueen over well, Pre T/I/O = SI/0/0; Removed purge valves, and re-installed VR plugs on opposing sides of OA valve; Replaced all W/H jewelry (IA); Installed 1/2" plugs in Conductor. Pressured up OA with 1 bbls of diesel to 1800 psi, Initial T/I/O = SI/0/1800; 15 min. T/I/0=0/0/1710; 30 min T/I/O = SI/0/1680; Bled down OA; Final T/I/O = SI/0/0. ~®~~~ To: Jim Regg ~, j ~ ~ 7(~l'~% P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 30, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPI-IILLIPS ALASKA INC 2M-03 KUPARUK RIV UNIT 2M-03 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~x-- Comm Well Name: KUPARUK RN UNIT 2M-03 Insp Num: mitJJ0806221214s4 Rel Insp Num: API Well Number: 50-1 03-20 1 60-00-00 permit Number: 191-141-0 Inspector Name: Jeff Jones Inspection Date: 6/22!2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2M-03 Type Inj. ~ G I TVD ; 5939 IA ~ 1040 2700 2640 2620 ~- ~ 1911410 SPT P.T. i I,TypeTest i Test psi '~; i tsoo /, OA I so ~ so i so so Interval 4YRTST P/F P / Tubing i 207s 2075 ~ 207s li 2075 Notes: This well failed an MIT on 6/2/08 and operator rep. Mr. Greenwood indicated that post failure the well was lubricated and bled several times to remove a "bubble". 2.2 BBLS diesel pumped, no exceptions noted. ~~~ ~~~~ au ~ ~ _~ 2008 Monday, June 30, 2008 Page I of 1 2M-03 Failed MITIA Page 1 of 1 • Regg, James B (DOA) - J l`~ ~.- ~~ i From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, June 07, 2008 1:17 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) ~~~ -~~~r 0~ Cc: Loveland, MJ Subject: 2M-03 Failed MITIA Attachments: 2M-03.pdf; 2M-03 TIO plot.png; MIT KRU 2M 06-02-2008.x1s Jim /Tom, Injector 2M-03 (PTD# 191-141) failed an ITIA witnessed by (Jeff Jones) on 06/02/08. The T/I/O prior to the test was 3450/1130/420 and the T/I/O after the test was 3500/1250/440. A file containing the results is attached. The immediate action to be taken is to shut the well in and perform diagnostic testing. Depending on the outcome of the diagnostics, ConocoPhillips will follow up with a 10-403 for repair or a AA request for continued injection. J A 3 month TIO plot and a well schematic are attached. ~~ Russ ~ ~ .~ PWS «2M-03.pdf» «2M-03 TIO plot.png» «MIT KRU 2M 06-02-2008.x1s» 7/31 /2008 KRU 2M-0> PTD 191-141 T/l!O Plot - 2M-0~ 3000 2500 2000 a 1500 1000 500 0 200 150 Q E a~ 100 ~ ~c 0 s U 50 0 01-Apr-08 01-May-08 01-Jun-08 Date • • t' ,~ ~ KRU 2M-03 CanocoPhillps Alaska, Inc. - -- 2M-03 - -- _ - API: SutOd2016000 V~ell T e: - INJ - An le a~ T5: -- - - 35 de m 1185 SSSV Type: TRDP Orig 1/3/1992 Angle @ TD: 34 deg @ 7512 Com letion: sssv (1793-1794, ___ Annular Fluid: Last W/O: Rev Reason: TAG FILL oD:3.5o0) -- Reference Lo Ref Lo Date: Last U date: 1/20/2007 j Last Ta : 7261 TD: 7512 ftKB Last Tag Date: _ 1!18/2007 - Max Hole Angle: -_ _ 41 deg @ 240Q _ Casing String - CONDUCTOR ~ Description T `;ize Top - ~ ~ Bottom ~ TVD Wt ~ - ' Grade ' Thread Gaslift , ~.ONDUt`TUR i) 1r~ Op 1_"1 123 (1_ _50 H--10 andrel/Dummy ~ Casing String -SURFACE (2822 2823, fp j - - Gas Lift 3ndrellDummy Valve 2 (afifis-asfi7, OD:5.540) Gas Lift ~ndrel/Dummy Valve 3 (6223-6224, OD:5.540) Gas Lift andrel/Dummy Valve a (ssss-sss7, OD:5.960) PBR (7049-7050, OD:3.500) PKR (7064-7065, OD:6.151) NIP (7080-7081, OD:3.500) TUBING (0-7090, OD:3.500, ID:2.992) SOS (7089-7090, OD:3.500) Perf (7183-7203) Perf (7274-7224) Perf (7238-7258) Perf (7258-7278) , c~ Descnpuon ToQ Siz~ B atom TVD Wt Grade Thread BUR C r~ ~INr ~ ~ ~- '5 0 - J _ :~ 3 2914 ; -- . _ 6 Ou J- ,5 Casing String -PRODUCT ION Description Size ~_ Top --- Bottom _ TVD _ _ I Wt Grade Thread PP.UD. G~~ING ~ 7 000 ; 0 '503 6305 I 2[;_00 I J-55 Tubing String -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 7090 5960 9.30 J-55 ABM EUE Perforations Summary _ Interval TVD Zone Status Ft SPF Date T e Comment 7183 - 7203 6037 - 6053 C-4 20 4 11/8/1992 IPERF 180 deg. phasing; Oriented 105 de .CCW, 2 1/2" Titan 7214 - 7224 6062 - 6071 A-4 10 4 2/22/1992 IPERF 180 deg. phasing; Oriented 84.25 deg. CCW, 4 1/2" HJ II Cs Gun 7238 - 7278 6082 - 6115 A-3 40 4 2/21/1992 IPERF 180 deg. phasing; Oriented 172 deg. CCW, 4 1/2" HJ II Ccn l:un Gas Lift Mandrels/Valves „i' St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2822 2528 Otis WB DMY 1.0 BK 0.000 0 2/22/1992 2 4886 4157 Otis WB DMY 1.0 BK 0.000 0 2/22/1992 3 6223 5254 Otis WB DMY 1.0 BK 0.000 0 2/22/1992 4 6996 5883 Otis LB DMY 1.5 RM 0.000 0 12/1/1992 -___ Other (plugs, equip., etc.) -COMPLETION Depth I TVD j Tvpe I Description i ID i 1793 1724 SSSV Camco TRDP-4A-RO' Mod 2.812 7080 5952 NIP Camco 'D' Ni le NO GO 2.750 7089 5960 SOS Otis 2.992 7090 5960 TTL 2.992 MElVi®RANDLIM To: Jim Regg ~ ~ j j /~ P.I. Supervisor G ~ 17 FROM: Jeff Jones Petroleum Inspector ~~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June l 1, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-03 KUPARUK RIV UNIT 2M-03 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv .J~'-~ Comm Well Name: KUPARUK RN UNIT 2M-03 Insp Num: mitJJ080610123321 Rel Insp Num: API Well Number: 50-103-20150-00-0o Permit Number: 191-141-0 ~ Inspector Name: Jeff Jones Inspection Date: 6/2/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2M-03Type Inj. I G ~'~1D 5939 v~ IA ~' 1130 ~ 2140 1800 1780 yi' p T. Ivuato TypeTest SPT' Test psi I Isoo~A :; azo szo ~ szo sto Interval 4YRTST Pte, F ,,,~ 3450 i 3450 I _ Tllbing' 3450 3450 ___ NOtes: 5.8 BBLS diesel pumped; pressure loss during MIT > 10% (failed MIT). / ~~7`@6TId~~~ JU~ ~ ~ LUU~ Wednesday, June 11, 2008 Page l of I KRU 2M-03 (PTD 191-141) Report Of Failed MITIA Page 1 of 1 • • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, June 03, 2008 9:56 AM ~~ ~ I5 ~~~U To: Regg, James B (DOA); Maunder, Thomas E (DOA} ~ C Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK ~ Subject: KRU 2M-03 (PTD 191-141) Report Of Failed MITIA Attachments: 2M-03 Wellbore Schematic.pdf; 2M-03 TIO Piot.ppt Jim/Tom, i Kuparuk WAG Injector 2M-03 (PTD 191-141) failedmate witnessed MITIA on 06/02/08. The T/IA/OA prior to the test was 3450/1130/420 and 3500/1250/440 afterwards. CPAI's immediate plan is to convert the well to water injection, confirm the results of the test, and perform diagnostic testing to determine the nature of the failure. «2M-03 Wellbore Schematic.pdf» «2M-03 TIO Plot.ppt» ~% Attached is a Wellbore schematic and 3 month TIO Plot. A complete report of yesterday's testing on DS2M and DS2V will soon follow. Please contact me at your convenience if you have any questions or comments. Martin Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office 907-659-7224 Cel I 907-943-1720 Pager 907-659-7000 #909 ~~~ ,~~~ Y 2~~~ 6/4/2008 SRI- i4l -- IAP 3000 2500 2000 N a 1500 1000 500 0 OAP TII/O Plot - 2M-03 200 150 a E a~ 100 Y O t V 01-Apr-08 01-May-08 5a ~~ 0 01-Jun-08 Date nr-. ` ConocaPhi##ips A[aska, #r>lia. 2M-03 sssv •- (1793-1794, ~' --_ OD:3.500) i ----~ Gas Lift 3ndrel/Dummy Valve 1 (2822-2823, OD:5.540) Gas Lift 3ndrel/Dummy Valve 2 (4886-4887, OD:5.540) Gas Lift 3ndrel/Dummy Valve 3 (6223-6224, OD:5.540) Gas Lift 3ndrel/Dummy Valve 4 (6996-6997, OD:5.960) PBR poas-7oso, OD:3.500) PKR posy-loss, OD:6.151) NIP (7080-7081, OD:3.500) TUBING (0-7090, OD:3.500, ID:2.992) SOS (7089-7090, OD:3.500) Perf (7183-7203) Perf (7214-7224) Perf (7238-7258) API: 501032016000 SSSV Type: TRDP Annular Fluid: KRU 2M-03 Well T e: INJ An le TS: 35 de 71ts5 Orig Com letion: 1/3/1992 Angle @ TD: 34 deg @ 7512 Last W/O: Rev Reason: TAG FILL Ref Loa Date: Last Update: 1!20/2007 Last Ta : 7261 TD: 7512 ftKB Last Tai Date: 1/18!2007 Max Hole Angle: 4i deg @ 2400 _ Casing String -CONDUCTOR _ _ _ _ p ~ _ ~ p ~ m~TVD Descn tinn _ Size T~ Botto _ ) Wt _ ~ Grade_ ~ Thre INDUCTOR 16.000 ~ 1~ '~ w f~J ~i'~ 1140 t Trt .Casing String -SURFACE DPSCripbon Size T~~p Bottom TVD - - Wt 7 _Grade ~__ Threw - -- ~-~_ SUR. CASING t 9.625 !_! 2914 36.00 J-55 r Casing Strin -PRODUCTION - Descr~uon Size Top B uom TVD - r _ Wt Grade ~ .Thre FF~ ~D. CASIt1i3 _ 7.000 w _ U ~' _ 63.05 ~2F 0>D J-55 I _ ' Tubing String -TUBING __ - -- ~_- 5i l Top ~ Bottom TVD Wt Gra eded I Thread ~~~) _ 0 i 7090 5960 9.30 ~ f J 55 ABM EUE - Perforations Summar~_ __ _ T interval TVD Zone Status Ft SPF Date T e Comment 7183 - 7203 6037 - 6053 C-4 20 4 11/8/1992 IPERF 180 deg. phasing; Oriented 105 de .CCW, 2 1/2" Titan 7214 - 7224 6062 - 6071 A-4 10 4 2!22/1992 IPERF 180 deg. phasing; Oriented _ 84.25 deg. CCW, 4 1/2" HJ It Cs Gun 7238 - 7278 6082 - 6115 A-3 40 4 2/21!1992 IPERF 180 deg. phasing; Oriented 172 deg. CCW, 4 1/2" HJ II - - Cs~Gun - Gas Lift Mandrels/Va{ves ~ } St MD --- TVD - _. Man Mfr ~ Man T ype Mfr Type OD atch _ Port RO _ _ Date Run _ Vlv _ Cmnt 1 2822 2528 Otis WB DMY 1.0 BK 0.000 0 2/22/1992 2 4886 4157 Otis WB DMY 1.0 BK 0.000 0 2/22/1992 3 6223 5254 Otis WB DMY 1.0 BK 0.000 0 2/22/1992 4 6996 5883 Otis LB DMY 1.5 RM 0.000 0 12/1/1992 ' . Other lugs, equip., etc.) -COMPLETION De th TVD T e Descri lion _ _ ID 1793 1724 SSSV Camco'TRDP-4A-RO' Mod 2.812 7049 5927 PBR Otis 2.970 7064 5939 PKR Otis'HVT' Retr. 3.250 7080 5952 NIP Camco'D' Ni le NO GO 2.750 7089 5960 SOS Otis 2.992 7090 5960 TTL 2.992 ~i Ped (7258-7278) 01/24/07 Schlulmbepgel' {) î{j{:)1 ~"ð) j l.~ ~ NO. 4121 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ~ll\1\\ 2. 9 Z007 Company: Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 l.II c,. 