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191-114
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 25, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1R-17 KUPARUK RIV UNIT 1R-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2023 1R-17 50-029-22212-00-00 191-114-0 W SPT 6462 1911140 1616 2500 2500 2500 2500 70 70 70 70 4YRTST P Austin McLeod 5/28/2023 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1R-17 Inspection Date: Tubing OA Packer Depth 780 1910 1880 1875IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230528185742 BBL Pumped:1.2 BBL Returned:1 Tuesday, July 25, 2023 Page 1 of 1 1 Regg, James B (OGC) From:NSK DHD Field Supervisor <n2238@conocophillips.com> Sent:Monday, May 8, 2023 2:26 PM To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:Well Integrity Specialist CPF1 & CPF3 Subject:3K-11 and 3K-22 and 1R-17 10-426 forms from 5-7-23 Attachments:MIT KRU 3K-11 and 22 05-07-23-.xlsx; MIT KRU 1R-17 NON WITNESSED 05-07-23.xlsx Good AŌernoon, Please see the aƩached 10‐426 forms for the AOGCC witnessed tests that were performed at 3K‐11, 3K‐22 and 1R‐17 on 5‐7‐23. Please let me know if you have any quesƟons or concerns. Thanks, Bruce Richwine/Shelby Sumrall DHD Field Supervisor KOC F‐wing 2‐14 (907) 659‐7022 Office (907) 943‐0167 Cell N2238@COP.com 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. KRU 1R-17PTD 1911140 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1911140 Type Inj N Tubing 1190 1200 1200 1200 Type Test P Packer TVD 6462 BBL Pump 2.0 IA 30 2000 1960 1960 Interval 4 Test psi 1616 BBL Return 2.0 OA 10 20 20 20 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD 5448 BBL Pump IA Interval Test psi 1500 BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: 1R-17 Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 1R PAD N/A Weimer / Arend 05/07/23 Form 10-426 (Revised 01/2017)2023-0507_MIT_KRU_1R-17 jbr Originated:Delivered to:15-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 1A-07 50-029-20658-00 n/a Kuparuk River Packer Setting Record Field- Final 26-Oct-20 0 1 2 1B-102 50-029-23167-00 906749775 Kuparuk River Multi Finger Caliper Field & Processed 7-Oct-20 0 1 3 1D-05 50-029-20417-00 906744243 Kuparuk River Packer Setting Record Field- Final 1-Oct-20 0 1 4 1R-17 50-029-22212-00 906744935 Kuparuk River Packer Setting Record Field- Final 5-Oct-20 0 1 5 2B-07 50-029-21080-00 906716400 Kuparuk River Multi Finger Caliper Field & Processed 2-Oct-20 0 1 6 2B-07 50-029-21080-00 906716400 Kuparuk River Leak Detect Log with ACX Processed 1-Oct-20 0 1 7 2H-11 50-029-20052-00 906792896 Kuparuk River Plug Setting Record Field- Final 31-Oct-20 0 1 8 2N-315 50-103-20270-00 906731635 Tarn Participating Area Leak Detect Log with TMD3D Field & Processed 28-Sep-20 0 1 9 2P-451 50-103-20402-00 906771682 Meltwater Perforation Record Field- Final 19-Oct-20 0 1 10 2T-38A 50-103-20229-01 906748612 Kuparuk River Plug Setting Record Field- Final 17-Oct-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 12/16/2020 12/16/2020 Abby Bell PTD: 1911140 E-Set: 34410 MEMORANDUM TO: Jim Regg �ll P.I. Supervisor ��vq (�'11i✓D FROM: Brian Bixby Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 21, 2020 SUBJECT: Mechanical Integrity Tests CwwcoPkillips Alaska, Inc. 1R-17 KUPARUK RN UNIT IR -17 Sre: Inspector Reviewed By: P.L Sup" Comm Well Name KUPARUK RIV UNIT 1R-17 API Well Number 50.029-22212-00-00 Inspector Name: Brian Bixby Permit Number: 191-114-0 Inspection Date: 10/1312020 ' Insp Num: mitBDB201013155941 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IR -17 Type Inj W -TVD 6462 Tubing 2300 2295 2300 2300 PTD 1911140 Type Test SPT -Test psi 1616 IA 1090 1815 - 1790 ' 1780 BBL Pumped: 0.5 - IBBL Returned: 0.5 OA 1 65 - 65 65 65 - Interval OTHER P/F P Notes: MITIA Per SUNDRY 320-269 Post Patch v Wednesday, October 21, 2020 Page 1 011 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 10345 feet N/A feet true vertical 6857 feet N/A feet Effective Depth measured 10118 feet 9591 feet true vertical 6716 feet 6396 feet Perforation depth Measured depth 9793-10054 feet True Vertical depth 6517-6676 feet Tubing (size, grade, measured and true vertical depth)3.5 L-80 9697' MD 6460' TVD Packers and SSSV (type, measured and true vertical depth)Packer 47B2 FHL 9591' MD 6396' TVD SSSV None 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: 10/16/2020 Contact Phone: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name N 4. Well Class Before Work:5. Permit to Drill Number: Other: Tubing patch Junk measured Burst Collapse 191-114 50029222120000 ADL0025628/ADL0025635 KRU 1R-17 P.O. Box 100630, Anchorage, Alaska 99508 N/A Kuparuk River Field/Kuparuk River Oil Pool Plugs measured Packer measured true vertical Casing Length Size MD TVD N/A N/A N/ASurface56619.625 5703 4024 N/A Conductor 77 13 120 120 N/AProduction103017103396953N/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 320-269 Authorized Name: Authorized Signature with date: ----- ----- nttt e Fra O g g g l g yy e 6. A y GGGJ LLLLL PG R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:39 am, Oct 20, 2020 Dusty Freeborn Digitally signed by Dusty Freeborn Date: 2020.10.16 17:05:49 -08'00' SFD 10/20/2020 VTL 11/03/20 RBDMS HEW 11/12/2020 DSR-10/20/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 16, 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 injector KRU 1R-17 (PTD 191-114). 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: 2020.10.16 17:02:11 -08'00' Date Event Summary Executive Summary Kuparuk Injector 1R-17 lost tubing by inner annulus integrity via a tubing leak at ~8150'. A retrievable tubing patch was set from 8137'-8162'. Diagnostics testing indicates the newly set tubing patch has regained tubing by inner annulus integrity. 04/08/20 RAN LDL WITH READ CASED HOLE ACOUSTIC LOGGING TOOL. LOG BASELINE PASS DOWN FROM SURFACE TO CA-2 PLUG AT 9644'. LRS PUMP DIESEL DOWN TUBING TAKING RETURNS UP IA TO FLOWLINE AT 3000 PSI. LOG UP AT 30 FPM TO SURFACE, LOCATE LEAK AT ~8150. JOB CONTINUED ON 9-APR-2020. 10/05/20 PULLED 2.81 CA-2 PLUG BODY @ 9644' RKB BRUSH n' FLUSH PATCH AREA FROM 8200' TO 8100' RKB, GOOD TBG x IA TEST W/ 3 1/2 SMART HOLE FINDER @ 8162' RKB, SET LOWER 2.72" P2P @ 8162' RKB (ME) (OAL 4.01' / SN:CPP35293). IN PROGRESS 10/06/20 CMIT TBG x IA 2500 PSI (PASS), CMIT TBG x IA T/I/O= 875/750/0 START TO PRESSURE UP TBG & IA SLOWLY EQUALIZING RIG UP JUMPER, (2 BBLS TO PRESSURE UP T/I/O= 2550/2500/0, 15 MIN T/I/O= 2525/2475/0, 30 MIN T/I/O= 2525/2475/0PRE SET UPPER 2.72" P2P SPACER & ANCHOR LATCH @ 8137.12' RKB (ME)(OAL 25.72' / SN:CPP35276 / CPAL35161), MIT IA 2500 (PASS). COMPLETE. MITIA T/I/O= 850/800/0, PRESSURE UP T/I/O= 875/2500/0, 15 MIN T/I/O= 875/2450/0, 30 MIN T/I/O=875/2450/0 10/13/20 (SW) STATE WITNESSED (BRIAN BIXBY) MIT-IA TO 1815 PSI (PASSED). Initial T/I/O = SI 2300/1090/65. IA FL @SF. Pressurize IA to 1815 psi w/ 0.5 bbls of diesel. Monitor 30 min. Starting T/I/O = 2295/1815/65. 15 min T/I/O = 2300/1790/65 (-25). 30 min T/I/O = 2300/1780/65 (-10). Bleed IA to T/I/O = 2300/1090/65 (0.5 bbls back). Final T/I/O = SI 2300/1090/65. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 10,118.0 11/10/2018 1R-17 fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pull plug, Set Patch 10/6/2020 1R-17 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 43.0 Set Depth (ftKB) 120.0 Set Depth (TVD) … 120.0 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) 42.2 Set Depth (ftKB) 5,702.7 Set Depth (TVD) … 4,024.0 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 37.8 Set Depth (ftKB) 10,338.9 Set Depth (TVD) … 6,852.8 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC-MOD Tubing Strings Tubing Description TUBING RWO 2016 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 21.5 Set Depth (ft… 9,697.1 Set Depth (TVD) (… 6,459.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 21.5 21.5 0.08 HANGER FMC Tubing Hanger, TC-1A-EN, 6" x 3-1/2" EUE 8rd Box x Box, 3" ISA BPVG 2.992 9,560.0 6,378.3 53.75 LOCATOR Locator Sub, GBH-22 (bottom of locator spaced out 6.91') 2.990 9,561.0 6,378.9 53.75 SEAL ASSY Seal Assembly, 80-40 (total seal assembly length = 21.70') 2.990 9,567.3 6,382.6 53.73 PBR PBR, 80-40 4.000 9,590.6 6,396.4 53.67 PACKER 47B2 FHL Retrievable Packer (shear ring = 60K) 2.960 9,644.0 6,428.1 53.59 NIPPLE Nipple, Camco, 2.813" DS, SN: 3651-8 2.812 9,686.9 6,453.6 53.54 LOCATING COLLAR Locating Collar, 3-1/2, 9.3#, J-55, EUE 8rd Mod Box x Box 2.992 9,687.4 6,453.9 53.54 SHOE Mule Shoe Pup Joint, 3-1/2", 9.3#, J-55, EUE 8rd Pin x mule shoe 2.992 Tubing Description Original Tubing 3-1/2" x 2-7/8" String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 9,687.4 Set Depth (ft… 9,877.4 Set Depth (TVD) (… 6,567.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-BTC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,687.4 6,453.9 53.54 PBR BAKER PBR 3.000 9,701.1 6,462.0 53.52 PACKER BAKER HB RETRIEVABLE PACKER 2.890 9,759.2 6,496.6 53.41 BLAST RINGS CARBIDE BLAST RINGS 2.992 9,825.2 6,536.1 53.06 SLEEVE-C CAMCO CB-1 SLIDING SLEEVE; SHIFT CLOSED 4/27/95 2.750 9,836.7 6,543.0 52.94 PACKER BAKER D PERMANENT PACKER 3.250 9,840.3 6,545.2 52.90 SBE BAKER SEAL BORE EXTENSION 3.250 9,860.5 6,557.3 52.68 NIPPLE OTIS XN NIPPLE NO GO 2.250 9,876.6 6,567.2 52.51 SOS BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 8,137.0 5,530.4 52.23 P2P Packer (Upper) Upper Patch Assembly consisting of P2P packer, hang off XO, spacer pipe, & anchor latch ( OAL 25.72') 10/6/2020 1.625 CPP35276 8,142.0 5,533.5 52.24 Spacer Pipe Spacer pipe (Part of upper packer assembly) 10/6/2020 1.570 CPAI 8,150.0 5,538.4 52.27 TUBING LEAK TUBING LEAK IDENTIFIED WITH ARCHER ACOUSTIC LDL, ~5 GPM AT 3000 PSI 4/8/2020 2.990 8,162.0 5,545.7 52.31 P2P Packer (Lower) Set P2P packer (Lower) 10/5/2020 1.625 CPP35293 9,900.0 6,581.4 52.26 FISH 1 PIECE 5/8"x1"x1/4" OF BROKE SLIP STILL IN HOLE 8/14/2009 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,793.0 9,809.0 6,516.8 6,526.3 C-1, UNIT B, 1R -17 12/15/1991 10.0 IPERF Spiral (72 deg. ) Phasing; 4.5" Csg Gun 9,967.0 10,025.0 6,622.5 6,658.3 A-4, A-3, 1R-17 12/14/1991 4.0 IPERF 180 deg. phase; 4.5" Csg Gun 10,051.0 10,054.0 6,674.3 6,676.2 A-2, 1R-17 12/14/1991 4.0 IPERF 180 deg. phase; 4.5" Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com 9,932.0 9,940.0 6,601.0 6,605.9 Squeeze Perforating 4 SPF; 22.5 deg. phasing 10,032.0 10,040.0 6,662.6 6,667.5 Squeeze Perforating 4 SPF; 22.5 deg. phasing 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 9,503.0 6,344.7 Camco MMG 1 1/2 INJ OPEN 10/2/2020 2 9,745.0 6,488.1 CAMCO MMG-W 1 1/2 INJ DMY RK 0.000 0.0 6/14/1992 Notes: General & Safety End Date Annotation 10/18/2010 NOTE: View Schematic w/ Alaska Schematic9.0 1R-17, 10/7/2020 8:00:00 AM Vertical schematic (actual) PRODUCTION; 37.8-10,338.9 IPERF; 10,051.0-10,054.0 Squeeze Perforating; 10,032.0 ftKB IPERF; 9,967.0-10,025.0 Squeeze Perforating; 9,932.0 ftKB FISH; 9,900.0 SOS; 9,876.6 NIPPLE; 9,860.5 SBE; 9,840.3 PACKER; 9,836.7 SLEEVE-C; 9,825.2 IPERF; 9,793.0-9,809.0 INJECTION; 9,745.0 PACKER; 9,701.1 PBR; 9,687.4 SHOE; 9,687.4 LOCATING COLLAR; 9,686.9 NIPPLE; 9,644.0 PACKER; 9,590.6 PBR; 9,567.3 SEAL ASSY; 9,561.0 LOCATOR; 9,560.0 GAS LIFT; 9,503.0 P2P Packer (Lower); 8,162.0 Spacer Pipe; 8,142.0 TUBING LEAK; 8,150.0 P2P Packer (Upper); 8,137.0 SURFACE; 42.2-5,702.7 CONDUCTOR; 43.0-120.0 HANGER; 21.5 KUP INJ KB-Grd (ft) 42.99 Rig Release Date 9/20/1991 1R-17 ... TD Act Btm (ftKB) 10,345.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292221200 Wellbore Status INJ Max Angle & MD Incl (°) 60.15 MD (ftKB) 2,800.00 WELLNAME WELLBORE1R-17 Annotation Last WO: End Date 2/25/2016 H2S (ppm) DateComment SSSV: NONE 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): 10339 NA None Casing Collapse Conductor NA Surface NA Production NA 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:6/17/2020 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 Well Integrity & Compliance Specialist Jan Byrne / Dusty Freeborn n1617@conocophillips.com 10301 120 120 10339 77 16 9.625 7 5661 Length TVD Burst 9697 MD NA NA NA 4024 6853 5703 6853 9644 PRESENT WELL CONDITION SUMMARY 6428 9644 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025628 / ADL0025635 191-114 P.O. Box 100630, Anchorage, Alaska 99508 50029222120000 ConocoPhillips Alaska, Inc. Kuparuk River Field / Kuparuk River Oil Pool KRU 1R-17 COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): 6517 - 6676 Perforation Depth TVD (ft):Tubing Size: 9793 - 10054 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. 659-7224 47B2 FHL Retrievable packer None 9591 / 6396 None Size Authorized Signature: 7/15/2020 3.5 Perforation Depth MD (ft): L-80 m n P 66 t Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:43 pm, Jun 17, 2020 320-269 Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: Kuparuk, F-wing, F-217 Date: 2020-06-17 13:34:17 Foxit PhantomPDF Version: 9.7.0 jan.byrne@conoco phillips.com DSR-6/17/2020 X 10-404 X X DLB 06/17/2020VTL 7/13/20Comm 7/13/2020 dts 7/13/2020 JLC 7/13/2020 RBDMS HEW 7/16/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 17 June 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 1R-17 (PTD 191-114) to install a retrievable tubing patch over a known tubing leak. Please contact Dusty Freeborn or myself at 659-7224 if you have any questions. Sincerely, Jan Byrne Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: Kuparuk, F-wing, F-217 Date: 2020-06-17 13:34:00 Foxit PhantomPDF Version: 9.7.0 jan.byrne@co nocophillips.c om 1R-17 Proposal 1. Set ~27’ overall length, 3.5” retrievable tubing patch over tubing leak at 8150’. 2. Perform MITIA. 3. Bring well online and allow to stabilize. 4. Perform AOGCC witnessed MITIA. 5. Submit 10-404. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 10,118.0 11/10/2018 1R-17 fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: SET CA2 PLUG, ANNOTATE TUBING LEAK 4/9/2020 1R-17 condijw Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 43.0 Set Depth (ftKB) 120.0 Set Depth (TVD) … 120.0 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) 42.2 Set Depth (ftKB) 5,702.7 Set Depth (TVD) … 4,024.0 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 37.8 Set Depth (ftKB) 10,338.9 Set Depth (TVD) … 6,852.8 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC-MOD Tubing Strings Tubing Description TUBING RWO 2016 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 21.5 Set Depth (ft… 9,697.1 Set Depth (TVD) (… 6,459.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 21.5 21.5 0.08 HANGER FMC Tubing Hanger, TC-1A-EN, 6" x 3-1/2" EUE 8rd Box x Box, 3" ISA BPVG 2.992 9,560.0 6,378.3 53.75 LOCATOR Locator Sub, GBH-22 (bottom of locator spaced out 6.91') 2.990 9,561.0 6,378.9 53.75 SEAL ASSY Seal Assembly, 80-40 (total seal assembly length = 21.70') 2.990 9,567.3 6,382.6 53.73 PBR PBR, 80-40 4.000 9,590.6 6,396.4 53.67 PACKER 47B2 FHL Retrievable Packer (shear ring = 60K) 2.960 9,644.0 6,428.1 53.59 NIPPLE Nipple, Camco, 2.813" DS, SN: 3651-8 2.812 9,686.9 6,453.6 53.54 LOCATING COLLAR Locating Collar, 3-1/2, 9.3#, J-55, EUE 8rd Mod Box x Box 2.992 9,687.4 6,453.9 53.54 SHOE Mule Shoe Pup Joint, 3-1/2", 9.3#, J-55, EUE 8rd Pin x mule shoe 2.992 Tubing Description Original Tubing 3-1/2" x 2-7/8" String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 9,687.4 Set Depth (ft… 9,877.4 Set Depth (TVD) (… 6,567.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-BTC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,687.4 6,453.9 53.54 PBR BAKER PBR 3.000 9,701.1 6,462.0 53.52 PACKER BAKER HB RETRIEVABLE PACKER 2.890 9,759.2 6,496.6 53.41 BLAST RINGS CARBIDE BLAST RINGS 2.992 9,825.2 6,536.1 53.06 SLEEVE-C CAMCO CB-1 SLIDING SLEEVE; SHIFT CLOSED 4/27/95 2.750 9,836.7 6,543.0 52.94 PACKER BAKER D PERMANENT PACKER 3.250 9,840.3 6,545.2 52.90 SBE BAKER SEAL BORE EXTENSION 3.250 9,860.5 6,557.3 52.68 NIPPLE OTIS XN NIPPLE NO GO 2.250 9,876.6 6,567.2 52.51 SOS BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 8,150.0 5,538.4 52.27 TUBING LEAK TUBING LEAK IDENTIFIED WITH ARCHER ACOUSTIC LDL, ~5 GPM AT 3000 PSI 4/8/2020 2.990 9,644.0 6,428.1 53.59 PLUG 2.81" CA-2 PLUG, 3/23/2020 0.000 9,900.0 6,581.4 52.26 FISH 1 PIECE 5/8"x1"x1/4" OF BROKE SLIP STILL IN HOLE 8/14/2009 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,793.0 9,809.0 6,516.8 6,526.3 C-1, UNIT B, 1R -17 12/15/1991 10.0 IPERF Spiral (72 deg. ) Phasing; 4.5" Csg Gun 9,967.0 10,025.0 6,622.5 6,658.3 A-4, A-3, 1R-17 12/14/1991 4.0 IPERF 180 deg. phase; 4.5" Csg Gun 10,051.0 10,054.0 6,674.3 6,676.2 A-2, 1R-17 12/14/1991 4.0 IPERF 180 deg. phase; 4.5" Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 9,932.0 9,940.0 6,601.0 6,605.9 Cement Squeeze 12/4/1991 10,032.0 10,040.0 6,662.6 6,667.5 Cement Squeeze 12/4/1991 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 9,503.0 6,344.7 Camco MMG 1 1/2 INJ DMY RK 0.000 0.0 3/4/2016 2 9,745.0 6,488.1 CAMCO MMG-W 1 1/2 INJ DMY RK 0.000 0.0 6/14/1992 Notes: General & Safety End Date Annotation 10/18/2010 NOTE: View Schematic w/ Alaska Schematic9.0 1R-17, 4/10/2020 6:05:48 AM Vertical schematic (actual) PRODUCTION; 37.8-10,338.9 IPERF; 10,051.0-10,054.0 Squeeze Perforating; 10,032.0 ftKB IPERF; 9,967.0-10,025.0 Squeeze Perforating; 9,932.0 ftKB FISH; 9,900.0 PACKER; 9,836.7 IPERF; 9,793.0-9,809.0 INJECTION; 9,745.0 PACKER; 9,701.1 PLUG; 9,644.0 NIPPLE; 9,644.0 PACKER; 9,590.6 GAS LIFT; 9,503.0 TUBING LEAK; 8,150.0 SURFACE; 42.2-5,702.7 CONDUCTOR; 43.0-120.0 HANGER; 21.5 KUP INJ KB-Grd (ft) 42.99 Rig Release Date 9/20/1991 1R-17 ... TD Act Btm (ftKB) 10,345.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292221200 Wellbore Status INJ Max Angle & MD Incl (°) 60.15 MD (ftKB) 2,800.00 WELLNAME WELLBORE1R-17 Annotation Last WO: End Date 2/25/2016 H2S (ppm) DateComment SSSV: NONE https://readcasedhole-my.sharepoint.com/personal/diane_williams_readcasedhole_com/Documents/D Drive/Achives/MasterTemplateFiles/Templates/Distribution/TransmittalSheets/ConocoPhillips_Transmit.docx Well Log Transmittal To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : READ Cased Hole, Inc. Attn: Diane Williams 4141 B Street Suite 308 Anchorage, AK 99503 Diane.Williams@readcasedhole.com 1) Leak Point™ Survey 08-Apr-20 1R-17 CD 50-029-22212-00 2) Signed : ______________________________________ Date : ___________________ Print Name: ______________________________________ READ CASED HOLE, INC, 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-ANCHORAGE@READCASEDHOLE.COM WEBSITE : WWW.READCASEDHOLE.COM Received by the AOGCC on 04/22/2020 PTD: 1911140 E-Set: 32776 Abby Bell Abby Bell 04/22/2020 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Friday, March 20, 2020 6:47 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: RE: KRU 111-17(PTD 191-114) Report of high IA pressure Attachments: 1 R-17 90 Day TIO plot.PNG Chris, KRU injector 111-17 (PTD 191-114) failed the diagnostics MIT -IA today. The well was shut in and the TIOs have stabilized around 1775/1625/10 psi. As previously communicated, diagnostics will continue and the proper paperwork for continued injection or repair will be submitted as required. Attached is the current 90 day TIO trend. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM ConocoP7aYips From: We ntegri Sent: Wednes To: Wallace, Chris Cc: CPA Wells Supt ty Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> March 18, 2020 5:28 PM Subject: KRU 111-17 (PTD Chris, <chris.wa I lace@a la ska.gov> )@conocophillips.com>; Well Integrity Compliance Specialist CPF1 & 2 Report of high IA pressure KRU injector 111-17 (PTD 191-114) was reporte y operations with the IA pressure at 2450 psi. The operator attempted to bleed the IA pressure, but the IA re-ftessurized quickly. The well will be shut in and freeze protected as soon as reasonably possible. CPA[ intends to performdi4gnostics to determine the failure mechanism. At the completion of diagnostics, CPAI will submit proper pal a 90 -day TIO plot and a wellbore schematic. Please let me know if you disagree with this plan. Regards, Paul Duffy for Jan Byrne/Dusty Freeborn Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM ConocpPHtlips for continued injection or repair as required. Attached is Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Wednesday, March 18, 2020 5:28 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: KRU 1 R-17 (PTD 191-114) Report of high IA pressure Attachments: 1 R-17 90 day TIO plot 3-18-20.pdf, 1 R-17.pdf Chris, KRU injector 1R-17 (PTD 191-114) was reported by operations with the IA pressure at "2450 psi. The operator attempted to bleed the IA pressure, but the IA re -pressurized quickly. The well will be shut in and freeze protected as soon as reasonably possible. CPAI intends to perform diagnostics to determine the failure mechanism. At the completion of diagnostics, CPAI will submit proper paperwork for continued injection or repair as required. Attached is a 90 -day TIO plot and a wellbore schematic. Please let me know if you disagree with this plan. Regards, Paul Duffy for Jan Byrne/Dusty Freeborn Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM Cpnoco`RhiYlps MEMORANDUM State of Alaska Pretest Initial 15 Min 30 Min 45 Min 60 Min 2i?a 2450-F2450- 'i50 IA "30 1910 1880 I80 OA '0 20 20 - 20 Alaska Oil and Gas Conservation Commission TO: Jim Reg q S'�iL/t DATE: Monday, May 20, 2019 SUBJECT: Mechanical Integrity Tests P.I. Supervisor 1 CONOCOPHILLIPS ALASKA, INC. IR -17 FROM: Adam Earl KUPARUK RIV UNIT IR -17 Petroleum Inspector Src: Inspector Reviewed By: rnn P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1R-17 Insp Num: mitAGE190510092205 Rel Insp Num: API Well Number 50-029-22212-00-00 Inspector Name: Adam Earl Permit Number: 191-114-0 Inspection Date: 5/8/2019 ✓ Packer Well e-17 TypeInj ti 'TVD PTD 1911140 T.Test SPT Test psi BBL Pumped: BBL Returned: 1 Depth 6462 -Tubing Pretest Initial 15 Min 30 Min 45 Min 60 Min 2i?a 2450-F2450- 'i50 IA "30 1910 1880 I80 OA '0 20 20 - 20 1616 - I2 - P - Intervale: 4YR-IS2 - IP/F Notes: MIT IA - _-- _�— Monday, May 20, 2019 Page 1 of I 191114 Schlumberger 14 -MARCH -2019 Notice of Revisions Please find the enclosed data set for well 1R-17 Final Field IPROF Veit, to super- sede all previous editions received. Revisions made were isolated to 1R-17 Final Field IPROF Ver2. No other well data has been changed. Joseph D. Wilson Data Speaa&t; PetroTecGnical Servicer Schlumberger 6411 A Street Anchorage, AK 99518 1 CELL: (907)240-4838 OFFICE (907)273-1702 Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700main (907)273-4760fax Delivered to: 7 3 AOGCC ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision •. 333 W. 7th Ave, Suite 100 -•yg Anchorage, AK 99501 191114 TRANSMITTAL DATE �. TRANSMITTAL#,. WELL NAME 1R-17 1 E•168L1 1C-190 API ti 50-029-22212-00 50-029-23230-60 50-029.23136.00 ORDERSERVICE # '1111 EA77-00002 E9OU-00005 E9OU-00006 FIELD NAME KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER DESCRIPTION DELIVERABLE WL WL WL DESCRIPTION (PROF Ver2 IPROF IPROF DATA TYPE FINAL FIELD FINAL FIELD FINAL FIELD DATELOGGED Prints 13 -Feb -19 23 -Feb -19 23 -Feb -19 CD's 1 1 1 1J-164 50-029.23278-00 E9OU-00007 KUPARUK RIVER Memory (PROF FINAL FIELD 25 -Fah -19 1 1J-136 50-029-23331-00 E9OU-00009 KUPARUK RIVER Memory IPROF FINAL FIELD 26 -Feb -19 1 2M-21 50-103-20156-00 E540-00062 KUPARUK RIVER WL Caliper FINAL FIELD 7 -Mar -19 1 AOGee 6 Signature Please return via courier or sign/scan and email a copy Date lumberger and CPAI. Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. - specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. SLB Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Deliveredto: $/ AOGCC s ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 -qd6 Anchorage, AK 99501 TRANSMITTALDATE TRANSIVIM N 1R-26 3M-26 IR -01B 1R-04 1F-07 .. # 50.029-22193-00 50-029-22431.00 50.029.21404-02 50-029-21407-00 50-029••20830-00 ORDERSERVICE DWUJ-00077 DWUJ-00078 DWUJ-00079 DWUJ-00080 E9KH-00003 FIELD NAME DESCRIPTION KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL's WL WL WL WL DELIVERABLE DESCRIPTIONDATA EMIT Caliper P EMIT EMIT PPROF TYPEColor FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD r. TELOGGED Prints 2 -Feb -19 4 -Feb -19 5 -Feb -19 6 -Feb -19 9 -Feb -19 r IIIIIIII 1 1 1 1 1 1B -15A 1R-17 50.029-22465-01 50-029-22212-00 EA77-00001 EA77-00006 KUPARUK RIVER KUPARUK RIVER WL WL1 PPROF (PROF FINAL FIELD FINAL FIELD 12 -Feb -19 13 -Feb -19 1 7 Signatu Please return via courier or sign/scan and email a Date Schlumberger and CPAI. Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the ;package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. III S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,April 08,2016 TO: Jim Regg P.I.Supervisor '-1-ZC (t 4(l gp SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IR-17 FROM: Jeff Jones KUPARUK RIV UNIT 1R-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry JE - NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1R-17 API Well Number 50-029-22212-00-00 Inspector Name: Jeff Jones Permit Number: 191-114-0 Inspection Date: 4/3/2016 Insp Num: mitJJ160403I60741 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IR-17 Type Inj W' TVD 6462 ' ,Tubing 1960 ,1 1960- 1960 - 1960 PTD 1911140 Type Test SPT Test psi 1616 - IA 695 2800 - 2770 - 2760 - 1 Interval ITA �P/F P ✓ OA 80 , 85 — 85 , 85 Notes: 2 BBLS diesel pumped. 1 well inspected,no exceptions noted. . SCANNED SEP 2 7 2016 Friday,April 08,2016 Page 1 of 1 E OF ALASKA KRU 1R-17 A KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations E Fracture Stimulate fl Pull Tubing IF Operations Shutdown E Performed: Suspend E Perforate E Other Stimulate I Alter Casing E Change Approved Program 1 Plug for Redrill r Perforate New Pool Repair Well F Re-enter Susp Well E I-- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development E Exploratory E 191-114 3.Address: 6.API Number: Stratigraphic l Service F P.O. Box 100360,Anchorage,Alaska 99510 50-029-22212-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25635,ADL 25628 KRU 1 R-17 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10345 feet Plugs(measured) 9730, 9861 true vertical 6857 feet Junk(measured) 9900 Effective Depth measured 10253 feet Packer(measured) 9591,9701,9837 true vertical 6798 feet (true vertical) 6396,6462,6543 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 120 120 SURFACE 5661 12 5703 4024 PRODUCTION 10301 7 10339 6853 RECEIVED Perforation depth: Measured depth: 9793-9809,9967-10025, 10051-10054 True Vertical Depth: 6517-6526,6622-6558, 6674-6676 MVM A k 03 2016 AOGCC Tubing(size,grade,MD,and TVD) 3 1/2 x 2 7/8, L-80,9877 MD,6568 TVD Packers&SSSV(type,MD,and TVD) PACKER-4782 FHL Retrievable Packer(shear ring+60K)9591 MD,6396 TVD PACKER-BAKER HB Retrievable Packer 9701 MD,6462 ND PACKER-BAKER D Permanent Packer 9837 MD,6543 ND SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: S ) ,f ;i, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-in Subsequent to operation waiting for hookup 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F , Exploratory E Development fl Service F Stratigraphic E Copies of Logs and Surveys Run E , 16.Well Status after work: Oil E Gas E WDSPL E Printed and Electronic Fracture Stimulation Data E GSTOR E WINJ E WAG F GINJ E SUSP E SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-031 Contact Danny Kane Cad.265-6048 Email danny.kaneaconocoohillips.com Printed Name Danny Kane Title Senior Wells Engineer Signature , Phone:265-6048 Date 02—MkQ -2411(p 1/77, / G Form 10-404 Revised 5/2015 AB,, )MA RBDMS t.1. MAR 0 4 2016 Submit Original Only 1 R-17 • • DTTMS.JOBTYP SUMMARYOPS 2/21 RE RU berming around the sub, pits, and cuttings box. Complete rig acceptance checklist, start taking on COMPL seawater to the pits, and accept the rig at 04:00 hours. Install secondary IA valve and RU to circulate ETION through the rig choke utilizing the cellar manifold to the kill tank. RU the lubricator, pull the ISA BPV, and RD the lubricator. PT all lines from the pits to the kill tank to 2600 psi. Reverse circulate 43 bbls of seawater to the kill tank. While circulating seawater to the kill tank at 3 BPM = 120 psi the rupture disc on the SSV burst closing the SSV causing a pump pressure increase and setting off the pop off on mud pump#2. A mist of hydraulic fluid was released spilling 1/2 cup of hydraulic fluid onto containment. Hydraulic fluid was clean up with absorb and disposed of properly. An employee got hydraulic fluid in contact with their eyes and exposed skin. Employee was sent to the medic for evaluation and released back to work by the medic. Valve crew replaced the rupture disc and added a gauge to the SSV to monitor the pressure. Continue to circulate seawater to the kill tank until good seawater to surface. Line up to take returns through the gas buster to the pits. Circulate an additional 340 bbls of seawater at 4 BPM = 579 psi. Monitor the well for flow and had a slight flow from the tubing for 15 minutes then flow stopped. Monitor the well for flow for 30 minutes and the well is static. 