10; I - J¿¡ I Field: Kuparuk Well CD Job# Log Description Date BL Color 1 C-111 11415647 RST WFL 10/29/06 1 2B-01 11536780 PROD PROFILE 01/04/07 1 2H-11 11539477 PROD PROFILE 01/04/07 1 2B-02 11538781 PROD PROFILE 01/05/07 1 3N-19 11538782 PROD PROFILE 01/06/07 1 2W-06 11538784 PROD PROFILE 01/08/07 1 1C-28 L 1 N/A GLS 01/16/07 1 2M-06 11628958 INJECTION PROFILE 01/20/07 1 1C-117 11628954 INJECTION PROFILE 01/18/07 1 2K-16 11638814 PRODUCTION PROFILE 01/22/07 1 1Y-22 11638815 PRODUCTION PROFILE 01/23/07 1 2N-337 A N/A SBHP SURVEY 01/21/07 1 2M-26 N/A SBHP SURVEY 01/21/07 1 2M-03 N/A INJECTION PROFILE 01/22/07 1 Please sign and return one copy of this transmittal to Beth at the above address orfax to (907) 561-8317. Thank you. . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ~(/, i( "1 f, ?( 04 Emall to:Tom_Maunder@admln.state.ak.us:Bob_Fleckenstein@admln.state.ak.us; and Jlm_Regg@admin.state.~ .us OPERATOR: ConocoPhillips Alaska Inc. FIELD I UNIT I PAD: KRU 2M DATE: 06/28/04 OPERATOR REP: Sauvageau 1 Arend - APC AOGCC REP: Waived Packer Depth Pretest Initial 15 Min. 30 Min. Well 2M-03 Type Inj S T.V.D. 5939 Tubing 2400 2400 2400 2400 Interval 4 P.TD. 1911410 Type Test P Test psi 1500 Casing 1250 1800 1770 1760 P/F P Notes: Well 2M-14 Type Inj G T.V.D. 6025 Tubing 3550 3550 3550 3550 Interval 4 P.T.D. 1920630 Type Test P Test psi 1506 Casing 550 1920 1910 1910 P/F P Notes: Well 2M-16 Type Inj S T.V.D. 5845 Tubing 2300 2300 2300 2300 Interval 4 P.TD. 1910320 Type Test P Test psi 1500 Casing 900 2910 2850 2840 P/F P Notes: Well 2M-17 Type Inj G TV.D. 6005 Tubing 3580 3580 3580 3580 Interval 4 P.TD. 1910180 Type Test P Test psi 1501 Casing 2800 1600 1620 1620 P/F P Notes: Drawdown test due to high IA initial pressure Well 2M-19 Type Inj S TV.D. 5856 Tubing 2000 2000 2000 2000 Interval 4 P.TD. 1911320 Type Test P Test psi 1500 Casing 135 2600 2600 2600 P/F P Notes: Well 2M-23 Type Inj N T.V.D. 1551 Tubing 100 100 100 100 Interval 4 P.T.D. 1910340 Type Test P Test psi 1500 Casing 0 1800 1750 1720 P/F P Notes: Class 2 disposal well. IA & OA common via circ string Well 2M-26 Type Inj G T.V.D. 5971 Tubing 3100 3100 3100 3100 Interval 4 P.TD. 1920550 Type Test P Test psi 1500 Casing 1550 2320 2300 2300 P/F P Notes: Well Type Inj TV.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 05/19/02 2004-0628_MIT _KRU_2M-26.xls 7/1 3/2004 THE MATERIAL UNDER THIS COVER HAS BEEN. MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 E E C:LORIWIFILM. DOC PL E W M A T E R IA L U N D ER THIS MARKER ARCO Alaska, Inc. Peal Office Box 100360 Ar~cho~-age~ A~aska 9951©,-@360 'Yeiephor~e 907 276 1215 May 16, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION WELL ACTION Stimulate '-:~,--,~-,, ,,, 2M-18 Stimulate Stimulate ~ii- li? 2M-19 Stimulate Stimulate ~::!?. ,_~ ?.. 2M-20 Stimulate Stimulate ~.~/.~-.. ~zq 2M-21 Stimulate Stimulate ~-7;z ~qq 2M-22 Stimulate Stimulate ~:i)_-. ~":' 2M-24 Stimulate Stimulate oi~. ,~, 2M-25 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (atch only) FTR051696 (w/o atch) AR3B-6003-93 , ,~,~ ,~- ,~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate X Change approved program _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 114' FSL, 36' FEL, SEC 28, T11N, R8E, UM At top of productive interval 1073' FSL, 1811' FWL, SEC 28, T11N, RSE, UM At effective depth 1107' FSL, 1681' FWL, SEC 28, T11N, RSE, UM At total depth 1119' FSL, 1634' FWL, SEC 28, T11N, RSE, UM 6. Datum elevation (DF or KB) RKB 147 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-03 9. Permit number ql- 10. APl number 50-103-20160 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing L e n g t h Structural Conductor 8 0' Surface 3 2 8 3' Intermediate Production 7 4 6 9' Liner Perforation depth: measured 7238'-7278', 7214'-7224' true vertical 7510' 6307' Plugs (measured) None 7424' Junk (measured) 6 2 3 6' None Size Cemented Measured depth True vertical depth 1 6" 212 Sx AS I 122' 122' 9-5/8" 655 Sx PF E & 3323' 291 3' 550 Sx Class G 7" 195 Sx Class G 7508' 6305' feet feet feet feet 4 SPF, 180° Phasing, Oriented @ 170° CCW High Side 4 SPF 7184'-7204' 4 SPF 6082'-6115' 6062'-6070' 6037'-6053' Tubing (size, grade, and measured depth) 3-1/2" J-55 set at 7090' Packers and SSSV (type and measured depth) ~EC Camco TRDP-4A-RO SSSV @1793', Otis HVT Retrievable Packer @ 7064' ~ IV ~ ~ 13. Stimulation or cement squeeze summary Intervals treated (measured) 7238'-7278' ~' Commission Gas Cons. Treatment description including volumes used and final pressure See Attached SummaryN.~S~ Anchorage 14. Prior to well operation 5/01/92 Subsequent to operation 7/03/92 Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 21 1 407 39 0 1 943 1 557 1 0 5 0 Tubing Pressure 125 163 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector X at present, was oil well when treatment was pumped Oil _ Gas Suspended Service 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~i~¢1~' ~ Title Senior En~lineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE ~1'I-03 06/20/92 GELLED SEAWATER FRAC W/ DS YF140D. PUMPED 215 BBL BREAK- DOWN @ 25 BPM. LAST WHTP = 3670 PSI, ISIP =1433 PSI, FG = .67 PSI/FT, EXCESS FRIC = 557 PSI. PUMPED 240 BBL PAD @ 25 BPM. PUMPED 10.5 MLBs 16/20 CARBOLITE IN 2 PPA STAGE AND 44.3 MLBS 12/18 CARBOLITE IN 4 TO 8 PPA STAGES. SCREENED OUT 72 BBLS INTO 8 PPA STAGE, LAST WHTP = 4275 PSI, PEAK WHTP = 8000 PSI. TOT PROP: DESIGN = 119 MLBS, IN FORM = 39.4 MLBS W/ 6.8 PPA @ PERFS. TOT FLUIDS: WATER = 699 BBLS, ADDS = 55 BBLS. ALL FLUIDS LOOKED GOOD. SMALL LEAK IN 9-5/8" CSG NOTED AT END OF JOB. (PALISCH/ OHMS/ SCHULTZ) PERMIT AOGCC Individual Well Geological Materials Inventory DATA T DATA_PLUS Page~ 1 Date- 01/19/94 SCALE DATE_RECVD 91-14i 91-141 91-141 91-141 CBT L 5800-7362 CDN CDR L 3350-7512, LWD L 3350-7512, LWD USIT(COMPO C&C) L 5800-7400 91-141 407 91-141 91-141 DAILY WELL OP SS DIRECTIONAL 91-141 5161 R COMP DATE: 02/22/92 R 12/27/92-02/23/92 R 0-7510 T 3350-7512,OH-CDR/CDN 2&5 2&5 02/11/92 01/13/92 01/13/92 02/11/92 03/20/92 03/20/92 03/31/92 01/21/92 Are dry ditch samples required? yes ~nd received? Was the well cored? yes/~~nalysis & description received? Are well tests require~ived?/X~// y~ Well is in compliance Initial yes Comments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Abandon Suspend Alter casing _ Repair well Change approved program _ 2. Name of Operator ARCQ Alaska. Inc. 3. AddreSs P. ©. Box 100360, Anchorage, AK 99510 4. Location of well at surface Operation Shutdown Plugging _ Pull tubing _ 5. Type of Well' Development __ Exploratory _ Stratigraphic _ Service X Re-enter suspended well_ Time extension Stimulate Variance Perforate Other 6. Datum elevation (DF or K'B) RKB 147 7. Unit or Property name Kuparuk River Unit 8. Well number feet, 114' FSL, At top of productive interval 1073' FSL, 1811' FWL, SEC 28, T11N, At effective depth 1107' FSL, 1681' FWL, SEC 28, T11N, At total depth 1119' FSL, 1634' FWL, SEC 28, T11N, 36' FEL, SEC 28, T11N, RaE, UM RaE, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 751 0' feet Plugs (measured) 6307' feet None 2M,03 9. Permit number 91-141 / 10. APl number 50-103-20160 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical Casing Length Structural Conductor 8 0' Surface 3 2 8 3' Intermediate Production 74 6 9' Liner Perforation depth: measured 7238'-7278', 7214'-7224' true vertical 6082'-61 1 5' 7424' 6236' Size 16" 9-5/8" ii feet Junk (measured) feet None Cemented Measured depth True vertical depth 212 Sx AS I 1 22' 1 22' 655 Sx PF E & 3323' 291 3' 550 Sx Class G 195 Sx Class G 7508' 6305' 4 SPF, 180° Phasing, Oriented @ 170° CCW High Side 7184'-7204' 6062'-6070' 6037'-6053' Tubing (size, grade, and measured depth) 3-1/2" J-55 set at 7090' Packers and SSSV (type and measured depth) Camco TRDP-4A-RO SSSV @ 1793', Otis HVT Retrievable Packer @ 7064' 13. Stimulation or cement squeeze summary Intervals treated (measured) "None associated with conversion" Treatment description including volumes 'used and final pressure 14. Pressure Prior to well operation Subsequent to operation 15. Attachments 17. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing 0 6080 BWIPD 1958 // 972 16. Status of well classification as: Copies of Logs and Surveys run __ Water Injector .... X Daily Report of Well Operations, Oil _ Gas Suspended I hereby certify that the foregoing is true and correct to the best of my knowledge. J U L - 8 993 &laslm 0il & Gas Cons. 60mmV. Anchorage Service ,., Si~tned Form 10-404 Rev 06/15~88 Date SUBMIT IN DUPLICATE MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: Leigh Griffin ~ Commissioner date: file: November 24, 1992 LOU11181.DOC thru' Blair E Wondzell~/~'~ Sr Petr Engineer from~:~ou Grimaldi Petr Inspector subject: BOP Test-Parker 245 ARCO Well #2M-3 Kuparuk River Unit Permit ~ Wednesday, November 18, 1992: I traveled to the Kuparuk River Unit to witness the weekly BOP Test on Parker Drilling Rig #245 presently drilling ARCO's Well # 2M-3. I found the rig to be in good shape and all equipment tested good with the exception of the annular preventer which failed the high pressure test. This failure is a reminder of a peculiar quirk that annular preventers have, this being that the rubber element develops a sod of memory for the size drill pipe that it is normally closed on and when closed on a smaller pipe there is the possibility of a failure that would not have been evident on the larger pipe. It should be noted that the rig crew performed a very good test and I could find no inconsistencies in procedure. Buford Berry (ARCO Representative) assured me that the annular preventer would be repaired before the rig continued with their program. SUMMARY: I witnessed a good BOP Test on Parker Rig 245 on ARCO's Well 2M-3 in Kru with one failure the annular preventer. Note: Thursday, November 19, 1992, approximately 0300 Darrell Gladden called and informed me that the annular preventer had been repaired and tested "good". Attachment STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOP Test Report DATE OPERATION: Drlg, ~ Wkvr TEST: Initial__ Weekly ~ Other Operator ~ ~C- ~ /~/~ ~tQ~JF Rep ~ ~0 ~ ~ ~~ ~ ._ Rig phone Well ~ ~ -- ~ Permit ~ ~'- ~ ~ Location: Sec~ T///~ R Drlg contrctr ~~~ ~~/~ Rig~ ~ ~'~ Rep csg set ~ ft Location (general) Housekeeping ( genera 1 )~d>o~'~ Ri g~~ Rsrve pit MUD SYSTEMS: Visual Audio Trip tank Flow monitor Gas detectors BOPE STACK: Annul ar preventer Pi pe rams B1 i nd rams Choke line valves HCR valve Kill line valves Check valve Test Pressure //-..- · ,,0,,/,4 ACCUMULATOR SYSTEM: Full charge pressure Press after closure Pump incr clos press 200 psig Full charge press attained N2 C/o ~0 ~-~7~-/~- ~'-~ / ~-~0 ~-~ psig Controls: Master mi n ~7/~--- sec min ~//~- sec psig b~ -%5q'0¢-5 a~ Remote~L-:O~r-> Blind switch cover KELLY AND FLOOR SAFETY VALVES: Upper Kelly Lower Kelly Ball type Inside BOP Choke manifold Number valves Number flanges Adjustable chokes Hydraulically operated choke Test pressure Test pressure Test pressure Test pressure Test .pressure co/d / TEST RESULTS: Failures / Test time d~ hfs Repair or replacement of failed equipment to be made within ~ days. Notify the Inspector, and follow with written/FAXed [276-7542] verification to Commission office. Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 07/92) STATE WITNESS REQUIRED? ye~. no 24-HR NOT, GIVEN? yes no Waived by: AOGCC phone 279-1433 - FAX 276-7542 ARCO Alaska, Inc. Post Office b,.,~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 23, 1992 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 pOrcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate are multiple Application for Sundry Approvals on the folloWing Kuparuk wells. Well Action 2M-03 2M-14 2M-26 Conv. to Wtr. Inj. Conv. to Wtr. Inj. Conv. to Wtr. Inj. Anticipated Start Date November 15, 1992 November 15, 1992 November 15, 1992 If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Engineer Kuparuk Petroleum Engineering S. P. Hoolahan ATO-1226~- P. A. Lindberg ATO-1417 FTR102293 (w/o attachments) (w/o attachments) (w/o attachments) ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany RECEIVED OCT ~ ? 1992 Alaska 0il & Gas Cons. bummissio~ Anchorage ^,:,~ ~,()~:~ (: S A EO.A ASKA 0 RIG I A L ALasKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOIl SUNDRY APPROVALS 1. Type of Request: Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well_ Alter casing _ Repair well Plugging _ Time extension Stimulate Change approved program ~ Pull tubing _ Variance _ Perforate _ Other __ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska, 3. Address P. ©. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ RKB .._ 147 7. Unit or Property name Ku.paruk River Unit .. feet 4. Location of well at surface 114' FSL, 36' FEL, SEC 28, T11N, R8E, UM At top of productive interval 1073' FSL, 1811' FWL, SEC 28, T11N, R8E, UM At effective depth 1107' FSL, 1681' FWL, SEC 28, T11N, R8E, UM At total depth .1..119' FSL.., 1634'.. FWL,..' SEC 28, T..1....1. N, R..8...E, UM.. 12. Present well condition summary Total Depth: measured Plugs (measured) None 751 0' feet true vertical 6307' feet measured 7424' feet true vertical 6 2 3 6' feet Effective depth: Junk (measured) None 8. Well number 2M-0~ 9. Permit number 91-141 10. APl number 50-103-.2_01 60 11. Field/Pool Kuparuk River Field Ku. paruk River. Oil P..ool .. Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 212 SX AS I 1 2 2' 1 2 2' Surface 3283' 9-5/8" 655 Sx PF E & 3323' 291 3' intermediate 550 SX Class G Production 7 4 6 9' 7" 195 Sx Class G 7 5 0 8' 6 3 0 5' Liner Perforation depth: measured 7238'-7278', 4 SPF, 180° Phasing, Oriented @ 170° CCW High Side true vertical I ECEIVED 6082'-6115' Tubing (size, grade, and measured depth) 3-1/2" J-55 set at 7090' Packers and SSSV (type and measured depth) OCT 2 7 1992 Camco TRDP-4A-RO SSSV @ !793', Oti,s HVT R.e!rievab, Ie Packer @ 7064' . Alaska. o/! &. c,~.~ ¢,,nn.~_ ~n_rnmisSi~ 13. Attachments Description summary of proposal X Detailed operation program ~ BO~n~t~f-~. Convert Well From Oil Producer to Water Injector. (Wellbore schematic attached). 14. Estimated date for commencing operation ' 115. siatus of ~vell classification as: November 15. 19,92 , ] Oil _ Gas _ Suspended _ 16. If proposal was verbally approved I Name of approver Date approved ~ Service Water Injector 17. I hereby certify t~s true and correct to the best of my knowledge, S!~lned ¢.M.,~. Title ...Engineer Dato)(::)(/2'~/ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test Location clearance Mechanical integrity Test ~ .Approved by order of the Commission Form 10-403 Rev 09/12/90 -- Subsequent form r--~quire 10-.~-,/~"¢ UR~6~NAL SIGNED BY . ,~s,~ELL,A, DOUG.LASS . Commissioner IApproval No. , , SUBMIT IN TRIPLICATE Well 2M-03 Conversion to Water Injection Service ARCO Alaska requests approval to initially complete Well 2M-03 as a water injection well. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 7184' MDRKB and 7349' MDRKB This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. RE6EIVED OCT ~ ? 1992 Alaska 0il & Gas Cons, (:;ommissio~' Anchorage Drill Site 2M General Procedure for Water Injection Conversions AFC #996572 Downhole Work: K83339 Surface Facilities: K83321 The following general slickline procedure should be utilized for the initial completion of Drill Site 2M Well Nos. 26 and 14, and conversion of Well 2M-03, to water injection service. Well Nos. 26 and 14 have been completed but are unproduced to date. Well No. 3 has been on production since April, 1992. Copies of the individual wellbore schematics are attached for reference. 1. Contact J. B. Kewin (x-6806) to insure that the sundry notice for placing the well in water injection service has been approved by the AOGCC, 2. SI well and MIRU slickline and hot oil pump truck. 3. RIH and set SV in the "D" nipple. Pressure test the tubing/DV's to 1500 psi. 4. RIH and pull the DV out of the bottom 1-1/2" GLM. . Rig up hot oiler to the 3-1/2"x 7" annulus, and reverse circulate the annulus to diesel while taking returns from the tubing. Fill the annulus with diesel to the bottom GLM. Annular capacity is .0264 Bbls/Ft. 6. RIH and reset DV in bottom 1-1/2" GLM. 7. Pressure test the tubing to 2000 psi. 8. RIH and pull the SV. 9. RDMO slickline. Notify the State for witness of the Mechanical Integrity Test. 10. Conduct MIT test. Packer depths and 7" annular pressures required are shown below. Pressures must be held for 30 minutes with no more than a 10% decline. Bleed the annulus to 500 psi after completing each test. Well Packer TVD Depth Req'd Casing Pressure for MIT 2M-14 6025' 1510 psi 2M-26 5970' 1500 psi 2M-03 5938' 1500 psi 11. Initiate water injection and gradually ramp up rate until the WHP reaches 1500 psi. Keep the injection rate constant until KPE can conduct step rate tests on Wells 14 and 26. Once the step rate tests are complete, the wells will be opened up to maximum allocated water rates, or maximum header pressure available (if lower). REEEIVED OCT 2 ? 1992 Alaska Oil & Gas Cons. 6ommissiOO ;Anchorage WELL 2M-03 PRODUCER APl # 5010320160 SURFACE LOCATION: 114' FSL, 36' FEL, SEC. 28, T11N, R8E, UM TOP OF KUPARUK: 1073' FSL, 181 1' FWL, SEC 28, T11N, R8E, UM TD LOCATION: 1119' FSL, 1634' FWL, SEC 28, T11N, R8E, UM DEPTHS: REFERENCED TO 0' RKB ALL DEPTHS MD-RKB TUBING SPOOL RKB=39.00' 16": 62.5# H-40 @ 123' WELL TYPE: PRODUCER 9.625": 36# J-55 @ 3323' OTIS PBR: @ 7049' OTIS HVT PKR: CAMCO D NIPPLE: 2.75" ID @ 7064' @ 7080' OTIS SHROUT: @ 7089' C a_ A4 A3 7": 26# J-55 @ 7508' VOLUME: 0.0383 BBL/FT L SPUD: 12/27/91 COMPLETION' 2/22/92 SSSV · CAMCO TRDP-4A-RO @ 1793' GLMI: GLM2: GLM3: GLM4: 2822'/OTIS WB/1.0"/DV 4886'/OTIS WB/1.0"/DV 6223'/OTIS WB/1.0"/DV 6996'/OTIS LB/1.5"/DV 3.5" 9.3# J-55 ABM-EUE, @ 7090' VOLUME: 0.00870 BBL/FT HOLE ANGLE ACROSS KUPARUK = 34 DEGREES MAX. HOLE ANGLE = 41 DEGREES @ 2390' VOLUME TO TOP PERF = 67 BBLS RE( EIVED 0CT 2 7 1992 Alaska 0il & Gas Cons. 6ommiSs%o[~ Anchorage 7238,.7258, (20,),4 SPF,180° @172° ccw 7258,.7278, (20,),4 SPF, 180° @166° ccw PBTD: 7424' PBTDSS: 6089' LAST TAG DATE: 6/23/92 @ 7380' REVISION' 7/17/92 ARCO Alaska, Inc. Date: March 27, 1992 Transmittal #: 8392 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Records Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~/,,,,./¢.~ 2M-03 ~'/Sub-Surface Directional .//' Survey ?/-- / > '('" 30-01 ,~ f.~t~,~ 30-04 ~ / ~-/->' O/30-03 Sub-Surface Directional Survey Sub-Surface Directional Survey Sub-Surface Directional Survey Receipt Acknowledged: D&M 1 -27-92 92101 1 -31 -92 2-1 -92 1 -31 -92 92112 92113 92114 RECEIVED Date: State of Alaska (2 copies) Alaska 0il & C~as Cons. Commission Anchorage ' ' ' ST^TE O. ^L^S.^0 I{ lC INCA L ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL [~] GAS [~] SUSPENDED r~ ABANDONED [~ SERVICE [-'-1 ,, 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 91-141 3 Address 8 APl Number P,O. Box 100360, Anchorage, AK 99510-0360 50-103-20160 4 Location of well at surface 9 Unit or Lease Name 114' FSL, 36' FEL, SEC 28, T11 N, R8E, UM ' ............. ~ ~ I LC, C~, .q©?.!S~ KUPARUK RIVER At TopProducinglnterval ~ .