2/22 RE Install 3" 'ISA' BPV with dry rod. ND the tree, ND the tubing head adapter, and install the blanking plug. COMPL NU the DSA the tubing head and NU the BOP stack. RU BOPE testing equipment. Conduct initial ETION BOPE test to 250/3000 psi: test 2-7/8"x 5"VBR's (upper and lower pipe rams)with 3-1/2"test joint; test annular to 250/2500 with 3-1/2"test joints; conducted Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Jeff Jones via email on 2/21/16 at 06:40 hours. RD BOPE testing equipment. RU to pull completion and pull 3" ISA BPV with dry rod. BOLDS, unseat tubing hanger, and PU to max pull of 140K but tubing is not free. Work the tubing up to max pull of 140K with pumps on and pumps off. Tubing finally pulled free at 120K. Observe the well for flow. The well is static. POOH laying down 3-1/2"tubing spooling control line from 9666' RKB to SCSSSV at 7866' RKB. Lay down SCSSSV. Recovered 26 of the 33 stainless steel bands. RD Camco control line spooling unit. 2/23 RE Continue to POOH laying down 3-1/2" tubing from 7866' to 2795' RKB. PU, MU, and RIH with the storm COMPL packer. Set storm packer at 107' (center of element) and PT to 1000 psi (good test). ND the BOP ETION stack and ND the tubing head with Hydratight(casing growth = 7.0"). Spear the 7"casing, remove the packoff, re-land in slips, cut off excess casing, and install new packoff. NU the tubing head, PT void to 2500 psi (good test), NU the BOP stack, and PT breaks to 250/3000 psi (good test). Continue POOH laying down 3-1/2"tubing from 2795' to 500' RKB. 2/24 RE Continue to POOH laying down 3-1/2"tubing from 500'to surface. Recovered 5 GLM's, nipple COMPL assembly, and seal assembly. SLB chemical cut failed (-70%cut). PU, MU, and RIH with stacked ETION packer completion on 3-1/2"tubing to 9674'. Circulate 90 bbls of corrosion inhibited seawater at 3 BPM. Drop the ball & rod and locate on the PBR. Pressure up on the tubing to 2500 psi to set the FHL packer. PT the IA to 3000 psi for 10 minutes (good test)to confirm that the packer is set. With 2000 psi still on the tubing PU 10K over to shear the PBR. Circulate remaining 200 bbls of corrosion inhibited seawater at 4 BPM and chase with 75 bbls of seawater at 5 BPM. Engage the seal assembly into the PBR, locate out, and space out with pups. MU the FMC tubing hanger, land the tubing hanger, and RILDS. PT the tubing to 3500 psi for 15 minutes (good test) and PT the IA to 3000 psi for 30 minutes (good test). Quickly ramp up the IA to shear the SOV(sheared at 2100 psi). 2/25 RE Install 3" ISA BPV and perform CPAI Between Wells Maintenance (BWM)on the BOP stack. ND the COMPL BOP stack, NU the tubing head adapter, and NU the tree. Pull the BPV and install tree test plug. PT ETION the tree and tubing hanger void to 250/5000 (good test). Pull tree test plug and freeze protect the well with 81 bbls of diesel. Place the tubing and IA in communication allowing the well to u-tube and equalize. Install 3" ISA BPV Blow down all circulating line, RD all cellar lines, and RD annulus valve. Install gauges on the tree, secure the well, and secure the cellar. Release the rig at 20:00 hours. L KUP I� 1R-17 ConotoPhiiiip5 / 4 Well Attributes Max Angle TD AI 1=,itcj.int, Wellbore API/UWI Field Name Wellbore Status ncl('I MD(ftKB) Act Btm(ftKB) Cava;Phillips 500292221200 KUPARUK RIVER UNIT INJ 60.15 2,800.00 10,345.0 f Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 10-17,3/2/201611;00.40 AM SSSV:NONE Last WO: 2/25/2016 42.99 9/20/1991 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 10,145.0 4/17/2014 Rev Reason:WORKOVER lehalif 3/1/2016 HANGER',21.5 - 1i1_ Casing Strings Casing Description OD En) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WULen(...Grade Top Thread CONDUCTOR 16 15.062 43.0 120.0 120.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread - - SURFACE 95/8 8.921 42.2 5,702.7 4,024.0 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtiLen(I...Grade Top Thread i 'A ""` "'PRODUCTION 7 6.276 37.8 10,338.9 6,852.8 26.00 J-55 BTC-MOD - - Tubing Strings Tubing Description Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(TOD)(...Wt(Iblft) Grade Top Connection TUBING RWO 2016 1String 3 1/21 2.9921 21.51 9,697.11 6,459.61 9.301 L-80 !Top 8rd Mod Completion Details CONDUCTOR;43.0-120.0 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inc)C) Item Des Com (in) 21.5 21.5 0.08 HANGER FMC Tubing Hanger,TC-1A-EN,6"x 3-1/2"EUE 8rd Box 2.992 x Box,3"ISA BPVG • • 9,560.0 6,378.3 53.75 LOCATOR Locator Sub,GBH-22(bottom of locator spaced out 6.91') 2.990 SURFACE;42.2-5,702.7 ' 9,561.0 6,378.9 53.75 SEAL ASSY Seal Assembly,80-40(total seal assembly length= 2.990 21.70') 9,567.3 6,382.6 53.73 PBR PBR,80-40 4.000 GAS LIFT sso3.0 9,590.6 6,396.4 53.67 PACKER 47B2 FHL Retrievable Packer(shear ring=60K) 2.960 9,644.0 6,428.1 53.59 NIPPLE Nipple,Camco,2.813"DS,SN:3651-8 2.812 9,686.9 6,453.6 53.54 LOCATING Locating Collar,3-1/2,9.38,J-55,EUE 8rd Mod Box x 2.992 COLLAR Box I It 9,687.4 6,453.9 53.54 SHOE Mule Shoe Pup Joint,3-1/2",9.3#,J-55,EUE 8rd Pin x 2.992 LOCATOR;9,560.0 ilr mule shoe SEAL ASSY;9,561.0 Tubing Description String Ma... ID(in) Top(0KB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection - Original Tubing 3-1/2" 31/2 2.992 9.687.4 9,877.4 6,567.6 9.30 L-80 ABM-BTC PBR,9,567.3 amnia, x 2-7/8" yilDir PACKER;9,590.6 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) 9,687.4 6,453.9 53.54 PBR BAKER PBR 3.000 9,701.1 6,462.0 53.52 PACKER BAKER HB RETRIEVABLE PACKER 2.890 Ball B Rod;9,637.3 /- 9,759.2 6,496.6 53.41 BLAST CARBIDE BLAST RINGS 2.992 ' RINGS NIPPLE,9,6440 RMC Plug Body;9,844.2, ' 9,825.2 6,536.1 53.06 SLEEVE-C CAMCO CB-1 SLIDING SLEEVE;SHIFT CLOSED 2.750 ' ;1 4/27/95 9,836.7 6,543.0 52.94 PACKER BAKER D PERMANENT PACKER 3.250 ~ 9,840.3 6,545.2 52.90 SBE BAKER SEAL BORE EXTENSION 3.250 LOCATING COLLAR;96869 9,860.5 6,557.3 52.68 NIPPLE OTIS XN NIPPLE NO GO 2.250 SHOE,9,687.4 , 9,876.6 6,567.2 52.51 SOS BAKER SHEAR OUT SUB 2.441 PBR;9,687.4 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PACKER,9,701.1 Top(TVD) Top Incl Top(ftKB) (ftKB) C) Des Com Run Date ID(in) 9,637.3 6,424.1 53.60 Ball 8 Rod Ball 8 Rod 2/24/2016 0.000 PLUG,9,7300 9,644.3 6,428.2 53.59 RHC Plug RHC Plug Body 2/24/2016 1.000 Body 11 9,730.0 6,4792 53.46 PLUG 2.13"BAKER IBP 5/21/2014 INJECTION;9,745.0 9,861.0 6,557.7 52.68 2.25 XXN XXN PLUG IN XN NIPPLE PLUG 4/19/2014 9,900.0 6,581.4 52.26 FISH 1 PIECE 5/8"x1"x1/4"OF BROKE SLIP STILL IN 8/14/2009 0.000 HOLE IPERF;9,793.0-9,809.0- _ Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com SLEEVE-C;9,825.2 9,793.0 9,809.0 6,516.8 6,526.3 C-1,UNIT B, 12/15/1991 10.0 IPERF Spiral(72 deg.) 1R-17 Phasing;4.5"Csg Gun 9,967.0 10,025.0 6,622.5 6,658.3 A-4,A-3,1R- 12/14/1991 4.0 IPERF 180 deg.phase;4.5" 17 Csg Gun PACKER 9,836.7 ®e' 10,051.0 10,054.0 6,674.3. 6,676.2 A-2,1R-17 1204/1991 4.0 IPERF 180 deg.phase;4.5" SBE,9,840.3 _Tito Csg Gun ICement Squeezes Top(TVD) Btm(TVD( NIPPLE,9,860.5 Top(ftKB) Btm(ftKB) ((MB) (ftKB) Des Start Date Com 9,932.0 9,9400 6,601.0 6,605.9 Cement 12/4/1991 2.25 XXN PLUG,9,861 0 �', Squeeze • 10,032.0 10,040.0 6,662.6 6,667.5 Cement 12/4/1991 Squeeze SOS;9,876.61-1 Mandrel Inserts St au N Top(ND) Valve Latch Port Size TRO Run FISH;9,900.0 Top MB) (ftKB) Make Model 0110110/11122) Sery Type Type (in) (psi) Run Date Com 1 9.503.0 6,344.7 CamcoMMG INJ SOV RKP 0.000 0.0 2/24/2016 2 9,745.0 6,488.1 CAMCO MMG- INJ DMY RK 0.000 0.0 6040992 IW IPERF;9,967.0-10,025.0 I I Notes:General&Safety IPERF;10,051.0-10,054.0-.1 (O End Date Annotation 10/18/2010 NOTE:View Schematic w/Alaska Schematic9.0 IPERF;10,051.0.10,054.0 PRODUCTION;37.8-10,338.9 • • Operations Summary (with Timelog Depths) ={_ &We11s 1R-17 ocot*taiiilips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/16/2016 2/16/2016 4.00 MIRU MOVE RURD P Blow down and RD the pits. Bridle up 0.0 0.0 00:00 04:00 and lower the cattle chute. Shut off the steam and blow down the steam lines. Remove and replace condensate line. 2/16/2016 2/16/2016 2.00 MIRU MOVE RURD P Lower the derrick and secure. Clean 0.0 0.0 04:00 06:00 the cellar box. 2/16/2016 2/16/2016 2.50 MIRU MOVE RURD P Finish cleaning the cellar. Pick up 0.0 0.0 06:00 08:30 area for rig move. RD berming around cuttings box,pits,and sub. Complete pre-rig move checklist for the pits. 2/16/2016 2/16/2016 3.50 MIRU MOVE RURD P Continue to dig out and RD the 0.0 0.0 08:30 12:00 berming behind the sub. Rig off high line power at 09:00 hours. Clean and organize the rig. 2/16/2016 2/16/2016 6.00 MIRU MOVE WAIT P Wait for roads and pads to clear the 0.0 0.0 12:00 18:00 roads after phase 3 weather. SimOps: remove old steam pipe from the boiler room. Remove burrs off 1502 hammer unions and inner connect unions. Remove and replace choke valve#11. Change hydraulic hose on emergency brake bottles. Inspect the move system. 2/16/2016 2/16/2016 2.00 MIRU MOVE RURD P Dig out the jeep for the pits and hook 0.0 0.0 18:00 20:00 up the jeep to the pits. Prep the shops and satellite office to move. Fuel up the shop,pits,and satellite office. Move parts house and cutting box to 2H pad. 2/16/2016 2/16/2016 1.00 MIRU MOVE MOB P Move parts house and cutting box to 0.0 0.0 20:00 21:00 2H pad. 2/16/2016 2/16/2016 2.00 MIRU MOVE MOB P Pull the pits away from the sub. Move 0.0 0.0 21:00 23:00 the pits,shop,and satellite office from 2K pad to four corners. Pull the sub off well 2K-01 and stage in the middle of the pad. 2/16/2016 2/17/2016 1.00 MIRU MOVE RURD P Remove herculite and rig mats from 0.0 0.0 23:00 00:00 around well 2K-01. Continue to load out miscellaneous equipment 2/17/2016 2/17/2016 4.00 MIRU MOVE MOB P Move the pits,shop,and satellite 0.0 0.0 00:00 04:00 office from four corners to 1R pad. Spot and set up the satellite and shop. Stage the pits near 1R-17. SimOps: Continue to remove herculite and rig mats from around well 2K-01. Clean up around well 2K- 01. Load out rig mats. 2/17/2016 2/17/2016 3.00 MIRU MOVE RGRP T Rear driller side inboard#7 tire went 0.0 0.0 04:00 07:00 flat. Make notifications and call out for support equipment to replace the flat tire. 2/17/2016 2/17/2016 5.00 MIRU MOVE RGRP T RD sub support beam,steam line,air 0.0 0.0 07:00 12:00 line,and electrical. Move BOP stack off the stump. RD hydraulic hoses on the BOP stack and plug ports. RD choke and kill lines from the BOP stack. Page 1/11 Report Printed: 3/15/2016 • S o Milano Operations Summary (with Timelog Depths) 1R-17 conoccehittf ps Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/17/2016 2/17/2016 6.00 MIRU MOVE RGRP T Pull Koomey hoses to the upper 0.0 0.0 12:00 18:00 landing. RD secondary choke hose. Prep secondary kill line for removal. Rotate the BOP stack 180°,place the BOP stack in the cradle,secure,and remove from the cellar. Place boards under#7 and#8 wheel axels,jack up the sub,and spot matting boards under the front and rear beams. Disconnect hydraulic line to the BOP landing. Remove bottom pins and remove the lower cellar wind walls. Remove stop plates on the upper section of the wind walls. 2/17/2016 2/18/2016 6.00 MIRU MOVE RGRP T Remove cellar wind walls. RD 0.0 0.0 18:00 00:00 secondary kill line. Remove cross beams, BOP landings,and wheel well wall. Remove trunnion mount bolts from driller side axel. 2/18/2016 2/18/2016 1.50 MIRU MOVE RGRP T Continue to break trunnion bolts and 0.0 0.0 00:00 01:30 remove trunnion bushing. RU cannon to trunnion,remove wheels from the wheel well room,and stage in the cellar area. 2/18/2016 2/18/2016 4.50 MIRU MOVE RGRP T PJSM. Remove the studs from the 0.0 0.0 01:30 06:00 wheels and remove the wheels. Load the wheel onto a truck and send to Peak to mount new tires. 2/18/2016 2/18/2016 6.00 MIRU MOVE RGRP T Organize and maintain the rig. 0.0 0.0 06:00 12:00 Remove the choke HCR valve. 2/18/2016 2/18/2016 6.00 MIRU MOVE RGRP T Install choke HCR valve onto the BOP 0.0 0.0 12:00 18:00 stack. Organize pieces of the rig on location. Offload#7 tire and prep for installation. 2/18/2016 2/19/2016 6.00 MIRU MOVE RGRP T Install#7 tire onto trunnion and tighten 0.0 0.0 18:00 00:00 bolts. Peak torque to spec. Pick up tools. General housekeeping and maintenance. 2/19/2016 2/19/2016 6.00 MIRU MOVE RGRP T Wait on the tire to be mounted at 0.0 0.0 00:00 06:00 Peak. General housekeeping and maintenance. 2/19/2016 2/19/2016 6.00 MIRU MOVE RGRP T Install tire#8 onto trunnion and tighten 0.0 0.0 06:00 12:00 bolts. Peak torque to spec and finish airing the tires to 140 psi. Position the wheels under the trunnion and install clamps. 2/19/2016 2/19/2016 6.00 MIRU MOVE RGRP T Torque the trunnion bolts and place 0.0 0.0 12:00 18:00 steering arm in wheel well. Install cellar wall beam. Install driller site BOP landing and secondary kill line. 2/19/2016 2/20/2016 6.00 MIRU MOVE RGRP T Set the BOP stack in the cellar with 0.0 0.0 18:00 00:00 winch truck and cradle. Rotate the BOP stack 180°. Connect the Koomey lines. Install the off driller side BOP landings. Secure and MU the secondary kill line. Install the choke line and block to the BOP stack. Page 2/11 Report Printed: 3/15/2016 • • lling Operations Summary (with Timelog Depths) _. &Wells 1 R-17 Coitlips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/20/2016 2/20/2016 4.00 MIRU MOVE RGRP T Hang steam heater and MU steam 0.0 0.0 00:00 04:00 lines. Install the driller side cellar upper wind walls and lower wind walls. Install the off driller side cellar upper wind walls and lower wind walls. Connect the hydraulic line to the BOP landings. Hang the squeeze manifold. 2/20/2016 2/20/2016 1.50 MIRU MOVE RURD P Jack up the sub and pull the matting 0.0 0.0 04:00 05:30 boards. Set the sub down,warm up the moving system,and prep to move the sub. Load out mats and miscellaneous equipment. 2/20/2016 2/20/2016 0.50 MIRU MOVE SFTY P PJSM for moving the sub from 2K pad 0.0 0.0 05:30 06:00 to 1R pad. 2/20/2016 2/20/2016 1.50 MIRU MOVE MOB P Move the sub from 2K pad to 2H pad- 0.0 0.0 06:00 07:30 Check tires 2/20/2016 2/20/2016 1.00 MIRU MOVE MOB P Move the sub from 2K pad to four 0.0 0.0 07:30 08:30 corners. 2/20/2016 2/20/2016 2.25 MIRU MOVE MOB P Move the sub from four corners to 0.0 0.0 08:30 10:45 CPF 2 2/20/2016 2/20/2016 1.00 MIRU MOVE MOB P Move the sub from CPF 2 to 2X 0.0 0.0 10:45 11:45 access road. Stop and let traffic bye. 2/20/2016 2/20/2016 2.75 MIRU MOVE MOB P Move the sub from 2X access road to 0.0 0.0 11:45 14:30 Oliktok Y. Stop and let traffic bye. 2/20/2016 2/20/2016 0.50 MIRU MOVE MOB P Move the sub from Oliktok Y to 1G/1R 0.0 0.0 14:30 15:00 access road. 2/20/2016 2/20/2016 0.75 MIRU MOVE MOB P Move the sub from 1G/1R access to 0.0 0.0 15:00 15:45 1G Pad. 2/20/2016 2/20/2016 0.75 MIRU MOVE MOB P Move the sub from 1G Pad to 1R Pad. 0.0 0.0 15:45 16:30 2/20/2016 2/20/2016 1.00 MIRU MOVE MOB P Position the sub in front of 1R-17 to 0.0 0.0 16:30 17:30 raise the derrick. 2/20/2016 2/20/2016 2.00 MIRU MOVE RURD P Hang the tree in the cellar and raise 0.0 0.0 17:30 19:30 the derrick. 2/20/2016 2/20/2016 2.00 MIRU MOVE MOB P Lay out herculite for the cellar. Place 0.0 0.0 19:30 21:30 wellhead equipment in the cellar. Spot the sub over well 1R-17. Lay herculite in front of the rig for the fuel tank and set the sub down. 2/20/2016 2/21/2016 2.50 MIRU MOVE MOB P PJSM. Spot the pits to the sub,lay 0.0 0.0 21:30 00:00 out herculite,and set the pits down. Spot the cuttings box to the pits. 2/21/2016 2/21/2016 2.50 MIRU MOVE RURD P RU berming around the sub,pits,and 0.0 0.0 00:00 02:30 cuttings box. Hook up the interconnect. 2/21/2016 2/21/2016 1.50 MIRU MOVE RURD P Bridal down. Finish berming, 0.0 0.0 02:30 04:00 complete rig acceptance checklist, start taking on seawater to the pits, and accept the rig at 04:00 hours. 2/21/2016 2/21/2016 3.00 MIRU WELCTL RURD P RU the TD to the block,hang bridal 0.0 0.0 04:00 07:00 lines,organize the rig floor,put all subs on the sub rack,and remove A- leg spreader beam. 2/21/2016 2/21/2016 2.50 MIRU WELCTL RURD P Install secondary IA valve and RU to 0.0 0.0 07:00 09:30 circulate through the rig choke utilizing the cellar manifold to the kill tank. Pits loaded with 591 bbls of seawater. Page 3/11 Report Printed: 3/15/2016 • r Drtilll�ileg; Operations Summary (with Timelog Depths) &Wefts • 1R-17 Conoillips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/21/2016 2/21/2016 3.00 MIRU WELCTL MPSP P PU and RU lubricator. PT to 1000 psi 0.0 0.0 09:30 12:30 (good test). Attempt to pull BPV three times but collet on the retrieving tool kept shearing. Re-pin and on the fourth try pulled the BPV(tubing pressure=400 psi and IA pressure= 80 psi. ). RD and lay down the lubricator. 2/21/2016 2/21/2016 0.50 MIRU WELCTL RURD P RU circulating lines to the IA and 0.0 0.0 12:30 13:00 tubing. Line up the rig choke and cellar manifold to the kill tank. PT all lines from the pits to the kill tank to 2600 psi. 2/21/2016 2/21/2016 1.00 MIRU WELCTL KLWL P Bleed gas off the tubing. Reverse 0.0 0.0 13:00 14:00 circulate 43 bbls of seawater down the IA taking returns out the tubing to the kill tank. Shut down the pumps. 2/21/2016 2/21/2016 1.00 MIRU WELCTL KLWL P Line up to pump down the tubing 0.0 0.0 14:00 15:00 taking returns out the IA to the kill tank. Pump 104 bbls at 3 BPM= 120 psi and rupture disc on the SSV burst closing the SSV causing a pump pressure increase and setting off the pop off on mud pump#2. 2/21/2016 2/21/2016 1.50 MIRU WELCTL WAIT T A mist of hydraulic fluid was released 0.0 0.0 15:00 16:30 spilling 1/2 cup of hydraulic fluid onto containment. Hydraulic fluid was clean up with absorb and disposed of properly. An employee got hydraulic fluid in contact with their eyes and exposed skin. Employee was sent to the medic for evaluation and released back to work by the medic. Valve crew was mobilized to location. Replaced the rupture disc and added a gauge to the SSV to monitor the pressure. 2/21/2016 2/21/2016 1.50 MIRU WELCTL KLWL P Circulate 20 bbls to the kill tank at 3 0.0 0.0 16:30 18:00 BPM=65 psi. Shut down the pumps to empty kill tank. Spot the returns truck and empty the kill tank. 2/21/2016 2/21/2016 2.25 MIRU WELCTL KLWL P Continue to circulate seawater down 0.0 0.0 18:00 20:15 the tubing taking returns out the IA to the kill tank until good seawater returns to surface(ICP at 4 BPM= 417 psi and FCP at 5 BPM= 1021 psi). Shut down the pumps. 2/21/2016 2/21/2016 0.25 MIRU WELCTL OWFF P Monitor the well for flow and had slight 0.0 0.0 20:15 20:30 flow from the tubing/IA. RU to circulate back to the pits through the gas buster. 2/21/2016 2/21/2016 1.25 MIRU WELCTL KLWL P Circulate 170 bbls of seawater down 0.0 0.0 20:30 21:45 the tubing taking returns out the IA through the gas buster to the pits at 4 BPM=579 psi. Shut down the pumps. 2/21/2016 2/21/2016 0.25 MIRU WELCTL OWFF P Monitor the well for flow and had slight 0.0 0.0 21:45 22:00 flow from the IA. 2/21/2016 2/21/2016 1.25 MIRU WELCTL KLWL P Circulate 170 bbls of seawater down 0.0 0.0 22:00 23:15 the tubing taking returns out the IA through the gas buster to the pits at 4 BPM=579 psi. Shut down the pumps. Page 4/11 Report Printed: 3/15/2016 • • Operations Summary (with Timelog Depths) 1 R-17 conocoPhiul ps Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/21/2016 2/22/2016 0.75 MIRU WELCTL OWFF P Monitor the well for flow and had a 0.0 0.0 23:15 00:00 slight flow from the tubing for 15 minutes then flow stopped. Monitor the well for flow for 30 minutes and the well is static. 2/22/2016 2/22/2016 1.00 MIRU WELCTL RURD P Drain the gas buster. Blow down and 0.0 0.0 00:00 01:00 RD all circulating lines. 2/22/2016 2/22/2016 0.50 MIRU WHDBOP MPSP P Install 3"'ISA'BPV with dry rod. 0.0 0.0 01:00 01:30 2/22/2016 2/22/2016 1.00 MIRU WHDBOP NUND P ND the tree and pull the tree free with 0.0 0.0 01:30 02:30 the TD at 5K overpull. ND the tubing head adapter and install the blanking plug(12-1/2 right hand turns). 2/22/2016 2/22/2016 3.00 MIRU WHDBOP NUND P NU the DSA the tubing head and NU 0.0 0.0 02:30 05:30 the BOP stack. Install kill line. Install Koomey lines to the annular. Center the stack,install the riser and air up the air boot. 2/22/2016 2/22/2016 0.50 MIRU WHDBOP RURD P RU BOPE testing equipment. 0.0 0.0 05:30 06:00 2/22/2016 2/22/2016 1.50 MIRU WHDBOP RURD P Install 2"1502 on the OA and run 2" 0.0 0.0 06:00 07:30 line to the cuttings tank. Verify valve alignment. Flush/fill BOP stack and choke manifold with fresh water. Shell test the BOP stack to 250/3000 psi (good test). Page 5/11 Report Printed: 3/15/2016 • • Miniing, Operations Summary (with Timelog Depths) &Weds 1R-17 r- CortmaPhibli R-17 ,iHHi Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/22/2016 2/22/2016 5.50 MIRU WHDBOP BOPE P Conduct initial BOPE test to 250/3000 0.0 0.0 07:30 13.00 psi: test 2-7/8"x 5"VBR's(upper and lower pipe rams)with 3-1/2"test joint; test annular to 250/2500 with 3-1/2" test joints;conducted Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Jeff Jones via email on 2/21/16 at 06:40 hours. Tests: 1) Blind Rams,2"Demco Kill, Upper IBOP,Outer Test Spool,Chokes 1,2, 3,&16(Passed) 2) Blind Rams,HCR Kill, Inner Test Spool, Lower IBOP,Chokes 4,5,&6 (Passed) 3) Manual Kill,HT-38 TIW,Chokes 7, 8,&9(Passed) 4) HT-38 Dart Valve,Chokes 10,&11 (Passed) 5) Super Choke and Manual Adjustable Choke(Passed) 6) Chokes 12, 13,&15(Passed) 7) Annular with 3-1/2"test joint (Passed) 8) Upper Pipe Rams with 3-1/2"test joint,Choke 14(Passed) 9) Upper Pipe Rams with 3-1/2"test joint,3-1/2"EUE 8rd TIW,Choke HCR (Passed) 10)Upper Pipe Rams with 3-1/2"test joint, Manual Choke(Passed) 11)Lower Pipe Rams with 3-1/2"test joint(Passed) Conduct Koomey Draw Down Test: Starting Accumulator Pressure=2950 psi Accumulator Pressure After Closer= 1600 psi Pressure Gain of 200 psi= 14 seconds Full System=93 Seconds Average N2(5 Bottles)=1944 psi 2/22/2016 2/22/2016 1.00 MIRU WHDBOP RURD P Blow down BOPE testing 0.0 0.0 13:00 14:00 equipment,pull blanking plug with 3- 1/2"test joint,and RD BOPE testing equipment. 2/22/2016 2/22/2016 2.00 COMPZN RPCOMP RURD P Bring FMC,Camco,and Weatherford 0.0 0.0 14:00 16:00 tools tot he rig floor. RU Weatherford power tongs for 3-1/2"tubing and RU Camco control line spooler. 2/22/2016 2/22/2016 1.00 COMPZN RPCOMP MPSP P Check for pressure under BPV(no 0.0 0.0 16:00 17:00 pressure)and pull 3"ISA BPV with dry rod. 2/22/2016 2/22/2016 0.50 COMPZN RPCOMP RURD P MU landing joint, MU TIW to landing 0.0 0.0 17:00 17:30 joint,MU landing joint to tubing hanger,and MU the TD. Page 6/11 Report Printed: 3/15/2016 • • nOperations Summary (with Timelog Depths) ng &Wells 1R-17 ConocoPhillips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/22/2016 2/22/2016 0.50 COMPZN RPCOMP PULL P PJSM. BOLDS,unseat tubing hanger, 0.0 0.0 17:30 18:00 and PU to max pull of 140K but tubing is not free. Work pipe several time but still not free. Call out for E-line. 2/22/2016 2/22/2016 1.75 COMPZN RPCOMP WAIT T While waiting for E-line continue to 0.0 9,666.0 18:00 19:45 work the tubing up to max pull of 140K with pumps on and pumps off. Tubing finally pulled free at 120K. 2/22/2016 2/22/2016 0.25 COMPZN RPCOMP OWFF P Observe the well for flow. The well is 9,666.0 9,666.0 19:45 20:00 static. Cancelled call out for E-line. 2/22/2016 2/22/2016 3.50 COMPZN RPCOMP PULL P Pull tubing hanger to the rig floor(PU 9,666.0 7,866.0 20:00 23:30 =105K and SO=65K). Lay down landing joint,TIW,and tubing hanger. POOH laying down 3-1/2"tubing spooling control line from 9666'RKB to SCSSSV at 7866'RKB(PU=85K and SO=65K). Lay down SCSSSV. Recovered 27 of the 33 stainless steel bands. Note:5-20K drag on joint#3-8. No drag observed after joint#8. 2/22/2016 2/23/2016 0.50 COMPZN RPCOMP RURD P RD Camco control line spooling unit. 7,866.0 7,866.0 23:30 00:00 Send spooling unit and tools off the rig floor. 2/23/2016 2/23/2016 0.50 COMPZN RPCOMP RURD 'P Remove pulled tubing and SCSSSV 7,866.0 7,866.0 00:00 00:30 from the pipe shed. Load the storm packer and three joints of DP into the pipe shed. 2/23/2016 2/23/2016 5.50 COMPZN RPCOMP PULL P Continue POOH laying down 3-1/2" 7,866.0 2,795.0 00:30 06:00 tubing from 7866'to 2795'RKB(PU= 48K and SO=48K) 2/23/2016 2/23/2016 2.00 COMPZN WELLPR MPSP P Remove air slips and stripping 2,795.0 0.0 06:00 08:00 rubbers. Change elevators to 3-1/2" DP and MU crossover to the tubing. PU,MU,and RIH with storm packer. Set the storm packer at 107'RKB (center of element). Release from storm packer,stand back DP,and lay down running tool. PT the storm packer and 7"casing to 1000 psi for 10 minutes(good test). Bleed off pressure and blow down lines. 2/23/2016 2/23/2016 1.50 COMPZN WELLPR NUND P PJSM. ND the BOP stack,set back 0.0 0.0 08:00 09:30 on stump,and secure. ND the DSA. 2/23/2016 2/23/2016 2.50 COMPZN WELLPR NUND P RU Hydratight system to the tubing 0.0 0.0 09:30 12:00 head and ND the tubing head using Hydratight to control the casing growth. The casing grew 7.0". RD the Hydratight system and remove the tubing head. 2/23/2016 2/23/2016 0.25 COMPZN WELLPR BHAH P PU and MU 7"casing spear. 0.0 0.0 12:00 12:15 2/23/2016 2/23/2016 0.50 COMPZN WELLPR CUTP P Engage spear into the 7"casing,PU 0.0 0.0 12:15 12:45 to 125K,stretched the casing an addtional 11",install emergency slips, and release the spear. 2/23/2016 2/23/2016 0.25 COMPZN WELLPR BHAH P Make service breaks on the 7"casing 0.0 0.0 12:45 13:00 spear and lay the spear down. Page 7/11 Report Printed: 3/15/2016 • • Operations Summary (with Timelog Depths) W ells 1 R-17 h tlips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/23/2016 2/23/2016 1.00 COMPZN WELLPR CUTP P RU the Wachs cutter,cut off the 0.0 0.0 13:00 14:00 excess 7"casing(cut off 1.5'),and RD the Wachs cutter 2/23/2016 2/23/2016 2.00 COMPZN WELLPR WWSP P Install new 7"casing packoff and NU 0.0 0.0 14:00 16:00 new tubing head. 2/23/2016 2/23/2016 0.50 COMPZN WELLPR WWSP P PT void to 2500 psi for 30 minutes 0.0 0.0 16:00 16:30 (good test). 2/23/2016 2/23/2016 3.00 COMPZN WELLPR NUND P NU the DSA and NU the BOP stack. 0.0 0.0 16:30 19:30 Center the stack,torque bolts,and install the riser. 