~ ;~"~% ~ ! ~,i~!) ! 10 Well Number At Total Depth i: .~.~,~...~ .... ~ !i'~ ii' Field and Pool 1119' FSL, 1634' FWL, SEC 28, T11 N, RSE, UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 147', PAD 105' GLI ADL 25586, ALK 2672 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 116 No. of Completions 12/27/91. 12/31/91. 02/22/92.] N A feet MSL] 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 7510' MD, 6307' TVD 7424' MD, 6236' TVD YES [~ NO 1793' feet MD 1400' APPROX 22 Type Electric or Other Logs Run CDR,CDN,GR, USlT, CBT, GYRO 23 CASING, LINER AND CEMENTING RECORD J SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-I-I'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 121' 24" 212 SX ASI 9-5/8" 36# J-55 SURF 3323' 12-1/4" 655 SX PF E, 550 SX CLASS G 66 SX PFC TOP JOB 7" 26# J-55 SURF 7508' 8-1/2" 195 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 (MDI 3-1/2" 7090' 7064' 7238' -7258' W/4-1/2" CSG GUN @ 4 SPF MD 6082'-6099' TVD 7258' -7278' W/4-1/2" CSG GUN @ 4 SPF MD 6099'-6115' TVD 2.,6 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operatiol~ (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28 CORE DATA I~, ~ ~'~ i'~ II % J~ ~_ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. K ~'~ ~ E I V [~ MAR 0 1992 Alaska 0il & Gas Cons. Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GECLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, IVlEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 7184' 6038' NA KUPARUK C Bo'FrOM 7200' 6051' KUPARUK A TOP 7210' 6059' KUPARUK A BO'I-rOM 7349' 6174' 31. LIST OF ATTACHMENTS GYRO, REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S ig ne d __~_,___~__' _~___ _~___/.~ Title AREA DRILLING ENGINEEFI 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 r ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 2M-03 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 25586 ALK 2672 50-103-20160 91-141 ACCEPT: 12/27/91 SPUD: 12/27/91 RELEASE: 01/03/92 OPERATION: DRILLING RIG: POOL 7 AFE: AK6446 WI: 55.252072 12/27/91 ( 1) TD: 121' ( 121) SUPV:KKL 12/28/91 (2) TD: 3180'(3059) SUPV:KKL 12/29/91 (3) TD: 3345'( 165) SUPV:KKL 12/30/91 (4) TD: 3355'( 10) SUPV:KKL 12/31/91 (5) TD: 6965'(3610) SUPV:KKL 01/01/92 ( 6) TD: 7510' ( 545) SUPV:SS 01/02/92 ( 7) TD: 7510'( SUPV:SMS o) 01/03/92 (8) TD: 7508'( SUPV:SMS 0) 01/04/92 (9) TD: 7805' ( 297) SUPV: SMS NU DIVERTER MW: 0.0 VIS: 0 MOVE RIG FROM 2M-13 TO 2M-03. NU DIVERTER. DAILY:S42,476 CUM:$42,476 ETD:SO EFC: $1,242,476 DRLG AT 3180 MW: 9.1 VIS: 48 PU BHA. DRLD 90'-2610'. LOST RETURNS. POH 90' AND WORK DP. REGAINED RETURNS. DRLD 2590'-3180'. DAILY:S66,730 CUM:$109,206 ETD:SO EFC:$1,309,206 CMTG 9-5/8" CSG 9-5/8"@ 3323' MW: 9.3 VIS: 50 DRLD 3180-3345' SHORT TRIP. CIRC. POH. RAN 9-5/8" CSG. DAILY:S95,109 CUM:$204,315 ETD:SO EFC: $1,404,315 PERFORM EMW TEST 9-5/8"@ 3323' MW: 0.0 VIS: 0 CMTD 9-5/8" CSG. DID TOP JOB. MU BRADENHEAD. NU BOP & TEST. PU BHA. DRLD CMT. TEST CSG TO 2000 PSI. DRLD 10' NEW HOLE. PERFORM FORMATION TEST TO 12.5 PPG. DAILY:S129,090 CUM:$333,405 ETD:SO EFC:$1,533,405 DRLG DRLD 3355'-6965. 9-5/8"@ 3323' MW:10.1 VIS: 38 DAILY:S74,824 CUM:$408,229 ETD:SO EFC:$1,608,229 RU SWS FOR USIT 9-5/8"@ 3323' MW:10.3 VIS: 38 DRLD 6956'-7510'. CIRC. POH FOR CSG INSP LOG. DAILY:S72,203 CUM:$480,432 ETD:SO EFC:$1,680,432 WOC 7"@ 7508' MW:10.3 VIS: 41 RAN USIT CSG INSP LOG. RIH. CIRC. POH. RAN 7" CSG. CIRC. DAILY:S52,133 CUM:$532,565 ETD:SO EFC:$1,732,565 LD DP 7"@ 7508' MW: 0.0 VIS: 0 CMTD 7" CSG. ND BOP. SET SLIPS. INSTALLED TBG HEAD. LD DP. DAILY:S307,697 CUM:$840,262 ETD:SO EFC:$2,040,262 LD DP 7"@ 7508' MW: 0.0 VIS: 0 LD DP. RLSED RIG 0630 1/3/92. DAILY:S994 CUM:$841,256 ETD:SO EFC:$2,041,25 DRILLING S~R~ NTENDE~__~ RECEIVED MAR 0 ' 992 Alaska Oil & 6as Cons. 6ommissio~ ..,/./.., A...chora?. DATE'~/ / 7/ % ~ / ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 2M-03 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 25586 ALK 2672 50-103-20160 91-141 ACCEPT: 02/21/92 SPUD: RELEASE: 02/22/92 OPERATION: COMPLETION RIG: NORDIC AFE: AK6446 WI: 55.252072 02/22/92 (10) TD: 7805 PB: 7422 SUPV:DB/TB ND BOPE 7"@ 7508' MW:10.4 NaC1/Br ACCEPT RIG AT 0600 HRS 2/22/92,ND TREE NU BOPE, TEST SAME TO 3K PSI,OK, RU SWS, PERF 7238-7278' @ 4 SPF, 180 DEG PHS ORIENTED,POH,ASF,RD SWS,RU TO RUN COMP, LOAD,DRIFT, STRP TALLY TUBING AND JEWELRY WHILE PERF, RIH W/3-1/2" SINGLE COMP AS PER PROC,MU SSSV/C-LINE, TEST TO 5K PSI,OK, CRIH,MU HGR/C-LINE,TEST TO 5K PSI OK, RAN 33 SS C-LINE BANDS,LAND HGR RILDS,PRESS TBG IN 500 PSI INCREMENTS F/500 TO 3000 PSI TO SET OTIS PACKER, HOLD F/5 MIN AT EACH PRESS,BLEED TBG TO 1800PSI BOLDS,PU TO 90K# AND SHEAR PBR, RELAND TBG, RILDS PRESS ANN AND TBG TO 1000 PSI, CLOSE SSSV, BLEED TBG TO 500 PSI AND TEST SSSV F/15 MIN, OK, OPEN SSSV,PRESS ANN AND TBG TO 2500 PSI F/15 MIN, OK, PRESS TBG TO 3750 PSI AND SHEAR SOS,SET BPV, ND BOPE DAILY:S71,842 CUM:$913,098 ETD:SO EFC:$2,113,09 02/23/92 (11) TD: 7805 PB: 7422 SUPV:DB/TB RIG RELEASED 7"@ 7508' MW:10.4 NaC1/Br NU TREE,TEST PACKOFF TO 5K PSI,OK, TEST TREE TO 250/5000 PSI OK, REV CIRC 12 BBL DIESEL DN ANN, BULLHEAD 4 BBLS DIESEL DN TBG, SECURE WELL, RD LINES,RELEASE RIG, SITP=200,SICP=0,MOVE TO 2M-10 DAILY:S129,283 CUM:$1,042,381 ETD:SO EFC:$2,242,381 DRILLING S~E~INTENDEN~ RECEIV D Alaska Oil & Gas Oons. Corem~,ss~°~ Anchorage ORIGIN A L ,ICIIOFILME SUB - S URFA CE DIRECTIONAL SURVEY r-~ UIDANCE ~'! ONTINUOUS I'~ OOL RECEIVED MAR 3 1 1992 Alaska Oil .& ~Gas Cons. ;~o. al~. ,Ancher~ Company ARCO ALASKA, INC. Well Name 2M-3(114'FSL,36'FEL,SEC 28,TllN,RBE) Field/Location KUPARUK RIVER, NORTH SLOPE, ALASKA Job Reference No. 92101 Loqaed BV: D. WARNER/M. CHENEVEY Date 27-JAN-1992 Computed By; R. KRUWELL GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 2M - 03 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE: 27-JAN-1992 ENGINEER: D. WARNER/M CHENEVEY METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- Average~ deviation and azimuth INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 73 DEG 25 MIN WEST COMPUTATION DATE: 27-FEB-92 PAGE 1 ARCO ALASKA, INC. ~ DATE OF SURVEY: 27-JAN-1992 2M - 03 KELLY BUSHING ELEVATION: 1~'6.00 FT KUPARUK RIVER NORTH SLOPE, ALASKA ENGINEER: D.' WARNER/M ... INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH .~. ~' .... TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 0.00 -146.00 0 0 N 0 0 E 100 O0 100.00 -46.00 0 19 N 75 17 E 200 O0 200.00 54.00 0 21 N 66 28 E 300 O0 300.00 154.00 0 19 N 85 16 E 400 O0 399.99 253.99 0 22 N 85 30 E 500 O0 499.99 353.99 0 19 N 85 43 E 600 O0 599.99 453.99 0 5 S 1 38 E 700.00 699.87 553.87 4 22 N 76 52 ~ 800.00 799.49 653.49 6 5 N 76 12 W 900.00 896.67 752.67 8 2! N 74 20 W FEET DEG/IO0 FEET FEET 0.00 -0.16 -0.70 -1.13 -1.71 -2.29 -2.56 1.51 10.19 22.95 1000.00 997.20 851.20 ll 3 N 72 19 ~ 39.92 1100.00 1095.09 949.09 12 27 N 70'40 W 60.33 1200.00 1192.42 1046.42 14 19 N 70 8 W 83.22 1300.00 1288.44 1142.44 18 19 N 69 52 W 111.02 1400.00 1382.19 1236.19 22 19 N 70 19 W 145.69 1500.00 1473.61 1327.61 25 20 N 70 58 W 186.13 1600.00 1562.27 1416.27 29 59 N 72 44 W 232.29 1700.00 1647.28 1501.28 33 5 N 74 59 W 284.91 1800.00 1729.65 1583.65 36 0 N 76 15 W 341.53 1900.00 1810.55 1664.55 35 31 N 74 53 W 400.27 2000.00 1892.23 1746.23 35 21 N 74 23 W 457.95 2100.00 1972.68 1826.68 37 45 N 73 0 W 517.33 2200.00 2051.06 1905.06 39 1 N 72 45 W 579.43 2300.00 2127.69 1981.69 40 36 N 75 27 W 643.66 2400.00 2203.51 2057.51 40 45 N 75 22 W 708.81 2500.00 2279.40 2133.40 40 26 N 74 42 W 773.91 2600.00 2355.88 2209,88 39 53 N 74 29 W 838.32 2700.00 2432.94 2286.94 39 18 N 74 8 W 902.04 2800.00 2510.39 2364.39 39 17 N 73 52 W 965.30 2900.00 2587.66 2441.66 39 30 N 73 25 W 1028.77 3000.00 2664.70 2518.70 39 44 N 73 12 W 1092.53 3100.00 2741.57 2595.57 39 43 N 72 55 W 1156.49 3200.00 2818.60 2672.60 39 36 N 72 25 W 1220.26 3300.00 2895.67 2749.67 39 25 N 72 30 W 1283.96 3400.00 2972.98 2826.98 39 27 N 72 54 W 1347 39 3500.00 3050.17 2904.17 39 31 N 72 50 W 1410 95 3600.00 3127.23 2981.23 39 41 N 72 34 W 1474 68 3700.00 3204.10 3058.10 39 48 N 72 30 W 1538 63 3800.00 3281.02 3135.02 39 28 N 72 56 W 1602 52 3900.00 3359.24 3213.24 37 58 N 74 7 W 1664 82 0 O0 017 0 O0 0 17 0 O0 012 0 78 1 O1 4 36 2 4O 1.85 1.29 2.88 4.41 3.84 2.98 4.74 2.96 1.69 2.27 0.77 2.53 2.20 ] .05 0.54 0.54 0.50 0.54 0.39 0.30 0.22 0.49 0.32 0 72 0 17 0 26 0 35 0 15 1 49 0 25 0 O0 N 0 03 N 0 23 N 0 39 N 0 43 N 0 48N 0 47 N I 44 N 3 43 N 0 O0 E 0 17 E 0 1 1 2 2 1 9 FEET DEG MIN 0.00 N O' 0 E O. 18 N 79 58 E 80 E 0.83 N 73 38 E 30 E 1.36 N; 73. 5 E 92 E 1.96 N 77 17 E 53 E 2.57 ¢J"7.9 14 E 8z; E 2.88 hi...80 31 E 15 Vt' 1.84 'N 38 34 w 61 Vt' 10.21 N' 70 21 W 6.72 N 21 95 Vt 22.95 N 72 59 W 11.61 N 38.19 W 39.92 N 73 6 W 18.10 N 57.56 W 60.34 N 72 33 W 25.83 N 79.14 W 83.25 N 71 55 W 35.35 N 105.31 W 111.08 N 71 27 W 47.18 N 137.96 W 145.81 N 71 7 W 60.65 N 176.15 W 186.29 N 71 0 W 75.05 N 220.02 W 232.47 N 71 10 W 89.81 N 270.53 W 285.05 N 71 38 W 103.