2/23/2016 2/23/2016 1.00 COMPZN WELLPR BOPE P Install the test plug. PT breaks to 0.0 0.0 19:30 20:30 250/3000 psi: break between tubing head and DSA;break between DSA and BOP stack(good test). Blow down testing equipment and RD testing equipment. 2/23/2016 2/23/2016 1.50 COMPZN WELLPR MPSP P MU storm packer retrieving head, RIH, 0.0 2,795.0 20:30 22:00 engage the storm packer and open up the equalizing valve(no pressure on the tubing). Close the annular, PU 4' to release the storm packer,check for pressure(no pressure),and open up the annular. POOH laying down 3 joints of DP and lay down the storm packer. 2/23/2016 2/23/2016 1.75 COMPZN RPCOMP PULL P Continue POOH laying down 3-1/2" 2,795.0 500.0 22:00 23:45 tubing from 2795'to 500'RKB(PU= 33K and SO=33K) 2/23/2016 2/24/2016 0.25 COMPZN RPCOMP OWFF P Pull the air slips and stripping rubbers. 500.0 500.0 23:45 00:00 Monitor the well for 10 minutes. The well is static. 2/24/2016 2/24/2016 1.50 COMPZN RPCOMP PULL P Continue to POOH laying down 3-1/2" 500.0 0.0 00:00 01:30 tubing from 500'to surface. Recovered 5 GLM's,nipple assembly, and seal assembly. SLB chemical cut failed(-70%cut). Note: The tubing between GLM#4 and GLM#5 covered in shmoo like paraffin. 2/24/2016 2/24/2016 1.25 COMPZN RPCOMP RURD P Unload pipe shed of remaining pulled 0.0 0.0 01:30 02:45 tubing and jewelry. Have rig welder make a mule shoe pup joint from one of the good pup joints pulled from the well. Organize the pipe shed into running order. 2/24/2016 2/24/2016 0.25 COMPZN RPCOMP SFTY P PJSM with rig crew and third parties 0.0 0.0 02:45 03:00 for PU and running completion. 2/24/2016 2/24/2016 13.00 COMPZN RPCOMP PUTB P PU and MU mule pup joint, 1 joint of 0.0 9,687.0 03:00 16:00 tubing,nipple assembly, 1 joint of tubing,packer/PBR assembly, 1 joint of tubing,and GLM with SOV. RIH with stacked packer completion on 3- 1/2",9.3#, L-80,EUE 8rd Mod tubing to 9674'.Tag top of PBR, locate out at 9694'RKB,and PU to spot corrosion inhibitor. 2/24/2016 2/24/2016 0.50 COMPZN RPCOMP RURD P RU circulating equipment. 9,687.0 9,687.0 16:00 16:30 Page 8/11 Report Printed: 3/15/2016 • • Operations Summary (with Timelog Depths) 1R-17 ConocoPhinips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/24/2016 2/24/2016 1.00 COMPZN RPCOMP CIRC T Attempt to break circulation but the IA 9,687.0 9,687.0 16:30 17:30 is packed off. SO to locate and PU to previous mark.Work the pump pressure up to 700 psi and able to circulate. Circulate at 2 BPM=230 psi and 3 BPM-45 psi. The IA packed off a couple times but were able to achieve a steady pump rate of 3 BPM. 2/24/2016 2/24/2016 0.50 COMPZN RPCOMP CRIH P Circulate 90 bbls of corrosion inhibited 9,687.0 9,687.0 17:30 18:00 seawater at 3 BPM=347 psi.Shut down the pumps. 2/24/2016 2/24/2016 1.00 COMPZN RPCOMP PACK P Drop the ball&rod and locate on the 9,693.0 9,694.0 18:00 19:00 PBR. Pressure up on the tubing to 2500 psi for 5 minutes to set the FHL packer. SO 20K and bring the pressure up to 3000 psi for 5 minutes. 2/24/2016 2/24/2016 0.50 COMPZN RPCOMP PRTS P Bleed the tubing to 2000 psi,close the 9,694.0 9,694.0 19:00 19:30 upper pipe rams,and PT the IA to 3000 psi for 10 minutes(good test)to confirm that the packer is set. Bleed the pressure off the IA and open up the upper pipe rams. 2/24/2016 2/24/2016 0.50 COMPZN RPCOMP PACK P With 2000 psi still on the tubing PU 9,694.0 9,564.0 19:30 20:00 10K over to shear the PBR(PU= 115K). Continue to PU until the pressure on the tubing dumps(seal are out of the PBR). 2/24/2016 2/24/2016 1.00 COMPZN RPCOMP CRIH P Circulate remaining 200 bbls of 9,564.0 9,564.0 20:00 21:00 corrosion inhibited seawater at 4 BPM =420 psi and chase with 75 bbls of seawater at 5 BPM=626 psi. 2/24/2016 2/24/2016 0.75 COMPZN RPCOMP HOSO P Slow down the pump rate,engage the 9,564.0 9,536.0 21:00 21:45 seal assembly into the PBR(observed 100 psi increase),shut down the pumps,locate out,and mark the pipe. Lay down joint#306 and#305. MU 2.24'and 2.27'space out pups to the bottom of joint#304. RIH and set the slips on joint#304(PU=105K and SO =68K) 2/24/2016 2/24/2016 0.75 COMPZN RPCOMP THGR P PU and MU the FMC tubing hanger. 9,536.0 9,586.0 21:45 22:30 MU circulating equipment to the landing joint and MU the landing joint to the tubing hanger. Land the tubing hanger and RILDS. 2/24/2016 2/25/2016 1.50 COMPZN RPCOMP PRTS P PT the tubing to 3500 psi for 15 9,586.0 22:30 00:00 minutes(good test),bleed the tubing to 2000 psi,and PT the IA to 3000 psi for 30 minutes(good test). Bleed the IA to 0 psi and bleed the tubing to 0 psi. Quickly ramp up the IA to shear the SOV(sheared at 2100 psi). Pump 1 bbl each way to confirm a good circulating path through the sheared SOV. 2/25/2016 2/25/2016 0.25 COMPZN RPCOMP RURD P RD circulating equipment,lay down 0.0 0.0 00:00 00:15 landing joint,and blow down circulating lines. 2/25/2016 2/25/2016 0.25 COMPZN WHDBOP MPSP P Install 3"ISA BPV with dry rod. 0.0 0.0 00:15 00:30 Page 9/11 Report Printed: 3/15/2016 • Drilling Operations Summary (with Timelog Depths) &Wells 1 R-17 ConocoPhi6lips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/25/2016 2/25/2016 1.00 COMPZN WHDBOP WWWH P PU a joint of DP and MU stack jetting 0.0 0.0 00:30 01:30 tool. Jet the BOP stack, lay down the stack jetting tool,and lay down the joint of DP. Blow down the TD. 2/25/2016 2/25/2016 2.00 COMPZN WHDBOP OTHR P Blow down the TD,choke manifold,kill 0.0 0.0 01:30 03:30 line,hole fill,and mud line. RU super sucker and clean out the rotary table and prep for BWM. 2/25/2016 2/25/2016 1.50 COMPZN WHDBOP SVRG P Perform CPAI Between Wells 0.0 0.0 03:30 05:00 Maintenance(BWM)on the BOP stack: Break bolts on the lower ram doors,open doors,and function ram pistons to the closed position. Inspect rams,ram cavities,sealing surfaces, and door seals. Close the lower ram doors and tighten the bolts(photos taken of all components and of stack cavities). 2/25/2016 2/25/2016 2.00 COMPZN WHDBOP SVRG P CPAI BWM on the BOP stack: Break 0.0 0.0 05:00 07:00 bolts on blind ram doors,open doors, and function ram piston to the closed position. Inspect ram cavities,sealing surfaces,and door seals. Inspect blind upper seal and front packer assembly.Close blind ram doors and tighten bolts(photos taken of all components and of stack cavities). 2/25/2016 2/25/2016 1.50 COMPZN WHDBOP SVRG P CPAI BWM on the BOP stack: Break 0.0 0.0 07:00 08:30 bolts on the upper ram doors,open doors,and function ram pistons to the closed position. Inspect rams,ram cavities,sealing surfaces,and door seals. Close the lower ram doors and tighten the bolts(photos taken of all components and of stack cavities). 2/25/2016 2/25/2016 1.00 COMPZN WHDBOP SVRG P CPAI BWM on the BOP stack: Install 0.0 0.0 08:30 09:30 3-1/2"joint of DP and function annular checking for excessive wear and overall condition(photos taken of annular). 2/25/2016 2/25/2016 2.00 COMPZN WHDBOP NUND P Remove lower Koomey line from the 0.0 0.0 09:30 11:30 annular and attach lift ring to the annular. ND the BOP stack,set back on stump,and secure for rig move. ND the DSA. 2/25/2016 2/25/2016 1.00 COMPZN WHDBOP NUND P Clean tubing hanger void, NU the 0.0 0.0 11:30 12:30 tubing head adapter and NU the tree. 2/25/2016 2/25/2016 0.50 COMPZN WHDBOP PRTS P PT the tubing hanger void to 250/5000 0.0 0.0 12:30 13:00 psi(good test). 2/25/2016 2/25/2016 0.50 COMPZN WHDBOP MPSP P Check for pressure under the BPV(no 0.0 0.0 13:00 13:30 pressure),pull the 3"ISA BPV with dry rod,and install the tree test plug with dry rod. 2/25/2016 2/25/2016 0.75 COMPZN WHDBOP PRTS P PT the tree to 250/5000 psi(good test) 0.0 0.0 13:30 14:15 2/25/2016 2/25/2016 0.25 COMPZN WHDBOP MPSP P Pull the tree test plug with dry rod. 0.0 0.0 14:15 14:30 Page 10/11 Report Printed: 3/15/2016 • Operations Summary (with Timelog Depths) &Wells 1 R-17 ConocoPhitlips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/25/2016 2/25/2016 1.00 COMPZN WHDBOP FRZP P RU Little Red Services to freeze 0.0 0.0 14:30 15:30 protect. RU circulating lines to take returns to the cutting box. 2/25/2016 2/25/2016 1.00 COMPZN WHDBOP FRZP P PT LRS and circulating lines to 3000 0.0 0.0 15:30 16:30 psi(good test). Reverse circulate 83 bbls of diesel down the IA through the sheared SOV taking returns out the tubing to the cuttings box at 2 BPM (ICP=650 psi and FCP=900 psi) and suck back 2 bbls. RD LRS. 2/25/2016 2/25/2016 2.00 COMPZN WHDBOP FRZP P Place the tubing and IA in 0.0 0.0 16:30 18:30 communication allowing the well to u- tube and equalize. 2/25/2016 2/25/2016 0.25 COMPZN WHDBOP MPSP P Install 3"ISA BPV with dry rod. 0.0 0.0 18:30 18:45 2/25/2016 2/25/2016 1.25 DEMOB MOVE RURD P Blow down all circulating line, RD all 0.0 0.0 18:45 20:00 cellar lines,and RD annulus valve. Install gauges on the tree,secure the well,and secure the cellar. Release the rig at 20:00 hours. Final well pressures: Tubing=0 psi, IA=0 psi,and OA=0 psi. Page 11/11 Report Printed: 3/15/2016 PTP 1411 _ 61f- Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, February 09, 2016 8:41 AM To: 'Kane, Danny' Subject: RE: KRU 1R-17 (PTD 191-114, Sundry 316-031) - Revision to Approved RWO Sundry Danny, The revision outlined below is approved. Please include this approval along with the schematic and revised procedure with the approved Sundry 316-031. Our files will be updated with this revision. Thanx, Victoria Victoria Loepp SCANNED MAY 1 9 2010 Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeoo alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Kane, Danny [inailto:Danny.Kane©conocophillips.com] Sent: Monday, February 08, 2016 2:14 PM To: Loepp, Victoria T(DOA) Subject: KRU 1R-17 (PTD 191-114, Sundry 316-031) - Revision to Approved RWO Sundry Victoria, I was informed today that the KRU 1R-17 RWO Sundry was approved last month (316-031). I am following up on the email I sent at the end of last week to confirm if it is OK to proceed with the proposed scope change on the current Approved Sundry or if I need to resubmit the Sundry. The scope change involves stacking a packer,thereby moving the injection packer further uphole from 9,701' MD to 9,596' MD (proposed setting depth). I have attached the following: 1. Approved Sundry#316-031 2. Revised General Procedure 3. Revised Proposed Completion Schematic Please advise if this revision is OK on the current approved Sundry. Given that we may be ready to move to this RWO in a few days, I'll follow up with a phone call tomorrow morning if I haven't heard back from you. Regards, 1 • • - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1509 Office: +1907 265-6048 Mobile: +1907 227-6037 danny.kane@conocophillips.com From: Kane, Danny Sent:Wednesday, February 03, 2016 4:53 PM To:Victoria Loepp (AOGCC)<iictoria.loepp@alaska.go'.> Subject: KRU 1R-17 (PTD 191-114) -Submitted RWO Sundry Revision Importance: High Victoria, I would like to submit a revision to the KRU 1R-17 (PTD 191-114) RWO Sundry Application that I submitted mid- January. While finalizing the procedure, I decided instead to stack a packer over the pre-rig tubing cut instead of trying to fish the tubing stub (seals)from the existing PBR;this simplifies the work-over scope and reduces the risk of accidentally pulling the existing retrievable packer free. From a regulatory standpoint,this moves the injection packer up from 9,701' MD (existing packer)to 9,596' MD, placing it 197' MD above the shallowest perforations (9,793' MD). I have attached a new General Procedure&Schematic for your reference. Please contact me if you have any questions regarding this revision. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1509 Office: +1907 265-6048 Mobile: +1907 227-6037 danny.kane@conocophillips.com 2 • FMC Gen IV(5M) • KRU 1R-17 7-1/16"x 3'/:"EUE Tbg Hgr ConocoPh i l l i ps Kuparuk C-&A-Sand Injector Proposed 2016 RWO REVISED 03-Feb-2016 16"62.5#H-40 WLD,120'MD-► • Surface Casing Primary Cementing ' Replace IC Pack-Offs 400 bbls 12.1 ppg Class E 107 bbls 15.8 ppg Class G OA Shoe Squeeze 50 bbls 15.6 ppg Permafrost'C' 4 3-1/2"9.3#L-80 EUE-8RD AB-Mod Tbg 65 bbls 7.3 ppg Arctic Pack 9-5/8"36#J-55 BTC,5702'MD—►-- -1 Drilling Mud/Spacer Lead Cement Tail Cement Arctic Pack -.111- --1 i9510'MD,Camco 3'/2"x 1 1/2"MMG DCR-SOV Diesel , _ Seawater 4 9566'MD,Baker GBH-22 Locator&80-40 Seals Brine 741 i Form Fluids/Unknown 9573'MD,Baker 80-40 PBR Bailed Sand t-,' WellLock Resin - r 9596'MD,Baker 7"x 3-1/2"FHL Retr.Packer r -4- 9647'MD,Camco 2.813"DS Landing Nipple 9666'MD-Pre-Rig Tubing Cut— 9665'MD,Baker Poor-Boy Overshot Chemical Cut Performed 13-Jan-2016 • ,.- y 9687'MD,Baker 80-40 10'PBR M 1. 4+—9701'MD,Baker 7"x 31/z"HB Retr.Packer 9730'MD-2.13"IBP— v." 3-1/2"9.3#L-80 EUE-8RD AB-Mod IPC Tbg Set 21-May-2015,15 Sand Dump-Bailed J-55 Above/L-80 Below Packer CMIT-Tx1A Passed 11-Jan-2016 ,, Warn.411 - 9744'MD,Camco 3-1/2"x1-1/2"MMG-W,DMY-RK f .E. Kuparuk C-1 Perforations SQZ-9762'-9770'MD i 9759'-9819'MD,3-'/2"9.3#L-80 EUE-8RD/BTC 1991-9793'-9809'MD f Carbide Blast Rings-9784'-9811'MD 9814'MD-Tubing Leak in Selective Identified w/LDL 30-Apr-2014 i To Be Addressed Post-RWO 1 9825'MD,Camco CB-1 Sliding Sleeve CLOSED 27-Apr-1995,2.75"No-Go Profile ;.,( f;::. 9835'MD,Baker 80-32 Seals(1'Space-Out) --9836'MD,Baker 85-32 D Permanent Packer iIi 411--9840'MD,Baker Sealbore Extension ;i 2-7/8"6.5#J-55 EUE-8RD AB-Mod IPC Tbg -4- 9860'MD,Otis 2-7/8"2.313"XN Landing Nipple 2.25 No-Go,2.31"XXN Plug Set 19-Apr-2014 I i f--f--9876'MD,Baker Shear-Out Sub Kuparuk A-Sand Perforations SQZ 1991-9932'-9940'MD > 1 1991-9967'-10025'MD Production Casing Primary Cementing : . SQZ 1991-10032'-10040'MD TOC 8300'MD(CBL 24-Sep-1991) 1991-10051'-10054'MD 54 bbls 15.8 ppg Class G Tail No Returns at Surface 7"26#J-55 BTC-M,10338'MD 1 - Date: 03-Feb2018 Drawn By: Danny Kane • KRU 1R-17 Proposed Rig Workover ConocoPh i I I i ps Pull &Replace Tubing/Change-Out IC Pack-Offs Original PTD #:191-114 Alaska NOTE:This is a revision to the original Sundry documents submitted 14-Jan-2016. All revisions are highlighted in bold blue font. Current Status: KRU 1R-17,a single-selective Kuparuk A-&C-sand injector,is currently shut-in after failing a MIT-IA as a result of tubing leaks identified at 3,262'MD&9,814'MD;these leaks can't be patched because of a historical restriction within the SCSSV. Additionally,the IC pack-offs have failed. Please see below for a history of the SCSSV restriction,IC pack-off testing,&leak diagnostics: - 1991—KRU 1R-17 drilled and completed as single-selective Kuparuk A-&C-sand producer. - 1992—Post-fracture stimulation wireline work tagged-up on&damaged the SCSSV flapper. o Sometime prior,the control line penetration packing in the tubing hanger started leaking and the control line pressure started tracking the tubing pressure. As a result of this leak,the flapper partially closed during wireline operations and was initially damaged while pulling a toolstring up into the partially-open SCSSV flapper. o The well was secured and the tree&tubing head adapter were removed to replace the control line penetrator packing at the tubing hanger. o Attempts to repair the SCSSV flapper were unsuccessful and because the flapper couldn't be fully-opened and locked-out,a limited ID hold-open sleeve was designed and installed. - 1992—KRU 1R-17 converted to a single-selective Kuparuk A-&C-sand MWAG injector. - 2003—First report of inability to test IC Pack-Offs(damaged test port fittings). - 2004—TxIA communication observed while injecting dry-gas. o Subsequent diagnostics while on water injection showed no further communication. Well returned to MWAG service(no additional dry gas injection reported). - 2004—IC Pack-Offs first failed testing. - 2013—First failing MIT-IA with LLR of 1.46 gpm established. KRU 1R-17 shut-in. - 2014—Additional failed MIT-IA diagnostics. o Plug set in XN nipple at 9,814' MD—failed MIT-IA&CMIT-TxIA. o LDL ran,identified tubing leaks at 3,262'&9,814'MD. • 3,262'MD:Vicinity of GLM#1 (3,255' MD) • 9,814'MD:3'below base of CBRs in selective. o IBP set at 9,730' MD,CMIT-TxIA passed. - 2015—Unsuccessful attempts to remove SCSSV restriction so that tubing patch could be run. o Attempt to move flapper with wireline tools—unsuccessful. o Attempt to destroy the flapper using a downhole cannon—unsuccessful(Sundry 315-047). o Unable to drift tubing patch components/running tools through the ID restriction within the SCSSV. Well identified as RWO candidate. Scope of Work: The objective of this proposed RWO will be to fix the tubing leak at 3262' MD&replace the leaking IC Pack-Offs; the tubing leak at 9,814' MD within the selective will be repaired post-RWO using a non-rig solution. The scope of this proposed RWO will be to pull the upper completion to the pre-rig tubing cut. While pulling the upper completion, a storm packer will be set,the tubing head will be removed,the production casing will be grown and stretched,and the IC pack-offs will be replaced. After re-installing the tubing head, a new 3-1/2" upper completion with a stacked packer& poor-boy overshot will be run from surface and tie into the pre-rig tubing cut at 9,666'MD. Page 1 of 3 • • KRU 1R-17 Proposed Rig Workover ConocoPh i l l i ps Pull &Replace Tubing/Change-Out IC Pack-Offs Original PTD#:191-114 Alaska General Well Info: Well Type: Kuparuk A-&C-Sand Single Selective Injector MPSP: 2,746 psig using MASP=(PP-(0.1*TVD)),or dry gas gradient to surface. 2,746 psig=(3,405 psig—(0.1 psig/ft*6,595'TVD)) Reservoir Pressure/TVD: Kuparuk A/C Mid-Perfs—3,405 psig/6,595'TVD(10.0 ppg EMW) Wellhead Type: FMC Gen IV(5M Tubing Head/3M Casing Head) BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT Results: MIT-IA Failed 22-Oct-2013 Last passed 27-Dec-2011, Tubing Leaks at 3,262'&9,814'MD CMIT-TxIA Passed 11-Jan-2016 Passed after IBP Set at 9,730'MD MIT-OA Passed 12-Jul-2009 Note:Initially failed 18-Dec-1991,Performed Immediately After OA Shoe Squeeze in 1991 Earliest Start Date: 14-Feb-2016 Production Engineer: John Cookson Workover Engineer: Danny Kane (907)265-6048 danny.kane@conocophillips.com Summary of Proposed RWO Procedure: Completed&Proposed Pre-Rig Work: 1. Perform CMIT-TxIA to confirm installed IBP&IA integrity. 2. Confirm that GLMs 1-4 have DVs installed. 3. Pull 1-'/2"DMY-RM from GLM#5 for circulation point. 4. Cut 3-'/2"tubing at 9,666' MD. 5. Set BPV. Perform draw-down test on IA to confirm plug x packer integrity. Pressure-test BPV from below. Proposed Rig Workover Procedure: 1. MIRU RWO Rig. 2. ND tree,NU BOPE,&test BOPE to 250/3,000 psig low/high. 3. Pull BPV,screw in landing joint,BOLDS,&unseat tubing hanger. 4. P/U on tubing&pull tubing hanger to the rig floor. Displace diesel freeze protect from TxIA. Perform draw- down test to verify plug x packer integrity. 5. Verify well is static&TOH laying down 3-'/2"upper completion to 2,500'MD. 6. M/U storm packer,TIH two stands,&set storm packer as per Baker representative. 7. Pressure-test storm packer from above,perform a draw-down test,&flow check the OA. 8. Once static,ND BOPE,RU Hydratight,&allow 7"casing to grow. Remove tubing head. Stretch casing&re- land in slips with 50 klbs tension. Place new IC pack-offs&install new tubing head. 9. Pressure-test IC pack-offs&NU BOPE to new tubing head. Shell-test the BOP stack/tubing head break. 10. Retrieve the storm packer&L/D same. 11. Finish laying-down upper completion to pre-rig tubing cut at 9,666'MD. 12. M/U&TIH with new 3-'/2"upper completion with stacked packer&poor-boy overshot as per design to just above the chemical cut tubing stub at 9,666'MD. 13. Space-out poor-boy overshot,spot corrosion-inhibited brine in the IA to above the stacked packer,drop ball& rod,&set stacked packer. Pressure-up to 3,000 psig to confirm the stacked packer has set. 14. Shear-out of the PBR,space-out seals into existing PBR,mark-pipe at surface,&lay-down two joints. 15. Space-out with tubing pups,M/U tubing hanger,land hanger,&RILDS. Page 2 of 3 ! • fir` KRU 1R-17 Proposed Rig Workover ConocoPh i I I i ps Pull &Replace Tubing/Change-Out IC Pack-Offs Original PTD#:191-114 Alaska 16. Pressure-test tubing to 3,500 psig&IA to 3,000 psig. Bleed the IA&then the tubing. Ramp up the IA pressure quickly to shear the SOV. 17. Back-out landing joint&install BPV. 18. ND BOPE,NU tree,install tree test plug,&pressure test tree. 19. Freeze protect well through SOV. 20. Set BPV. 21. RDMO RWO Rig. Proposed Post-Rig Work 1. Pu11 BPV. 2. RU Slickline to swap the GLM#1 SOV with a DV,pull the ball& rod,& pull the RHC plug body from the nipple profile below the stacked packer. RD Slickline. 3. Reset well house(s)&re-attach flow line(s). 4. Turn well over to operations. Page 3 of 3 vOFT4, ID • • al."'\1//7," THE STATE Alaska Oil and Gas f, �� ��'6 A f ALASKA Conservation Commission � s ,�t�-it,�z�„ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 w ' Main: 907.279.1433 O' ALAS 3- Fax: 907.276.7542 www.aogcc.alaska.gov Danny Kane Senior Wells Engineer ConocoPhillips Alaska, Inc. SCANNED FEE 1 8 '2.016 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1R-17 Permit to Drill Number: 191-114 Sundry Number: 316-031 Dear Mr. Kane: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 22-ML day of January, 2016. RBDMS 0- Jiii4 L 5 2016 RECEIVED • STATE OF ALASKA • JAN 14 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION O7 3I � APPLICATION FOR SUNDRY APPROVALS AQG2-212-21a,GC 20 AAC 25.280 1.Type of Request: Abandon T Plug Perforations I Fracture Stimulate ....... Repair Well Operations Shutdown ir Suspend 1 Perforate E Other Stimulate I.... Pull Tubing F - Change Approved Program( Plug for Redrill f Perforate New Pool P Re-enter Susp Well P Alter Casing E Other: 1- 2. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory i....... Development ....... 191-114 3.Address: 6.API Number: Service P.. P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic 50-029-22212-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a Will planned perforations require a spacing exception. Yes No KRU 1R-17 9. Property Designation(Lease Number): 13 10. Field/Pool(s): ADL 25635 � 1562S Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): - 10,345' • 6,857' ` 10,253 - 6,798 2746 psi 9900 - Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 120' 120' Surface 5,661' 9.625 5,703' 4024' Intermediate Production 10,301' 7" 10,339' 6853' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9793-9809,9967-10025,' 6517-6526,6623-6658, 3.5 x 2.875 J-55 9,877' 10051-10054 ' 6674-6676 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER HB RETRIEVABLE PACKER ` MD=9701 TVD=6462 PACKER-BAKER D PERMANENT PACKER ' MD=9837 TVD=6543 SAFETY VLV-CAMCO TRDP-4A SAFETY VALVE • MD=1784 TVD=1672 12.Attachments: Proposal Summary E Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory =....... Stratigraphic Development r Service k • 14. Estimated Date for 2/14/2016 15.Well Status after proposed work: Commencing Operations: OIL WINJ 1 WDSPL i..... Suspended E 16.Verbal Approval: Date: GAS im WAG iv.. • GSTOR I- SPLUG P Commission Representative: GINJ i.... Op Shutdown 1..- Abandoned 1 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Danny Kane Email danny.kane(a�conocophillips.com Printed Name Danny Kane@265-6048 Title Senior Wells Engineer c.:77- 1:2 -----........_ /4-7AN- 2Q00 Signature Phone 265-6048 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \Lit - 031 Plug Integrity ❑ BOP Test d Mec anical Integrity Test ,Location Clearance ❑ Other: gOP t-rs t to 3 GUD 5,V/ye/S Z Fav �-hr�v!a rp�re.V z".GI rrs —7 5 c It 5/ `� `n �rc�i tr•141771 reci' /r—fit f—� i-Ift4 o f t-a I lI C Post Initial Injection MIT Req'd? Yes n. No ❑ Spacing Exception Required? Yes ❑ No 1 Subsequent Form Required: k -'- 4-13 4- RBDMS tet- JAN 2 5 2016 APPROVED BY / Approved by:4 / OMMISSIONER THE COMMISSION Date:!' o / pp it F and Form 10-'03 Revved 11/2. 5 • ' .0/t NIA, Is valid Tor 11 montns rrom tne aate of a ro al. Attachments in Duplicate yrL- l,/Z(j/fes //& it 9/i C.�` c gi ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 14th,2016 Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to workover Kuparuk Injector KRU 1R-17(PTD# 191-114). Well 1R-17 was spudded in September 1991 and completed as a single-selective Kuparuk A-& C-sand producer in December 1991. After well testing and fracture stimulation,the well was converted to a single-selective A-&C-sand MWAG injector in 1992. After the well was fracture stimulated, the post-frac wireline work damaged the SCSSV flapper when a leak in the control line penetrator packing caused the flapper to inadvertently partially close during wireline operations. Subsequent attempts throughout the years have failed to fully-open the flapper and a hold-open sleeve was designed and installed to allow wireline access;however,this hold-open sleeve has a limited ID and restricts the work that can be performed on the well. In 2003,difficulties testing the IC pack-offs were first reported and the IC pack-offs started failing tests in 2004. Also in 2004,TxIA communication was observed while the well was on dry-gas injection and the well was reported to the AOGCC. After a monitoring period on water injection failed to identify any further TxIA communication,the well was returned to MWAG injection(water&MI gas,no additional dry-gas injection). In 2013, 1R-17 failed a MIT-IA and the well was shut in. Diagnostic work performed showed that there were two tubing leaks: 3,262' MD(close to GLM#1)&9,814' MD(within the selective). The well was secured with an IBP set at 9,730' MD and confirmed with a CMIT-TxIA performed shortly thereafter. Because the hold-open sleeve in the SCSSV wouldn't drift tubing patch components or running equipment, additional efforts were made to try to fix/remove the SCSSV flapper and culminated in running a downhole cannon in May 2015(Sundry#315-047);despite these efforts,drift access was still insufficient to run a tubing patch and the well was placed on the rig work-over list. The proposed rig work-over will consist of pulling the existing upper completion, replacing the IC pack-offs, & reinstalling a new upper completion. The leak in the selective will be addressed post-RWO using a non-rig solution. This Sundry is intended to document the proposed work on KRU 1R-17 because of the intent pull tubing and repair the well(IC pack-offs)as well as to request approval to workover this well. If you have any questions or require any further information,please call me at 265-6048 or email me at danny.kane@conocophillips.com. Sincerely, Danny Kane Wells Engineer CPAI Drilling and Wells • KRU 1R-17roposed Rig Workover ConocoPh i 11 i ps Pull & Replace Tubing/Change-Out IC Pack-Offs Original PTD #:191-114 Alaska Current Status: KRU 1R-17,a single-selective Kuparuk A-&C-sand injector,is currently shut-in after failing a MIT-IA as a result of tubing leaks identified at 3,262' MD&9,814' MD;these leaks can't be patched because of a historical restriction within the SCSSV. Additionally,the IC pack-offs have failed. Please see below for a history of the SCSSV restriction,IC pack-off testing,&leak diagnostics: - 1991—KRU 1R-17 drilled and completed as single-selective Kuparuk A-&C-sand producer. - 1992—Post-fracture stimulation wireline work tagged-up on&damaged the SCSSV flapper. o Sometime prior,the control line penetration packing in the tubing hanger started leaking and the control line pressure started tracking the tubing pressure. As a result of this leak,the flapper partially closed during wireline operations and was initially damaged while pulling a toolstring up into the partially-open SCSSV flapper. o The well was secured and the tree&tubing head adapter were removed to replace the control line penetrator packing at the tubing hanger. o Attempts to repair the SCSSV flapper were unsuccessful and because the flapper couldn't be fully-opened and locked-out,a limited ID hold-open sleeve was designed and installed. - 1992—KRU 1R-17 converted to a single-selective Kuparuk A-&C-sand MWAG injector. - 2003—First report of inability to test IC Pack-Offs(damaged test port fittings). - 2004—TxIA communication observed while injecting dry-gas. o Subsequent diagnostics while on water injection showed no further communication. Well returned to MWAG service(no additional dry gas injection reported). - 2004—IC Pack-Offs first failed testing. - 2013—First failing MIT-IA with LLR of 1.46 gpm established. KRU 1R-17 shut-in. - 2014—Additional failed MIT-IA diagnostics. o Plug set in XN nipple at 9,814' MD—failed MIT-IA&CMIT-TxIA. o LDL ran,identified tubing leaks at 3,262'&9,814' MD. • 3,262' MD:Vicinity of GLM#1 (3,255'MD) • 9,814' MD: 3'below base of CBRs in selective. o IBP set at 9,730' MD,CMIT-TxIA passed. - 2015—Unsuccessful attempts to remove SCSSV restriction so that tubing patch could be run. o Attempt to move flapper with wireline tools—unsuccessful. o Attempt to destroy the flapper using a downhole cannon—unsuccessful(Sundry 315-047). o Unable to drift tubing patch components/running tools through the ID restriction within the SCSSV. Well identified as RWO candidate. Scope of Work: The objective of this proposed RWO will be to fix the tubing leak at 3262' MD&replace the leaking IC Pack-Offs; the tubing leak at 9,814' MD within the selective will be repaired post-RWO using a non-rig solution. The scope of this proposed RWO will be to pull the upper completion to the pre-rig tubing cut and fish the remainder of the upper completion to the seals engaged within the PBR that is just above the Baker HB packer. While pulling the upper completion, a storm packer will be set, the tubing head will be removed, the production casing will be grown and stretched,and the IC pack-offs will be replaced. After re-installing the tubing head,the new 3-1/2"upper completion will be run from surface and stab into the existing PBR just the Baker HB packer. Page 1 of 3 • KRU 1R-17 roposed Rig Workover ConocoPh i 11 i ps Pull &Replace Tubing/Change-Out IC Pack-Offs Original PTD #:191-114 Alaska General Well Info: Well Type: Kuparuk A-&C-Sand Single Selective Injector MPSP: 2,746 psig using MASP=(PP-(0.1*TVD)),or dry gas gradient to surface. 