~7 N 325.54 W 341.59 N 72 22 W 118.16 N 382.46 W 400.29 N 72 50 W 133.56 N 438.05 W 457.96 N 73 3 W 150.13 N 495.07 W 517.33 N 73 8 W 168.65 N 554 35 W 579.44 N 73 5 W 186.21 N 616 14 W 643.66 N 73 11 W 202.48 N 679 28 W 708.81 N 73 24 W 219.33 N 742 18 W 773.91 N 73 32 W 236.49 N 804 28 W 838.33 N 73 37 W 253.71 N 865 63 W 902.05 N 73 40 W 271.1'5 N 926.45 W 965.31 N 73 41 W 289.07 N 987.34 W 1028.78 N 73 41 W 307.41 N 1048.40 W 1092.54 N 73 39 W 326.03 N 1109.59 W 1156.50 N 73 38 W 345.04 N 1170.46 W 1220.26 N 73 35 W 364.32 N 1231.19 W 1283.96 N 73 31 W 383.16 N 1291.76 W 1347.39 N 73 29 W 401.88 N 1352.51 W 1410.96 N 73 27 W 420.84 N 1413.35 W 1474.68 N 73 25 W 440.08 N 1474.35 W 1538.63 N 73 23 W 459.14 N 1535.34 W 1602.52 N 73 21 W 476.67 N 1595.12 W 1664.82 N 73 22 W COMPUTATION DATE: 27-FEB-92 PAGE 2 ARCO ALASKA, INC. 2~ - 03 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 27-JAN-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: D. WARNER/M INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MXN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 4000.00 3438 12 3292.12 37 53 4100.00 3517 15 3371.15 37 30 4200 O0 3597 53 3451.53 35 35 4300 O0 3678 92 3532.92 35 29 4400 O0 3760 42 3614.42 35 20 4500 00 3842 04 3696.04 35 16 4600 00 3923.6~ 3777.68 35 18 4700 O0 4005.23 3859.23 35 28 4800 O0 4086.61 3940.6~ 35 33 4900 O0 4168.03 4022.03 35 25 N 73 51 w 1726 28 N 73 40 W 1787 N 74 53 W 1847 N 74 49 W 1905 N 74 53 W 1963 N 74 50 W 2020 N 74 47 W 2078 N 74 46 W 2136 N 74 56 W 2194 N 74 57 W 2252 55 02 11 03 79 53 39 48 53 0 15 1 56 0 33 O 12 012 0 06 0 10 0 21 0 18 0 10 493.61 N 1654 20 W 1726.28 N 73 23 W 5~0.80 N 1713 526.96 N 1770 542.16 N 1826 557.30 N 1882 572.42 N 1938 587.55 N 1993 602.77 N 2049 617.98 N 2105 633.05 N 2161 02 W 1787.55 N 73 24 W 26 W 1847.02 N 73 25 W 33 W 1905.11 N 73 28 W 27 W 1963.04 N 73 30 W 03 W 2020.80 N 73 33 W 77 W 2078.54 N 73 35 W 60 W 2136.40 N 73 37 W 69 W 2194.50 N 73 39 ~' 77 W 2252.55 N 73 41 W 5000.00 4249.53 4103.53 35 21 5100.00 4331.19 4185.19 35 9 5200.00 4413.04 4267.04 34 59 5300.00 4495.02 4349.02 34 52 5400.00 4577.14 4431.14 34 46 5500.00 4659.20 4513.20 34 59 5600.00 4740.97 4594.97 35 20 5700.00 4822.59 4676.59 35 12 5800.00 4904.74 4758.74 34 22 5900.00 4987.58 4841.58 33 48 N 74 51 W 23t0.45 N 74 50 W 2368.16 N 74 49 W 2425.58 N 74 45 W 2482.84 N 74 43 W 2539.88 N 74 48 W 2597.01 N 75 12 W 2654.56 N 75 42 W 2712.31 N 75 56 W 2769.27 N 76 39 W 2825.21 0.13 0.20 0.05 0.28 0.25 0.39 0.75 0.55 0.63 0.78 648.16 N 2217 70 W 2310.48 N 73 42 W 663.25 N 2273 678 30 N 2328 693 34 N 2384 708 35 N 2439 723 37 N 2494 738 34 N 2549 752 83 N 2605 766 83 N 2661 780 17 N 2715 42 W 2368.19 N 73 44 W 86 W 2425.63 N 73 46 W 12 W 2482.89 N 73 47 W 16 W 2539.94 N 73 48 W 31 W 2597.08 N 73 50 W 90 W 2654.64 N 73 51 W 83 W 2712.40 N 73 53 W 10 W 2769.38 N 73 56 W 50 W 2825.35 N 73 58 W 6000 O0 5070.87 4924.87 33 24 6100 O0 5153.84 5007.84 34 45 6200 O0 5235.54 5089 54 35 29 6300 O0 5316.69 5170 69 35 57 6400 O0 5397.74 5251 74 35 46 6500 O0 5478.89 5332 89 35 46 6600 O0 5560.08 5414 08 35 39 6700.00 5641.43 5495 43 35 29 6800.00 5722.89 5576.89 35 28 6900.00 5804.41 5658.41 35 12 N 77 17 W 2880.44 N 76 53 W 2936.14 N 76 21W 2993.70 N 74 49 W 3052.10 N 74 57 W 3110.67 N 75 19 W 3169.08 N 75 35 W 3227.42 N 75 52 W 3285.53 N 76 28 W 3343.47 N 76 43 W 3401.29 041 201 1 30 0 16 0 27 031 016 031 0 15 0 53 792.62 N 2769.42 W 2880.61 N 74 2 W 804.98 N 2823.85 W 2936.34 N 74 5 W 818.29 N 2879.95 W 2993.95 N 74 8 W 833.10 N 2936.47 W 3052.36 N 74 10 W 848.42 N 2993.02 W 3110.94 N 74 10 W 863.43 N 3049.49 W 3169.37 N 74 11 W 878.08 N 3106.00 W 3227.74 N 74 13 W 892.45 N 3162.36 W 3285.87 N 74 14 W 906.32 N 3218.68 W 3343.85 N 74 16 W 919.76 N 3275.01 W 3401.72 N 74 19 W 7000.00 5886.28 5740.28 34 52 N 76 24 W 3458.63 7100.00 5968.34 5822.34 34 50 N 75 34 W 3515.71 7200.00 6050.57 5904.57 34 32 N 74 46 W 3572.59 7300.00 6133.14 5987.14 34 5 N 75 41 W 3628.98 7400.00 6215.94 6069.94 34 13 N 75 42 W 3685.03 7500.00 6298.63 6152.63 34 13 N 75 42 W 3741.21 7510.00 6306.90 6160.90 34 13 N 75 42 W 3746.82 0.56 0.70 0.46 1.13 0.00 0.00 0.00 933.05 N 3330.88 W 3459.09 N 74 21 W 946.89 N 3386.32 W 3516.21 N 74 23 W 961.51 N 3441.31 W 3573.11 N 74 23 W 976.10 N 3495,80 W 3629.52 N 74 24 W 989.82 N 3550.20 W 3685.60 N 74 25 W 1003.71 N 3604.68 W 3741.81 N 74 26 W 1005.10 N 3610.13 W 3747.43 N 74 27 W COMPUTATION DATE: 27-FEB-g2 PAGE 3 ARCO ALASKA, INC. 2M - 03 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 27-JAN-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: D. WARNER/M INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4OOO 5000 6000 700O 7510 0.00 -146.00 0 0 N 0 0 E 0.00 O0 997 20 851.20 11 3 N 72 19 W 39.92 O0 1892 23 1746.23 35 21 N 74 23 W 457.95 O0 2664 70 ~ 2518.70 39 44 N 73 12 W 1092.53 O0 3438 12 3292.12 37 53 N 73 51 W 1726.28 O0 4249 53 4103.53 35 21 N 74 51 W 2310.45 O0 5070 B7 4924.87 33 24 N 77 17 W 2880.44 O0 5886.28 5740.2E 34 52 N 76 24 W 3458,63 O0 6306.90 6160.9[! 34 13 N 75 42 W 3746.82 0.00 1 .85 0.77 0 22 0 15 013 041 0 56 0 0 O0 N 11 133 307 493 648 792 933 OC 1005 0.00 E 61N 38.19 W 39 56 N 438.05 W 457 41 N 1048.40 W 1092 61 N 1654,20 W 1726 16 N 2217.70 W 2310 62 N 2769.42 W 2880 05 N 3330.88 W 3459 10 N 3610.13 W 3747 0 O0 N 0 0 E 92 N 73 6 W 96 N 73 3 W 54 N 73 39 W 28 N 73 23 W 48 N 73 42 W 61 N 74 2 W O~ N 74 21 V~ 43 N 74 27 W COMPUTATION DATE: 27-FEB-92 PAGE 4 ARCO ALASKA, INC. 2M - 03 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 27-JAN-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER; D. WARNER/M INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 0.00 0.00 -146.00 0 0 N 0 0 E 146.00 146.00 0.00 0 24 N 73 45 E 246.00 246.00 100.00 0 17 N 69 2 E 346.00 346 O0 200.00 0 21 N 87 33 E 446,01 446 O0 300.00 0 22 N 85 2 E 546.01 546 O0 400.00 0 14 N 89 40 E 646.02 646 O0 500.00 2 18 N 74 57 W 746.27 746 O0 600.00 4 50 N 76 50 W 846.84 846 O0 700.00 7 16 N 75 11 W 947.92 946 O0 800.00 9 45 N 73 23 4' 0 O0 -0 40 -0 89 -1 39 -1 98 -2 50 -1 84 5 20 15 72 30 4,; 0 O0 011 0 O0 0 O0 0 O0 0 52 6 67 1 68 1 79 3 56 0 O0 N 0 11 N 0 34 N 041 N 0 46 N 0 49 N 0651', 2 27 N 4.61 N 14.97 W 15 8.80 !',; 29.14 W 30 0.00 E 0.45 E 1.03 E 1.57 E 2.21E 2.75 E 2.11 E 4.74 W 0 O0 N 0 0 E 0 47 N 76 39 E 1 08 N 71 53 E 1 62 N 75 23 E 2 25 N 78 18 E 2 80 N 79 49 E 2 21 N 72 51E 5 26 N 64 23 W 72 N 72 ~ ~ 44 h 7~ 12 ~ 1049.78 1046.00 900 O0 11 49 N 71 32 W 49.76 1152.21 1146.00 1000 O0 13 12 N 70 14 W 71.90 1255.55 1246.00 1100 O0 16 19 N 70 1 W 97.84 1361.10 1346.00 1200 O0 20 47 N 70 9 W 131.45 1469.55 1446.00 1300 O0 24 28 N 70 40 W 173.31 1581.31 1546.00 1400 O0 29 3 N 72 24 W 223.09 1698.47 1646.00 1500.00 33 3 N 74 56 W 284.08 1820.23 1746.00 1600.00 36 9 N 75 57 W 353.44 1943.42 1846.00 1700.00 35 7 N 74 29 W 425.34 2066.46 1946.00 1800.00 36 49 N 73 37 W 497.00 1 ,30 1 .72 4.33 3.98 2.74 5.39 2.92 1 .33 0.54 3.40 14.67 h 47 57 W 49.78 N 72 52 W 21.98 N 68 30.82 N 92 42.35 N 124 56.43 N 164 72.29 N 211 89.59 N 269 106.35 N 337 124.80 N 406 144.29 N 475 47 W 71.91 N 72 12 W 91 W 97.88 N 71 39 W 54 W 131.55 N 71 13 W 02 W 173.46 N 71 1 W 24 W 223.27 N 71 6 W 73 W 284.22 N 71 38 W 10 W 353.48 N 72 29 W 63 W 425.35 N 72 56 W 60 W 497.01 N 73 7 W 2193.48 2046.00 1900 O0 38 52 N 72 37 W 575.31 2324.13 2146.00 2000 2456.05 2246.00 2100 2587.12 2346.00 2200 2716.87 2446.00 2300 2846.05 2546.00 2400 2975.70 2646.00 2500 3105.76 2746.00 2600 3235.58 2846.00 2700 3365.09 2946.00 2800 O0 40 39 N 75 41 W 659.35 O0 40 38 N 74 56 W 745.35 O0 39 56 N 74 30 W 830.06 O0 39 13 N 74 4 W 912.73 OO 39 23 N 73 37 W 994.49 O0 39 40 N 73 14 W 1077.01 O0 39 42 N 72 54 W 1160.17 O0 39 39 N 72 20 W 1242.95 O0 39 21 N 72 50 W 1325.23 1 .87 0 29 0 64 0 26 0 33 0 42 0 28 0 56 0 02 0 45 167.44 N 550.41 W 575.32 N 73 5 W 190.14 N 631.35 W 659.36 N 73 14 W 211.85 N 714.61 W 745 35 N 73 29 W 234.28 N 796.32 W 830 06 N 73 36 W 256.63 N 875.91 W 912 73 N 73 40 W 279.33 N 954.47 W 994 51 N 73 41 W 302.93 N 1033.54 W 1077 02 N 73 40 W 327.11 N 1113.11 W 1160 18 N 73 37 W 351.91 N 1192.09 W 1242 95 N 73 33 W 376.63 N 1270.59 W 1325 24 N 73 29 W 3494.60 3046.00 2900.00 39 30 N 72 51 W 1407.52 3624.40 3146.00 3000.00 39 44 N 72 31 W 1490.27 3754.53 3246.00 3100.00 39 46 N 72 37 W 1573.53 3883.20 3346.00 3200.00 38 0 N 74 6 W 1654.49 4009.98 3446.00 3300 O0 37 53 N 73 50 W 1732.41 4136.18 3546.00 3400 O0 36 46 N 74 3 W 1809.38 4259.56 3646.00 3500 O0 35 31 N 74 49 W 1881.63 4382.31 3746.00 3600 O0 35 22 N 74 53 W 1952.80 4504.85 3846.00 3700 O0 35 15 N 74 50 W 2023.59 4627.35 3946.00 3800 O0 35 19 N 74 44 W 2094.33 0.23 0.18 0.22 0.35 0 17 2 86 0 16 016 0 06' 0 05 400.86 N 1349.23 W 1407.52 N 73 27 W 425.53 N 1428.23 W 1490.27 N 73 25 W 450.55 N 1507.65 W 1573.53 N 73 22 W 473.84 N 1585.18 W 1654.49 N 73 21 W 495.32 N 1660.09 W 1732.41 N 73 23 W 516.87 N 1733.99 W 1809.38 N 73 24 W 536.01 N 1803.67 W 1881.63 N 73 27 W 554.63 N 1872.39 W 1952.80 N 73 30 W 573.16 N 1940.73 W 2023.60 N 73 33 W 591.70 N 2009.02 W 2094.34 N 73 35 W COMPUTATION DATE: 27-FEB-92 PAGE 5 ARCO ALASKA, INC. 2M - 03 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 27-JAN-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: D. WARNER/M INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET. DEG MIN 4750 08 4046.00 3900.00 35 33 4872 96 4146.00 4000.00 35 28 4995 67 4246.00 4100.00 35 22 5118 11 4346 O0 4200.00 35 7 5240 22 4446 O0 4300.00 34 58 5362 09 4546 O0 4400.00 34 45 5483.89 4646 O0 4500.00 34 55 5606.17 4746 O0 4600.00 35 20 5728.60 484E O0 4700.00 34 58 5849.90 4946.00 4800.00 34 2 N 74 49 W 2165.47 N 74 59 W 2236.85 N 74 51 W 2307.94 N 74 50 W 2378.57 N 74 47 W 2448.63 N 74 46 W 2518.27 N 74 47 W 2587.78 N 75 14 W 2658.13 N 75 45 W 2728.72 N 76 11 ~ 2797.30 0.17 0.31 628.98 N 2146 0.15 647.50 N 2215 0.16 665.98 N 2283 0.00 684.35 N 2351 0.27 702.66 h 2418 0.34 720.95 N 2485 0.7~ 739.25 N 2553 1.0~ 756.88 N 262; 0.82 773.60 N 2686 610.41 N 2077 67 W 2165.49 N 73 38 W 62 W 2236.87 N 73 40 W 28 W 2307.97 N 73 42 W 48 W 2378.61 N 73 44 W 10 W 2448.68 N 73 46 W 32 W 2518.33 N 73 48 W 