2,746 psig=(3,405 psig—(0.lpsig/ft* 6,595' TVD)) Reservoir Pressure/TVD: Kuparuk A/C Mid-Perfs—3,405 psig/6,595' TVD(10.0 ppg EMW) Wellhead Type: FMC Gen IV(5M Tubing Head/3M Casing Head) BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT Results: MIT-IA Failed 22-Oct-2013 Last passed 27-Dec-2011, Tubing Leaks at 3,262'&9,814'MD CMIT-TxIA Passed 11-Jan-2016 Passed after IBP Set at 9,730'MD MIT-OA Passed 12-Jul-2009 Note:Initially failed 18-Dec-1991, Performed Immediately After OA Shoe Squeeze in 1991 Earliest Start Date: 14-Feb-2016 Production Engineer: John Cookson Workover Engineer: Danny Kane (907)265-6048 danny.kane@conocophillips.com Summary of Proposed RWO Procedure: Completed&Proposed Pre-Rig Work: 1. Perform CMIT-TxIA to confirm installed IBP&IA integrity. 2. Confirm that GLMs 1-4 have DVs installed. 3. Pull 1-'/2"DMY-RM from GLM#5 for circulation point. 4. Cut 3-'/2"tubing at 9,666'MD. 5. Set BPV. Proposed Rig Workover Procedure: 1. MIRU RWO Rig. 2. Pull BPV. Circulate KWF around. Obtain SITP&SICP;if pressure is observed at surface,calculate new KWF and repeat circulation if necessary. Verify well is static prior to proceeding. 3. Set BPV,ND tree,NU BOPE,&test BOPE to 250/3,000 psig low/high. 4. Pull BPV,screw in landing joint,BOLDS,&unseat tubing hanger. 5. P/U on tubing & pull tubing hanger to the rig floor. Verify well is static & TOH laying down 3-'/2" upper completion to pre-rig tubing cut at 9,666'MD. 6. M/U&TIH with tubing body overshot, latch onto & engage seal assembly fish,&pull free from Baker PBR. TOH laying down three joints of drill pipe before racking back two stands of drill pipe. 7. M/U storm packer,TIH two stands,&set storm packer as per Baker representative. 8. Pressure-test storm packer from above,perform a draw-down test,&flow check the OA. 9. Once static,ND BOPE,RU Hydratight,&allow 7"casing to grow. Remove tubing head. Stretch casing&re- land in slips with 50 klbs tension. Place new IC pack-offs&install new tubing head. 10. Pressure-test IC pack-offs&NU BOPE to new tubing head. Shell-test the BOP stack/tubing head break. 11. Retrieve the storm packer&L/D same. 12. TOH laying down drill pipe and tubing fish to seals. 13. M/U&TIH with new 3-'/2"upper completion as per design to just above the Baker HB packer. 14. Space-out seals into existing PBR,mark-pipe at surface,&lay-down two joints. 15. Space-out with tubing pups,M/U tubing hanger,land hanger,&RILDS. 16. Pressure-test tubing to 3,500 psig&IA to 3,000 psig. Bleed the IA&then the tubing. Ramp up the IA pressure quickly to shear the SOV. Page 2 of 3 • KRU 1R-17 Proposed Rig Workover ConocoPh i I I i ps Pull & Replace Tubing/Change-Out IC Pack-Offs Original PTD #:191-114 Alaska 17. Back-out landing joint&install BPV. 18. ND BOPE,NU tree,install tree test plug,&pressure test tree. 19. Freeze protect well through SOV. 20. Set BPV. 21. RDMO RWO Rig. Proposed Post-Rig Work 1. Pull BPV. 2. RU Slickline to remove the SOV&replace with DV. RD Slickline. 3. Reset well house(s)&re-attach flow line(s). 4. Turn well over to operations. Page 3 of 3 KUP 1R-17 conoc P iillIj sirkel.^„, Well Attribu Max AngleD TD A1clsi(c1.IT 4,"°...„ Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) CargcoPhiIips 500292221200 KUPARUK RIVER UNIT INJ 60.15 2,800.00 10,345.0 , ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1R-17.1114/201612:12:47 PM SSSV:LOCKED OUT Last WO: 12/16/1991 42.99 9/200991 ...Vertical schematic(actual)... Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 10,145.0 4/17/2014 Rev Reason:Mandrel Orientations lehallf 7/22/2014 HANGER;21.5 mat': asmg rings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread • CONDUCTOR 16 15.062 43.0 120.0 120.0 62.50 H-40 WELDED II • f Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ji s ll, I 7 SURFACE 9 5/8 8.921 42.2 5,702.7 4,024.0 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 37.8 10,338.9 6,852.8 26.00 J-55 BTC MOD Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. TVD)(.6..Wt(Ibttt) Grade Top MOD-EUE Connection TUBING WO 31/2 2.992 21.51 9,8Set Depth( 77.4 6,567. 1 9.30 J-55 IAB CONDUCTOR;43.0-120.0 3.5 x2.875" Completion Details ii Nominal ID SAFETY VLV,1,784.2` ,i T., Top(ftKB) Top(TVD)(ftKB) Top Incl C( Item Des Corn (in) SLEEVE;1,784.0 21.5 21.5 0.08 HANGER FMC GEN IV TUBING HANGER 3.500 1,784.2 1,672.3 42.20'SAFETY VLV CAMCO TRDP-4A SAFETY VALVE(LOCKED OUT 2.812 6/14/92)FLAPPER BROKEN OFF(5/31/92) 11 9,650.2 6,431.7 53.58 NIPPLE OTIS X SELECTIVE LANDING NIPPLE 2.813 GAS LIFT,3,255.6Ill ' 9,687.4 6,453.9 53.54 PBR BAKER PBR 3.000 9,701.1 6,462.0 53.52 PACKER BAKER HB RETRIEVABLE PACKER 2.890 9,759.2 6,496.6 53.41-BLAST CARBIDE BLAST RINGS 2.992 RINGS 9,825.2 6,536.1 53.06 SLEEVE-C CAMCO CB-1 SLIDING SLEEVE;SHIFT CLOSED 2.750 SURFACE;42.25,702.7 I, 4/27/95 9,836.7 6,543.0 52.94 PACKER BAKER D PERMANENT PACKER 3.250 9,840.4 6,545.2 52.90 SBE BAKER SEAL BORE EXTENSION 3.250 GAS LIFT;5,952.3 M 9,860.5 6,557.3 52.68 NIPPLE OTIS XN NIPPLE NO GO 2 250 9.876.6 6,567.2 52.51 SOS BAKER SHEAR OUT SUB 2.441 GAS LIFT;7,9238 �. Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl e. Top 00(B) (ftKB) (°) Des Com Run Date ID(In) GAS LIFT,8,842.6111 1,784,0 1,672.2 42.20 SLEEVE 2.85 NO GO,2.5"OD SLEEVE,2.30"ID,126"OAL), 5/9/2014 2.300 9,730.0 6,479.2 53.46 PLUG 2.13"BAKER IBP 5/21/2014 GAS LIFT 8645.711 9,861.0 6,557.7 52.68 PLUG XXN PLUG IN XN NIPPLE 4/19/2014 9,900.0 6,581.4 52.26 FISH 1 PIECE 5/8"x1'x1/4"OF BROKE SLIP STILL IN 8/14/2009 0.000 HOLE NIPPLE,9,650.2 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn PBR;9,887.4 9,793.0 9,809.0 6,516.8 6,526.3 C-1,UNIT B, 12/15/1991 10.0 IPERF Spiral(72 deg.) 1R-17 Phasing;4.5"Csg Gun PACKER;9,701.1 ° 9,967.0 10,025.0 6,622.5 6,658.3 A-4,A-3,1R- 12/14/1991 4.0 IPERF 180 deg.phase;4.5" 17 Csg Gun PLUG,9,730.0 j�', 10,051.0 10,054.0' 6,674.3 6,676.2 A-2,1R-17 12/14/1991 4.0 IPERF 180 deg.phase;4.5" Csg Gun Cement Squeezes 4 Top(TVD) Btm(TVD) INJECTION,9,745.0 I ,, Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn 9,932.0 9,940.0 6,601.0 6,605.9 Cement 12/4/1991 Squeeze I 10,032.0 10,040.0 6,662.6 6,667.5 Cement 12/4/1991 IPERI 9.793.0-98090-1. ;,. I Squeeze Mandrel Inserts St ati SLEEVE-C;9,825.2 N Top(TVD( Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 3,255.6 2,495.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/1/2014 8:30 2 5,952.3 4,195.5 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 12/16/1991 9:30 PACKER,9,838.7 a e. 3 7,623.8 5,211.1 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 12/16/1991 7:30 SBE;8,840.4 `•r.• 4 8,842.6 5,955.7 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 12/16/1991 5:00 5 9,605.7 6,405.4 OTIS LBD 1 1/2 GAS LIFT DMY RM 0.000 0.0 6/24/1992 5:30 NIPPLE;9,860.5 ??? 6 9,745.0 6,488.1 CAMCO MMG- 11/2 INJ DMY RK 0.000 0.0 6/14/1992 PLUG,9,861.0 : 7 W Notes:General&Safety SOS,9,876.8 End Date Annotation 10/18/2010 NOTE-View Schematic w/Alaska Schematic9.0 FISH,9,900.0 , (PERF;9,967.0-10,0250--. I I 1 P IPERF;10,051 0-10,054.0-+ PRODUCTION;37.8-10,338.9---)/ • • FMC Gen IV(5M) NIIP"'- 7-1/16"x 3-%"EUE Tbg Hgr KRU 1 R-1 7 COnocoP 4 1i"i ps \,.:j , „- • _... Kuparuk C-&A-Sand Injector Current Shut-In Status - 16"62.5#H-40 WLD,120'MD \ • Surface Casing Primary Cementing Failed IC-Pack-Offs 400 bbls 12.1 ppg Class E ::i 107 bbls 15.8 ppg Class G _1784'MD,Camco TRDP-4A SCSSSV I Broken Flapper,Failed Attempt to Clear w/Cannon OA Shoe Squeeze : :: : , , . , 33 SS Bands for Control Line 50 bbls 15.6 ppg Permafrost'C' 4 : :i 3-1/2"9.3#J-55 EUE-8RD AB-Mod IPC Tbg 65 bbls 7.3 ppg Arctic Pack .:i 4:::: ; 3255'MD,Camco 3-1/2"x1"KBUG(OPEN) 3262'MD—Tubing Leak : . ►— -.- ::: DMY-BK Removed 22-May-2015,No Evidence Replaced Identified w/LDL 30-Apr-2014 :: i DV Not Replaced During Pre-Rig Work Unable to Patch w/SCSSSV ID Restriction 9-5/8"36#J-55 BTC,5702'MD=i' ..N.- -' 4 i 5952'MD,Camco 3-%"x1"KBUG DMY-BK2 Drilling Mud/Spacer : :�e#1. 0.4l$nt :: -:Tail-Cement _ ' 41 7623'MD,Camco 3-h"x1"KBUG DMY-BK2 Arctic Pack Diesel Seawater • y..4 J' ` . } y 4y, -1--—8842'MD,Camco 3-1/2"x1"KBUG DMY-BK2 Form Fluids/Unknown We//Lock Resin - -4 9605'MD,Otis 3'/:"x1'/:"LBD(OPEN) -: ; w DMY-RM Removed 12-Jan-2016(Pre-RWO) Well Loaded w/SW 8 80 bbls Diesel Freeze Protect ]u - 9650'MD,Otis 2.813"X Landing Nipple . 9666'MD—Pre-Rig DSL Chem Cut Cut Performed 13-Jan-2016 . First Full-Joint Above PBR :'''),:'1-;:,: "',i-,,,, 9687'MD,Baker 80-40 10'PBR *or—9701'MD,Baker 7"x3-%"HB Retr.Packer iii 9730'MD—2.13"IBP 3-1/2"9.3#L-80 EUE-8RD AB-Mod IPC Tbg Set 21-May-2015,15'Sand Dump-Bailed ' I J-55 Above/L-80 Below Packer CMIT-TxIA Passed 11-Jan-2016 , 11.'r, -9744'MD,Camco 3-%"x1-%"MMG-W,DMY-RK S Kuparuk C-1 Perforations SQZ—9762'-9770'MD9759'-9819'MD,3-1/2"9.3#L-80 EUE-8RD/BTC 1991—9793'-9809'MD ' Carbide Blast Rings—9784'-9811'MD 9814'MD—Tubing Leak in Selective .. IP- /dent/fled Identified w/LDL 30-Apr-2014 To Be Addressed Post-RWO I 9825'MD,Camco CB-1 Sliding Sleeve CLOSED 27-Apr-1995,2 75"No-Go Profile f-: : 9835'MD,Baker 80-32 Seals(1'Space-Out) : . f—9836'MD,Baker 85-32 D Permanent Packer �}—9840'MD,Baker Sealbore Extension f : :, 2-7/8"6.5#J-55 EUE-8RD AB-Mod IPC Tbg —9860'MD,Otis 2-7/8"2.313"XN Landing Nipple 2.25 No-Go,2.31"XXN Plug Set 19-Apr-2014 El i -9876'MD,Baker Shear-Out Sub igi Kuparuk A-Sand Perforations SQZ 1991—9932'-9940'MD .: :' •. • .i Production Casing Primary Cementing 1991—9967'-10025'MD TOC 8300'MD(CBL 24Sep-1991) SQZ 1991—10032'-10040'MD 54 bbls 15.8 ppg Class G Tail 1991—10051'-10054'MD No Returns at Surface 7"26#J-55 BTC-M,10338'MD ? ' I Date: 144an-2018 I Drawn By: Danny Kane FMC Gen IV(5M) 7-1/16"x 3-1A"EUE Tbg Hgr KRU 1R-17 ConocoPhillips �; ; : KuparukC-&A-Sand injector Proposed 2016 RWO 16"62.5#H-40 WLD,120'MD Surface Casing Primary Cementing Replace IC Pack-Offs 400 bbls 12.1 ppg Class E 107 bbls 15.8 ppg Class G OA Shoe Squeeze 50 bbls 15.6 ppg Permafrost'C' 3-1/2"9.3#L-80 EUE-8RD AB-Mod Tbg 65 bbls 7.3 ppg Arctic Pack -ii :tl 9-5/8"36#J-55 BTC,5702'MD-► -- Drilling Mud/Spacer i-ead/Ce10017t, ;:i Arctic Pack Diesel Seawater Brine Form Fluids/Unknown Bailed Sand WeHlock Resin < :- 9572'MD,Camco 3-W'x 1-W'MMG DCR-SOV :i ;:j 9630'MD,Camco 2.813"X Landing Nipple :a .0- .,; 9684'MD,Baker 80-40 Seal Assembly 4 :i ,,, Ii 4 9687'MD,Baker 80-40 10'PBR MD 4 9701'MD,Baker 7"x3-%"HB Retr.Packer 9730'MD-2.13"IBP-- 3-1/2"9.3#L-80 EUE-8RD AB-Mod IPC Tbg Set 21-May-2015,15'Sand Dump-Bailed J-55 Above/L-80 Below Packer OMIT-TxIA Passed 11-Jan-2016 9744'MD,Camco 3-%"x1-1/2"MMG-W,DMY-RK I Kuparuk C-1 Perforations SQZ-9762'-9770'MDI 9759'-9819'MD,3'/:"9.3#L-80 EUE-8RD/BTC 1991-9793'-9809'MD ; ___ Carbide Blast Rings-9784'-9811'MD 9814'MD-Tubing Leak in Selective 1 - Identified w/LDL 30-Apr-2014 To Be Addressed Post-RWO 1 9825'MD,Camco CB-1 Sliding Sleeve CLOSED 27-Apr-1995,2 75"No-Go Profile -41- 9835'MD,Baker 80-32 Seals(1'Space-Out) '1 'a �= 9836'MD,Baker 85-32 D Permanent Packer -4114.--9840'MD,Baker Sealbore Extension f 2-7/8"6.5#J-55 EUE-8RD AB-Mod IPC Tbg -41--i9860'MD,Otis 2-7/8"2.313"XN Landing Nipple 2.25 No-Go,2.31"XXN Plug Set 19-Apr-2014 I i -41119876'MD,Baker Shear-Out Sub Kuparuk A-Sand Perforations SQZ 1991-9932'-9940'MD i Production Casing Primary Cementing 1991-9967'-10025'MD • •I • TOC 8300'MD(CBL 24Sep-1991) SQZ 1991-10032'-10040'MD 54 bbls 15.8 1991-10051'-10054'MD ppg Class G Tail No Returns at Surface 7"26#J-55 BTC-M,10338'MD-II. I Date: 13-Jan-2016 1 Drawn By: Danny Kane STATE OF ALASKA AL A OIL AND GAS CONSERVATION CON. SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon f Rug Perforations r Fracture Stimulate r Pull Tubing r- Operations Shutdown r Performed Suspend r Perforate r Other Stimulate r,�,,,,�� Alter Casing r Change Approved Program r for Redrill 1- Perforate New Pool r Repair Well IV Re-enter Susp Well r Other Break damaged SSSV flapper Ri 2.Operator Name: 4.Well Class Before Work: 5 Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory I— y 191-114 3.Address: 6 API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service A 50-029-22212-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25635 0tyA5&18 4 r KRU 1 R-17 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s) r none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary. Total Depth measured 10345 feet Plugs(measured) 9730, 9861 true vertical 6857 feet Junk(measured) 9900 Effective Depth measured 10253 feet Packer(measured) 9701,9837 true vertical 6798 feet (true vertical) 6462,6543 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 120 120 SURFACE 5661 9.625 5703 4024 PRODUCTION 10301 7 10339 6853 RECEIVED Perforation depth: Measureddepth• 9793-9809, 9967-10025, 10051-10054 saINNED AUG 2 6 2015 True Vertical Depth: 6517-6526,6623-6658,6674-6676 AOGCC Tubing(size,grade,MD,and TVD) 2.875,J-55, 9877 MD, 6567 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER HB RETRIEVABLE PACKER @ 9701 MD and 6462 TVD PACKER-BAKER D PERMANENT PACKER @ 9837 MD and 6543 TVD SSSV-CAMCO TRDP-4A SAFETY VALVE FLAPPER BROKEN OFF(5/31/92)@ 1784 MD and 1672 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured) no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25 070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Exploratory r Development r Service Fo Stratigraphic fl Copies of Logs and Surveys Run r 16.Well Status after work: Oil Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r vvWNJ r WAG417 GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 315-047 Contact Diana Guzman @ 265-6318 Email Diana.Guzman@conocophillips.com Printed Name Diana Guzman Title Sr. Wells Engineer /I Signature Phone:265-6318 Date s/2 5 vrV /� / 7.� S � RBDMS AUG 2 6 2015 Form 10-4 4Revised 5 2015 Submit Original Only Allsup-Drake, Sharon K From: Loepp,Victoria T(DOA) <victoria.loepp@alaska.gov> Sent: Thursday,August 20, 2015 11:04 AM To: Guzman, Diana Cc: Allsup-Drake, Sharon K Subject: [EXTERNAL]RE: KRU 1R-17 - Sundry Number 315-047- PTD 191-114 Please submit a 10-404 for work completed and to close out sundry. From: Guzman, Diana [mailto:Diana.Guzman©conocophillips.com] Sent: Thursday, August 20, 2015 10:57 AM To: Loepp, Victoria T(DOA) Cc: Allsup-Drake, Sharon K Subject: KRU 1R-17 - Sundry Number 315-047- PTD 191-114 Good morning Victoria, I submitted a sundry application for well work on 1R-17,sundry#315-047, PTD#191-114 earlier this year.We attempted to complete the work(Downhole cannon)as described in the sundry and were unsuccessful. We were evaluating if we should try the Downhole cannon again but upon further review,we have decided against it. Would you want us to submit a 10-404 to close out the sundry?Or should we leave the sundry open until it expires? Please let me know how you would like us to proceed or if you need any other information. Thank you for your time. Sincerely, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 1 KUP INJ 1R-17 ConocoPhillips Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status Ind(") MD(RKB) Act Btm(ftKB) 500292221200 KUPARUK RIVER UNIT INJ 60.15 2,800.00 10,345.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 1R-17,7/22/20144.5158 PM SSSV:LOCKED OUT Last WO: 12/16/1991 42.99 9/20/1991 Vertical schematic(actual) Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag:SLM 10,145.0 4/17/2014 Rev Reason:Mandrel Orientations lehallf 7/22/2014 HANGER;215 MIR Casing Strings Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 43.0 120.0 120.0 62.50 H-40 WELDED iwaCasing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I. Len ..Grade Top Thread •. •, • k1 '. -{... SURFACE 95/8 8.921 42.2 5.702.7 4,024.0 36.00 J-55 BTC ' Casing Description OD(in) ID(in) Top(RKB) Set Depth(ORB) Set Depth(TVD)...WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 37.8 10,338.9 6,852.8 26.00 J-55 BTC-MOD Tubing Strings M.41, ,,Tubing Description String Ma...ID(in) Top(MB) Set Depth IN..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection UB 875I WO I 3 1/2 2.992 21.5 9,877.41 6,567.6 9.30 J-55 AB MOD-EUE CONDUCTOR;43.0-120.0-4. 3.5"x2.875" __ Completion Details / Nominal ID SAFETY VLV;1,784.2.E Top MEI) Top(ND)(RKB) Top Ind(*) Item Des Com (in) SLEEVE;1.784.0 _- 21.5 21.5 0.08 HANGER FMC GEN IV TUBING HANGER 3.500 1,784.2 1,672.3 42.20 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE(LOCKED OUT 2.812 6/14/92)FLAPPER BROKEN OFF(5/31/92) 9,650.2 6,431.7 53.58 NIPPLE OTIS X SELECTIVE LANDING NIPPLE 2.813 GAS LIFT;3,255.6 9,687.4' 6,453.9 53.54 PBR BAKER PBR 3.000 9,701.1 6,462.0 53.52 PACKER BAKER HB RETRIEVABLE PACKER 2.890 9,759.2 6,496.6 53.41 BLAST RINGS CARBIDE BLAST RINGS 2.992- 9,825.2 6,536.1' 53.06 SLEEVE-C CAMCO CB-1 SLIDING SLEEVE;SHIFT CLOSED 2.750 SURFACE;422-9702.7-- 4/27/95 9,836.7 6,543.0 52.94 PACKER BAKER D PERMANENT PACKER 3.250 9,840.4 6,545.2 52.90 SBE BAKER SEAL BORE EXTENSION 3.250' GAS LIFT;5,952.3- 9,860.5 6,557.3 52.68 NIPPLE OTIS XN NIPPLE NO GO 2.250 9,876.6; 6,567.2 52.51 SOS BAKER SHEAR OUT SUB 2441 I GAS LIFT;7,623.8 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(RKB) (RKB) (°) Des Com Run Date ID(in) GAS LIFT;8,842.6 1,784.0 1,672.2 42.20'SLEEVE 2.85 NO GO,2.5"OD SLEEVE,2.30"ID,126"OAL), 5/9/2014 2.300 9,730.0 6,479.2 53.46 PLUG 2.13"BAKER IBP 5/212014 GAS LIFT;9,605.7 -1 9.861.0 6,557.7 52.68'PLUG XXN PLUG IN XN NIPPLE 4/192014 9,900.0 6,581.4 52.26 FISH 1 PIECE 5/8"x1"x1/4"OF BROKE SLIP STILL IN 8/14/2009 0.000 HOLE me Perforations&Slots NIPPLE:9.650.2 MM. ii AM Shot Dens Top(TVD) Btm(TVD) (shots/f Top MEI) Btm(RKB) (RKB) (RKB) Zone Date t( Type Can 9,793.0 9,809.0 6,516.8 6,526.3 C-1,UNIT B, 12/15/1991 10.0 IPERF Spiral(72 deg.) PBR;9,687.4 1R-17 Phasing;4.5"Csg Gun PACKER;9,701.1 - _.: 9,967.0 10,025.0 6,622.5 6,658.3 A-4,A-3,1R- 12/14/1991 4.0 (PERF 180 deg.phase;4.5" 17 Csg Gun PLUG;9,730.0 'T///.� 10,051.0 10,054.0 6,674.3 6,676.2 A-2,1R-17 12/14/1991 4.0 IPERF 180 deg.phase;4.5" Csg Gun f- - Cement Squeezes Top(ND)'Btm(ND) INJECTION;9,745.0 Top(MB) Btm(RKB) (RKB) (RKB) Des Start Date Cent 9,932.0 9,940.0 6,601.0 6,605.9 Cement Squeeze 12/4/1991 10,032.0 10,040.0 6,662.6 6,667.5 Cement Squeeze 12/4/1991 (PERF;9.793.0-9809.0-_ - Mandrel Inserts I St ati on Top(ND) Valve Latch Port Size TRO Run SLEEVE-C;9,825.2 I N Top(RKB) (RKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Comm f 3,255.6 2,495.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/1/2014 8:30 2 5,952.3 4,195.5 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 12/16/1991 9:30 3 7,623.8 5,211.1 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 12/16/1991 7:30 PACKER;9,836.7 °off" 4 8,842.6 5,955.7 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 12/16/1991 5:00 SBE;9,840A Cff 5 9,605.7 6,405.4 OTIS LBD 11/2 GAS LIFT DMY RM 0.000 0.0 6/24/1992 5:30??? i 6 9,745.0 6,488.1'CAMCO MMG-W 1 1/2 INJ DMY RK 0.000 0.0 6/14/1992 NIPPLE;9.860.5 1 t Notes:General&Safety PLUG;9,861.0 End Date Annotation 10/1 End Da NOTE:View Schematic w/Alaska Schematic9.0 SOS;9.876.6 FISH;9,900.0 0 co r=i - IPERF;3967.0.10.025.0- CD in (PERF;10,051.0-10.054.0 PRODUCTION;378-10.338.9 • " 1R-17 WELL WORK SUMMARY DATE~ SUMMARY 5/19/2015 DUMP BAILED SAND ON TOP OF IBP @ 9730' RKB...JOB IN PROGRESS. 5/20/2015 FINISH DUMP BAILING SAND ON TOP OF IBP @ 9730' RKB, '15'ABOVE IBP, PULL ISO SLEEVE IN SSSV @ 1784' RKB...JOB IN PROGRESS. 5/21/2015 DRIFT MULTIPLE TIMES & RUN MULTIPLE LIB'S TO DETERMINE FLAPPER POSITION, INCONCLUSIVE IMPRESSIONS....JOB SUSPENDED DUE TO CANNON AVAILABILITY. 5/22/2015 ATTEMPT TO CLOSE FLAPPER WITH DP USING LRS, PULL ST# 1 @ 3255' RKB, ATTEMPT TO CLOSE FLAPPER AGAIN W/ LRS BUT UNABLE TO CREATE PRESSURE DIFFERENTIAL JOB IN PROGRESS. 5/23/2015 FIRE TWO BULLETS © FLAPPER BUT UNABLE TO CLEAR OBSTRUCTION COMPLETELY, RUN LIB & FLAPPER CHECKERS TO CONFIRM, LIB & SECOND CANNON SHOT LOOK VERY SIMILAR....JOB IN PROGRESS. 5/24/2015 RECOVERED 3/4 OF A BTM PLUG FROM PREVIOUS DAY'S CANNON SHOTS, SHOT CANNON, PARTED EFIRE TS & FISHED EFIRE TS W/CANNON FROM SSSV....JOB IN PROGRESS. 5/25/2015 RAN MAGNET& LIB SHOWING OBSTRUCTION ON THE SIDES OF THE SSSV, ATTEMPTED TO SWAGE OUT SSSV BUT GAINED LITTLE TO NO GROUND, ATTEMPTED TO SCRAPE TRASH OFF SIDE OF SSSV BUT UNABLE TO GAIN GROUND....JOB SUSPENDED. *****FISH IN HOLE, BULLET FROM CANNON, SEE WSR**** FI�j, sA THE STATE Alaska Oil and Gas (7<, ofALASKA Conservation Commission x==_�y = 333 West Seventh Avenue O� a TR GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc alaska.gov SEAMED t L[ Diana Guzman Sr. Wells Engineer .r r l ConocoPhillips Alaska, Inc. j ` 14 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1R-17 Sundry Number: 315-047 Dear Ms. Guzman: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, • iv Daniel T. Seamount, Jr. Commissioner /4.. DATED this 7- day of February, 2015 Encl. STATE OF ALASKA AL :A OIL AND GAS CONSERVATION COM14, ON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request. Abandon r Rug for Redrill r Rerforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Tiirre Extension r Operational Shutdown r Re-enter Susp.Well r StimulateAlter casino g r Other:Break damaged SSSV flapper F 2 Operator Name. 4.Current Well Class: 5 Permit to Drill Number: ConocoPhillips Alaska, Inc. - Exploratory r Development r 191-114 3.Address: 6.API Number: Stratigraphic r Service r - P.O. Box 100360,Anchorage,Alaska 99510 50-029-22212-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No p` KRU 1 R-17 9.Property Designation(Lease Number). 10.Field/Pool(s): ADL 25635 • Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft). Plugs(measured): Junk(measured): 10345 . 6857 • 10253' 6798' 9730,9861 9900' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 120' 120' SURFACE 5661 9.625 5703' 4024' PRODUCTION 10301 7 10339' 6853' RECEIVED JAN 3 0 2015 AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9793-9809,9967-10025,10051-10054 6517-6526,6623-6658,6674-6676 3.5 x 2.875 J-55 9877 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER HB RETRIEVABLE PACKER ' MD=9701 TVD=6462 PACKER-BAKER D PERMANENT PACKER • MD=9837 TVD=6543 SSSV-CAMCO TRDP-4A SAFETY VALVE • MD=1784 TVD=1672 12.Attachments: Description Summary of Proposal p- 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 14 Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/13/2015 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG F ‘ Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Diana Guzman @ 265-6318 Email: Diana.Guzman@conocoohillips com Printed Name 7.4.0.A-4-a— Diiana Guzman Title: Sr. Wells Engineer Signature sPhone:265-6318 Date 1/2<9 /� Commission Use Only Sundry Number: V Conditions of approval: Notify Commission so that a representative may witness -7. \rj— c A 1 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: j f D J`z , -v C e e- 5 5 f,/, A. b C W r v , /- Gl r Fiz�)`vl /� �c kyl C/st7 fi,bi svh-nr, ' - Spacing Exception Required? Yes ❑ No i Subsequent Form Required: /O -- 4- 0 4- Approved 4- Approved by: /�� COMMISSIONER APPROVED BY THE COMMISSION Date: ate: I 41 / 5 1/7.1... Z/f//J5- UKpblpnisraA Lr.12 months trom the date of approval.fft 02_41_/.5. Form 10-403(Revised 10/2012) PIZ 1/31:0PS Submit Form ad Attachments in Duplicate RBDMS FEB - 6 2015 • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 21,2014 Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to use a Downward Shooting Cannon(DSC)to remove the broken SSSV flapper on the Kuparuk Well 1R-17(PTD# 191-114). Well 1R-17 was originally drilled and completed in 1991. During 1992 the well was fracked and while performing the post-frac work a cutter bar got hung up at 1774' WLM. Unsuccessful attempts to fish the toolstring located just below the SSSV showed that the control line pressure was tracking the tubing pressure.A BPV was set in the tubing hanger and the tree and adapter flange were removed in order to repair a leaking tubing hanger. The cut seals in the control line packing area of the tubing hanger were replaced. Post well work showed that toolstrings still could not get through the SSSV flapper. It also appeared that the SSSV flapper was 3 open with frac sand. Coil tubing washed the SSSV profile numerous times using 194 bbls of diesel. CT also tried to tag the SSSV flapper unsuccessfully after the SSSV did not pass the closure test. SL ran LIB and confirmed that the flapper was about 3 open. SL then ran in hole with the FTR tool and hit the flapper until the tool sheared but the flapper could not be opened all the way. Several LIB's ranging from 2.30"to 2.80"were ran in hole,tagging the flapper at 1768' WLM. Unsuccessful attempts to break the SSSV flapper with Kinley power jars were then performed. On June 14, 1992 the SSSV flapper moved behind the flow tube and the flapper was locked out. After a failing MIT-T on October 21, 2012, a Leak Detect Log was performed on April 30, 2014. Two leaks were identified at 9814' RKB and on GLM # 1 at 3262' RKB. A caliper ran on July 10, 2014 determined that the GLM area is patchable. Currently, due to many difficulties working past the SSSV, a set ISO sleeve with a 2.3" ID is holding open the SSSV. The 3.5"retrievable patch does not drift through the SSSV. Therefore, 1R-17 would need a RWO in order to repair the broken flapper to regain the injection into the A and C sands. Before being shut-in in 2013,well 1R-17 was injecting 600 bwpd. This sundry is intended to document the proposed work on the injection well, as well as request approval to break the SSSV flapper using the SLB Downward Shooting Cannon. Subsequently,a retrievable patch will be placed over the leaking GLM# 1 at 3262' in order to return 1R-17 to service without a RWO. If you have any questions or require any further information,please contact me at 907-265-6318. Sincerely, Diana Guzman Wells Engineer CPAI Drilling and Wells t KUP INJ 1R-17 COnOGOi'NftipS 0- Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl I") MD(ftKB) Act Btm(ftKB) 500292221200 KUPARUK RIVER UNIT INJ 60.15 2,800.00 10,345.0 --• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1R-17.7/2220144:5t58 PM SSSV:LOCKED OUT Last WO: 12/16/1991 42.99 9/20/1991 Vertical schematc lactuap Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'SLM 10,145.0 4/17/2014 Rev Reason:Mandrel Orientations lehallf 7/22/2014 HANGER:21.5 -mi. or Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 43.0 120.0 120.0 62.50 H-40 WELDED ', � Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread ,,,.,,...,,,,,�.,,,,., 1j Casing SURFACE 95/8 8.921 42.2 5,702.7 4,024.0_ 36.00 J-55 BTC I Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade 'Top Thread i. PRODUCTION 7 6.276 37.8 10,338.9 6,852.8 26.00.1-55 BTC-MOD Tubing Strings .Y.Tubing Description I String Ma...I ID(in) 'Top(ftKB) I Set Depth(ft..J Set Depth(ND)(...I Wt(Ibltt) (Grade 'Top Connection TUBING WO 312 2.992 21.5 9,877.41 6,567.6 9.30 J-55 AB MOD-EUE CONDUCTOR,43.0-120.0--• 3.5"x2.875" Completion Details Nominal ID SAFETY VLV;1,784.2 •;.7.11:7,,i Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) SLEEVE;1,784.0 21.5 21.5 0.08 HANGER FMC GEN IV TUBING HANGER 3.500 1,784.2 1,672.3 42.20 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE(LOCKED OUT 2.812 • 6/14/92)FLAPPER BROKEN OFF(5/31/92) 9,650.2 6,431.7 53.58 NIPPLE OTIS X SELECTIVE LANDING NIPPLE 2.813 GAS LIFT:3,255.6 - 9,687.4 6,453.9 53.54 PBR BAKER PBR 3.000 9,701.1 6,462.0 53.52 PACKER BAKER HB RETRIEVABLE PACKER 2.890 • 9,759.2 6,496.6 53.41 BLAST RINGS CARBIDE BLAST RINGS 2.992 9,8252 6,536.1 53.06 SLEEVE-C CAMCO CB-1 SLIDING SLEEVE;SHIFT CLOSED 2.750 SURFACE;42.25,702.7-s 4/27/95 9,836.7 6,543.0 52.94 PACKER BAKER D PERMANENT PACKER 3250 9,840.4 6,545.2 52.90 SBE BAKER SEAL BORE EXTENSION 3250 GAS LIFT;5,952.3 9,860.5 6,557.3 52.68 NIPPLE OTIS XN NIPPLE NO GO 2.250 9,876.6 6,567.2 52.51 SOS BAKER SHEAR OUT SUB 2.441 GAS LIFT;7,6230 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) • Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) GAS LIFT;8,842.6 1,784.0 1,672.2 42.20 SLEEVE 2.85 NO GO,2.5"OD SLEEVE,2.30"ID,126"OAL), 5/9/2014 2.300 9,730.0 6,479.2 53.46 PLUG 2.13"BAKER IBP 5/21/2014 F 9,861.0 6,557.7 52.68 PLUG XXN PLUG IN XN NIPPLE 4/192014 GAS LIFT:9,605.7. 9,900.0 6,581.4 52.26 FISH 1 PIECE 5/8"x1"x1/4"OF BROKE SLIP STILL IN 8/14/2009 0.000 HOLE Perforations&Slots NIPPLE;9.650.2 , I Shot (shotslf Top(ftKB) Btm(ftKB) Top(TVD) Btm(TVD) (ftKB) Dens (ftKB) Zone Date t) Type Com 9,793.0 9,809.0 6,516.8 6,526.3 C-1,UNIT B, 12/15/1991 10.0 IPERF Spiral(72 deg.) PBR:9,687.4 1R-17 Phasing;4.5"Csg Gun PACKER;9,701.1 -" 9,967.0 10,025.0 6,622.5 6,658.3 A-4,A-3,1R- 12/14/1991 4.0 IPERF 180 deg.phase;4.5" 17 Csg Gun PLUG:9,7300 F 10,051.0 10,054.0 6,674.3 6,676.2 A-2,1R-17 12/14/1991 4.0 IPERF 180 deg.phase;4.5" Csg Gun Cement Squeezes Top(ND) Btm(NG) INJECTION;9,745.0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com ' 9,932.0 9,940.0 6,601.0 6,605.9 Cement Squeeze 12/4/1991 • 10,032.0 10,040.0 6,662.6 6,667.5 Cement Squeeze 12/4/1991 • (PERF;9,793.0-9,8090 Mandrel Inserts • St , aB _ Top(ND) Valve Latch Port Size TRO Run SLEEVE-C;9.825.2 N Top(ftKB) MB) Make Model OD En) Sew Type Type (in) (psi) Run Date Com 1' 3,255.6 2,495.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 00 5/1/2014 8:30 2 5,9523 4,195.5 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 12/16/1991 9:30 3 7,623.8 5,211.1 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 12/16/1991 7:30 PACKER;9,036.7 ;; 4 8,842.6 5,955.7 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 12/16/1991 '5:00 SBE;9.840.4 N, 5 9,605.7 6,405.4 OTIS LBD 112 GAS LIFT DMY RM 0.000 0.0 6/24/1992 5:30?7? 6 9,745.0 6,488.1 CAMCO MMG-W 112 INJ DMY RK 0.000 0.0 6/14/1992 I NIPPLE;9,860.5 Notes:General&Safety � End Date Annotation PLUG;9.8610 !///i 10/18/2010 NOTE:View Schematic w/Alaska Schematic9.0 SOS;9,876.6 FISH;9,900.0- 0 I IPERF:9067.010,025.0-wI 1 t3 IPERF;10,051.0.10,054.0- PRODUCTION;37.0-10,338.9 ConocoPh i l l i ps Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 Well Name: 1R-17 PTD#: 191-114 Well Type: Injector Current Status: Shut in since 10/31/13 after failing a MIT-T (10/21/13) Tubing Size: 3 '/z", 9.3#, J-55, AB MOD-EUE 2 '/8", 6.5#, J-55, AB MOD-EUE Max Inclination: 60.15° 2800' MD Min ID in Well: ISO Sleeve with 2.30" Min ID at 1784' (5/9/14) Last Tag: 2.13" Baker IBP at 9730' (5/21/14) Scope of Work: To break the SSSV damaged flapper using the SLB Downward Shooting Cannon Estimated Start Date: February 6, 2015 Production Engineer: John Cookson Workover Engineer: Diana Guzman Work: 265-6318 E-mail: Diana.Guzman@conocophillips.com Procedure: DSL Pre-Downward Shooting Cannon Procedure: 1. Inspect Pad and work area for Hazards. Complete the Pre job safety meeting. 2. RU Digital Slickline and PT surface equipment as required. 3. Dump sand on top of the Baker IBP to protect it from flapper debris and Cannon bullet). 4. MU toolstring and pull DV from GLM #5 and leave open for circulation point. RWO needed if Cannon run is unsuccessful. 5. RIH and retrieve sleeve holding open broken SSSV flapper. 6. RIH and drift to flapper. Simulate total length of Cannon BHA to be confirmed by eFire and SLB DTR Cannon specialists. 7. RIH with LIB to confirm the SSSV flapper position. 8. Inspect impression and discuss flapper orientation with DSL Well Supervisor and Cannon specialist. Downward Shooting Cannon Procedure: 1. RIH with a no-go and tag the SSSV, paint flag on the line. 2. RIH with Downward Shooting Cannon configured and enough weight bars for a minimum of 350 lbs. Follow and perform the checks according to the SLB Explosives Safety Placard. 3. Prepare the Downward Shooting Cannon as follows: a. Ensure that the bore of the Barrel is clean. b. Ensure that the 'O' ring is assembled on the Bullet c/w holding rod and ring and insert to the required depth within the Barrel. c. Ensure that the 'O' ring is assembled on the Bull Plug and insert into the end of the Barrel (if assembly is to be run into well for pre-operational BOP pressure test, tape Bull Plug in place). 4. Lay down a layer of paper sheet on bench. Ensure work area is cleaned of any grit, dust or contaminant. Measure explosive charge and place in the power charge container. Ensure that the power charge container is then totally sealed. 5. Check the SLB Cannon Adaptor and Firing Head are undamaged and free of grit. ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 4. Lay down a layer of paper sheet on bench. Ensure work area is cleaned of any grit, dust or contaminant. Measure explosive charge and place in the power charge container. Ensure that the power charge container is then totally sealed. 5. Check the SLB Cannon Adaptor and Firing Head are undamaged and free of grit. 6. Take the power charge container to the cannon and insert into the Barrel. 7. Insert detonator into Firing Head and make up to Cannon. Ensure that all threads are free of any debris and that the adaptor will not foul the Power charge container as it is screwed in. 8. SLB DSL personnel will raise the DSL assembly and spot over the Downward Shooting Cannon. 9. Check that all threads and sealing faces are free of grit or contaminant with a cloth and assemble the Firing Head onto the Downward Shooting Cannon Adapter. Ensure that all connections on the DSL assembly are made up tight. 10. Raise the Downward Shooting Cannon assembly. Lower the Cannon assembly into the well and zero the depth counter. 11. Run the Cannon assembly in hole, tag flapper gently. 12. Pick up and retag to confirm that the cannon is in contact with the flapper based on the painted flag on the line. 13. Lightly tag flapper with cannon. 14. Remove any slack of the line as advised by the SLB DTR and SLB DSL Specialists, standby for tool firing. 15. Fire Downward Shooting Cannon. 16. After firing, DO NOT USE THE CANNON TO HAMMER ON TOP OF THE TARGET. Cannon may be used to gently retag the target. 17. POOH. 18. Clear the wellhead and wellhouse of all non-essential personnel. 19. Disconnect the Cannon Adaptor from the DSL assembly. On recovery from the well visually confirm the tool detonation, Disconnect the Adaptor. Lay down the Barrel. 20. In the event of a misfire clear the area of all personnel. a. Immediately disarm the Cannon ballistically by removing the firing head from Power charge container then remove cable head from firing head. b. Remove the detonation cord and place in explosives bunker in a marked bag. Post-Downward Shooting Cannon Procedure: 1. RIH with LIB to confirm flapper is gone. 2. Begin fishing cannon bullet and flapper remnants. 3. RIH with bailer and clean sand and flapper debris from top of IBP. 4. POOH 5. RDMO , . • Schlumberger Downward S APPLICATIONS The downward shooting cannon(DSC)is a ballistic device,which ' ■ Eliminates obstructions in tubing and propels a large bullet in a downwards direction to break or dislodge casing wellbore obstructions.The DSC can be used as an alternative when ■ Dislodges set bridge plugs target material hardness or free rotation of the target makes milling • Opens casing restrictions and re-aligns operations impractical. parted casing The DSC has been used successfully in both oil and gas wells and has • Alternative when milling target material completed the following operations: is impractical ■ fragmentation of broken flappers from subsurface safety valves BENEFITS • unsetting bridge plugs,allowing them to be pushed downhole • Saves operational costs by eliminating • removing bull plugs from the end of tubing completions wellbore obstructions more quicklyh`f and effectively than other costly inter- Using propellant,or a similar equivalent,the resulting gas expansion vention methods accelerates the bullet down the barrel of the tool to directly impact the target at a velocity of 3,000 to 5,000 ft/s. FEATURES • Bullet has standard fishing neck The DSC bullet is retrievable from the well and custom made fishing necks can be added to the bullet to aid recovery. • Custom designs available upon request • Can be run on slickline,e-line,coil Downward Shooting Cannon Specifications tubing,or drillpipe Barrel Dimensions Bullet OD,in OD,in ID,in Length,ft 2.157 1.50 10 1.437 2.700 2.00 10 1.937 3.375 2.75 8 2.690 4.0 to 5.5 3.00 8 2.937 4.5 to 5.5 3.50 8 3.437 5.0 to 5.75 4.00 8 3.937 5.625 4.50 8 4.437 Downward shooting cannon 'Mark of Schlumberger Other company,product,and service naives,are the properties o1 their respective owners. {, Copyright©2011 Schlumberger.All rights reserved.11-S11-0041 1IV IV W.S I U.C OITI 17` I Jilii U n 016110111%, A Business Unit of Smith International,(North Sea)Ltd RED BARN r ROUP 4iir HOTFORGE JUNK SHOTS FOR THE PERFORATION, DISLODGING OR FRAGMENTATION OF FLAPPER VALVES, BALL VALVES, BRIDGE PLUGS OR OTHER DOWN HOLE JUNK HOTFORGE JUNK SHOTS DOWNWARD SHOOTING CANNON Hotforge Junk Shots have been used to perforate The Downward Shooting Cannon is a ballistic 4 ball and flapper valves and successfully dislodge device which propels a large bullet in a bridge plugs and other obstructions within downwards direction to break or dislodge downhole tubing strings. wellbore obstructions. Hotforge Junk Shots are run on wireline and The Downward Shooting Cannon can be used as 4 incorporate a conical shaped charge within a an alternative where target material hardness or f` specially designed junk shot body. When free rotation of the target makes milling , initiated,the shaped charge creates a plasma jet operations impractical. +. which exits the bottom of the charge case and penetrates through the target.For this jet to form The Downward Shooting Cannon has been used correctly an air filled stand-off chamber is successfully in both oil and gas wells and has incorporated into the design.An additional shock completed the following operations: wave is directed onto the target.This shock wave The fragmentation of broken flappers from sub can produce failure in brittle targets. The surface safety valves. explosive charge weight within the assembly is The fragmentation of ball valves. not however of sufficient quantity to cause The un-setting of bridge plugs to allow them to rupture of the tubular in which the Junk Shot is be pushed downhole. & `, detonated. The removal of bull plugs from the end of tubing *y completions. To ensure that the jet is directed down the tubing axis,a leaf spring centraliser is included on the Utilising Black Powder as the propellant, once shock absorbing mandrel connected to the ignited the resultant gas expansion accelerates TRSSSV Monel K500 flapper fragments charge. This centraliser orients the axis of the the bullet down the barrel of the tool to impact Junk Shot with the axis of the tubular. directly onto the target with typically 2 x 106 and 2.6"OD Bullet Crossovers to fit the wireline assembly are ft.lbs of kinetic energy.As the gas generated is after impact by the supplied as standard with the Junk Shot contained by the body of the tool, there is no 3 3/8"OD Downward Shooting Cannon equipment. lateral expansion or deformation created to the tubular assembly in which the Cannon is The Hotforge Junk Shots body can be supplied in deployed. For maximum effect the Downward a choice of materials. Upon detonation the steel Shooting Cannon is required to be in intimate Junk Shot body is designed not to fragment(in contact with the target. After exiting the barrel, order to prevent further junk being left the speed of the bullet is very rapidly attenuated downhole). The steel body does however swell to fall with the gravitational balanced velocity. and it must be noted that retrieval through The bullet is readily deflected off the sides of the restrictions may prove difficult.As an alternative tubular and only minimal superficial damage is to the steel Junk Shot body, a plastic body created to the tubular completion. (PEEK)can be provided.This Junk Shot design has been pressure tested to 7000 psi at a The Downward Shooting Cannon bullet is temperature of 258° F and has been utilised retrievable from the well and custom made downhole at depths over 13,000 ft. fishing necks can be incorporated onto the bullet to aid recovery. Versions of the Hotforge Junk Shot utilise shear pins to secure the charge case to the detonator The Downward Shooting Cannon is best initiated housing. These shear pins break when a tension through electric wireline. To minimise recoil of 890 lbf is applied to the wireline. This 3501bs weight typically is added to the wireline ensures that after detonation the wireline assembly. Crossovers provided are compatible assembly can be retrieved to surface. However with all major wireline companies equipment.In the inclusion of shear pins in the design does the unlikely event that the deployment assembly increase the chance of the remains of the swollen breaks,a no-go ring can be incorporated into the Junk Shot Body being left downhole during Cannon assembly thus preventing the assembly retrieval of the wireline. being lost downhole. Hotforge Junk Shots can be designed and The stock size of Downward Shooting Cannon manufactured to meet with customer Smith Red Baron provides is 3.375 inches OD. specifications. There are currently four sizes of Other sizes of Cannon can be custom made to Junk Shot that Hotforge have available. meet the Client's specification. Description O.D.(Inches) 3 3/8" Downward Shooting Cannon Specification: 51DP Junk Shot 3.25 Total length c/w Barrel,Firing Head HP Adaptor 41C Junk Shot 2.579 and X-Over -6ft. Bullet Specifications - 2.6" OD x 12" long. FFGDP Junk Shot 2.275 Weight 5.5 kg. Maximum operational propellant temperature 16 P Junk Shot 2.0 rating-400°F. Maximum operational pressure rating - 10,000 psi. Bullet exit velocity-768m/s(1718 mph). SMITH 3.375" OD Downward Shooting Cannon — Shot Summary Date Job No. Customer Location Target Apr 96 0496/038 CSOL Hotforge Test Centre Inconel 925 Flapper from SSSV The valve housing was submerged in water at ambient pressure. The Cannon was centralised vertically on top of the flapper sitting flat in the housing. The Cannon was restrained against a concrete tower. Upon detonation the flapper fragmented into several parts. Only superficial damage was created to the housing. Sept 96 0996/038 Phillips Hotforge Test Centre 5.5" Guiberson AVA Shorty Bridge Plug The Cannon was centralised vertically in water at ambient pressure on top of the plug. The Cannon was restrained against a concrete tower. The initial shot resulted in no apparent movement or damage to the bridge plug. For the second shot, the Cannon was stood vertically but un-centralised against the wall of the tubing before being restrained against the concrete tower. Upon retrieval of the Cannon, the plug could be pushed down the tubing. Examination of the remains of the plug showed that the top of the mandrel had been sheared off and that tensile failure of the mandrel had occurred within the body of the plug. A number of the screws retaining the elements had sheared, thereby allowing the packer elements to retract. Nov 96 1196/110 Maersk Hotforge Test Centre TRSSSV Flapper K500 Monel The flapper was initially perforated with a Schlumberger "Energet" perforator centralised and in contact with the flapper in air at ambient pressure. The perforator produced a neat hole of approximate 0.25" entrance diameter in the centre of the flapper. The flapper was then placed horizontally in the flapper housing. The Cannon was then centralised on top in direct contact with the flapper. The Cannon was restrained against a concrete tower. Upon detonation the flapper fragmented into approximately 8 pieces. A second shot was conducted as previously described with the exception that the flapper was not initially perforated with the "Energet". Upon initiation of the second shot the flapper fragmented into approximately 12 pieces. Only superficial damage had occurred to the flapper housing. May 97 1196/110 Maersk Gorm B GBN-15 4.5" TRB-8-FSR-SHC Flapper K500 Monel Run on Schlumberger wireline with 5001bs sinker bars in a gas well (gas above and below the flapper). Vertical hole. Prior video run showed the flapper in a horizontal position at 358 ft. Cannon in contact with neutral weight on flapper. Flapper fragmented at first shot (not pre-perforated by Schlumberger). Cannon retrieved with no problem. No attempt made to fish for the Bullet. Subsequent drift run to perforations at 8,011 ft showed no apparent damage caused to the completion and side pocket mandrel clear. Jun 97 0697/039 KCA Dunlin DA-36 5.5" Ocre Valve L80 Flapper Run on Atlas wireline with 500 lbs sinker bars in vertical well (displaced to water) after video run shows that the flapper was sitting horizontally on the housing at 7,926ft. Cannon deployed to contact flapper with neutral weight. Successful full order detonation results and the Cannon was retrieved without problem. However 2" LIB shows that the flapper is still in position but the bullet has disappeared. Second shot not attempted. Subsequently at a later date the completion was pulled. On examination, scoring marks on the flapper and housing showed that the bullet had impacted on one side of the flapper causing the flapper to flip over and allowing the Bullet to pass through without fragmenting the flapper. y TH Aug 97 0897/061 Oryx UK Murchison M27 5.5"Halliburton SP-1 SSV Flapper Inconel 925 Run on Atlas wireline with 5001bs sinker bars. Video camera could not determine exact orientation of the flapper but was assumed to be in an almost horizontal orientation in vertical hole. Shot-1 full order detonation but flapper remained in place. Cannon was retrieved without event. Shot-2 fragmented flapper. Cannon retrieved from valve housing after overpull being applied. No attempt made to recover the Bullet. Subsequent operations showed that no apparent damage had been created to the well. Oct 97 0997/074 BP Foinaven P27 5.5" Halliburton SP-1 SSV Flapper Inconel 925 The well was displaced to seawater/glycol mix and a camera run was performed to ensure that the flapper was in a horizontal position before the Cannon was run on Schlumberger wireline with 5001bs sinker bars. Indications on surface showed that the first shot was fired full order but did not achieve penetration through the flapper and the Cannon was recovered with the Bullet still held in the end of the Barrel. The second shot successfully fragmented and removed the flapper. However the wireline assembly parted by failure of the grub screws holding the Red Baron Group X-over to the Schlumberger Shooting Adaptor. (This X-over has now been superseded by one with a MH22 thread connection). The Cannon had been prevented from falling downhole by the inclusion of a no-go ring assembled on the Cannon's Firing Head (the Cannon had been held up by the flapper sleeve. The Cannon was successfully fished. Subsequent well operations showed that no unacceptable damage had been caused to the valve housing or well. Aug 98 0898/053 Shell HotforgeTest Centre 5" Halliburton Ball Valve Pyromet 31 Yield 80kpsi 35RC The Cannon was positioned vertically on top of the ball valve assembly in the closed position at atmospheric conditions. The Cannon was restrained against a concrete tower before being initiated. Upon initiation the upper half of the ball broke into pieces with the lower half remaining intact. The ball has plastically deformed (squashed by the impact) resulting in expansion to the valve housing. As permanent deformation to the valve housing was an unacceptable outcome,no further shots were conducted. Sept 98 0998/055 Oryx UK Murchison M38 5.5" Halliburton SP-1 SSV Flapper Inconel 925 Run on Schlumberger wireline with 5001bs sinker bars. The flapper was determined to be in an almost horizontal orientation before the Cannon was run. The Cannon was run in hole (running weight 2001bs down, 6001bs up) to contact the flapper at 988ft in vertical hole. The Cannon was fired with 1501bs weight on the flapper. The flapper was fragmented with the initial shot and the wireline c/w Cannon was retrieved to surface without event. No attempt made to recover the Bullet. Subsequent feedback was that no apparent damage had been created to the well. Oct 98 1098/064 Halliburton Hotforge Test Centre 7" TRSV Halliburton Flapper Inconel 718 Yield 125 kpsi Two shots were conducted on separate flappers in air at ambient conditions. The Cannon was centralised vertically on each flapper and restrained against a concrete tower before being initiated. Shot 1- resulted in the flapper being broken into 3 pieces. Shot 2-the other flapper was broken into 6 pieces. Little damage was sustained to the valve housing as the bullets passed through. Stith- IN Nov 98 1198/075 Total North Alwyn N18 Halliburton SP-01 SSV Flapper Video camera run could not determine orientation of the flapper. LIB run on slickline however showed that the flapper was inverted and in a horizontal position. The Cannon run on Schlumberger wireline with 6501bs weight, fragmented the flapper at the first attempt at 276.3 metres. However the wireline assembly had parted at the connection immediately beneath the wireline weak point. The Cannon had been prevented from falling downhole past the TRSV by the inclusion of a no-go ring on the assembly. The Cannon was successfully fished. Subsequently a 4" gauge ring successfully passed through the flapper profile. After three broach runs to clean seal bore, the valve was successfully locked open to allow the control line fluid path and the insert valve to be set and tested. The well was put back into production flowing at a rate of 4000 BOPD. Dec 01 1201/032 BP Amoco Adriatic 6 PES Plug in 4'h" Tail Pipe Shot 1- Cannon deployed on Schlumberger wireline with 500 lbs sinker bars to tag plug at 10,080ft. Full order detonation (report heard on drill floor).Temporary well pressure reduction noted. Cannon retrieved without event. Bullet successfully fished on slick-line (impact marks noted on bottom of Bullet). Shot 2- Plug tagged at 10,080ft. Cannon fired in contact with plug, full order detonation and fluctuation of pressure noted on drill floor, no apparent movement of fish. POOH with no problem. Drill floor reports that well is now flowing. Review of Cannon retrieved from well shows that the Bullet was 3ft up inside of Barrel. Debris including remains of a JRC tubing cutter mandrel, both Cannon Bull Plugs, unidentifiable o-rings and steel fragments found inside Barrel. Bullet once recovered from Barrel showed scoring and impact marks. Shot 3 — Plug tagged at 10,080ft. Cannon fired in contact with plug, full order detonation and fluctuation of pressure noted on drill floor, no apparent movement of fish. POOH again with no problem. Observations of Cannon retrieved from well detailed that The Cannon Bull Plug was protruding from the end of the Barrel, that debris including remains of a JRC tubing cutter charge case and other steel pieces were found inside the Barrel. The Bullet was 5ft up inside of Barrel. Again indentation and scoring to end and side of Bullet noted. No further Cannon runs conducted. Jul 03 0403/010 Talisman Limehillock Test Centre 3" Baker Bridge Plug in 7"x 29#Casing A Well Tractor drilled a 3.8 inch diameter hole with an expandable bit through the 2ft cement plug on top to the mandrel of the pre-set Bridge Plug. This hole was then sufficiently large enough to allow the Cannon to drift through. The trial was completed on surface at ambient conditions in air but with a fluid barrier beneath the bridge plug. Recoil was minimised by the means of restraining strops attached from the top of the Cannon to a concrete tower. Upon initiation of the Cannon, the bullet entered and stuck in the bore of the bridge plug mandrel's fishing neck, causing this fishing neck to expand, split and a piece to break off. Insufficient shock had been transferred down the mandrel by the impact to cause the bridge plug element to move or rupture. The complete 2 feet depth of the cement on top of the bridge plug fragmented. In addition the cement in the annulus between bridge plug mandrel and casing was extensively fractured. The cement bonds with both the mandrel and the casing wall had additionally failed. Apr 05 1104/014 Shell Sedco 711 5.5" Otis Ser 10 TRSSSV Flapper 110Kpsi Yield Run on Schlumberger wireline and initiated with Schlumberger 2 7/8 SAFE setting tool initiating system. Minimum 350 lbs of weight bars utilised (BHA down-hole hanging weight 7501bs).No-go of 4.6325" incorporated in wireline BHA. Cannon fired at 1305ft with flow tube in contact with flapper. Subsequent camera run showed approximately 2/3rds of flapper remaining with two further smaller pieces of junk on top. These smaller pieces fall down hole on application of injection flow and functioning of flow tube. nem The bottom of the flow tube had been bent inwards slightly. Subsequent swage runs were unsuccessful but a 2.25" drift run was successful in passing through the valve. June 07 8080-088050 Schlumberger,Alaska 4 'A" TRCF-4A Safety Valve,Inconel 718 Run on Schlumberger wireline and initiated with E-Fire system. 