40 W 2587.85 N 73 49 W 35 ~' 2658.27 N 73 5~ W 75 W 2728.E~ N 73 54 W 33 W 2797.42 N 73 57 ~ 5970.19 5046.00 4900.00 33 29 6090.46 5146.00 5000.00 34 34 6212.85 5246.00 5100.00 35 33 6336.19 5346.00 5200.00 35 54 6459.47 5446.00 5300.00 35 45 6582.67 5546.00 5400.00 35 41 6705.62 5646.00 5500.00 35 28 6828.38 5746.00 5600.00 35 28 6950.85 5846.00 5700.00 35 3 7072.78 5946.00 5800.00 34 52 N 77 8 ~ 2864.05 N 76 58 W 2930.71 N 76 0 W 3001.17 N 74 49 W 3073.33 N 75 10 W 3145.40 N 75 33 W 3217.32 N 75 53 W 3288.79 N 76 32 W 3359.90 N 76 39 W 3430.50 N 75 50 W 3500.17 0.77 2.57 1..72 0.36 0.22 0.18 0.33 0.30 0.32 0.41 788.98 N 2753.40 W 2864.21 N 74 1 W 803.75 N 2818.55 W 2930.91 N 74 5 W 820.09 N 2887.20 W 3001.42 N 74 9 W 838.67 N 2956.96 W 3073.60 N 74 10 W 857.39 N 3026 59 W 3145.69 N 74 11 W 875.56 N 3096 22 W 3217.63 N 74 13 W 893.25 N 3165 52 W 3289.13 N 74 15 W 910.17 N 3234 68 .W 3360.29 N 74 17 W 926.49 N 3303 48 W 3430.94 N 74 20 W 943.04 N 3371 25 W 3500.67 N 74 22 W 7194.45 6046.00 5900.00 34 33 7315.52 6146.00 6000.00 34 3 7436.35 6246.00 6100.00 34 13 7510.00 6306,90 6160,90 34 13 N 74 47 W 3569.45 N 75 54 W 3637.67 N 75 42 W 3705.45 N 75 42 W 3746.82 0.54 0.59 0.00 0.00 960.68 N 3438.28 W 3569.97 N 74 23 W 978.24 N 3504.23 W 3638.21 N 74 24'W 994.87 N 3570.00 W 3706.04 N 74 26 W 1005.10 N 3610.13 W 3747.43 N 74 27 W COMPUTATZON DATE: 27-FEB-g2 PAGE 6 ARCO ALASKA, INC. 2M - 03 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READ[NG GCT PBTD 7" CASING TD DATE OF SURVEY: 27-JAN-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: D. WARNER/M INTERPOLATED VALUES FOR CHOSEN HOR[ZONS SURFACE LOCATION = 114' FSL & 36' FEL, SEC28 TllN RBE UM MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3323.00 2913.44 7184.00 6037.39 7200.00 6050.57 7210.00 6058.81 7349.00 6173.74 7372.34 6193.07 7424.00 6235.7& 7508.00 6305.25 7510.00 6306.90 2767.44 5891.39 5904.57 5912.81 6027.74 6047.07 6089.78 6159.25 6160.90 368.70 N 1245.11 959.13 N 3432.56 961.51 N 3441.31 963.00 N 3446.78 982.80 N 3522.41 986.00 N 3535.10 993.15 N 3563.27 1004.82 N 3609.04 1005.10 N 3610.13 ARCO ALASKA, INC. 2M - 03 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GC~ PBTD 7" CASING TD COMPUTATION DATE: 27-FEB-92 PAGE 7 DATE OF suRVEy: 27-JAN-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: D. WARNER/M SURFACE LOCATION = 114' FSL & 36' FEL, SEC28 T11N RBE UM MEASURED DEPTH BELOW KB 3323.00 7184.00 7200.00 7210.00 7349.00 7372.34 7424.00 7508.00 7510.0C TVD FROM KB SUB-SEA 2913 44 6037 39 6050 57 6058 81 6173 74 6193 07 6235 76 6305 25 6306 9C 2767 44 5891 39 5904 57 5912 81 6027 74 6O47 O7 6089 76 6159 25 6160 go RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 368 70 N 959 13 N 961 51N 963 O0 N 982 80 N 986 O0 N 993 15 N 1004 82 K 1005 10 N 1245 11W 3432 56 W 3441 31 W 3446 78 W 3522 41W 3535 10 ~ 3563 27 w 3609 04 ~ 3610 13 ~ FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 7510.00 6306.90 6160.90 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 3747.43 N 74 27 W DIRECTIONAL SURVEY COMPANY FIELD WIn. L, ARCO AL.ASKA, INC. KUPARUK RIVER 2M - 03 COUNTRY USA mJN ONE DAT! LO(MilD 22 ~ UNIT I=B~T .IFININCl 92101 WELL' 2M-3 ( l14'FSL,36'FEL,SEC 28,T11N,R8E) HORIZONTAL PROJECTION -.GO00 -4000 -30')0 72000 -1000 0 '~ 000 2000 WELL' 2M-3 (114'FSL,$6'FEL,SEC 28,T11N,R8E) VERTICAL PROJECTION PelOJ~¢TION ON YERTtCAL. ~ t07 on ~ r -~n ~Z:AUEO IN VEI;I~IC,,L. OF.l='rl.4~ ~O~qlZ ~C*L£ - I , 1000 ~I/FT 4~7' ~~ .0 .~_,,~~ ' c.~'~icdo, rcport ' 403 yes no sundry application .... ~104 yes no repod of sundry application "' Open ' , required received ~ased- 'requi~:i~j ..... ~-l~-e-i~;~l--., ~'~j~C~ioi ~:equired received hole log .~-: . hole log Io~. , MUD 'GCT ~~~ ~ '"TEMP ' DI~SFL" ' cNL p~oD , BHCISL gET SPINNER j ~_~ .~_ , ,, I.~ L BUClaC e~ omen ~ata ........ sss PACKER digital" ff~/ Data ......... , .... CNL FbC RwD ' required rc'ccivcd sAMPLeS rCqui~cd received MWD LgIIcuL cO ~ ~ "~ dw ditch "ML ~~ / / 'cot"' ~ C~BER ....... core .... LOOK .... ~S/~ ~ ~ A~,,.~r.~. .... R~ ., ........ ~ , .... NGT ...... . ARCO Alaska, Inc. Date: February 7, 1992 Transmittal #: 8357 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of this transmittal. ~..22M-03 Cement Bond Log M 03 Ultrasonic Imager 2 M - 1 5 Cement Bond Log 2M 15 UltrasoniC Imager Please acknowledge receipt and 1 -27-92 1 -27-92 1 -27-92 1 -27-92 5800-7362 5800-7400 5200-6900 5200-6862 Receipt Drilling Acknowledge: State of Alaska(+sepia) Date: P.E.CE.[.V.E D NsKFEB 1 1 199~ Alaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: January 17, 1992 Transmittal #: 8337 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~ / "'/~P'"M '/'/'''''/ 2 M - 1 3 LIS Tape and Usting ' 1 2 - 2 4 - 9 1 2 -0 3 LIS Tape and Usting ?/'/¢/ 1-1-9_ .~__.2 Receipt Acknowledged: - 75340 °° ECEIVE'D Date' -J'A"N-'2-- 1 1992 Alaska 0il & Gas Cons. Commission Anchorage DISTRIBUTION: Lynn Goettinger ARCO Alaska, Inc. Date: January 10, 1992 Transmittal #: 8332 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return one signed copy of this transmittal. 2M-03 C[~ 12/29/91 -1/1/92 C[~ 12/29/91 -1/1/92 2M-03 L Receipt Acknowledged: Please acknowledge receipt 3350-7512 3350-7512 Date: R E£E ..V.E D JAN lb 1992 DISTRIBUTION: D&M Drilling Alaska 0ii & (]as Cons. CommJsslon Anchorage Vendor Package(Johnston) NSK State ~~p~a) ALASKA OIL AND GAS CONSERVATION COMMISSION December 10, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2M-03 ARCO Alaska, Inc. Permit No. 91-141 Sur. Loc. ll4'FSL, 36'FEL, Sec. 28, TllN, R8E, UM Btmhole Loc.1214'FSL, 1553'FWL, Sec. 28, TllN, R8E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE test that it wishes to witness. Sincerely, ,.- mi -~,onn~e C,(E~IEth, Commissioner A~aska O~L and Gas BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA AIJ~d~ OIL AND GAS CONSERVATION COMMI~k'51ON PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Drill X , Redrill -- I lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil Re-Entry _ Deepen --I Service _ Development Gas __ Single Zone X Multiple Zone 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska., Inc, RK~ 146', Pad Elev. 105' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25586 ALK 2672 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 114' FSL, 36' FEL, Sec. 28, T11N, R8E, UM KuDaruk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number #U630610 1155' FSL, 1750' FWL, Sec. 28, T11N, R8E, UM 2M-03 At total depth 9. Approximate spud date Amount 1214' FSL, 1553' FWL, Sec 28, T11N, R8E, UM 20-DEC-91 $200,000 1 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line: 2M-10 (proposed) 7614' MD 1553' @ TD feet 175' at 600' MD feet 2560 6375' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 600' feet Maximum hole angle 37° Maximum surface 1726 pslg At total depth (TVD) 3280psicj @ 6375' 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD linclude stage data) 24 16" 62.5# H-40 Weld 80' 41' 41' 121° 121' +200 CF 12.25 9.625 36.0# J-55 BTC 3249 41' 41' 3290 2915' 330Sx. PFE& HF-ERW 550 Sx. Class G 8.5 7" 26.0# J-55 BTC 7573 41' 41' 7614' 6375' 160SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Intermediate Production Liner - 2 !991 Perforation depth: measured _. true vertical Alaska 0ii & Gas Cons. C0m~[ss't0~ nchorage 20. Attachments Filing fee ~ Property plat __ BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program ~ Time vs depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correcl to the best o! my knowledge Signed ~, ~/( ~~/~.~ Commission Title Use Area Drillin~ Engineer Only Date Permit Number I APInumber I Approva' da'e ?/-/~7// 50-//O ,~' - -~, O ,/~" O ~./~,~ --~' ~ other recluirements Cor{ditions of approval Samples required .~Y e s )¢' N o Mud log r~q~ired~ Y e s ~ N o Hydrogen sulfide measures ~ Y e s ~ N o Directional survey required ~ Yes~ N o Required working pressure for BOPE 2M; ~ 3 M ;~.._~ 5 M · 1 0 M · I 5 M Other: .........__:.~/.'' .- ~ ~ by order of ,/ ~ Approved by . .~-~,,..~ r.~~.~.~(,--- Commissioner the commission Dale Form 10-401 Rev. 7-24-89 ~/ Submit in triplicate DRILLING FLUID PROGRam1 WELL 2M-03 Spud to 9-5/8" Drill out to surface casing weight uo Density 9.0-10.0 9.0-9.3 PV 1 5-35 5-1 5 YP 15-35 5-8 Viscosity 50-100' 30-40 Initial Gel 5-1 5 2- 4 10 Minute Gel 15-40 4-8 APl Filtrate 1 0-1 2 8-1 0 131-1 9-10 8.5-9 % Solids 10 +/- 4 - 7 Weight up 10.4 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <10-12 Drilling Fluid System: - Tandem Brandt Shale Shakers - Tandem Derrick Shale Shakers - Solids Processing System to minimize drilling waste - Mud Cleaners, Centrifuge, Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators RECEIV[D Alaska Oil & 6as Oon$. 6ormn~ss~O'° Anchorage NoteS' Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface preSsure of 1726 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2M-03 will be proposed Well 2M-10. As designed, the minimum distance between the two wells would be 175' at 600' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (>4 hrs) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. Spud mud shoUld be adjusted to a funnel viscosity between 100-120 sec/qt to drill gravel beds. ARCO ALASKA, [nC. Structure ' Pod 2M Well' 3 Field · Kuparuk River Unit Location ' North Slope, Alask( o 300 o ~ 0 · . 