387 lbs of weight bars. Shot fired at 2,089'. POOH. RIH LIB.No evidence of bullet on top of target. Flapper appeared to be gone. Fishing operations to recover bullet commenced but no further communication with client. -Loepp, Victoria T (DOA) From: Guzman, Diana <Diana.Guzman@conocophillips.com> Sent: Wednesday, February 04, 2015 9:53 AM To: Loepp,Victoria T(DOA) Subject: RE: KRU 1R-17(PTD 191-114, Sundry 315-047) Good morning Victoria, The sundry only covers the Cannon procedure. If we're successful removing the SSSV flapper we will submit a separate sundry requesting approval to run the tubing patch. Thank you, Sincerely, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax•918-662-1893 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, February 04, 2015 9:42 AM To: Guzman, Diana Subject: [EXTERNAL]KRU 1R-17(PTD 191-114, Sundry 315-047) Diana, Is this sundry also requesting approval to run the tubing patch or will a separate sundry be written? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp analaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loem@alaska.gov 1 XHVZE Pages NOT Scanned in this Well History File 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. PAGES TO DELETE Complete RESCAN ri Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED -1:3' Logs-of vadous kinds . Other COMMENTS: Scanned by: Dianna Vincent Nathan Lowell ''L n TO RE-SCAN Notes: · Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: isl • • Wallace, Chris D (DOA) From: NSK Problem Well Supv[n1617@conocophillips.com] Sent: Friday, October 25, 2013 1:54 PM To: Wallace, Chris D(DOA) Cc: Dethlefs, Jerry C; NSK Problem Well Supv Subject: RE: 1R-17(PTD 191-114) Report of IA pressure increase Chris, An update on the diagnostics. The MITIA failed and the well has been SI. Further diagnostics will be scheduled. The well has been added to the monthly report. Please let me know if you have any questions. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907)659-7000 pgr. 909 From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent:Tuesday, October 22, 2013 7:09 AM To: NSK Problem Well Supv Cc: Dethlefs,Jerry C Subject: [EXTERNAL]RE: 1R-17 (PTD 191-114) Report of IA pressure increase Brent, Your request to leave the well on injection for monitoring and diagnostics is approved. Thanks and Regards, Chris Wallace `p► `) 2t,',Sr. Petroleum Engineer S �N Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace @alaska.sov From: NSK Problem Well Supv [mailto:n16170conocophillips.com] Sent: Monday, October 21, 2013 4:55 PM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; Dethlefs,Jerry C Subject: 1R-17 (PTD 191-114) Report of IA pressure increase Chris, Kuparuk injector 1R-17(PTD 191-114)was reported with a pressure spike on the IA. The immediate action was to bleed the IA down. The initial diagnostics will include tubing and inner casing packoff testing,an MITIA and an IA DD test if the MIT passes. Further diagnostics will be dependent upon the initial results but may include E-line and Slickline work. ConocoPhillips requests to leave the well on injection at least until the MITIA and/or IA DD test is complete. The initial diagnostics are scheduled to be done on 10/22/13. Once any communication has been confirmed the well will be shut in while a plan forward is decided upon. The appropriate paperwork will be submitted as needed. 1 • Attached is a copy of the wellbore schematic and 90 day TIO plot. Brent Rogers/Kelly Lyons Problem Wells Supervisor Conoco Phillips Alaska, Inc. Desk Phone(907)659-7224 Pager(907)659-7000 pgr. 909 CHOKE FTP IAP TWO Plot - 1R-17 OAP 2000 1500 (7) a- 1000 - 500 -LI•••• 21-J ul-13 03-Aug-13 16-Aug-13 29-Aug-13 11-Sep-13 24-Sep-13 07-Oct-13 Date 2 Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, October 22, 2013 7:09 AM To: 'NSK Problem Well Supv' Cc: Dethlefs, Jerry C Subject: RE: 1R-17 (PTD 191-114) Report of IA pressure increase Brent, Your request to leave the well on injection for monitoring and diagnostics is approved. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907) 793-1250(phone) (907) 276-7542(fax) chris.wallace @alaska.gov From: NSK Problem Well Supv [mailto:n1617©conocophillips.com] Sent: Monday, October 21, 2013 4:55 PM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; Dethlefs, Jerry C Subject: 1R-17 (PTD 191-114) Report of IA pressure increase Chris, Kuparuk injector 1R-17(PTD 191-114)was reported with a pressure spike on the IA. The immediate action was to bleed the IA down. The initial diagnostics will include tubing and inner casing packoff testing,an MITIA and an IA DD test if the MIT passes. Further diagnostics will be dependent upon the initial results but may include E-line and Slickline work. ConocoPhillips requests to leave the well on injection at least until the MITIA and/or IA DD test is complete. The initial diagnostics are scheduled to be done on 10/22/13. Once any communication has been confirmed the well will be shut in while a plan forward is decided upon. The appropriate paperwork will be submitted as needed. Attached is a copy of the wellbore schematic and 90 day TIO plot. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 Pager(907)659-7000 pgr. 909 1 CHOKE FTP FIT IAP T/1/0 Plot - 1R-17 OAP 2000 - 1500 - (7) 1000 _ 500 = • • •• . 0 21-Jul-13 03-Aug-13 16-Aug-13 29-Aug-13 11-Sep-13 24-Sep-13 07-Oct-13 Date 2 KUP 1 R-17 ConocoPhillips ..""'*' Well Attributes Max An le&MD TD 1 -g---- Alaska lac. Wellbore API/UWI Field Name Well Status Intl() MD(ftKB) Act Btm(ftKB) tt>KUnt+Vwps 500292221200 ]KUPARUK RIVER UNIT INJ 1 60.15 . 2,80000 10.345.0 (Comment H2S(ppm... ) Date A notation End Date KB-Grd(ft) Rig Release Date SSSV:LOCKED OUT 1Last WO: 12/16/1991 42.99 9/20/1991 I Well Confq -1R-17 114 2013 9.05.11 ALI _ Schem n Actual Annotation Depth(HKB) End Date Annotation Last Mod...End Date Last Tag:RKB 10,007.0 11/23/2012 Rev Reason:SET SLIPSTOP ON TRDP SLEEVE osbod HANGER,21 Casing_Strin t s Casing Description String 0... String ID...Top(ftKB) Set Depth(}...Set Depth(TVD)...String Wt..String...String Top Thrd CONDUCTOR 16 15.062 43.0 120.0 120.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd t. t Tubin. St` E. Tubing Description String 0... String ID...Top MKS) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd �F TUBING WO 3 1/2 2.992 21.5 9,877.4 6,567.6 9.30 J-55 AB MOD-EUE ) 3.5"x2.875" CONDUCTOR._ 43-120 r•'r. Top Depth SLIPSTOP, (TVD) Top net Noml... 1,782 L.. - _ Top(ftKB) (MB) PI Item Description Comment ID(In) SLEEVE,Y 1,784 0.09 FMC GEN IV TUBING HANGER 3.500 i SAFET1,784 - 42.20 CAMCO TRDP-4A SAFETY VALVE(LOCKED OUT 6/14/92)FLAPPER !. BROKEN OFF(5/31/92) • t 53.62 NIPPLE OTIS X SELECTIVE LANDING NIPPLE GAS LIFT. _ 53.55 PBR BAKER PBR 3.000 3.258 9,701.1 • t 53.52 PACKER BAKER HB RETRIEVABLE PACKER 2.890 9,759.2 6,496.6 53.41 BLAST RINGS CARBIDE BLAST RINGS 9,825.2 6,535.9 52.51 CAMCO CB-1 SLIDING SLEEVE;SHIFT CLOSED 4/27/95 2.750 52.47 PACKER BAKER D PERMANENT PACKER 3.250 S 42-5 703 '4 t 52.46 SBE BAKER SEAL BORE EXTENSION 3.250 I.. 52.40 NIPPLE OTIS XN NIPPLE NO GO 2.250 GAS LIFT._. _--_ +' 9,876.6 6,567.2 52,34 SOS BAKER SHEAR OUT SUB Mil 5,952 .. •"'er ' `o it(Wireline °::plugs,valves pumps,fish, GAS LIFT. Top Depth T 7,524 (TVD) Top Inc! Top(ftKB) (MB) 1 (1 Description Comment Run Dab ID(in) 1,782.0 1,670.7 42.14 SLIPSTOP 3.5"D&D SLIPSTOP SET ON TOP OF SLEEVE IN TRDP 12/12/2012 1.490 GAS LIFT, 8,843 y 1,784.2 1,672.3 42.20 SLEEVE SLEEVE(1.785"ID)SET IN TRDP TO HOLD IT OPEN, 8/11/2006 1.490 OAL 63 1/4" It 9,900.0 6,581 52.27 FISH -1 PIECE 5/8"x1"x1/4"OF BROKE SLIP STILL IN HOLE .,8/14/2009 0.000 GAS LIFT, . - ,. ____lo _ .. 0,608 IC. Perforations&Slots IShot l Top(TVD) Dens Top(NKB)Bbn(ftKB) (ftKB) Zone Dab (oh- Type Comment NIPPLE,9.850- ft 9,793.0 9,809.0 6,516.8 6,526.1 C-1,UNIT B, 12/15/1991 10.0 IPERF Spiral(72 deg.)Phasing;4.5"Csg I 1R-17 Gun 9,967.0 10 025.0 6,622.5 662 A-4 A-3,1R-17 12/14/1991 4.0 IPERF 180 deg.phase;4.5"Csg Gun 10,051.0 10,054.0 6,674.3 6.676.2 A-2,1R-17 12/14/1991 I 4.0 IPERF 180 deg.phase;4.5"Csg Gun PBR.9,587 PACKER,9.701 II.I�y Cement Squeezes Top Depth'Btm Depth (TVD) (WD) Top(ftKB)Btm(ftKB) (ftKB) MKS) Description Start Date Comment 9,932.0 9,940.0 6,601.0 6,606.0 Cement Squeeze 12/4/1991 INJECTION, 10,032.0 10,040.0 6,662,5 6,667,5 Cement Squeeze 12/4/1991 -- 9,745 ate*:.G. neral&Safety End Dab Annotation 10/18/2010 NOTE:View Schematic w/Alaska Schematic9.0 IPERF, 9,793-9809 SLEEVE-C, 0825 PACKER,9,837 1 SBE,9840 NIPPLE.9,860 SOS,9.877 - FISH,9,900 - Y Mandrel Details Top Depth Top Port Squeeze (WD) Intl OD Valve Latch Size TRO Run Perforati,. 9,932 Stn Top(ftKB) (ftKB) PI Male Model (in) Sore T . Type On) (Psi) Run Dab Com... IPERF. 1 3,255.6 2,495.0 56.84 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/29/1992 9957-10025- - - --* 2 5,952.3 4,195.1 47.99 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 12/16/1991 3 7,623.8 5,211.0 51.19 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 12/16/1991 Squeeze Perforating I 4 8,842.6 5,955.6 53.77 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 12/16/1991 10,032 5 9,605.7 6,405.6 53.71 OTIS LBD 1 12 GAS LIFT DMY RM 0.000 0.0 6/24/1992 IPERF. _ 10,051-10.064 0_ 6 9,745.0 6,488.2 53.43 CAMCO MMG-W 1 1/2 INJ DMY RK 0.000 0.0 6/14/1992 PRODUCTION, 313-10.339 N TO 10,345 A ! • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission r 7 DATE: Thursday, December 29, 2011 TO: Jim Re gg ,0 t P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1R -17 FROM: Bob Noble KUPARUK RIV UNIT 1R -17 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1R - 17 API Well Number: 50 029 - 22212 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN111227163500 Permit Number: 191 - 114 - Inspection Date: 12/27/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I R-17 'Type Inj. W ' TVD 6462 IA 928 2535 ' 2505 2496 P.T.D 1911140 , TypeTest SPT Test psi 1615 - OA 580 620 620 620 Interval 4YRTST p/F P . Tubing 1400 1400 1400 1400 Notes: Thursday, December 29, 2011 Page 1 of 1 • C011 ~ . . ocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ ~ . .iry 1 ~ e _ 4 { -° ... a.~ 4}::. . v, r . i: . av"~ir .. .~, ~ SEP 0 ~ 2009 A~~~k~ 0~1 ~ f~;~ CAnsa ~o 'ssion ~~~~~~~ 1 ~ `, ~ l~4 ~- ~'~ /~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 15~' and 23`d 2009, and the corrosion inhibitor/sealant was pumped August 27~`, 28;~ and 29th 2009. The attached spreadsheet presents the well name, top of cement depth prior to filiing, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, .i'~~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor - '.1. • ~ ~ ~ _. _ . . , -- ~,~;~ ~ ~ ~~ ~ . 1~~., _ . ~. r _, ~ ;~~ _.~, .,~ ~,. ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-~404) Kuparuk Field Date 8/29/09 1R PAD Well Name AP4 # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitorl sealant date ft bbls ft al 1 R-01 B 50029214040200 . 2001560 13'7" 2.0 26" 8/15/2U09 5.1 8/27/2009 1 R-02 50029214050000 1851760 80' 13.30 23" 8/23/2009 4.7 8/28f2009 1 R-03A 50029214060100 2000210 15' 3.00 27" 8/15/2009 5.3 8/28/2009 1 R-04 50029214070000 1851780 15'2" 3.00 26" 8/15/2009 5.1 8/28/2009 1 R-05 50029213300000 1850700 20'9" 2.20 23" 8/15/2009 3.8 8/28/2009 1 R-06 500292'13310000 1850710 14' 2.00 23" 8/15/2009 3.8 8/28/2009 1 R-07 50029213320000 1850720 44' 5.00 24" 8/15/2009 4 8/28/2009 1R-08 50029213330000 1850730 8' 1.00 21" 8/15/2009 13.7 8/28/2009 1 R-09 50029213500000 1850950 9' 1.20 25" 8/15/2009 4.3 8/28/2009 1 R-10 50U29213510000 1850960 32' 5.40 22" 8/15/2009 3.4 8/28/2009 1 R-11 50029213520000 1850970 47' 6.00 38" 8/15/2009 13.9 8/28/2009 1 R-12 50029213530000 1850980 38' 6.00 24" 8/15/2009 4 8l28/2009 1 R-13 50029213850000 1851500 10' 0.50 25" 8/15/2009 4.3 8/29/2009 1 R-15 50029213870000 1851520 21'4" 4.00 35" 8115/2009 12 8/29/2009 1R-16 50029213880000 1851530 12'6" 9.00 21" 8/23/2009 3.8 8/29/2009 1 R-17 50029222120000 1911140 20" N/A 20" N/A 4.4 8/28/2009 1R-18 50029221880000 1910870 9'4" 1.20 21" 8/15/2009 3.7 8/28/2009 1 R-19A 50029221850100 1910850 18" N/A 18" N/A 10.2 8/29/2009 1 R-20 50029222070000 1911080 8'4" 2.00 19" 8/15/2009 11.3 8/29/2009 1R-22A 50029222060100 1990490 16" N/A 16" N/A 9 8/29/2009 1 R-23 50029222000000 1911010 18'8" 2.30 39" 8/15/2009 13.9 8/29/2009 1 R-25 50029221530000 1910470 7'4" 1.50 26" 8/15/2009 5.1 S/27/2009 1 R-26 50029221930000 1910920 7' 3.50 38" 8/23/2009 13.9 8/28/2009 1 R-27 50029222010000 1911020 18" N/A 18" N/A 5.1 8/28/2009 1R-29 50029221950000 1910940 18" N/A 18" N/A 4.1 8/28/2009 1R-35 50029230500000 2012100 18" N/A 18" N/A 5.3 8/29/2009 1R-36 50029230570000 2012270 19" N/A 19" N/A 5.3 8/29/2009 . . MEMORANDUM TO: FROM: State of Alaska Alaska Oil and Gas Conservation Commission J iill Regg 'Kki:;1 6 (4iù 7 P.I. Supervisor (" DATE: Friday. May 11. 2007 RCN Petroleum Inspector Sl'B.JECT: Mechanical Integnty Tests C01\OCOPHJLLIPS ALASKA rNC JR-J7 KUPARUK RIV UNIT IR-17 Src: [nspector NON-CONFIDENTIAL Well Name: KUPARUK RN UNIT IR-l7 Insp Num: mitRCN07051 02 10426 Rei Insp N urn: Well I P.T.Di Interval Notes: Friday, May 11, 2007 API Well Number: 50-029-22212-00-00 Permit Number: 191-114-0 Packer Depth \ ~ \ _ \\ '1 Reviewed Bv: P.I. Suprv $12-- Comm Inspector Name: RCN Inspection Date: 5/9/2007 1470 2500 Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. __l____~~ 1R-17 !Type Inj~ i G I TVD 1_646:.! ITypeTest I SPT !~st.~s} I 1615.5 ý/ ------. I IA OA I I ---- ---.----,,-- : -¡----------. - 3400 3400 ·__·"T___ ___________..____ 1911140 760 760 760 4YRTST Tubing i 3400 P/F P .-----.- sCANNED JUN 06 2007 ~_.---- 2440 I 2420 I ~--- , ~_~L__ _._--'------~ 3400 -. ~------- Page I of I e e KRU_1R-17_TXIA-2004-0914.txt subject: Kuparuk injector 1R-17 From: NSK Problem well supv <n1617@conocophillips.com> Date: Tue, 14 sep 2004 15:50:39 -0800 To: "Tom Maunder AOGCC (E-mail)..<tom_maunder@admin.state.ak.us> CC: NSK Problem well supv <n1617@conocophillips.com>, "Jim Regg AOGCC (E-mail)" <jim_regg@admin.state.ak.us> i~m~0~~~~i~~ti~~lw~~ï~70~~~n~sI~ j~~tih~dc~o~_~~;~ ~iTi1o~~n~/~)8~Swhfc~ x had the following information (this has already been submitted to you): 4-Year MITIA (waived) - passed, T/I/O= 3700/1450/800, Pressure up IA with diesel, start MITIA T/I/O= 3700/2030/800, 15 minute reading T/I/O= 3700/2020/800, 30 minute reading T/I/O= 3700/2020/800 we have swapped the well back to water injection and it currently has wellhead pressures of 2135/1950/930 psi. Tubing packoff testing was good so the problem appears to be downhole. The bleed log shows the IA was bled about once per week in August and september (gas). we will continue with diagnostics, possibly run a video camera to see if we can find a leak. This appears to be a very small one but big enough to be affected by gas injection. We will keep the well on water only injection and follow-up on diagnostics. we may be able to repair it, but otherwise will be waivered for water-only injection. Let me know if you have any questions. Jerry Dethlefs problem well supervisor conocoPhillips Alaska 907-659-7224 SCANNEL! NOV 0 9 2005 page 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount Commissioner THRU: Blair Wondzell P.I. Supervisor FROM: John Cris~pp ~,~ ~-~,- Petroleum Inspector DATE: September 28, 2000 SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 1 R Pad 17,18,198,23,26 Kuparuk River Unit Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI- 1R-17 I Typelnj.] G I T.V.D. ] 6462 '1 Tubing I 3700 I 3700 ] 3700 ] 3700 I Interval] 4 P.T.D.I :1911140 TypetesiI P ITestpsil 1616I casing'I 1~00 I 2800 I 2275 I 2200 I P)F J _P-~ Notes: Pressure stabilized (~ 2200 psi. Monitored for one hour. ,, WellJ 1R-18 Type lnj, J N I T.V.D. J3182 J TubingJ 250 I ~o I ~.o I ~o J lnt~'rvalJ 4 P.T.D.J 1910870 Type'testJ P 'JTestpsiJ 796 J CasingJ 900 'J 1640 J 1600 I 1590I P')F I _.P'~ jNotes: We,Ii1R-198 JTypelnj. J S I T.V.D. I Jlntervalr 4 P.T.D.J 1910850 TypetestJ ~P JTestpsiJ 1637 J Casing"I 1110 I 1940 I 1920 I 1920 I PrE Notes: we,,JIR-23 JType,nj.J SJ I I I J,nter a,J P.T.D.J 1911010 JTypetestJ P JTestpsiJ 1678 I Ca. sing, I 1100I 1900 I 1875 I 1850I P/F J _P" Notes: "' we, J 1R-26 J Type~nJ.I s J T.V.D. J 6535 JTubing'J 2300J 2300J 2300J 2300 J~ntervall 4 P.T.D.J 1910920 JTypetestJ P JTestpsiJ 1634 J CasingJ 1220 i 1720.J ~7~o I ~89o I P/F I Pi Notes: Type INJ. Fluid Codes F = FRESH WATER IN Jo G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Vadance W-' Test during Workover O= Other (describe in notes) Test's Details I witnessed MIT's in the Kuparuk River Field on IR Pad..The pressure on 1R-17 stabilized ~ 2200 test pressure, test was held for one hour. No failures witnessed. .I.T.'s performed: 5_ Attachments: none Number of Failures: 0 Total Time during tests: 2.5 hrs. cc: MIT report form 5/12/00 L.G. MIT KRU 1Rb 9-28-00jc.xls THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 2, 2000 PL E W M A TE R IA L U N D E TH IS M A R K E R C:LORI~LM.DOC R INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 91-114 CBT 91-114 CBT-POST SQZ 91-114 CDN 91-114 CDR 91-114 CET 91-114 CET-POST SQZ 91-114 INJP 91-114 407 91-114 DAILY WELL OP 91-114 SURVEY 91-114 SURVEY 91-114 5126 5",8150-10155 5",9540-10152 2&5",5698-10345 2&5",5698-10345 5",8150-10134 5",9540-10173 5",9700-9990 COMP DATE:12/16/91 09/12/91-12/16/91 SS DIRECTIONAL SS DIRECTIONAL OH-CDR,5588-10344 SUMMARY Are well tests required? Yes Was well cored? Yes (No~ If yes, was the core analysis & description received? S es Are dry ditch ampl required? Yes WELL IS IN COMPLIANCE. 11/17/1993 PAGE: 1 Yes Q ................. ~ COMMENTS' AlasKa Oil Gas Conservation Commission 30111 Porcupine Drive Anchorage, Alasl<a §§~;t]1-3192 To: ~i~C~ The following data is hereby acknowledged as being received: Copy sen~.f.o sender: Yes ~ No / , , STATE OF ALASKA ,. AL~oK.A OIL AND GAS CONSERVATION COMMI~,,.,,C)N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Pull tubing ~ Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 638' FSL, 214' FEL, Sec. 18, T12N, R10E, UM At top of productive interval 1192' FSL, 1138' FWL, Sec. 7, T12N, R10E, UM At effective depth 1519' FSL, 893' FWL, Sec. 7, T12N, R10E, UM At total depth 1577' FSL, 850' FWL, Sec. 7, T12N, R10E, UM 12. Present well condition summary Total Depth: measured 1 03 4 5 feet true vertical 6855 feet 6. Datum elevation (DF or KB) . RKB 88 7. Unit or Property name Kuparuk River Unit 8. Well number 1R-17 9. Permit nu.rnber/approv, al number 91-114 //ffZ- Z.l+ 10. APl number 5o-02~-22212 11. Field/Pool Kul3aruk River Oil Pool Plugs (measured) None Effective depth' measured 1 0 2 5 3 feet true vertical 6798 feet Junk (measured) None Casing Length Size Structural Conductor 1 2 0' 1 6" Surface 5654' 9 5/8" Intermediate Production 1 0 2 9 9' 7" Liner Perforation depth: measured 9793'-9809', true vertical 6515'-6524', Tubing (size, grade, and measured depth) Cemented Measured depth 331 SX AS I 1 2 0' 1040 SX Type E & 5 7 03' 520 SX Class G 250 SX Class G Pram. 1 0 33 9' True vertical depth 120' 4037' 6855' 9967'-10025', 6621'-6657', 10051'-10054' 6673'-6675' 3.5", 9.3#, J-55 @ 9728'; 3.5", 9.3#, L-80 @ 9728'-9866', 2.875", 6.5#, J-55 @ 9866'-9898' Packers and SSSV (type and measured depth) PKR's: Baker HB @ 9722' & Baker "D" @ 9857'; SSSV: MACCO Inj. Valve @ 1784' 13. Stimulation or cement squeeze summary Convert well from oil producer to WAG injector. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A ~ ,..,., ni~ 2. ~.~ c. ort,~. G0mt~ss'V 14 Representative Daily Averaoe Production or Injection D~ · - - Anch_.0r. age OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure /uoing Pressure Prior to well operation 1422 1269 75 1150 185 Subsequent to operation 15. Attachments Well Schematic Copies of Logs and Surveys run Daily Report of Well Operations 0 - 0- 2200 500 2200 16. Status of well classification as: Oil Gas Suspended __ Service WAG In!ector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE MORNING WELL, R,.EPORT FOR 02/17/93 ~LLS ITE 1R~ i'= ,,"it ODUC T ]; (]i".I ,41:.u~ .~ I ,,'~T JS GAS LIFT STATUS IGOR = 6500 W Z S E 0 T ,'.]Ht]!:,,E 7" L N A OR WC H2S CS,9 L E T % F" "F P !:'-F T % P P M P S I 1 B TS 2 B PR 5 B PR 7 A PR 11 APR 12 A PR 14 B PR 16 B PR 20 B PR 21 A PR ~_2 C PR 25 C PR 27 C PR 29 B PR 10" CS,9 PSi 2.09 '"'"":= ,..,c, -;,..~ 50 ""~ ,...',.:,,..-, -';' ,- : ..: 1 1 209 2i1 '72 2 45 i~00 209 229 ~.2.2 61}- i 00 1400 209 2~ '2 -..s '-, ..... 1 ,-' 20 900 -?Q:: '"'" ' "06 "-' _ _ ,, ~ ,_ 7 .;. ,¢ .--' 1200 209 2.:L 27. S2 33 4.0 1380 300 600 700 0 600 0 20~ ..-s, ~ ,,'.. 96 48 ~C9 2,-'5 i2S 209 214 12.3 209 20 :i. 5 iL 209 ~ I ':' ~"- - ,.¢ .: / 2 209 164- 27 0 209 '"' '"'"' ~',_..,.'., 7'~_ 0 60 i480 1050' 20 1330 500 60 1200 300' 60 1240 200 40 1000. 150 40 820 300 59 1150 260 50 1200 40,3 GAS GAS INJ OPT OPT · METER VOL RATE GL READING MSCF MSCFD ROOTS 0 119 50 0.4 0 1434 1266 4.6 0 705 400 1.4 0 504 3'71 1.3 0 1441 1500 10.0 0 1422 1500 10.2 0 41 837 33.4 0 1041 746 2.7 0 818 678 2.3 0 2089 2000 6.7 0 876 1000 1.8 0 793 721 4.8 0 1045 1032 2.9 0 716 976 6.5 SI DA' H M R I 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 O000 0000 TOTALS' 13044 13077 IN,JECTiON UiELL_ STATUS INJECTION VOLUMES SI DATA W Z S E 0 T CH(]KE L N A tSIx. L E T '7" 10" rP.~ ~':'S.[ FTT PSi PS! WATER RECMD GAS [NJ INJ INJ METER VOL RATE VOL READING BBLS BWPD MMSCF H M R I S N CODE 3 B SW 4 B SW 6 B SW 8 B SW 9 B SW 10 B gt 13 B gl 15 B SW (~f7 B ,,SW 19 B SW 23 C 26 B SW 70 !800~ 100 71 24.00* 100 59 1780- 380 71 1600 420 7! 860 30 S9 1300 20O 87 610 400 72 t ~.., 4.20 '72 420 300 '73 400 0 ~ 550 300 72 780 200 0 4904 0 4429 0 2212 0 800 0 497 '0 0 0 0- 0 42,8_-5 2789 0.000 3491 0.000 3682 0.000 1045 0.000 821. 0 000 0 2 421 0 6 497 4421 0 000 0 1848~ 2012 0 000 0 383! 2451 0 000 0 ti15 0 0 000 0 5806 5899 0 000 0000 0000 0000 0000 0000 QO00 0000 0000 0000 0000 0000 0000 TOTALS' 0 = 29728 26611 8.918 RECE! JED Alaska Oil & Gas Cons, knchOrag~ ... ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 DECEMBER 29, 1992 WATTY STRICKLAND ARCO ALASKA INc. P O BOX 1900360 ANCHORAGE, ALASKA 99510 RE: 91-0114 KUPARUK RIVER UNIT 1R-17 91-0085 KUPARUK RIVER UNIT 1R-19RD 91-0092 KUPARUK RIVER UNIT 1R-26 91-0101 KUPARUK RIVER UNIT 1R-23 DEAR MR. STRICKLAND, OUR FILES INDICATE THAT ARCO ALASKA INC. IS THE OPERATOR FOR THE REFERENCED WELLS. OUR FILES ARE MISSING PAPER WORK FOR THE CONVERSION OF THESE WELLS AS I MENTION DECEMBER 28, 1992 IN A CONVERSATION I HAD WITH VICTORIA FURGENSON. THESE WELLS HAD 403 SUNDRYS SUBMITTED EARLIER IN 1992 TO CONVERT THESE OIL WELLS TO WATER-INJECTORS AND OUR MONTHLY PRODUCTION REPORTS SHOW THESE WELLS WERE CONVERTED IN NOVEMBER AND AOGCC DIDN'T RECEIVE THE 404'S WHEN THE CONVERSION WAS COMPLETED. THIS MATTER NEEDS TO BE CORRECTED SO OUR FILE ARE CURRENT AND UP TO DATE. WOULD YOU PLEASE CHECK THIS PROBLEM AND FORWARD THE APPROPRIATE DOCUMENTS TO ME. SINCERELY, STEVE MCMAINS STATISTICAL TECHNICIAN C: ROBERT CRANDALL SR PETR GEOLOGIST ARCO Alaska, Inc. i Post Office Bu,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 19, 1992 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is the Application for Sundry Approval on the following Kuparuk well. Well Action Anticipated Start Date 1 R-17 Convert to Water Inj. September 15, 1992 If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Engineer Kuparuk Petroleum Engineering CC: S. P. Hoolahan ATO-1226~v~'~ KOE1.4-9 (w/o attachments) (w/o attachments) REEEIVED AUG 41992 Alaska 0il & 6as Cons. Commiss~ot~ ;Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C A~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_ Suspend _ Operation Shutdow~~'_ Re-enter suspended well _ Alter casing _ Repair well Plugging _ Time extension Stimulate Change approved program _ Pull tubing _ 2. Name of Operator ARCO Alaska, ID¢. 3. Address P. O. Box 100360, Anchorage, AK 99510 Variance _ 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 638' FSL, 214' FEL, SEC 18, T12N, R10E, UM At top of productive interval 1192' FSL, 1138' FWL, SEC 7, T12N, R10E, UM At effective depth 1519' FSL, 893' FWL, SEC 7, T12N, R10E, UM At total depth 1577'FSL, 850' FWL, SEC 7, T12N, R10E, UM Perforate _ Other _~_ 6. Datum elevation (DF or KB) RKB 88', PAD 45' Gl,- 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1R-17 9. Permit number ~)1-114 10. APl number 50-029-22212 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 Length Structural Conductor 1 2 0' Surface 5 70 3' Intermediate Production 1 0,3 3 9' Liner Perforation depth: measured 9793'-9809' true vertical 6515'-6524', 10,345' feet Plugs (measured) 6855' feet None 1 0,253' feet Junk (measured) 6 79 8' feet None Size Cemented Measured depth True vertical depth 16" 331 SxASI 120' 120' 9-5/8" 1040 Sx Type E & 5724' 4037' 520 Sx Class G 7" 250 Sx Class G Prem 10,345' 68_.55.' REEEIvED 9967'-10,025', 6621'-6657', 10,051'-10,054' 6673'-6675' AUG ~ 4 ~0~9~ Tubing (size, grade, and measured depth) Alaska 0il & Gas CODS. C0~issi0u 3-1/2" J-55 set at 9835' and 2-7/8" J-55 set at 9877' Anchorage Packers and SSSV (type and measured depth) Camco TRDP-4A-RO SSSV @ 1784', Baker HB Retr. Pkr @ 9701' & Baker 35-32 D Perm. Pkr @ 9836' 13. Attachments Description summary of proposal X Detailed operation program X BOP sketch _ Convert well from oil producer to WAG injector. (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: ' September 15, 1992 Oil __ Gas _ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service _WAG Injector 17. I hereby certify that the foregoin~ is true and correct to the best of my knowledge. Title Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity w BOP Test Location clearance Mechanical Integrity Test ~ Approved by order of the Commission Form 10-403 Rev 09/12/90 IApproval No. -- -- ~,,.,~pproved Copy I ~,~._ ,=;z/f/ Subsequent form require 10-,,..: Returned Original Signe~ By David W. Johnsten Commissioner Date ~/~/~2[-'/~ SUB~IT I~ TRIPLICATE Well 1R-17 Conversion to WAG Injection ARCO Alaska requests approval to convert Well 1R-17 from an oil producer to a WAG injector. This well will be operated as a Class II UlC well in compliance with Area Injection Order No. 2. Water and gas will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 9590' MDRKB and 10,148' 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. REEEIVED AUG ~ 4199~. AlasI(a 0il & Gas Cons. C, omm~ss'~o~ Anchorage CONVERSION PROCEDURE WELL 1 R-17 AFC # 995452 August 17, 1992 10. 1. Obtain a final 12-hour well test. Notify S. A. Smith (x-4192) to insure that the sundry notice for converting the well to water injection has been approved by the AOGCC. 2. SI well and MIRU slickline and pump truck. 3. RIH and set SV in the "D" nipple at 9898' MD-RKB. 4. Rig up pump truck to the 3-1/2"x 7" annulus, and circulate the annulus to diesel while taking returns from the annulus. Annular capacity should be approximately 90 Bbls. 5. RIH and pull 1" KBUG OV from GL station at 3276' MD-RKB. 6. RIH and set 1" DV in GL station at 3276' MD-RKB. 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. 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 Rea'd Casing Pressure for MIT 1 R-17 6472' 3500 psi 11. Initiate water injection at approximately 500 BWPD and gradually ramp up rate until the WHP reaches maximum header pressure available. RECEIVED AU G 2 4 1992 Alaska 0ii & Gas Cons. [j~r[~miss~, Anchorage ALASKA INC. - KUPARUK FLE-LD ARCO ~11:1 R-1 7 ~ Ar,# 50-029-2221 2-00 Spud Date: 9-12-91 CSand: CLOSED Completion Date: 12-16-91 ASand: CPB~ Maximum Hole Angle: 60.5 deg. @ 2857' MD Original Rig RKB:42' ( 21.5' Nordic) All depths are Well Type: WAG INJECTION Tree Type: FMC GEN IV 5000~ Tree Cap Type: OTIS Tree Cap Size: Tree Cap O-ring ASN: MD-RKB to top of equipment. Last Workover Date: 1 2/1 6/9 1 K-VALVE-2.81" C.X. LOCK @ 327#@60 SERIAL#K-315 2 SLN: OTIS'X' 2.813" PB ID @ 9671' 1 3 PBR: BAKER 3.0" ID @ 9708' 4 PKR: BAKER 'HB' RETR 2.89" ID @ 972Z 5 PKR: BAKER 'D' PERM 3.25" ID @ 9857' 6 NOGO: OTIS'XN' NIPPLE 2.25' ID @ 9881' 7 SHEAR OUT: BAKER @ 9897' 8 TUBING TAIL: 2 7/8· TUBING @ 9898' J Minimum ID:2.25" NOGO J j Casing and Tubing Pipe Tally Size Wei(iht Grade To~ Bottom 0Qscrlotion .I 1 6" 62.5# H-40 0 120' CASING 9 5/8" 36# J-55 0 5703' CASING J 7" 26# J-55 0 10339' CASING 3 1/2" 9.3# J-55 0 9728' TUBING 3 1/2" 9.3# L-80 9728' 9866' TUBING :3 I: 2 7/8" 6.5# J-55 9866' 9898' TUBING 2 Gas Lift Information X X 3 Deoth Stn# Valve Tvoe Sz. Latch port Sz. AID# 4 3276' 1 KBUG O/V 1" BK2 1 6/64" J 5973' 2 KBUG D/V I" BK2 _, 7644' 3 KBLJG D/V 1" BK2 · 8863' 4 KBUG D/V I" BK2 II 9626' 5 OTIS D/V 1.5" RM K:~ ~ 9766' 1 McMH D/V 1.5" F~ 9846' 2 CAMCO C B-1 SLIDING SLEEVE ~ 5 6 7,8 = · Perforation Data -"~ Interval SPF Date Zone 9793-9809 5 12/14/91 C 9967-10025 4 12/14/91 A / ~ 10051-10054 4 12/14/91 A Jewelry I SSSV: CAMCO TRDP-4A 2.812" ID @ 1784' FLOW TUBE LOCKED OUT Date Run 06-24-92 12-16-91 12-16-91 12-16-91 06-24-92 06-14-92 12-16-91 Comments 2 RUNS RECEIVED Comments: FLAPPER BROKEN OFF SCSSV 1784' RKB. 2.80"1D RESTRICTION LAST TAG: 10078' RKB 6-23-92 TD: 10345' PBTD: 10253' LAST A U G 2 4 1992 Alaska 0il & Gas Cons. Commission Anchorage REV: 7.10-92 ARCO Alaska, Inc. Date: February 21, 1992 Transmittal #: 8369 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. 3Q-03 - LIS Tape and Listing I -27-92 92095 3 R- 1 2 D LIS Tape and Listing 2 - 4 - 9 2 9 21 1 5 THE FOLLOWING LIS TAPES ARE STAMPED WITH A CORRECTED COPY STAMP. PLEASE REPLACE THE PREVIOUS COPY THAT YOU HAVE ALREADY . RECEIVED WITH THIS ONE. THANK YOU. I R - 1 7 LIS Tape and Listing 9 - 1 9 - 91 9 2026 I R - 2 0 LIS Tape and Listing 9 - 9 - 91 92026 I R - 21 LIS Tape and Listing 1 0 - 6 - 91 9 2026 I R-22 LIS Tape and Listing 9- 24- 91 92026 I R - 2 3 LIS Tape and Listing I 0 - 2 2 - 91 92026 I R - 2 4 LIS Tape and Listing 7 - 3 0 - 91 92026 I R - 2 6 LIS Tape and Listing 7 - 1 8 - 91 92026 I R - 2 7 LIS Tape and Listing 8 - 31 - 91 92026 I R - 2 9 LIS Tape and Listing 8 - 1 4 - 91 92026 Receipt LIS Tape and Listing 6 - 1 9 - 91 920 26 LIS Tape and Listing 1 1 - 1 1 - 91 92026 LIS Tape and Listing 1 I - 1 7 - 91 920 26 LIS Tape and Listing 5 - 9 - 9 1 92026 LIS Tape and Listing 5 - 1 9 - 91 92026 LIS Tape and Listing 5 - 2 6 - 91 92026 LIS Tape and Listing 6 - 3 - 9 1 92026 Acknowledged: R-EC--E+VE D DISTRIBUTION: Lynn Goettinger FEB 2 8 1992. Alaska Oil & Gas Cons. Commission Anchorage State of Alaska ARCO Alaska, Inc. Date: February 7, 1992 Transmittal #: 8355 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return o. ne signed copy of this transmittal. ~jl 17~,~I2M'1° Lithe-Density & Casing Neutron 11-29-91 7000-7756.~~ '" Porosity Data & 12-29-91 7000-7669 2M-1 0 Lithe-Density & Casing Neutron I I-29-91 7000-7756 Raw Data & 12-29-91 7000 - 7669 I3Q-04 CCN ,.,/ 1-12-16-92 4517.7-7720 &- c3Q-03 CCN ,.2 1-24-27-92 5090-9640 },.l~,,~'~3Q-03 C[~ b} 1-24-27-92 5090-9640 THE FOLLOWING LOGS ARE CORRECTED COPIES. IT HAS BEEN REQUES~"T~"D~ THAT YOU THROW OUT THE PREVIOUS (UNCORRECT) COPY OF THIS LOG ~_THANK YOU. . )e. ~J 1L-2~'"2~---,7'~ ~ . : 5:9-13-91 ~.- . , 5237-1047~ ~ 1 L- 26 ~-~p~ 6-3-6-91 ' 5225-10065 2M-19~ ~ 11-17-'91 3835-9250 / I R-17/ ~ 9-1 5-1 9-91 1R-19J/ ~ 6-19-23;91 · ~',~', I R-20J ~ 9-9-91 1R-21~ ~ 10-6-11-91 5070:10180 ~[~.~1 R-22 ~ ~ 9--24-29-91 6001-10813 1R 2 - 3~/ , ~ 10-22-91 6330-12188 : 7-18-21-91 5591-10218 ~,.~ 1R-29 ~ ~~ 8-31-91 6547-9250 8-14-91 6042-11368 1L-24 ~ ~ J 5-19-22-91 5081-9241 1L-25 ~ ~ ~ 5-26-29-91 4978 9352 ~ RECEIVED FEB 1 1 1992 Alaska 0il & Gas Cons. Commission Anchorage co..,Ss,o p AL~$KA OIL AND GAS CONSERVATION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classificalion of Service Well OIL E~] GAS ~ SUSPENDED ~ ABANDONED E] SERVICE r--] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 91-114 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22212 4 Location of well at surface 9 unit or Lease Name 638' FSL, 214' FEL, SEC 18, T12N, R10E, UM ~ .................... ~ ~: .... .~:-~ ;' '~:":':-:~ KUPARUK RIVER At Top Producing Inte~al ~~~~ .......~ ~ 10 Well Number 119~ FSL, 11~' FWL, SEC 7, T12N, R10E, UM . : - 1R-17 At To~l Depth ;~ Vi;:.¢~ F~i~, { ~ ~ ;~' 11 Field and Pool 1577 FSL, 850' FWL, SEC 7, T12, R10E, UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lea'se Designation and Serial ~. KUPARUK RIVER OIL POOL RKB 88', PAD 45' GL[ ADL 25628, ALK 2561 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or AbaS. 115 Water Depth, if offshore ~16 ~. of Completions 09/11/91. 09/17/91. 1 ~16/91.~ NA feet MSLI. 1 17 Total Dep~ (MD+~D) 18 Plug Back Depth (MD+TVD) 19 Direc~o~l Su~ey 20 Depth where SSSv set 21 Thickness of ~afrost 10,345' MD ,6855' TVD 10,253' MD, 6798' TVD YES ~ NO ~ 1784' feet MD 1700' APPROX 22 Ty~ El~tric or Other Logs Run CD~CD~G~CET/CBT 23 CASING, LINER AND CEME~ING RECORD ' SE~iNG DEPTH MD " CASING SIZE ~. PER ~. GRADE TOP ~OM HOLE SIZE CEMENTING RECORD AMOU~ PULLED 16" 62.5¢ H-40 SURF 120' 24" 331 SX ASI 9-5/8" 36¢ J-55 SURF 5703' 12-1/4" 1040 SX TYPE E, 520 SX CLASS G 7" 26¢ J-55 SURF 10339' 8" 250 SX CLASS G PREM ~, ,, 24 Pedorations open to Production (MD+~D of Top and BoEom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9793'-9809' W/ 4-1/2" CSG GUN ~ 10 SPF MD 6515'-6524'~D 3-1/2" 9.3¢ , 2-7/8" 6.~ 9835', 9877' 9701', 9837' 9967-10,025' W/ 4-1/2 CSG GUN ~ 4 SPF MD 6621'-6657' ~D 10,051'-10,0~' W/ 4-1/2" CSG GUN ~ 4 SPF MD 6673'-6675' ~D 26 ACID, F~CTURE, CEME~ SQUEEZE, ETC DEPTH INTERVAL (MD) I AMOU~ & KIND OF MATERIAL USED 9762'9770'J 15.7 BBLS C~SS G CEMENT 9932'-9940' 10,032'-10,040' 11BBLS C~SS G CEMENT 27 PRODUCTION TEST Date First Production lMethod of Operation (Flowing, gas liE, etc.) I DateofTest Hours Test~ PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL RATIO 1 TEST PERIOD FIowTubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OILG~VITY-API (corr) Press. 24-HOUR RATE 28 CORE DATA Brief description of lithology, porosi~, fractures, apparent di~ and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME GEOLOGIC MARKERS KUPARUK C TOP KUPARUK C BOTTOM KUPARUK ATOP KUPARUK A BOTTOM 9733' 9809' 9949' 10147 ME. AS. DEPTH TRUE VERT. DEPTH FORMATION TESTS Include interval tested, pressure data, all fluids recoverd and gravity, GOR, and time of each phase. 6479' 6524' 6609' 6732' NA 31. LISTOF ATTACHMENTS GYRO, REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed v~''~ ~"~ _~~' Title AREADRIIIING ENGINEER Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repod 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 P~p, Hydraulic P~mp, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: 1R-17 BOROUGH: NORTH SLOPE UNIT: KUPARUK RIVER UNIT FIELD: KUPARUK RIVER FIELD LEASE: ADL 25628 ALK 2561 API: 50-029-22212 PERMIT 91-114 APPROVAL: RECEIVED SPUD:09/11/91 RELEASE: 09/20/91 FEB - 4 1'99 OPERATION: DRILLING RIG: POOL 7 Alaska 0il & ~as Cons. ~ummissio~ AFg: A~5865 Anchorage ~z: 55.252072 09/12/91 (1) TD: 933'( 933) SUPV:DS 09/13/91 (2) TD: 4056'(3123) SUPV:DS 09/14/91 (3) TD: 5724' (1668) SUPV:DS 09/15/91 (4) TD: 5724'( SUPV:DS o) 09/16/91 ( 5) TD: 7512' ( 1788) SUPV:DS 09/17/91 (6) TD: 9215' (1703) SUPV:DS 09/18/91 (7) TD:10345' (1130) SUPV:DS 09/19/91 (8) TD:10345' ( SUPV:DS 0) 09/20/91 (9) TD:10345' ( SUPV:DS o) DRLG AT 933' MW: 9.1 VIS: 64 MOVED RIG FROM 1R-20 TO 1R-17. ACCEPT RIG 9/12/91 1730. NU DIVERTER. WORK ON TOP DRIVE. DRLD TO 933' DAILY:S50,807 CUM:$50,807 ETD:S50,807 EFC:$1,590,000 DRLG MW: 9.4 VIS: 47 DRLD 933'-3517'. TRIP FOR BIT. DRLD 3626'-4056'. DAILY:S63,686 CUM:$114,493 ETD:S114,493 EFC:$1,590,000 POH MW: 9.6 VIS: 43 DRLD 4058'-5723'. SHORT TRIP. POH FOR 9-5/8" CSG. DAILY:S61,299 CUM:$175,792 ETD:S175,792 EFC:$1,590,000 REPAIRING INSIDE BOP MW: 9.7 VIS: 41 POH. RAN 9-5/8" CSG & CMTD W/ 1140 SX PF E & 520 SX CL G. CMT TO SURF. NU BOP. DAILY:S224,515 CUM:$400,307 ETD:S400,307 EFC:$1,590,000 DRLG AT 7512' MW: 9.2 VIS: 36 TEST IBOP. RIH. DRLD CMT. TEST CSG TO 2000 PSI. DRLD FLOAT EQ & 10' NEW HOLE. TEST FORM TO 12.5 PPG EMW. DRLD 5733'-7512' DAILY:S68,003 CUM:$468,310 ETD:S468,310 EFC:$1,590,000 RIH MW:10.7 VIS: 36 DRLD 7512'-9215'. TRIP FOR BIT. DAILY:S63,220 CUM:$531,530 ETD:S531,530 EFC:$1,590,000 CIRC 7"@10338' MW:ll.0 VIS: 39 RIH. DRLD 9215'-10345'. CIRC, PREP TO POH. DAILY:S57,554 CUM:$589,084 ETD:S589,084 EFC:$1,590,000 RIH W/ 7" CSG 7"@10338' MW:ll.0 VIS: 38 CIRC. SHORT TRIP. POH. RUNNING 7" CSG. DAILY:S125,351 CUM:$714,435 ETD:S714,435 EFC:$1,590,000 RIG RELEASED 7"@10338' MW:ll.0 VIS: 0 RIH W/ 7" CSG & CMTD W/ 250 SX G W/ NO RETURNS.ND BOP. DAILY:S263,219 CUM:$977,654 ETD:S977,654 EFC:$1,590,00 DATE: ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 1R-17 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 25628 ALK 2561 50-029-22212 91-114 ACCEPT: 12/03/91 SPUD: RELEASE: 12/16/91 OPERATION: COMPLETION RIG: NORDIC AFE: AK5865 WI: 55.252072 12/03/91 (10) TD:10345 PB:10253 SUPV:DB/TB 12/04/91 (11) TD:10345 PB:10253 SUPV:DB/SS 12/05/91 (12) TD:10345 SUPV:DB/SS 12/06/91 (13) TD:10345 PB:10253 SUPV:DB/SS NU BOPE 7"810338' MW:ll.0 NaCl/Br MOVE RIG FROM 1A-26 TO 1R-17,ACCEPT RIG AT 05:30 HRS 03-DEC-91,LEVEL RIG, STEAM OFF AND ND DRY HOLE TREE,NU BOPE DAILY:S20,586 CUM:$998,240 ETD:SO EFC:$2,588,240 RIH W/STINGER ON 3-1/2" DP 7"810338' MW:ll.0 NaCl/Br CONT ND DRY HOLE TREE,NU BOPE, TEST SAME TO 3000 PSI,RU SWS RIH W/6.05"GR/JB, TAG FILL AT 10163'WLM, POH, REHEAD WIRELINE RIH W/GYRO AND SURVEY FROM 10102'WLM TO SURFACE,RIH W/EZSV AND SET SAME AT~_!0,050'WLM, POH,MU 22.5 DEG SQUEEZE GUN, RIH AND PERFORATE AT 4 SPF FROM 10032~.!Q040',POH,MU 22.5 DEG SQUEEZE GUN, RIH AND PERFORATE AT 4 SPF FROM 9~r.9~Q',POH MU EZSV, RIH AND SET SAME AT 10018', POH, RD SWS,MU STINGER ON 3-1/2" DP,RIH DAILY:S58,157 CUM:$1,056,397 ETD:SO EFC:$2,646,397 MU RIH W/EZSV ON W/L 7"810338' MW:ll.0 NaCl/Br SERVICE RIG, SLIP/CUT DRLG LINE,CONT RIH W/DP,REV OUT ONE OUT OF RET AND EST CIRC RATE OF 3 BPM 800 PSI,STING INTO RET AND EST CIRC THRU PERFS AT 3 BPM/1400 PSI,CIRC 43 BBLS, UNSTING FROM RET AND RU CMT LINES,BATCH MIX~0___~SC~G W/1GPS LATEX 2000 .11 GPS FDP-C434B,.05 GPS-~U~AIR-3'i"~0% BENTONITE, 3.0%CAL-SEAL,.5% CFR-3,.2% HR-5,WEIGHTED TO 15.6 PPG, TT=5 HRS 18 MIN, FL=62 CC/30 MIN,ALSO MIX 15 BBLS ARCO SPACER WEIGHTED TO 12.0 PPG, PRESSURE TEST LINES TO 3000 PSI PUMP 10 BBLS ARCO SPACER, 20 BBLS CMT, 5 BBLS ARCO SPACER FOLLOWED BY 31 BBLS 11.0 PPG BRINE, HELD 500 PSI BACK PRESSURE ON CHOKE WHILE SPOTTING CEMENT TO STINGER, STING INTO RETAINER AND DISPLACE CEMENT INTO PERFS WITH 17 BBLS BRINE,SHUT IN BACK SIDE AND SQUEEZE AWAY 11 BBLS CMT AT 1 BPM/llL0 PSI,CIP820:45 HRS,PULL 3 STDS AND REVERSE OUT 2 TUBING VOL, TRACE CMT TO SURFACE,POH W/DP, RD FLOW RISER, RU SWS,MU 6.0" GR/JB, TEST LUBRICATOR TO 1000 PSI,RIH WITH GR/JB TO 9800',POH,MU AND RIH WITH EZSV ON WIRELINE DAILY:S52,891 CUM:$1,109,288 ETD:SO EFC:$2,699,288 POH W/3-1/2" DP 7"810338' MW:ll.0 NaCl/Br CONT RIH W/EZSV, SET SAME AT 9780'WLM, POH,MU 22.5 DEG SQUEEZE GUN, PERF FROM 97___~2-~__977~._~ AT 4 SPF, POH, RD SWS,NU FLOW NIPPLE RU TO RIH W/DP,RIH WITH 3-1/2" DP OPEN ENDED, TAG EZSV AT 9773'DPM, CBU AT 4 BPM/1350 PSI,UP WT 156K#,DN WT 65K EST INJ RATE AT 2 BPM/1200 PSI,RU CMT LINES,BATCH MIX CMT 75 SX CLASS G W/.2% CFR-3,.25% HR-5,.3% HALAD-344,AT 15.'~ PPG, TT=4 HRS 28 MIN, FL=61CC/30MIN, TEST LINES TO 3500 PSI,PUMP 8 BBLS WATER, 16 BBLS CMT, 2 BBLS WATER, 58 BBLS BRINE,PU 10 STDS,REV OUT 1-1/2 DP VOL.,HESITATE SQUEEZE TOTAL OF 12.7 BBLS CMT AWAY AT 1350-2300 PSI,SHUT IN WELL WITH 2300 PSI FOR 6 HRS RD HALLIBURTON, PRESSURE DROP TO 2050 PSI AFTER 6 HRS,BLEED OFF PRESS,POH W/D DAILY:S74,360 CUM:$1,183,648 ETD:S0 EFC:$2,773,64 WELL: 1R-17 OPERATION: DRILLING RIG: PAL 74 PAGE: 2 12/07/91 (14) TD:10345 PB:10253 SUPV:DB/SS 12/08/91 (15) TD:10345 PB:10253 SUPV:DB/SS 12/09/91 (16) TD:10345 PB:10253 SUPV:DB/SS 12/10/91 (17) TD:10345 PB:10253 SUPV:DB/SS 12/11/91 (18) TD:10345 PB:10253 SUPV:GB/TB RECEIVED FF_B - 4 992 Alaska Oil & Gas Cons. u~mm[ss~'°~ Anchorage RIH W/ 3-1/2" DP 7"@10338' MW:ll.0 NaCl/Br SERVICE RIG, CONT POH W/3-1/2" DP,MU 6-1/8" BIT/JB/BS/JARS/DC RIH, TEST UPPER KELLY VALVE, SERVICE KELLY, DRILL CMT STRINGERS F/9440-9681',DRILL GOOD HARD CMT F/9719' TO EZSV AT 9773' CBU, TEST SQUEEZE PERFS TO 1500 PSI,LOST 200 PSI IN 3 MIN CHECK FOR LEAKS IN SURFACE EQUIP,REPEAT TEST, LOST 200 PSI IN 3 MIN, EST BREAKDOWN WITH .25 BPM AT 1700 PSI,BLEW DN AND STD BACK KELLY,MU HEADPIN ON DP EST INJ AT 1 BPM/2000 PSI,POH W/3-1/2" DP AND BHA, SLIP AND CUT DRLG LINE, RIH W/DP OPEN ENDED DAILY: $34,592 CUM: $1,218,240 ETD: $0 EFC: $2,808,240 RIH W/BHA ON DP 7"@10338' MW:ll.0 NaCl/Br SERVICE RIG, RIH W/3-1/2" DP OPEN ENDED,CBU, RU CMT LINES,EST INJ INTO LEAKING PERFS AT .5 BPM/2500 PSI AND 1.6 BPM AT 3000 PSI,BATCH MIX 100 SX CLASS G W/ 1.1%FL-20,.l%CD-31 · 06%A-2,1 GPS FP-6L AT 15.8 PPG, TT=4:23,FL=43 CC/30 MIN, PUMP 8 BBLS WATER, 20 BBLS CMT, 2 BBL WATER, DISPLACE WITH BRINE,PULL 12 STDS TO 9013',REVERSE OUT DP,SQUEEZE AWAY 3 BBLS AT 1 BPM/3025 PSI,SHUT DN, BLED DN TO 2985 PSI,PUMP .25 BBLS,PRESSURED UP TO 3200 PSI,SHUT IN WELL, CIP AT 16:30 HRS HELD PRESSURE ON CMET FOR 6 HRS,FINAL PRESSURE 2350 PSI SLOWLY BLED PRESSURE BACK, POH W/DP,MU 6-1/8" BIT/JB/BS/JARS/DC, RIH W/BHA ON DP DAILY: $46,076 CUM: $1,264,316 ETD:SO EFC: $2,854,316 DRILLING ON EZSV 7"@10338' MW:ll.0 NaCl/Br SERVICE RIG, CONT RIH W/BHA ON DP,WASH DN F/9282-9356',DRILL FIRM CMT TO EZSV AT 9773',CBU, TEST 7" CSG TO 1500 PSI,LOST 50 PSI IN 15 MIN, DRILL EZSV, BREAK THRU AT 9775',TAG UP AT 9898',DRILL ON JUNK AND CMT TO NEXT EZSV AT 10012',CBU TEST 7" CSG TO 1500 PSI,LOST 300 PSI IN 10 MIN, CHECK SURFACE EQUIP,RETEST CSG LOST 300 PSI IN 10 MIN, EST INJ INTO PERFS AT 1 BPM/2300 PSI,DRILL UP EZSV DAILY: $41,863 CUM: $1,306,179 ETD:SO EFC: $2,896,179 POH W/ DP 7"@10338' MW:ll.0 NaCl/Br DRLD EZSV @ 10043'. WASH TO 10160' DRLD CMT TO 10193'. CBU. ATT TO TEST CSG. COULD PUMP IN @ 1 BPM AND 2150 PSI. POH. MAKE BIT AND SCRAPER RUN. POH TO RUN CMT EVALUATION LOGS. DAILY: $28,147 CUM: $1,334,326 ETD:SO EFC: $2,924,3 RU HALLIBURTON TO PUMP SW 7"@10338' MW:ll.0 NaCl/Br SERVICE RIG, CONT POH W/DP AND BHA, RD FLOW NIPPLE,RU SWS,MU CET/CBT AND LOG F/ 10185-9534',LD LOGGING TOOLS AND LUBRICATOR, PULL WEAR RING, SET TEST PLUG, C/O PIPE RAMS, TEST BOPE TO 3000 PSI,OK, SET WEAR RING, RU LUBRICATOR, MU JB/GR FOR 7" CSG, TEST LUBRICATOR TO 500 PSI,RIH W/GR/JB TO 10120',POH MU BRIDGE PLUG ON E-LINE, RIH AND SET SAME AT 9950'WLM, POH,MU CMT RETAINER ON E-LINE,RIH AND SET SAME AT 9877'WLM, POH,RD SWS,NU FLOW NIPPLE, SLIP/CUT DRLG LINE,MU STINGER AND PLUG CATCHER ON DP,RIH,MU CMT LINES,STING INTO RETAINER, BREAKDOWN PERFS WITH 1-1/3 BPM AT 2525 PSI,UNSTING F/RETAINER, TEST CASING ABOVE RET. TO 1500 PSI F/ 15 MIN, LOST 125 PSI,OK, RU HALLIBURTON TO PUMP SEAWATER DAILY: $28,147 CUM: $1,362,473 ETD:SO EFC: $2,952,473 WELL: 1R-17 12/12/91 ( 19) TD:10345 PB:10253 SUPV:GB/TB 12/13/91 (20) TD:10345 PB:10253 SUPV:GB/TB 12/14/91 (21) TD:10345 PB:I0253 SUPV:GB/TB 12/15/91 (22) TD:10345 PB:10253 SUPV:GB/TB 12/16/91 (23) TD:10345 PB:10253 SUPV:GB/TB PAGE: 3 RIH W/DP AND 2-7/8" STINGER 7"@10338' MW:ll.0 NaCl/Br TEST CMT LINES TO 3500 PSI,DISPLACE DP W/SW, STING INTO RET. EST INJ RATE INTO PERFS AT 0.4 BPM/3000 PSI,SURGE BACK TO TANK, REPEAT INJ AT 0.1 BPM/3000 PSI, BLEED BACK TO TANK, RD HALLIBURTON, CLEAN PITS AND HALLIBURTON, DISPLACE SW WITH BRINE, SLIP DRILL LINE, POH W/3-1/2" DP,LAY DN STINGER/PLUG CATCHER, MU 6-1/8"BIT 2 JB/BS/DC, RIH TO RET.,PU KELLY, DRILL UP RET.,WASH DN TO 9942',CBU, BLOW DN AND STD BK KELLY, POH W/DP AND BHA, NO JUNK IN JB, MU AND RIH WITH 16 JTS 2-7/8 TBG/ PLUG CATCHER ON DP DAILY:S77,339 CUM:$1,439,812 ETD:SO EFC:$3,029,812 PU KELLY TO DRILL EZSV 7"@10338' MW:ll.0 NaC1/Br SERVICE RIG, CONT RIH W/3-1/2" DP,TAHG EZSV AT 9942',RU HALLIBURTON, ESTABLISH INJ RATE .8 BPM/2300 PSI INTO PERFS BLEED OFF AND CIRC WELL, BATCH MIX CMT, PUMP 10 BBLS SW, 16 BBLS CMT, 2 BBL SW, HOLD 600 PSI BACK PRESSURE ON CHOKE WHILE DISPLACING CMT TO EZSV, SPOT CMT ON EZSV, PULL 10 STDS DP SLOW REV OUT DP,BEGIN SQUEEZE, 2.7 BBLS PUMPED/P~2750 PSI,PERFS BROKE DN, P=1500 PSI/.5 BPM, AT 5.5 BBL P=2600 PSI,PERFS BREAK DN, P=l150 PSI,CONT SQUEEZE AT .25 BPM/ll50 PSI,PRESS BUILT TO 1950 PSI,TOTAL CMT PUMPED=6.5 BBLS,SHUT IN WELL WITH 1950 PSI ON DP, RD HALLIBURTON,WOC F/6 HRS,LOST 410 PSI,FINAL SHUT IN PRESSURE=1540 PSI,BLEED PRESSURE,POH W/DP,MU AND RIH W/6-1/8" BIT,BS,DC, SLIP AND CUT DRLG LINE,CONT RIH, TAG CMT AT 9690',PRESS TEST CSG TO 1500 PSI F/15 MIN, LOST 25 PSI,OK PU KELLY AND DRILL CMT TO BELOW TOP PERFS,PRESS TEST TOP PERFS TO 1500 PSI F/15 MIN, LOST 25 PSI,OK DAILY:S51,710 CUM:$1,491,522 ETD:SO EFC:$3,081,52 RU SWS TO PERFORATE 7"@10338' MW:ll.0 NaC1/Br CONT DRLG CMT TO BP AT 9942',SERVICE RIG/KELLY, CONT DRLG CMT TO BP,PRESS TEST CSG/MIDDLE PERFS TO 1500 PSI F/20 MIN, LOST 80 PSI,OK, CONT DRLG BP,PUSH BP TO 10192',BLOW DN/STD BK KELLY,DISPLACE WELL WITH CLEAN BRINE,WORK PIPE WHILE CIRC PUMP 11.2 PPG DRY JOB, POH LAYING DN 110 JTS DP,POH STD BK 100 STDS DP,DC, RU SWS DAILY:S87,987 CUM:$1,579,509 ETD:SO EFC:$3,169,509 RUNNING COMPLETION 7"@10338' MW:ll.0 NaCl/Br RU SWS,TEST LUBRICATOR TO 700 PSI,RIH AND PERFORATE 'A' AND 'C' SANDS IN 5 RUN 'A' SAND FROM 9967'-10025' AND 10,051'-10 054' 4 SPF, 15 DEG CW, 43C CHARGES, 'C' SAND FROM 9793'-9809' 5 SPF, 51B CHARGES,POH,MU 6.05" GR/JB, RIH TO 9925', POH, RECOVERED PLASTIC/FIBER FRAGMENTS,RIH W/GR/JB, POH NO JUNK,MU BAKER 'D' PKR AND TAILPIPE ASSY AS PER PROCEDURE RIH ON W/L TO 9840' DAILY:S37,763 CUM:$1,617,272 ETD:SO EFC:$3,207,27 RELEASE RIG 7"@10338' MW:ll.0 NaC1/Br SET PKR ON W/L AT 9840',POH, RD SWS,MU AND RIH WITH 3-1/2" SELECTIVE SINGLE COMPLETION AS PER PROCEDURE,MU SSSV, TEST C-LINE TO 5000 PSI,OK, CONT RIH W/COMP MU HGR AND C-LINE, TEST SAME TO 5000 PSI F/15 MIN, OK, SPACE OUT AND LAND COMP, RILDS PRESS UP TO 2500 PSI TO SET PKR, HOLD PRESS ON TBG AND PRESS ANNULUS TO 1000 PSI F/10 MIN, OK, BLEED ANNULUS PRESS,BLEED TBG TO 1500 PSI,BOLDS,PU l17K# TO SHEAR PBR, RILDS,TEST SSSV W/500 PSI DIFF,OK, TEST CSG AND PKR TO 2500 PSI F/ 15 MIN, OK PRESS UP TO 3100 PSI TO SHEAR OUT BALL, SET BPV,ND FLOW LINE AND BOPE NU FMC GEN 4 TREE, PULL BPV, SET TEST PLUG, TEST TREE AND PACKOFF TO 5000 PSI,OK, PULL TEST PLUG,DISPLACE ANNULUS WITH 15 BBLS DIESEL, BULLHEAD TBG WITH 5 BBLS DIESEL, SITP=500 PSI,SICP=0 PSI,SECURE WELL, CLEAN PITS,RELEASE RIG AT 05:00 HRS 16-DEC-91 DAILY:S113,814 CUM:$1,731,086 ETD:SO EFC:$3,321,086 DATE: SUB- SURFACE DIRECTIONAL SURVEY F~ UIDANCE [~ ONTINUOUS F~ OOL Company ARCO ALASKA, INC. Well Name 1R-17(638'FSL,214'FEL,SEC 18,T12N,R10E) Field/Location KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 75326 Loqc~ed By: JEFF FORMICA Date 03-DEC-1991 Computed By: R:,KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 1R-17 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE: 03-DEC-1991 ENGINEER: JEFF FORMICA METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: TANGENTIAL- Averaged Oeviat4on and azimuth LINEAR HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 29 DEG 12 MIN WEST ARCO ALASKA, [NC. 1R-17 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 18-DEC-91 PAGE 1 DATE OF SURVEY: 03-DEC-1991 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -88.00 0 0 N 0 0 E 100.00 99.94 11.94 0 23 S 44 4 W 200.00 199.94 111.94 0 46 N 2 43 W 300.00 299.93 211.93 0 27 S 23 22 E 400.00 399.93 311.93 0 29 S 2 54 W 500.00 499.92 411,92 0 57 N 61 46 W 600.00 599.82 511.82 4 16 N 33 49 W 700.00 699.18 611.t8 8 19 N 33 4~ W 800.00 797.65 709,65 11 51 N 32 42 W 900.00 894.57 806.57 16 47 N 31 12 W 0.00 0.30 0.37 0.81 1.23 2.08 6.09 17.12 34.39 58.89 1000.00 989.11 901.11 20 36 N 29 5 W 91.41 1100.00 1082,18 994.18 22 6 N 28 8 W 127.97 1200.00 1174.36 1086.36 23 37 N 27 40 W 166.71 1300,00 1265.15 1177.15 26 0 N 29 34 W 208.60 1400.00 1354.52 1266.52 27 4 N 31 43 W 253.45 1500.00 1443.01 1355.01 28 44 N 32 1 W 299.96 1600.00 1528.87 1440.87 33 37 N 32 8 W 351.08 1700.00 1608.53 1520.53 39 48 N 31 43 W 411.36 1800.00 1683.68 1595.68 42 39 N 31 48 W 477.25 1900.00 1755.37 1667.37 46 21 N 30 25 W 546.88 N 29 10 W 622.37 N 30 23 W 703.49 N 29 56 W 786.84 N 29 31 W 869,64 N 31 13 W 952.59 N 31 9 W 1036.05 N 34 8 W 1120.02 N 33 9 W 1204.49 N 32 30 W 1290.17 N 32 12 W 1376.86 2000.00 1820.89 1732.89 51 50 2100.00 1879.29 1791.29 56 7 2200.00 1934.52 1846.52 56 23 2300.00 1990.59 1902.59 55 34 2400.00 2046,41 1958.41 56 40 2500.00 2101.43 2013.43 56 46 2600.00 2155.43 2067.43 57 47 2700.00 2208.53 2120.53 58 12 2800.00 2259.80 2171.80 60 9 2900.00 2309.43 2221.43 59 32 3000.00 2360.40 2272.40 , 59 37 N 32 7 W 1462.77 3100.00 2411.54 2323.54 58 20 N 31 38 W 1548.61 N 30 48 W 1633.47 N 31 23 W 1717.69 N 31 45 W 1800.65 N 30 39 W 1883.36 N 29 41 W 1966.68 N 28 54 W 2050.07 N 28 17 W 2133.64 N 28 31 W 2217.45 3200.00 2464.36 2376.36 57 58 3300.00 2518.22 2430.22 56 32 3400.00 2573.92 2485.92 55 50 3500.00 2630.05 2542.05 56 10 3600.00 2685.33 2597.33 56 32 3700.00 2740.52 2652.52 56 36 3800.00 2795.44 2707.44 56 41 3900.00 2849.95 2761.95 57 6 0 O0 2 65 2 52 3 28 3 45 0 85 4 33 2 97 4 46 5 87 0 O0 N 0135 0 15 N 0 24 N 0 56 N 1 29 N 4 46 N 13 66 N 28 17 N 49 02 I~ 0 O0 E 0 84W 0 48 W 1 23 W 1 53 W 1 97 W 4.5i W 10.65 W 20. O8 W 32.99 W 0.00 N 0 0 E 0.85 5 81 13 W 0.51 N 72 53 W 1 .26 N 78 58 W 1.63 N 70 1 W 2,35 N 56 48 W 6.34 N 45 2O W 17.33 N 37 57 W 34.60 N 35 29 W 59.09 N 33 56 W 2.04 1 .23 2.04 2.60 0.82 2.75 7.57 2.35 2.30 5.82 77.13 N 49.36 W 91.57 N 32 37 W 109.27 N 66.79 W 128.06 N 31 26 W 143.54 N 84.88 W 166.76 N 30 36 W 180.38 N 104.84 W 208.63 N 30 10 W 218.96 N 127.73 W 253.49 N 30 15 W 258.45 N 152.41 W 300.04 N 30 32 W 301.84 N 179.56 W 351.21 N 30 45 W 353.08 N 211.44 W 411.55 N 30 55 W' 409.13 N 246.19 W 477.49 N 31 2 W 468.72 N 282.31 W 547.17 N 31 4 W 5.89 2.26 1 .83 1 .25 0.37 2.78 0.91 1 .88 1 .91 2.41 534.35 N 319 60 W 622.64 N 30 53 W 604.83 N 359 78 W 703.75 N 30 45 W 676.78 N 401 89 W 787.11 N 30 42 W 748.81 N 442 73 W 869.90 N 30 36 W 820.29 N 484 84 W 952.86 N 30 35 W 891.92 N 527 76 W 1036.36 N 30 37 W 962.54 N 573 52 W 1120.45 N 30 47 W 1032.98 N 620 62 W 1205.08 N 31 0 W 1105.15 N 667.12 W 1290.89 N 31 7 W 1178.57 N 713.44 W 1377.69 N 31 11 W 0.85 1 .27 0.77 2.77 1 .42 1 .22 1 .00 1 .01 0.79 2.17 1251.34 N 759.33 W 1463.71 N 31 15 W 1324.33 N 804.68 W 1549.63 N 31 17 W 1396.96 N 848.67 W 1634.54 N 31 17 W 1469.29 N 891.88 W 1718.80 N 31 15 W 1539.86 N 935.65 W 1801.84 N 31 17 W 1610.69 N 978.47 W 1884.60 N 31 17 W 1682.70 N 1020.40 W 1967.92 N 31 14 W 1755.45 N 1061.16 W 2051.26 N 31 9 W 1828.83 N 1101.16 W 2134.75 N 31 3 W 1902.74 N 1140.72 W 2218,48 N 30 57 W ARCO ALASKA, INC. 1R-17 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 18-DEC-91 PAGE 2 DATE OF SURVEY: 03-DEC-1991 KELLY BUSHING ELEVATION: 88.00 FT ENG[NEER: JEFF FORMICA 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 FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 2905.27 2817.27 55 24 N 31 12 W 2300.74 4100.00 2962.22 2874.22 55 34 N 3t 59 W 2382.86 4200.00 3018.20 2930.20 56 2 N 31 36 W 2465.63 4300 O0 3074.93 2986.93 54 33 N 30 54 W 2547.92 4400 O0 3134.24 3046 24 52 6 N 29 28 W 2628.40 4500 O0 3197.54 3109 54 49 17 N 28 39 W 2705.80 4600 O0 3263.85 3175 85 47 58 N 28 30 W 2780.65 4700 O0 3330.96 3242 96 47 47 N 28 0 W 2854.77 4800 O0 3398.48 3310 48 47 14 N 27 4 W 2928.5! 