300 U~ 600 - fCreated by ; jones I~or: BRM)LEY/I;TrZPATRICK] Dote plotted : 24-Nov-91 Plot Reference is 5 Version ~2. oordinates ore in feet reference slot rue Vertical Depths are reference wellhead.I ~J])~ EASTMAN [Z//JLIIJC H R I STE N S E N 1200 _ 1500- - ~=_1800- - 2100- 2¢00- _ 2700- - 3000- 3300- _ 3600- 39~ - _ 42~- - ~5~- _ ~8~- N 73.41 DEG W 3~4e' (~o rAl~,r) <-- West Scale 1 ' 150,00 4200 3900 3600 3300 3000 2700 2(00 21 O01800 1500 1200 gOO 600 300 0 300 I II II II II II II II II II II II II II I I I TD LOCATION: 1121,4.' FSL, 1553' FWL/ RKB ELEVATION: 146' / ~oP ~=~oo r.D=6oo 0cP=0 / J TARGET LOCATION: I ~ 6 O0 J t 155' FSL. 1750' FWLi 900 \ ' I SEC. 28. TI1N, RSE J 12.00 BUILD 5 DEG / 1OO' TARGL-T TVD=6101 ~'~ TMD=7271 18.00 DEP=3646 NORTH 1041 k, 24.00 8/ PERMAFROST TVD=1596 TMD=I421 DEP=174 WEST3494 T/ UONU SNDS TVD=1436 TM0=1465 0EP=193 30 O0 / 6.00EOC TVD=17¢5 TMD=1828 DEP=382 SURFACE LOCATION:l x B/ W SAK SNDS TVD:2556 TMD=28¢I DEP=989 J 114' FSL, W SAK SNDS 'P/O=2001 TMD=2148 0EP=573 LSEC. 28, TllN, RSEJ 5400 ~ 5700- 6000- TARGET - T/ 7.0NE C TVD=6101 TMD=7;871 DEP=8646 ' X X ',~ T/ ZONE A TvO=611¢ TMD=7288 DEP=3656 6300- .~\ B/ KUP SNDS TVD=621§ TMD=7¢14 DEP=3731 TD / LOGGING PT TVD--6375 TMD=7614 DEP=3861 300 0 300 600 900 1200 1500 180~ 21 O02400 2700 3000 330(I$600 3900 ¢200 t l500 1200 - 900 -- _ - 300 _ -o 300 ,Alaska Oil & Gas Oons. Gore~¢ssim'~ Anchorage Scale 50.00 Eas 150 I 100 ! 50 ,I 0 50 100 150 200 250 43OO 21 O0 1900 1500 1300 1100 1500 ~ X ~ ~oo 3900 300 350 400 450 I I ! ARCO ALASKA, Inc. Pod 2M Well: 3 -- 13 - 15 field: Kupemk Elver Un# Leeefle.: No~l SlOl~, Aleaka 1300 1100 900 )0 3500 500 4-50 400 -350 -300 -250 -200 -150 -100 - 50 A I ('3 , . 3e . . Se , , , 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 2M-03 Move in and rig up Pool #7. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED DEO- 2 1,99 Alaska Oil & Gas Cons, Cornlf~issiO~'. Anchora..q. e .(UPARUK RIVER Uh, I' 20" DIVERTER SCHEMATIC DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION 3 2 . . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2,000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. RECEIVED . ~ F. C - 2 1,99~ ~aska 0JJ & (~as Cons. Commission Anchorage 10" HCR GATE VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 20" - 2000 PSI ANNULAR PREVENTER MLP 8/14/91 7 ,6 , 13 5/8" 5000 , $1 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILLAND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOWAND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST 8. ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM 9. RAMS TO 250 PSI AND 3000 PSI. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUT OF HOLE. 10 CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD 11. AND 12. LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE 13. DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR RECEIV[D DEC - 2 ,991 Alaska 0il & Gas Cons. Anchora,.qe I oeoeeeeeoeoeo ooeo9 oeoeeoee ~Y; 4~, ~9.~8 ~0~I~' /8.~?~" X LAT. 48T, 8~4. 41' ?0~1~' 18.~T9" 4~;~.3f ~0~/~'/~.~9 · ~?, ~4.37 ?0Ol6' I~.~" 4~, 00~.39 ?O~16'la.~l " 488, 0~9,45 488, 119.27 480, 144.4~ 4~, 488, ~t~. 4 ~8, 244.~1 ~0~t6' I~,~" 4 8~, S IR I~ ?0~16' 18.~S" 4~8, 394~ ?0~16' /O.~O&" 4~8, 4 t9.~ RECEIVED VICINITY MAP, SCALE 1"=2 M/LES ~ ONe. ~, S. ~. ~. £.~. De. · IEOeO~ '~X, 2~? " I 1 d ' 111 ' iOl.O' 104.9 0~' ~, $~ ' t t 4 ' 86' I01,0' 104. IEO°O&'~5. 809" / 14 ' 6/ ' I01.0' 104.9 /~ 0~'~.6~0 " //4' /4' I~.~' ~0~, ~ t~0°0~'~1.~0'' 114' 89' IOQ8' 105.4 /~oO~,EO. X20 . //~' //4 ' I00.?' I05.~ /~0~05'4~.~4'' //4~ /~' I00.~' / ~0° 0~'4~E34 " //4' / ~' 1~,5' I0~.~ /~0e0~'4~.919 " //4 ' ~X~' 100.3' I05.6 0~'4~. /~ ~ " //4 ' ~04 ' ~,2' ~05,6 /~0°0~'44.4X0" //~' ~' ~0.~' 105.5 05'43. X4~ " /I 4' 3EA' I~.t' ~05.6 /50~0$'4~,0/ / " //4' ~9' I~.0' ~0~.? /~O°O$'4~,ffX6" //4 ' 404' 99.9' 105.7 /&OeO~'4/,&E4" //4 ' 4frS' 9S, 9' 105.6 OS"40, O~ " 114 ' 47~' 99.7' ;05.5 /50e0~'~,~4' /1~' ~' 99.7' /~0°0~'~.6~0" //4' ~' 99.6' ~04,9 /~0=0~'~//" //~' 55~' 99.5' /04.9 · APR O (~ !~I ~,_ OF ~,~_ .'..,_ AND TNAT THIS PL;T RE~ESENT$ A $UNV~ ~,~ ;~' '~'~<~ "' ~'~ " ~ "' ~ 'MADE BY ME OR UN~R MY BIRECT ~U~SI~ ~'~";' -. ,5~.: ;% '- AND THAT AL~ O~ENSlONS ~NO OTHER ' ,.., ~.:., , .... . ', ,.. '~ ~', .' . ,.~ D~ ! · De ~ ct/Df/on ARCO ALA,~KA, INC. OW(; a* N$OK. CMO0. CEA 'ORMX. 62 i$ D 7 J a, Inc. ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (2]) Loc ~=.~~ [2 thru '[ ~ th. ru [10 S 13] thru 22 ] (5) BOPE '~',~/,~ '~ [23 thru 28] Other' [29 thru 313 (6) Add] · e 3. 4. 5. 6. 7. 8. 0 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. Company Lease & Well YES Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Z ' is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... ~_ Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease ngrnber appropriate .......................................... ~_ Does well have a unique name & nL~er ................................ ~ .. Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ ~ ...... Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. j - NO REMARKS 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~a~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. 0 --4 -rZ ~-~0 geology' eng.i neer i ng ~ DWJ .. MTM/C-~--E LCS .ff~ i R P C.~./¢~. BEW-//~ RAD"~ dH ~2. ~r~,,..~ rev 03/29/91 INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA SHORE /-o,'/ Additional remarks' Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIx. No special 'effort has been made to chronologically organize this category of information. , ALASKA COMPUTING CENTER * *mme~mmem~mmmm~mNmmmememmm~ee* ~emmmmm~memmmmmm~mmmem~eeemmm~ COUPAMY NAH£ : ARCO ALASKh, INC. WELL ~iA~E : 2~-03 FIELD MA~E ~ KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-103-20160 REFEREMCE NO : 92006 RECEIVED ,JAN 2 1 lgg~. Alaska 011 & Gas Cons. Commission Anchorage BiS Tane verification Listin~ Schlumberqer ~!asKa Com~utiD~ Center IO-JAN-IQ9~ 07:21 PAGE~ ORIGIN : FblC REET~ ~}Ar~E : Q2006 CONTINUATION ~ : P~EVIOUS RE~G : CO:~4.E~!T : ARCL] ALASKA I~C., 2~-03, KUPARUK RIVER, 50-103-20160-00 **** TAPE HEADER SERVICE NA~E : ~OlT DATE : 92/Ol/10 ORIGIN : FDIC TAPF ~A~E : 92006 COnTINUaTION # : P~EVIO{I$ TAPE CO~q~ENT : ARCO ALASKA INC., 2~-03, KUPARUK RIVER, 50-103-'20160-00 **** FILE HEADER **** FILE NA~E : EDIT ,001 SEpVlCE : FLIC V~RSlON : O01A06 DATE ~ 92/01/10 ~AX REC SIZE : 1024 FILw TYPE : LO DAST FILE : FILE ' EDIT,O01 ARCO ALASKA INC. KUPARUK RIVER 2g-03 50-103-20160 ?~AIN PASS I~WD LOG DATA THE DE~7~SIT'Y DATA PRESENTED Oixi THIS LIBRARY TAPE IS FROM 'RHOB ~AX' !)ATA SAMPLED EVERY -.5000 FEET D~T~ I~CLUD~D - 'fOOL EXTE~SION TOOL TYPE USED NAYE LOGGING W~II,.f: DRILLI~G RESISTIVITY/GR 3350' TO 7449' LOGGI~!'G wHILE 0~ILbI~gG NEUTRON/DENSITY 3350' TO 738~' LIS Tape verification bistlno Schlumberger Alaska Co~Dutino Center 07:2! PAGE{ 2 CM F~ API~ FL SFCT RaNG COU~ STAW L~TI LONG WIT~ pDAT EPD APD TDD B~I TLI DFP~ D~V R~F~ ~ST RMC$ STE~ VALU DEFI TYPE ARCO ALASKA INC, Company Name KL!PARUK RIVER Field Name 2M-03 Well 50-103-20160 APl $ 114' FSL & 36' FEL Field 28 Secti lin Towns 8E Range NORTH SLOPE Count ALASKA State USA Natlo Latit Longl wit. ne Name erial NumDer Location on ¥ or Province ude rude Ss' Name 152g~ Service Order Number MS5 Permanent datum FT 0, Elevation of Perm. Da DF Log ~easured Fro~ rT 147, ABOVE PERMANENT DATU~ FT 147. Elevation of Kellv Bu FT 147, Elevation of Derrick FT 105 Elevation of Ground L FT 751~. Total DePth - Driller FT 7512. Total Depth - Logger FT 7512. Bottom Lo~ Interval WT 3350. ToP Log interval LSND Drilling Fluid Type. G/C3 10.3 Drilling Fluid Densit Drilling Fluid Ph ZONE CP Drilling Fluid Viscos ZONE F3 Drllllng Fluid Loss ZONE OH~ 5 0t.' Resistl~it~ Of Mud Sa DEGP 6~ ~ud. Sam~le Temperatur OHMM 4 ~7 ~eslstl.it~ O~ mud fl DEGF ~, ~ud. Flltra-e Sample T OHMM Resistivity of Mud Ca ZONE DEGF Mud Cake Sample Tempe ZONE DEGF -10. Surface Temperature his Tame Verification Listing Schlumberoer ~lasKa Computinq Cemter ]O-jAN-]992 07:21 PAGEj T~BTE TYPE : ZDb~E TABLE TYPE DEPT ROS9 D~HO DCA[, DPHI DPOP TNP~ ATR ROPF DEFI Depth Channel ~ame 5S2 RHO DeDsitV - bDT Bulk Density Delta R~O Photoelectric Factor Differential Caliper Density Porosity Density Porosity Output from an Application Pro,ram Thermal Neutrom Porosity Gamma Ray ~............~..~..~.~----~..........m...~--.------~.....--.--..~. ** DATA FORe, AT SPECIFICATION RECORD ** ** SET TYPE 64,.~8 ** ''''''''''''~''''~'''''''''''TYPE V~LUE .~..~. ~...........~...'.'... 1 66 0 2 66 0 3 73 56 4 66 5 66 6 73 7 65 8 68 0 5 1~ 66 18 12 68 1~ 66 0 ~4 65 FT ~5 66 6~ ]6 66 0 66 0 IS Tape Verification Listimq chlUn, beroer AlasKa Computl~q Center lO-JAN-lq92 07:21 PAGEI ** SET ID DEPT FT RO$~ LWD G/C3 D~O L~D G/C3 PEF [.WD DCAL LWD IN DPHT LWD PU DPOR LWD PU T~P~ L~D PU ATR LWD OHM~ DEP LWD 0~ ROPF [.WD ~/HR G~ L~D GAPI TYPE - CHAN ** ..... o;'";';";;o.. .... ; .................... , t ,. ..... .... 1529~3 00 000 O0 0 1 1 1 4 68 0000000000 ~52983 00 000 O0 0 1 ! 1 4 68 0000000000 152983 O0 000 O0 0 1 1 1 4 68 0000000000 15~983 O0 000 O0 0 1 ! i 4 68 0000000000 152983 O0 000 O0 0 1, 1 ! 4 68 0000000000 152983 O0 000 O0 0 i I 1 4 68 0000000000 152983 O0 000 O0 0 1 I 1 4 68 0000000000 152983 O0 000 O0 0 1 1 I 4 68 0000000000 152983 00 000 O0 0 1 ! ~ 4 68 0000000000 152993 O0 000 O0 0 1 I 1 4 68 0000000000 152983 O0 000 O0 0 1 1 t 4 68 0000000000 ~5~983 O0 000 O0 0 1 1 1 4 68 0000000000 152983 O0 000 O0 0 1. 1 ! 4 68 0000000000 ** DATA ** DEPT. 7512.000 PEF.L~D -999,250 NPN,LWD -999,250 OP~.[,,WO 70.350 DFPT, 7500,000 PEF,LWD -999.250 TNPH,LWD -999,250 ROP~.L~D 45,000 DEPT, 7400,000 PEF.L~!D -999.250 TMPH.LWD -999.250 ROPF,LWD 11,257 DEPT, 7300,000 PEF.LWD 4,054 TNPH,LWD 36,50{) ROPF,LWO 48,911 DEPT, 7200,000 PEF,LWD 7,55~ TNP~.LWD 37.700 ROPE,LW~3 17.175 DFPT, 7100.O00 PEF.L~D 3.766 TNpM,LWD 43.400 ~OpF.I,wn 103,4~96 ROS2.LWD ~999,250 RHOB.LWD 999.250 DRHO,LWD DCA~,L~D 999 250 DPHI.LWD :999.250 DPOR,LWD ATR,LWD ~:099 250 P$R,LWD -999,250 DER,LWD GR.I, WD -999.250 ROS2.bWD -999.250 RHOB,LWD -ggg 250 DRHg,LWD DCAL.LWD -99~,250 DPHI.LWD -999i250 DPO~.bWD ATR,LWD '99~,250 PSR.LWD -999 250 DER,LWD GR, LWD -999,250 ROS2.[,WD '999.250 RHOB,LWD -999 250 DRHO,LWD DCAL.LWD '999,250 DPHI,LWD -999~250 DPOR,LWD ~TR.LWD 2.534 PSR.LWD 2~658 DER.LWD GR,LwO 87,603 ROS2.LWD 2,505 RHOB.LWD 2 DCAL LwD 0 866 OPHI LWD O,505' DRHO,LWD . . , 071 DPOR,LWD ATR,LWD 3,593 PSR,LWD 3,677 DER,LWD GR.I~W[> 77,671 ROS2,LWD 2.461 RHOM,LWD 2,461 DRHO,LWD DCAL,LWD 0,633 DPHI,LWD 0.097 DPOR,LWD ATR,L~D 1,7tl PSR,bWD 1,882 DER,LWD GR,LWD 107.949 '999,250 -999,250 -999,250 -999,250 -999,250 -999,250 '999,250 -99~,250 ,610 0,020 o:g, 0,014 0,097 1,807 his Tape Verification Listing SchlUmberger Alaska Computing Center 07:21 PAGE: DF, PT. 7000.000 R[~S2.L~D PEF.I,WD ~.687 DCAL.LWD TNPH.I, WD 43.800 ATR.LWD ROPE.[,WP 48.00n GR,LWD DFPT, 6900.000 ROS2.LW[) PEF,L~D 6,411 DCAL.LWD TNPH,[.,WD 38,500 ~T~,LWD ROPW.L~ 129,495 GR,LWD DEPT. 6800,000 ROS~.L~D PEF.I.,~iD 3,871 DCAL,LWD TNpH.L~i) 38,900 ATR,LWD ROPF.LWD !85,748 GR.LWD DEPT 6700.000 ROS2 LWD PEF:LwD 3,971 DCAL.'b~D TNPR. LWO 35. 000 ATR. L~'D ROPE, LW9 153. 856 GR, LWD DEPT. 6600.000 ~n$2.bWD PEF.Lt~D 3,]33 DCAL,LWD TNPN.L~D 33.400 ATR.b~D ROPF.I.,WD 174,856 GR.L.D DEPT. 6500.000 ROS2.LWD PEW.LWD 3,629 DCAL,LWD TNPM,LWD 32,000 ATR,LWD ROPE.L~) 160,715 GR.L~D DEPT. 6400.000 ROS2,[,WD PEF.LWD 2,771 DCAL.LWD TMPN.I.,WD 34.000 ATR.LWD RCP~,LW~ 135,330 GR,LW~ FPT. 6300 000 ROS2,bWD DP~:~iLWD 3 549 DCAb. LWD TNP~.LWD 33 500 ATR,LWD ROPF.L~!D 90 000 GR,LWD D~PT. 6200.000 ROS2.LWD PEF.[.wD 2,926 DCAL.LWD TNPH,L~D 30,400 ATR,LWD ROP~,LW9 ~00,231. GR.LWO DEPT 6100,000 ROS2.LWD PEF:!.,i~9 3.122 DCAb. LWD TNPH. LNI) 38,400 ATR, L~'D ROPE. LWD 187, ~ 16 GR. LWD DEPw. 6000.000 ~O$2 LWD PEF.LND 3.i. 1'7 DCAU:LWD TNPR.I,wD 36,600 ATR.LWD ROPF.L~VO 197,34,1 GR,Lw9 13 21 2.415 REOO.LWD 0.279 DPHI,LWD 2.590 PSR.LWD 3.253 2,490 RHO8,LWD 0.182 DPHI,Li{D 2 075 PSR.LWD o~752 2.4B7 RFOB.LWD 0,417 DPHI.LWD 2.898 PSR,LWD 109.812 z," 504 R}~OB,LWD 0.331 DPHI,LWD 3.136 PSR.LWD 9g,g31 2,456 RHOR.LWD 0.345 DPHI,LWO 3,348 PSR,LWD 101.820 2.526 RFOO.LWD 0.368 OPNI.bWD ~.639 PSR.LWD 91,491 2,3~7 RHOB.LWD 0.360 DPHI,LWD 3 947 PSR,LWD 93.486 2 4~2 RHOS.L~D 0:2 2 DPHI'LWD 2,716 PSR,LWD 83.898 ,37g RHOB.LWO ~.000 DP~,~I.LWD 2.729 PSR.LWD 105,~95 2.390 RHO~.LWD 0.422 DPHI.LWD 2.987 PSR.bWD 75.220 2.415 0.125 2.487 2.490 0.080 2.058 2.487 0.082 2.784 2 504 0:071 2.944 2.456 0.100 3.234 2 526 0i058 3 568 2 387 3,671 2 472 0i091 2 460 2 432 0!115 2 606 2.379 0.147 2.641 390 2.858 DRHO.LWD DPOR.LWD DER.bwD DRHO.LWD DPOR.LWD DER.bWD DRHO.LWD DPOR LWD DER:LWD DRHO.LWD DPOR.LWD DER.LWD DRHO.LWD DPD~,LWD DER.LWD DRHO.LWD DPOR.LWD DER.LWD 'DRHO.LWD DPOR.LWD DER.LWD DRHO.LWD DPOR LWD DER:LWD DRHO.bWD DPOR'LWD DER.LWD DRHO LWD DPOR:LWD DER.LWD DRHO LWD DPOR:LWD DER.LWO 0,009 0,125 2,520 '0,001 0,080 2,065 0.004 0,082 2,823 0 010 0~071 3,007 '0,008 0.100 3,272 o'o21 0,058 3,591 -0,011 0,i42 3,755 0'022 0,091 2,503 0'005 o:[ s ' 0 ', 007 0,147 2.672 0,040 , 1.40 ,901 ISTape Verification Listing chlumheroer AlasKa Comoutinq Center i0-jAN-1992 07:21 PAGE: DEPT, 5800.000 ROS2.LWD PEF.LWD 2,903 DCAL.LWD TNp~,[.WD 37.800 ATR.LWD ROPE.L~D 321.788 GR.LWD DEpT, 5700,000 ROS2.LWQ PEF,LWD 2.975 DCAL.LWD TNPH.LWD 38,000 ATR.LWD ROPE,LND 360,050 GR.LWD DEPT. 5600,009 ROS2.LWD PEv bWl) 2.861 DCAL.bWD T~PW~LW~ 35,700 aTR LWD ROPF.L~D 168,233 GR~LWD DE~T, 5500.000 ROS2.L~D PEF.L~D 3,08b DCAL,LWD I,WD 33,600 ATR,LWD TMP~'LWD 346.1~2 GR,LWD ROPV, . DEPT, 5400 000 ROS2.LWD ~gr.b~ 3:025 OC~b.b~D TNPH bWD 46,100 ATR~LWD ROPE: L~D 144. 567 OR. LwD DEPT 5300,000 ROS2 PEF.I,~O 3,283 OCAL,LWD T~P~.I, WD 51,000 ATR,LWD ROPE.LwD 247.04g G~,LWD DEPT. 5200.000 ROS2.LWD PEF.LWD 2,892 OCAL.LWD TNpH.LWD 37.700 ATR.LWD ROPE.LWD 202,244 GR.bWD DEPT, 5100.000 ROS2.L, WD PEV,L~D 2,752 TNPg,LWD 40,000 ATR.LWD ROP~.LwD 210,342 GR.LWD DEPT. 5000.000 ROS2.LWD PEr LWD 2,'7~ o DCAL, b~O TNPH. [,;dD 4.6 700 ROPE. [,wi) 202,244 OR, L~ID 2.545 RHOB.bwO 0.302 DPHI.LWD 3.998 PSR.I, WO ~2.65~ 2.352 RHOB.LWD 0.213 DPHI LWD 2.760 PSR:LWO 9!.001 2.390 RHOB.L, WD 0 1~2 DPHI.hWD 2.' 9-4 PSR. LWD 86,962 2.341 RHOB.LWD 0.123 DPHI,LWD 2.599 DSR,LWD 80.037 2.444 RHOB,LWD ().~36 DPHI.LWD 3 063 PSR.LWD 112~174 2.311 RHOB.bWD 0.163 DPHi.GWD 109. 4 0:0 6 2,019 153.690 2.383 0.207 ,593 12 ,763 2.330 0.169 1,738 88.035 2.347 0.1~4 1.4 7 89.732 RHOB,LWD DPHI,LWD PSR.LWD RHOB.LWD DDHI,LWD PSR,LWD RHOB.LWD DPHI.LWD PSR.LWD RHOO,LWD DPHI,LWD PSR,LWD DEPT, 4900,00o ROS2.LWD 2.398 RHO6.LWD PEV,t, ND 2.g30 DCAL,L~D 0.220 DPHI.hWD TNPH,L~D 36,400 ATR,L~D 3,116 DSR,LWD RODE.LWP 218.774 GR.bbg 1.17.642 2,545 DRHO.LWD 0.046 DPOP.L~D 6.731 DER.LWD 2 352 DRHO,LWD 0i163 DPOR.LWD 2 618 DER.LWD 2.390 DRHO,LWD 0.140 DPOR,LWD 2.944 DER.LWD 2 341 DRHO.LWD 0:170 DPOR.LWD 108 DPOR.LWD 2.852 DER.LWD 2.311 DRHO,LWD 0.188 DPOR.LWD 1.768 DER,LWD 2.265 DRHO,LWD 0 216 DPOR,LWD t:834 DER,LWD ,:383 DRHO.L~D .145 DPOR.LWD 2.404 DER,LWD g. 330 DRH, O.LWD ,176 DPOR.LWD 1.614 DER.LWD 2 347 DRHO,LWD 0:166 DPOR,LWD 1..414 DER,LWD 2.398 DRHO,L'~D 0.135 DPOR.LWD 3.124 DER.L~D '0,014 0,046 6.290 -0.008 ,1 63 ,667 0,005 0,.140 2,954 0,001 54? 2,920 49 '0,008 1o ? 001 2,468 O, 003 0,008 66 1442 o 3't2t LIS Taoe verification l. istinq 5chlumberoer AlasKa Computing Center 10-JAN-ID92 07:21 PAGEI DEPT 4700 000 PO$2,LWD TNPP., [.,~P 4 1,300 ~TR, L~D RGP~, L~D 221,47 2 GR, LWD DEPT. 4600.000 PEW.L~D 2.734 DCAL.LWD TNPH,L~D 43,100 ATR,LWD ROPF.LWD 262.095 GR.LwD DEPT. 4500,000 ROS2.LWD PE~.LWD 2.812 DCAL,LWD TNPW.LwD 40.900 ATR.LWD ROPW,LWD 308,563 D~PT 4400.000 ~OS2.LWD PEF't.~D 2,972 .CAb,LWD TNPN:[..WD 42,000 ATR.LWD ROP~,LWD 187,065 GR,LWD v~p~ 4300.000 ~os2 TNPN.LWD 41~200 ATR.LWD ROP~.LWD ]40,538 GR.LWD DEPT 4200 000 ROS2.LWD PEF~LWD 2:745 DCAL.LWD TNPN.LWD 42,800 ATR.LWD ROPE.I. WD 353,201 GR.LWD DEPT. 4100.000 ROS2.LWD PEV'LWD 2.6~4 DCAL.LWD TNPN.LWD 38,800 ATR.LWD ROPF,LWD 279,446 GR,[~WD D~PT 4000.000 ROS2,LWD PBF:L~D 2.595 DCAL.LWD TNPH. LWD 49,300 ATR, bwP ROPF.LWD 228. 867 GR. LWD DEPT. 3900 OOO RO$2,L~D TNPH, !~[') 49,100 ATR, ~WD ROP~, LwD 224.98~ GR, LWD D~PT. 3800,000 ROS2,b~D PEF.[,,W!) 2,615 OCAb. DWD . ~ T' bWO TNPN bwD 45.300 A..R, ROD~.L~{'~ 173,70t GR,LW!) 2.458 RHOB.LWD 0.203 DPNI.LWD 3.066 PS~.LWD 72.915 2.295 RNOB.LWD 0.081 DPHI.LWD 2.583 PSR.LWD 97.664 2,295 RMOB.bWD 0.I29 DPHI,LWD 2.904 PSR,LWD 92.541 2.253 RNOB.LWD 0.039 DPHI.LWD 3.169 PSR,bWD B5.277 2.298 RHOB.LWD 0.070 DPHI,LWD 3.128 PSR.LWD 81.407 2.275 R~OB,LWD 0.134 DPHI,LWD 2.729 PSR.LWD 92.071 2.2~4 RHOB.LWD 0.0 0 DPHI,LWD 2.915 PSR,LWD ~1.812 2.196 RHOB.LWD 0,000 DPHI 3.199 PSR: WD 85,625 2,249 RHOB,LWD 0.136 DPMI.LWD 2,856 PSR,LWD 90.383 2.245 RHOB,LWD 0.104 DPWI,bWD 2,659 PSR.LWD 85.798 2.193 RHOB.'LWD 0.25B DPMI,LWD 3,310 PSR,SWD 66.104 2.458 0.099 2.742 2.295 0 198 2:496 2.295 0.198 2.877 2 253 3.031 2.298 0,196 3.014 2 275 o221o 2.688 2 254 2.805 2,196 0.258 3.070 2.249 0,226 2,794 2.576 2 193 o12 o 3,0.]8 DRHO.LWD DER.LWD DRHO.LWD DPOR.LWD DER.L~D DRHO.LWD DPOR LWD DEP:LWD DRHO.LWD DPOR.LWD DER.LWD DRHO,L~D DPOR,LWD DER,LWD DRHO.LWD DPOR.LwD DER.LWD DRHO.LWD DPOR.LWD DER.LWD DRHO.LWD DPOR,LWD DER.LWD DRHO LWD DPOR:LWD DER.LWD DRHO, LWD DPOR, L. wD DER.LWD DRHO LWD DPOR:LWD DER.L~D 0,045 0,099 2,842 '0,002 0.198 2.527 '0,003 0,198 2,887 '0,001 g;OlO 196 3,052 '0,006 0,2 0 2,?~2 -0,003 0,223 2,842 '0, 3,113 oO:OO 2,605 0,006 0,2:60 3,i23 LiS Tape Verificatlon I, istinO 5chlumberaer Alaska Computing Center lO-JAN-1992 07:21 PAGE{ DFPT, T~P~,LwD 3700,'.)00 2,4gl DCAL,hWD 43,000 ATR,LWB 15~.002 GR.GWD 2,727 DCAB,I,~D 41.900 AT~.LWD 298,090 GR,LWD 3500.000 2.7~6 DCAL.LWD 45.4n0 ATR.LWD 260.284 GR.LwD 3400.000 ROS2 2,338 45,100 ATR,LW~ 236.839 GR.LW~ D~PT. PEF.LWB ROPF.LND DFpT, PEF.L~D T~!Pg,L~D ROP~,LWD DEPT PEF~f, WD DEPT. PEF.LWD TNPg. LWD ROP~.LWD 3300,000 ROS2.LW9 lO0.O0<) DCAL,LWD 55 500 ATR,LWD -999~250 GR.LWD DEPT. PEF.LWD TNPN.LWD ~207,500 ROS2.LWD 999,250 QCAB,LWD -909,250 ATR.LWD -999,250 G~.bWD ** END OF DATA ~.105 RHOB.bWD 0.000 DPHI,LWD 4.636 PSR.LW9 65.046 2.186 RHOB.LWD 0,102 OPHI,LWD 3.903 PSR.LWD 94,869 2.199 RHOB.LWD 0,000 DPHI,LWD 3.702 PSR.LWD 106.713 2,1~5 Ri. IOB.LWD 0,0 0 DPHI,SWD 4.098 PSR,LWD ~2,~43 2.320 RHOB.LWD 0,642 DPHI,LWD 0.004 PSR,bWD 60.709 -999.250 RHOB.LWD -999 250 OPHI.LWD -99g'~50 PSR LWD -999,250 2.105 4.162 2.186 0.264 3.662 2.199 0 256 3~631 2.105 0.313 4,370 320 183 15,580 -g99 250 -999i250 -999 .250 DRHO.LWD DPOR.LWD DER.£~WD DRHO,LWD DPOR.LWD DER.LWD DRHO,LWD DPOR,LWD DER,LWD DRHO.I, WD DPOR.LWD DER.LWD DRHO.LWD DPO~,LWD DER.LWD DRHO.LWD DPOR.LWD DER.LWD 0,028 0,313 4,293 264 3,736 '0,015 655 -0,001 0,3i{ 4,274 -0.284 0.183 2000:000 -999',250 -999,250 -ggg,,250 **** FILE TRAILER **** FILE ~AME : EDIT .001 VERSION : OOlA06 DATE : 92/01/!0 MaX AEC SIZE : ~024 FILE TYPE : LO L~ST FILE : **** TAPE TRAILE~ **** SERVICE NAME ~ EDIT DATW ; 92/01/10 ORIGIN : FLIC TAPE NAgE : 92006 CONTINUATION ~ : 1 PREVIOUS TAPE COg~ENT : ARCO ALASKA INC., KUPARUK RIVER, 50-103-201 60-00 >IS Tape verlftcation bistln~ ~chlumberoer ~.la$~a ComDutlne Ce.nter 10-JA~-1992 07:Pl PAGE: **** RE,fL TRA I [,F.~ **** SFPVICF N~.IM : EDIT DSTF : Q2/Ol/lO O~ICIN : FL]C RF~I, NA~E : 92006 CDNTI~,~UATION ~ COu~E~4T : ARC[} ALASKA INC., 2M-03, FUPARUK ~IVER, 50-103-20~60-00