4900.00 3466.59 3378 59 46 55 N 26 5 W 3001.64 2.56 1974.94 N 1182.26 W 2301.76 N 30 54 W 0.91 2044.84 N 1225.50 W 2383.95 N 30 56 W 0.82 2115 20 N 1269.27 W 2466.80 N 30 58 W 1.56 2185 59 N 1311.99 W 2549,15 N 30 59 W 3.99 2255 09 N 1352.62 W 2629.64 N 30 57 W 2.73 2322 81 N 1390.10 W 2706.99 N 30 54 W 0.28 2388 59 N 1425.81 W 2781.78 N 30 50 W 0.63 2453 88 N 1460.91 ~ 2855.84 N 30 46 W 0.88 251~ 29 N 1495.02 W 2929.49 N 30 41 W 0.97 2584 61 N 1527.7t W 3002.52 N 30 35 W 5000.00 3535.47 3447.47 46 13 N 26 9 W 3074 02 5100.00 3603.63 3515.63 47 39 N 27 2 W 3147 12 5200.00 3671.41 3583.41 46 48 N 26 37 W 3220 57 5300.00 3740.91 3652.91 45 5 N 25 36 W 3292 37 5400.00 3812.66 3724.66 43 25 N 24 25 W 3361 81 5500.00 3884.52 3796.52 45 10 N 25 53 W 3431 17 5600.00 3952.70 3864.70 48 13 N 26 34 W 3504.22 5700.00 4020.21 3932.21 46 45 N 25 31 W 3577.86 5800.00 4089.12 4001.12 46 12 N 26 13 W 3650.20 5900.00 4158.30 4070.30 46 27 N 26 25 W 3722.32 1.48 2649.99 N 1559.45 ~ 3074.79 N 30 29 W 0.39 2715.37 N 1592,29 W 3147.79 N 30 23 W 1.12 2780.98 N 1625.45 W 3221.17 N 30 18 W 1.80 2845.52 N 1657.14 W 3292.88 N 30 13 W 1.02 2908.72 N 1686.40 W 3362.23 N 30 6 W 3.46 2971.65 N 1715.97 W 3431.51 N 30 0 W 1.02 3037.16 N 1748.49 W 3504.50 N 29 56 W 1.65 3103.48 N 1780.76 W 3578.09 N 29 51 W 0.50 3168.71 N 1812.34 W 3650.38 N 29 46 W 1.26 3233.40 N 1844.40 W 3722.46 N 29 42 W 6000.00 4225.31 4137.31 49 23 N 27 31 W 3796.47 6100.00 4289.03 4201.03 50 56 N 28 4 W 3873 52 6200.00 4351.80 4263.80 51 17 N 28 17 W 3951 35 6300.00 4414.23 4326.23 51 29 N 28 21 W 4029 45 6400.00 4476.39 4388.39 51 37 N 28 32 W 4107 78 6500.00 4538.29 4450.29 51 58 N 28 35 W 4186 32 6600.00 4599.58 4511.58 52 26 N 28 37 W 4265 32 6700.00 4660.02 4572.02 53 7 N 28 37 W 4344.99 6800.00 4719.68 4631.68 53 36 N 28 34 W 4425.24 6900.00 4778.81 4690.81 53 53 N 28 31 W 4505.88 2.30 3299.57 N 1878.01 W 3796.59 N 29 39 W 0.51 3367.74 N 1913.96 W 3873.61 N 29 37 W 0.19 3436.35 N 1950.73 W 3951.44 N 29 35 W 0.31 3505.13 N 1987.76 W 4029.53 N 29 33 W 0.27 3574.03 N 2025.03 W 4107.85 N 29 32 W 0.51 3643.00 N 2062.60 W 4186.38 N 29 31 W 0.39 3712.39 N 2100.40 W 4265.38 N 29 30 W 0.74 3782.31 N 2138.57 W 4345.04 N 29 29 W 0.38 3852.79 N 2176.97 W 4425.29 N 29 28 W 0.52 3923.65 N 2215.47 W 4505.92 N 29 27 W 7000.00 4837.77 4749.77 53 22 N 29 50 W 4586.64 7100.00 4897.77 4809.77 53 15 N 30 26 W 4666.63 7200.00 4957.23 4869.23 53 46 N 30 42 W 4747.01 7300.00 5016.14 4928.14 54 2 N 30 55 W 4827.78 7400.00 5074.52 4986.52 54 30 N 31 7 W 4908.93 7500.00 5132.56 5044.56 53 49 N 31 33 W 4990.31 7600.00 5194.00 5106.00 51 17 N 32 24 W 5069.09 7700.00 5256.65 5168.65 51 9 N 32 50 W 5146.90 7800.00 5319.40 5231.40 51 7 N 33 11 W 5224.58 7900.00 5381.99 5293.99 51 28 N 33 11 W 5302.38 3.12 3994.34 N 2254.53 W 4586.68 N 29 27 W 0.57 4063.42 N 2294.89 W 4666.68 N 29 27 W 0.57 4132.68 N 2335.72 W 4747.06 N 29 28 W 0.62 4202.08 N 2377,11 W 4827.84 N 29 30 W 0.46 4271.66 N 2418.94 W 4909.01 N 29 31 W 5.08 4341.29 N 2461,17 W 4990.40 N 29 33 W 0.32 4408.13 N 2503.06 W 5069.21 N 29 35 W 0,43 4473.78 N 2545.07 W 5147.04 N 29 38 W 0.18 4539.07 N 2587.49 W 5224,77 N 29 41 W 0.49 4604.31 N 2630.22 W 5302.62 N 29 44 W COMPUTAT[ON DATE: 18-DEC-91 PAGE 3 ARCO ALASKA, INC. 1R-17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: KELLY BUSHING ELEVATION: ENGINEER: 03-DEC-1991 88.00 FT JEFF FORM[CA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH 'TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL SECTION FEET DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE~ SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEG/IO0 FEET FEET FEET DEG MIN 8000.00 5443.98 5355 8100.00 5505.57 5417 8200.00 5566.75 5478 8300.00 5627.56 5539 8400.00 5688.25 5600 8500.00 5748.76 5660 8600.00 5808.96 5720 8700.00 5868.80 5780 8800.00 5928.26 5840 8900.00 5987.36 5899 .98 51 51 N 33 0 W 57 52 7 N 32 56 W 75 52 26 N 32 47 'W 56 52 33 N 32 35 W 25 52 44 N 32 19 W 76 52 50 N 32 9 W 96 53 9 N 32 4 W BO 53 21 N 32 8 W .26 53 39 N 32 13 W .36 53 55 N 32 25 W 5380.67 5459.29 5538.22 5617.46 5696.82 5776.32 5856.07 5936.09 6016.38 6096.93 33 4670 24 4736 38 4802 27 4869 19 4936 21 5003 31 5071 28 5139 27 5207 33 5275 07 N 2673.04 17 N 2715.90 61 N 2758.82 43 N 2801.68 50 N 2844.33 86 N 2886.78 51N 2929.20 39 N 2971.75 46 N 3014.54 62 N 3057.69 5380 5459 5538 5617 5697 3O 5776 86 5856.66 5936.72 6017.07 6097.67 95 N 29 47 W 62 N 29 50 W 61 N 29 52 W 9O N 29 55 W N 29 57 W N 29 59 W N 30 1 w N 30 N 30 4 W N 30 6 W 9000.00 6046.07 5958.07 9100.00 6104.48 6016.48 9200.00 6163.14 6075.14 9300.00 6222.31 6134.31 9400.00 6281.50 6193.50 9500.00 6340.57 6252.57 9600.00 6399.66 6311.66 9700.00 6459.02 6371.02 9800.00 6518.62 6430.62 9900.00 6579.12 6491.12 54 9 N 32 24 W 54 10 N 32 24 W 53 56 N 32 52 W 53 40 N 33 38 W 53 42 N 34 17 W 53 55 N 35 4 w 53 38 N 35 34 W 53 31 N 35 49 W 53 19 N 36 17 W 52 16 N 37 4 W 6177.75 6258.79 6339.65 6420.05 6500.39 6580.70 6660.92 6740.87 6820.61 6899.56 0.22 0.56 1 .09 0.35 0.76 0.72 0.45 0.51 1 .29 1.11 5343 5412 548O 5548 5615 5681 5747 5812 5877 5941 95 N 3101.09 W 6178.56 N 30 8 W 49 N 3144.57 W 6259.67 N 30 9 W 76 N 3188.16 W 6340.59 N 30 11 W 13 N 3232.41 W 6421.08 N 30 14 W 04 N 3277.37 W 6501.52 N 30 16 W 39 N 3323.26 W 6581.97 N 30 19 W 21 N 3369.93 W 6662.34 N 30 23 W 55 N 3416.90 W 6742.47 N 30 27 W 55 N 3464.06 W 6822.41 N 30 31 W 40 N 3511.62 W 6901.57 N 30 35 W 10000.00 6640.61 6552.61 10100.00 6702.65 6614.65 10200.00 6764.67 6676.67 10300.00 6826.69 6738.69 10345.00 6854.61 6766.61 51 56 N 37 22 W 6977.65 51 40 N 37 41 W 7055.28 51 40 N 37 41 W 7132.87 51 40 N 37 41 W 7210.45 51 40 N 37 41 W 7245.36 0.73 0.00 0.00 0.00 0.00 6004.23 N 3559.28 6066.45 N 3607.07 6128.53 N 3655.02 6190.61 N 3702.97 6218.55 N 3724.54 w 6979.91 w 7057.82 w 7135.69 w 7213.58 w 7248.63 N 30 N 3O N 30 N 3O N 3O 4O W 44 W 49 W 53 W 55 W F'T'i ARCO ALASKA, INC. 1R-17 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 18-DEC-91 PAGE 4 DATE OF SURVEY: 03-DEC-1991 KELLY BUSHING ELEVATION: 88.00 FT INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH ENGINEER: JEFF FORMICA 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 -88 O0 0 0 11 20 36 89 51 50 40 59 37 27 55 24 47 46 13 31 49 23 77 53 22 N 0 0 E N 29 5 W 91 N 29 10 W 622 N 32 7 W 1462 N 31 12 W 2300 N 26 9 W 3O74 N 27 31 W 3796 N 29 50 W 4586 98 51 51 N 33 0 W 5380 07 54 9 N 32 24 W 6177 0.00 0.00 1000.00 989.11 901 2000.00 1820.89 1732 3000.00 2360.40 2272 4000.00 2905.27 2817 5000.00 3535.47 3447 6000.00 4225.31 4137 7000.00 4837.77 4749 8000.00 5443.98 5355 9000.00 6046.07 5958 0 O0 41 37 77 74 02 ,47 64 67 75 10000.00 6640.61 6552.61 51 56 N 37 22 W 6977.65 10345.00 6854.61 6766.61 51 40 N 37 41 W 7245.36 0.00 2.04 5.89 0 85 2 56 1 48 2 3O 3 12 0 33 0 22 0.00 N 0 O0 E 0.00 N 0 0 E 77.13 N 49 36 W 91.57 N 32 37 W 534.35 N 319 60 W 622.64 N 30 53 W 1251.34 N 759 33 W 1463.71 N 31 15 W 1974.94 N 1182 26 W 2301.76 N 30 54 W 2649.99 N 1559 45 W 3074.79 N 30 29 W 3299.57 N 1878 01 W 3796.59 N 29 39 W 3994.34 N 2254.53 W 4586.68 N 29 27 W 4670.07 N 2673.04 W 5380.95 N 29 47 W 5343.95 N 3101.09 W 6178.56 N 30 8 W 0.73 6004.23 N 3559.28 W 6979.91 N 30 40 W 0.00 6218.55 N 3724.54 W 7248.63 N 30 55 W COMPUTATION DATE: 18-DEC-91 PAGE 5 ARCO ALASKA, INC. 1R-17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 03-DEC-1991 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: JEFF FORMICA [NTERPOLATED 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 MIN 0 O0 88 188 288 388 488 588 688 790 893 0.00 -88.00 0 0 N 0 0 E 0.00 0.00 06 88.00 0.00 0 36 S 64 44 W 0.30 1.78 06 188.00 100.00 0 42 N 17 18 E 0.24 1.72 07 288.00 200.00 0 30 S 25 52 W 0.88 1.91 07 388.00 300.00 0 36 S 55 24 W 1.27 2.48 08 488.00 400.00 0 53 N 61 50 W 1.92 0.43 15 588.00 500.00 3 46 N 34 4 W 5.26 4.38 71 688.00 600.00 7 58 N 33 45 W 15.53 3.24 14 788.00 700.00 11 26 N 32 50 W 32.40 4.33 14 888.00 800.00 16 24 N 31 15 W 56.91 6.28 0.00 N 0.08 S 0.00 N 0.31 N 0.62 N 1.19 N 3.77 N 12,33 N 26.50 N 19 47.33 N 31 0 O0 E 0 0 1 1 1 4 9 0.00 N 0 0 E 76 W 0.76 S 84 19 W 49 W 0.49 N 89 52 W 23 W 1.27 N 75 46 W 49 W 1.61 N 67 22 W 80 W 2.16 N 56 25 W 04 W 5.53 N 47 2 W 77 W 15.73 N 38 23 W 01 W 32.61 N 35 39 W 97 W 57.11 N 34 2 W 998.82 988,00 900.00 20 34 N 29 6 W 1106.29 1088.00 1000.00 22 10 N 28 6 W 130 1214,88 1188.00 1100.00 23 55 N 27 42 W 172 1325.46 1288.00 1200.00 26 30 N 30 12 W 219 1437.65 1388.00 1300.00 27 24 N 32 6 W 270 1551,71 1488.00 1400.00 30 35 N 32 2 W 325 1673.45 1588.00 1500.00 38 53 N 31 47 W 394 1805.88 1688.00 1600.00 42 47 N 31 46 W 481 1948.51 1788.00 1700.00 48 52 N 29 34 W 582 2115.64 1888.00 1800.00 56 23 N 30 32 W 716 90 99 35 65 83 66 42 55 23 76 48 2 04 1 2 1 1 4 4 2 5 0 76.77 N 49.16 W 91 16 N 32 38 W 24 111 37 N 67.91 W 130 44 N 31 22 W 02 148 81 N 87.64 W 172 70 N 30 30 W 60 190 13 N 110.42 W 219 86 N 30 9 W 34 '233 59 N 136.83 W 270 72 N 30 22 W 85 280 07 N 165.91 W 325 52 N 30 39 W 68 338 76 N 202.59 W 394.72 N 30 53 W 17 412 52 N 248.29 W 481.48 N 31 3 W 29 499 82 N 300.20 W 583.04 N 30 59 W 85 616.04 N 366.35 W 716.74 N 30 ~4 W 2295.42 1988.00 1900.00 55 35 N 29 29 W 865 86 2475,55 2088,00 2000.00 56 32 N 30 43 W 1015 2661.24 2188.00 2100.00 57 52 N 33 41 W 1171 2857.11 2288.00 2200.00 60 29 N 32 10 W 1339 3054.50 2388.00 2300.00 59 19 N 31 49 W 1509 3244,34 2488.00 2400,00 57 36 N 30 41 W 1670 3425,02 2588.00 2500.00 55 42 N 31 27 W 1821 3604,84 2688.00 2600.00 56 32 N 29 38 W 1970 3786,46 2788.00 2700.00 56 39 N 28 24 W 2122 3969,35 2888,00 2800.00 56 6 N 30 31 W 2275 63 70 76 72 97 32 72 33 43 1.13 745.52 N 440.87 W 866.12 N 30 36 W 0.74 874.40 N 517.25 W 1015.94 N 30 36 W 1.55 1005.54 N 602.52 W 1172.24 N 30 56 W 0.82 1147.12 N 693.67 W 1340 54 N 31 10 W 2.32 1291.22 N 784.20 W 1510 70 N 31 16 W t.ll 1429.21 N 867.83 W 1672 06 N 31 16 W 1.39 1557.48 N 946.49 W 1822 53 N 31 17 W 0.94 1686.21 N 1022.39 W 1971 95 N 31 14 W 0.72 1818.87 N 1095.80 W 2123 45 N 31 4 W 3.35 1953.21 N 1169.26 W 2276 44 N 30 54 W 4145,89 2988.00 2900.00 56 3 N 31 58 W 2420.77 4322.46 3088.00 3000.00 54 16 N 30 45 W 2566,17 4485.34 3188.00 3100.00 49 41 N 28 45 W 2694.67 4636.04 3288.00 3200.00 47 52 N 28 21 W 2807.39 4784.55 3388.00 3300.00 47 19 N 27 13 W 2917.16 4931.25 3488,00 3400.00 46 38 N 25 56 W 3024.37 5076.84 3588,00 3500,00 47 30 N 26 59 W 3130,03 5224,16 3688,00 3600.00 46 29 N 26 27 W 3238,12 5365,96 3788.00 3700.00 43 46 N 24 31 W 3338.44 5504,93 3888.00 3800.00 45 20 N 25 56 W 3434.65 0.86 2077.04 N 1245.60 W 2421.90 N 30 57 W 1.30 2201.27 N 1321.35 W 2567.40 N 30 58 W 3.69 2313o04 N 1384.76 W 2695.87 N 30 54 W 0,48 2412.11 N 1438.54 W 2808.50 N 30 49 W 0.82 2509.19 N 1489.84 W 2918.16 N 30 42 W 1.04 2605.27 N 1537.68 W 3025.21 N 30 33 W 1.24 2700.13 N 1584.53 W 3130,72 N 30 24 W 1.68 2796.70 N 1633,29 W 3238.70 N 30 17 W 2.13 2887.36 N 1676.70 W 3338,89 N 30 9 W 3.69 2974.79 N 1717.49 W 3434.99 N 30 0 W ARCO ALASKA, [NC. 1R-17 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 18-DEC-91 PAGE 6 DATE OF SURVEY: 03-DEC-1991 KELLY BUSHING ELEVATION: 88.00 FT ENGZNEER: JEFF FORM[CA [NTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 5652.67 3988.00 3900.00 47 29 5798.38 4088.00 4000.00 46 12 5943.55 4188.00 4100.00 47 42 6098.37 4288.00 4200.00 50 55 6257.93 4388.00 4300.00 51 22 6418.70 4488.00 4400.00 51 39 6581.03 4588.00 4500.00 52 21 6746.77 -4688.00 4600.00 53 22 6915.61 4788.00 4700.00 53 58 7083.68 4888.00 4800.00 53 10 N 25 51 W 3543.25 N 26 13 W 3649.03 N 26 47 W 3754.14 N 28 3 W 3872.25 N 28 19 W 3996.56 N 28 34 W 4122'.43 N 28 36 W 4250.30 N 28 35 W 4382.46 N 28 33 W 4518.50 N 30 25 W 4653.56 1 .84 0.55 4.41 0.49 0.13 0.31 0.51 0,37 0.61 0.49 3072.21 N 1765.76 W 3543.50 N 29 53 W 3167.66 N 1811.83 W 3649 21 N 29 46 W 3261.90 N 1858.65 W 3754 3366.62 N 1913.37 W 3872 3476.17 N 1972.15 W 3996 3586.91 N 2032.03 W 4122 3699.20 N 2093.21 W 4250 3815.22 N 2156.50 W 4382 3934.74 N 2221.50 W 4518 4052.15 N 2288.27 W 4653 27 N 29 40 W 35 N 29 37 W 64 N 29 34 W 50 N 29 32 W 36 N 29 30 W 51 N 29 29 w 54 N 29 27 W 61 N 29 27 W 7252.16 4988.00 4900.00 53 55 7423.25 5088 O0 5000.00 54 37 7590.40 5188 O0 5100.00 51 18 7749.98 5288 O0 5200.00 51 8 7909.66 5388 O0 5300.00 51 31 8071.42 5488 O0 5400.00 52 2 8234.90 5588 O0 5500.00 52 33 8399.59 5688 O0 5600.00 52 44 8565.10 5788.00 5700.00 53 3 8732.20 5888.00 5800.00 53 28 N 30 50 W 4789.11 N 31 9 W 4927.86 N 32 22 W 5061.61 N 33 3 W 5185.74 N 33 10 W 5309.93 N 32 57 W 5436.79 N 32 43 W 5565.86 N 32 19 W 5696.49 N 32 4 W 5828.20 N 32 9 W 5961.91 0.18 0.46 0.38 0.44 0.51 0.22 0.37 0.19 0.27 0.38 4168.87 N 2357 27 W 4789 17 N 29 29 W 4287.87 N 2428 73 W 4927 94 N 29 32 W 4401.80 N 2499 05 W 506~ 73 N 29 35 W 4506.45 N 2566 23 W 5185 90 N 29 40 W 4610.65 N 2634 35 W 5310 16 N 29 45 W 4717.25 N 2703 64 W 5437 11 N 29 49 W 4825.90 N 2773 79 W 5566.26 N 29 53 W 4936.23 N 2844 15 W 5696.98 N 29 57 W 5047.86 N 2914.38 W 5828.76 N 30 0 W 5161.28 N 2985.50 W 5962.56 N 30 3 W 8901.08 5988.00 5900.00 53 55 9071.80 6088.00 6000.00 54 18 9242.09 6188.00 6100.00 53 42 9410.99 6288.00 6200.00 53 42 9580.32 6388.00 6300.00 53 41 9748.63 6488.00 6400.00 53 25 9914.48 6588.00 6500.00 52 9 10076.52 6688.00 6600.00 51 30 N 32 25 W 6097 8O N 32 23 W 6235 95 N 33 16 W 6373 53 N 34 23 W 6509 20 N 35 29 W 6645 16 N 35 55 W 6779 67 N 37 7 W 6910 89 N 37 40 W 7037 10 10237.61 6788.00. 6700.00 51 40 N 37 41 W 7162.05 10345.00 6854.61 6766.61 51 40 N 37 41 W 7245.36 0.33 0 6O 0 85 0 66 0 35 1 O8 0 77 1 29 5276.36 N 3058.16 W 6098.55 N 30 6 W 5393.17 N 3132.31 W 6236.80 N 30 9 W 5509.21 N 3206,69 W 6374,50 N 30 12 W 5622.34 N 3282.37 W 6510,35 N 30 17 W 5734.30 N 3360.73 W 6646,56 N 30 22 W 5844.21 N 3439.77 W 6781.36 N 30 29 W 5950.52 N 3518.52 W 6912.94 N 30 36 W 6051.89 N 3595.84 W 7039.57 N 30 43 W 0.00 6151.88 N 3673.05 W 7164.98 N 30 50 W 0.00 6218.55 N 3724.54 W 7248.63 N 30 55 W !"1'i ARCO ALASKA, INC. 1R-17 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASZNG TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A LAST READING GCT BASE KUPARUK A PBTD 7" CASING TD COMPUTATION DATE: 18-DEC-91 PAGE 7 DATE OF SURVEY: 03-DEC-1991 KELLY BUSHING ELEVAT[ON: 88.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 638' FSL & 214' FEL, SEC18 T12N RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 5702.00 9733.00 9809.00 9949 O0 10093 70 10147 O0 10253 O0 10339 O0 10345 O0 4021 58 6478 68 6524 O0 6609 21 6698 74 6731 80 6797 54 685O 88 6854 6! 3933.98 6390.68 6436.00 6521,21 6610.74 6643.80 6709.54 6762.88 6766.61 3104.80 N 5834 04 N 5883 36 N 5972 24 N 6062 54 N 6095 63 N 6t61 44 N 6214 83 N 6218 55 N 1781 39 3432 41 3468 33 3534 95 3604 O5 3629 61 3680 43 3721.67 3724.54 ;::r ARCO ALASKA, INC. 1R-17 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A LAST READING GCT BASE KUPARUK A PBTD 7" CASING TD COMPUTATION DATE= 18-DEC-91 PAGE 8 DATE OF SURVEY: 03-DEC-1991 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: JEFF FORMICA SURFACE LOCATION = 638' FSL & 214' FEL, SEC18 T12N RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COOED[NATES NORTH/SOUTH EAST/WEST 5702.00 4021.58 9733.00 6478.68 9809.00 6524.00 9949.00 6609.21 10093.70 6698.74 10147.00 6731.80 10253.00 6797.54 10339.00 6850.88 10345.00 6B54.61 3933.58 6390 68 6436 O0 6521 21 6610 74 6643 BO 6709 54 6762 88 6766 61 3104.80 N 5834 04 N 5883 36 N 5972 24 N 6062 54 N 6095 63 N 6161 44 N 6214 83 N 6218.55 N 1781.39 W 3432.41W 3468.33 W 3534.95 W 3604.05 W 3629.6t W 3680.43 W 3721.67 W 3724.54 W FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 10345.00 6854.61 6766.61 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7248.63 N 30 55 W DIRECTIONAL SURVEY COMPANY FIELD (2OUNTRY RUN ARCO ALASKA, INC. 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L-:....i...~ ....... i...i..4...! ......... ~-..~..-~ ..... ~--.~...~.'-~.. :i::i::.i. i :%!::i::i::::::E:EE:~:: ::]::: ::: :::F.::::i:::i:::i::: ::::::F: :::i; i:i::i::i.:::...~-::-.....!..l...i ...... !-..i ....... i ..... i...i ...... i-.-i...i.-.i ....... i-..i...i-..'~ ...... i.-i.--i..-~ ....... ! .................. i"'i ........... i"'i'"i" "'F'H-k :-i-~'i:'k:: ::!:~: i: :k:: :::!:::i:::!:::i:: ;:::}:::i:::i:::i::: :::i: :i i (:l: i:::}:: i::!::: ::::::::::::::::::::::::::::::::::::: ::::i:::¢::;:::i::: :::~::i:::F ::: ?:: ::: :::i:::i::: :::i::i:::i:::¢::: :::i:::!:::F!::: :::i::: :::!:::!::: :::i:::i::~:~:: :::~:;::~.::~. q--:.'--.:.'-.+-~ .-4--~,--.H.-,..-i---i-..i---! ...... i-..i.--F.i.-.I.++--i.-i--. !'--H'"i"-h '--i"-k-.?i'" d"-H"! ..... ?-i-"i-'~'-' ['"i"i:::!:::!'" :::!::E:Et::: :::!:::!:%!::: :%1:::!:::!:" 4. 4- i -.:-. -~..i +-- -..~-.'---,~--+-~ ..-:.-,h-+...: ....... .~::~: ......... ~- -:- .... .:.-+.-,'.-:-'.,-'".--:--'r r'~ '"? '? t' ':' "r :' -:' ~ ' '! ~ .." , ' ~ : ~ ; : : : : : : : : : :~ : : :1'~'u ~ i : : I : : : i : : ..... r ....... !'!'~"i ~ i !!ii ~ i ! ! ! , ! ~ i ~" ;~ RECEIVED FEB - 4 1,992 Alaska Oil & Gas Cons. 6ommissiOr~ Anchorage ARCO Alaska, Inc. D~te: DecernbP. r 20. 1991 ARCO Alaska, Inc. Date: January 3, 1992 Transmittal Ct: 8321 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Records Clerk ATO-11 19 P.O. Box° 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed copy of this transmittal. ~/,-/'~1R.17v'~ Cl i.~lol 1R-23 / Please acknowledge receipt and return Sub-Surface Directional I 2- 3- 9 1 75326 Survey Sub-Surface Directional 1 0- 2 9- 91 75325 Survey Receipt Acknowledged: D&M .................. Date: RECEIVED JAN 0 6 1992 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: November 22, 1991 Transmittal #: 8290 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 c0py of this transmittal. ~,/_/oz. I R - 2 7 ." LIS Tape and Listing -~ ~'/~,'~ ~'/-? ~ 1 R-2 9 .x~ LiS Tape and Listing..~j-/~ ~/"/°~ I R-2 0. / LIS Tape and Listing ~r~ 5--/~f,/ ~/",//P/ I R- 1 7 ~'/ LIS Tape and Listing .~ ?/--/~t I R-23 ~' .... LIS Tape and Usting 8-31 -91 74904 8- 1 4-91 74854 9-9-91 74922 9- 1 9-91 74934 1 0-22-91 75103 Receipt Acknowledged: -- Date: .......................... DISTRIBUTION: Lynn Goettinger RECEIVED State of Alaska ? NOV 2 ? 1991 Naska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: October 4, 1991 Transmittal #: 8244 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. Please acknowledge receipt and return one signed copy of this transmittal. 1R-17 Cement Bond Log 9-24-91 8150-10155 1 R - 1 7 Cement Evaluation Log 9 - 2 4 - 9 1 81 5 0 - 1 01 3 4 Acknowledge' '>-- ~ .... Date' Receipt Drilling State of Alaska(+sepia) NSK ARCO Alaska, Inc. Date: September 27, 1991 Transmittal #: 8237 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 1 R-17 CDR 9-1 5-1 9-91 5698-10345 I R-17 CDN 9-1 5- 1 9-9 1 5698-10345 Receipt Acknowledged' - Date' - ......... DISTRIBUTION: D&M . Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) 0 7 997 A°Choroge~'°°s' Cofo~i**/bn August 15, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A W McBride Area Drlg Engr ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Well No. Kuparuk River Unit 1R-17 Company ARCO Alaska Inc Permit No 91-114 Surf Loc 638'FSL, 214'FEL, Sec 18, T12N, R10E, UM Btmhole Loc 1660'FSL, 1081'FWL, Sec 07, T12N, R10E, 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 determina- tions are made. Sufficent notice must be given to allow for a representative of the Commission to witness the BOPE installed on the surface casing and a test of same prior to drilling out the surface casing shoe. Sincerely, Russell A Douglass Commissioner BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section, w/o encl Dept of Environmental Conservation w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of Work Drill X Redrill D I lb. Type of Well Exploratory D Stratigraphic Test D Development Oil X Re-Entry D Deepen DI Service r~ Development Gas r~ Single Zone X Multiple Zone r~ 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 88', Pad 45' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25628, ALK 2561 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.O25) 638' FSL, 214' FEL, Sec. 18, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1160' FSL, 1360' FWL, Sec. 7, T12N, R10E, UM 1R-17 #UG30610 At total depth 9. Approximate spud date Amount 1660' FSL, 1081' FWL, Sec. 7, T12N, R10E, UM 8/1 6/91 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1R-12 10,303 MD 1081' @ TD feet 58' @ 500' TVD feet 2437 6,807' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035(e)(2)) Kickoff depth 500 feet Maximum hole angle 53° Maximum surfac~ 2382 pslg At total depth (TVD) 3500 pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantity/ of cement Hole Casin~l Wei~lht Grade Couplin~l Len~lth IVD TVD IVD TVD (include sta~le data) 24" 16" 62.5# H-40 Weld 80' 43' 43' 123' 123' +_200 CF 12.25" 9.625" 36.0# J-55 BTC 5581' 43' 43' 5,624' 4,023' 1130 Sx Permafrost E & HF-ERW 520 Sx Class G 8.5" 7" 26.0# J-55 BTC 10260 43' 43' 10,303 6,807' 220SxClassG 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 ~l~e~rj~, ~l~h% ~ I,,,T~ Vertical depth Structural KI:Li:/V U Conductor Surface Intermediate ProductionAUG I 5 1991 Liner Alaska 0il & Gas Cons. C0mm[ss'ten Perforation depth: measured true vertical Anchorage 20. Attachments Filing fee X Property plat D BoP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot r-~ Refraction analysis r"] Seabed report D 20 AAC 25.050 requirements X 21. I hereby cer,~t the foregoing is true and correct to the best of my knowledge Sig Title Area Drillincj Engineer Date /'~"'/9// Commission Use Only Permit Number I API numberI ~'~f~'~/I Approval_d~te/~;~J! See cover letter for ?~/-~//~/~ I 50-O~.,~ - .,~.~-~-/'Z // other requirements Conditions of approval Samples required D Yes ~ No Mud Io~rc~quired D Yes /'~ No Hydrogen sulfide measures D Yes ,~ No Directional survey required ~]~ Yes ~--~ No Required working pressure for ROPE D 2M j~ 3M r'~ 5M r-~ 1OM r'~ 15M Other: Approved by Commissioner the commission Date ~-//,~ ~ ! Form 10-401 Rev. 7-24-89 Submit in triplicate DRILLING FLUID PROGRAM (1R-17) Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing ?.o 8~6-10.0 ~t~,~,/.~ 5-35 ' -:'~-15-35 '~'~'/'~'50-100' 5-15 15-40 10-12 9-10 10% _+ Drill out to weight up .8:6'-9.3 5-15 5-8 30-40 2-4 4-8 8-10 8.5-9 4-7% Drillina Fluid System: Tandem Brandt Shale Shakers Tandem Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuge, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes' Weight up to TD 11.0 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <10-12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 2382 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3,000 psi. The nearest well to 1 R-17 is 1 R-12. As designed, the minimum distance between the two wells would be 58' @ 500' TVD. 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 (< 4hr) 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 FV between 100-120 sec/qt to drill gravel beds. RECEIVED AU G 1 5 1991 Alaska Oil & Gas Cons. Comm'tss~en Anchorage ARC 0 ALASKA, ][nC, Structure · Pad 1R Well · 17 Field · Kuparuk River Unit Location · North Slope, Alaska Created by : jones For: E FITZPATRICK Date plotted : 14-Aug-91 IPlot Reference is 17 Version //3. kCoordinates are in feet reference slot //17. ITrue Vertical Depths are reference wellhead. / I-7//J/~ E A S T M A N / IZ//JLI~CH R ISTE N S E N ! A I~ker Hughes comp.ny N 29 DEG 12 MIN W 6647' (TO TARGET) 0 0 0 0 · ' 400 '5 8oo 1200 _ 1600- - .. 2000- (D - ~ 2400-~ ~ 2800- O - -I~ 3200- _ 3600- _ 4000- _ 4400- _ 4800- - V 5200- 5600- 6000- 7200 RKB ELEVATION: 88' TARGET LOCATION: I 1160' FSL, 1360' FWL SEC. 7, T12N, RIOE TARGET 'P,/D=6383 TM0=9591 0EP=6647 NORTH 5802 WEST 3243 KOP 'rVD=500 TMD=500 DEP=O 3.00 9.00 15.00 BUILD 3, DEG / 100' 21,00 27.00 33.00 39.00 B/ PERMAFROST TVD=1663 TM°=1750 DEP=395 45.00 51.00 EOC 'P/D=2055 TMD=2283 DEP=774 T/ UONU SNDS TVD=2698 TMD=3397 DEP=1669 <-- West 3600 3200 2800 2400 2000 1600 1200 800 4000 I I I I I I I I I I I I I I I I I I I I I 9 5/8"CS0 PT TVD=4023 TMD=5624 DEP=3459 T/ W SAK SNDS 'rVD=3398 TMD=4574. DEP=2615 TD LOCATION: ] 1660' FSL, 1081' FWL SEC. 7, T12N, RIOE AVERAGE ANGLE 53 DEG 29 MIN B/ W SAK SNDS TVD=3823 TMD=5288 0EP=3189 K-lO TVD=4133 TMD=5809 DEP=3607 ~6400 -6000 _ -5600 _ -5200 -4800 _ -4400 _ - 4000 3600 5200 -2800 - -2400 _ -2000 _ -11500 -1200 8O0 400 o SURFACE LOCATION: 638' FSL, 214' FEL SEC, 18, T12N, RIOE RECEIV£D TMo=.8 9 oE.:6o 9 AUG 1 5 1991 TARGT£; 70"TVED;6~W~:T64M'Ds:TgMSDg--l@TDoEoPD=E6pt467735 ~~S~ ~aS CONS. Co~[Sg[O~ TD / LOGGING PT WD=6807 TMD=10303 DEP=7220 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 0 ~0 8~ 1200 1600 2000 2400 2800 3200 3~0 ~0 4400 4800 5200 sea0 6~0 6400 6800 7200 7600 Scale 1 ' 200.00 Vertical Section on 330.80 azimuth wHh reference 0.00 N, 0.00 E from slot ~17 400 350 300 250 200 150 100 50 0 50 100 250 200 150 100 5O I \1700 \ \ \ \ 500 50O 31 O0 500 3700 3500 50 1500 1 O0 I 150 I 1300 1100 900 RECEIVED 700 AUG 1 5 t991 Alaska Oil & Gas Cons. Comm'mJ~isn lmchorage I~ I I I I I I I [ 250 200 150 100 50 0 50 100 150 _ 4OO _ 350 _ 300 _ 250 _ 200 _ 150 _ 100 5O _0 _ 5O _ 100 . . . . . . . . . 10. 11. 12. 13. 14. 15. 16. 17. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1R-17 Move in and rig up Pool Rig 7. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (5,624') according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2,000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole logging while drilling to total depth (10,303) according to directional plan. Run and cement 7" casing. Pressure test to 3,500 psi. ND BOPE and install lower production tree assembly. Secure well and release drilling rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic Rig 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 AU G 1 5 1991 Alas~.Oil & 6as Cons. Commission ;Anchorage 13 5/8" 5000 BOP STACK 7 5 4 ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC 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 30(X) PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTT'OM PIPE RAMS. TEST BO'FrOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. 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 RECEIVED 1 § t991 Alaska 0ii & 6as Cons. Commisslen Anchorage KUPAR,UK RIVER UNI'~ 20" DIVERTER SCHEMATIC I 6 51 4 , DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES i H CR MAINTENANCE & OPERATION 3 0 " . . 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) RECEIVED AU G 1 5 199t Alas~ 0il & Gas Cons. Commissien Anchorage 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. 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. 6. 20" - 2000 PSI ANNULAR PREVENTER MLP 8/1~ ITEM (1) .Fee (2) Loc ,, ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE [2 thru 8] · (3) Admin [9 thru :[~] ' ElO & 13] (4) Casg ~.~. [14 thru 22] (5) BOPE [23 thru 28] (6) Other '['29 thru ~1] (6) Addl 2, 3. 4. 5. 6. 7. 8. · 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. Is permit fee attached ............................................... Is well to be located in a defined pool ............................... Is well located proper distance from property line ................... 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 ............................ Lease & Well YES NO Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nt~nber appropriate .......................................... Does well have a unique name & nL~nber ............................ ,... / -I7 REMARKS 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 ............................. 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,~:~ psig ..... Does choke manifold comply w/API RP,~3 (May 84) ...................... Is presence of H2S gas probable ...... 't .............................. 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 ........ ~ ................................. O -.I ZEZ ,-,O u~-.t geology' eng i neer ing: DWJ MTM_~ LCS rev 03/29/91 jo/6.011 INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE 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. CORRECTED COPY C{~PANY NA~E : ARCO ASASKA, INC. FIELP NA~ : KUPARUK RIVER BOROUGH : NORTH SSOPE STATE : ALASKA APl ~U~BER : 50-029-22212 REFERENCE NO : g2026 RECEIVED FEB 2 5 1992 Alaska 011 & G~s Cons. Commission Anchorage bis tone ¢'erlf.lcation Listing Sch]'.,.]mheroor Alas.ks Computinq Center 2 ! '"J A N-199'2,. EDIT 92/01. t21 FLIC ARCO AEASKA ].NC,, 1~-17, KUPARUK F~IVER, 50-029-22212-00 **** TAPE HEADE~ **** SERVICE NA~E : EDIT D~TE : 92/01/21 O~I~IN : FDIC TAPM NAqE : 74934 Co~'~TIN~iATtON # : 1 PREV!O[IS TAPE : CO~E!~T : ARCO ALASKA INC., 1R-17, KUPARUK ~!VER, 50-029-22212-00 FI[.~ NA~E : EDIT .001 SERVICE : FLIC V~RSiO~ : 001A06 O~T~ : 92101121 ~AX REC SIZE : 1.024 F~LF TYPE; : LaST FIDE , FILE - EDIT.O01 ARCO ALASKA INC. KUPABUK RIVER 1~-!7 50-029-222~2 ~qAiN PASS 6tqO bOG DATA I'H[~ DF~SITY DATA PRESENTED f.)N THiS LIBRARY TAPE IS FRON 'RHOB NAX' DATA TOOL E':XT E:N S t 0~,~ TOOL TYPE USED ~ A~'~ E RGS .[,WD [,.,OGGI{'~G ~H!5~: ~.)[~ILL!~,;G RESISTIVITY/GR 5698' TO 10278.5' ~.~DS .L{~D [~r]GGIhG :,~HILE OPI'.LLI~G ?~EI[TROf.]/DENSITY 5698' TO i02~2.5' bis 'Tape Verification [.,istins .~chlumher,~:.~er 41asKa Computinq CeDter 2l-JA~-!992 06:49 CKSTER REMARKS (20-JAN-92): THIS I,I~ARY TAPE .~iAS 6EE~.~ REVISED TI) INCLUDE RECALIBRATED CDN i)FiNS].TY DA'fA DATA PRES~'NTED IS F~O~'~ 'R~{OB MAX' PAGE: 2 TYPE pT FT FT MT FT FT ~T CP F3 OHM~ DEGF OEGF PElF Fb SEC? ECL D FT DWD DFI, M S T R~FS ~iFST ~! C $ ,r 50'029"22212 638' FSI, & 214' FEL NO~TH SLOPE, ALASKA US A 599R79 88. 45. 1034,5. 10345. 10345. 5698. LSN D 5, 75, 1.50. Well Name API Serial Number Field Location Section Townshi~ Range County State or Province Natio~ Latitude Lo~oItude Witness' Name Service order Number Permanent datum Elevation o~ Perm, Da LDO Measured From ABOVE PERMANENT DATUM Elevation pi Kelly SU Elevation of Derrick Elevation of Ground L Total DePth - Driller ~otal Depth - Logger Bottom Lo~ Interval ToO Lo~ Interval Orilll g Fluid Type. Drilling Flt~ld Denslt Drilling Fluid P~ DrilllnO Fluid Vlscos Drillin~ Fluid Loss Resistlgity of Mud Sa Mud,SamPle Temperatur Pesistivit~ of'mud fi Mud,.Filtra e Sample T Resistivity of Mud Ca ZONE aud Cake Sample Tempe ZONE Surface Temperature Botto~ Mole Temperatu LIS T~ne verJf, ication 'Listir~a ,Scblun~erger Alaska ~om~ut!n~ Center 06:49 PAGEI 3 TYPE : CURV DEFI Depth ' ~ame Lhannel ~OS~ S$2 RHO Density - bDT P~OB Bulk Oenslty DRgO Delta PEF Photoelectric ~actor DC~L, Oifferenttal Caliper DPHI Density Porosity l)POp Density Porosity out~ut from an AI~plt. catlon Pro,ram 7'~P!~ Thermal ~eutron Porns!ty A'FR RG$ B~C ATTE~UATION RESIS,~IVITY Pg~ ~G$ BiiC PHASE S~IFT R~]S~STIVITY I)~g DIEI~ECTR!C RESISTIVITY FPOM RCS ROPE RATE OF DRILLING PENMT~ATIOH G~ Gamma Ray 2 66 0 .1 73 56 5 66 6 73 7 65 a 68 0,5 9 65 FT 1.1. 66 !.8 I2 1 3 66 0 1.4 65 t5 66 68. ;1.6 66 0 6 6 ~IS "raoe VerffJcation Listlnq ~ch]u,~ber¢~er Alaska ComD~tJn~ (?enter ~ !-JA~'~-! 992 06:49 PAGE~ :--;mm.mmmmmmmmm~m.mmmm~mmm 9 379 O0 000 O0 TYPE - CHAN ** SERV'ICE AP1 bPI AP] API FILK NUMB NUMB SIZE REPR PROCESS ORDER # LOG TYPE CLASS ~['JO NU~ SAMP ELE~ CODE (HEX) 1 RoS2 L,t,~,n. G/C3 599379 O0 000 [;0 0 I I 1 4 68 0000000000 RHt'3~ [~D G/C3 599379 O0 000 O0 0 I I 1 4 68 0000000000 D~HO b~'O G/C3 599379 O0 000 O0 'J 1 I 1 4 68 0000000000 P~F' [,.D 59q379 ()n 000 O0 0 1 I 1 4 68 0000000000 [)CAt b~,;O IN 599379 gO gO0 O0 0 1 , 1 1 4 68 0000000000 {'.>P H 1 [, ~ O PU 599379 O0 000 O0 0 1 ! 1 4 68 0000000000 O ~(1)~ L,~O PU 599379 O0 000 O0 0 1 I 1 4 68 0000000000 T~Pg L~D PU 599379 O0 000 O0 0 I I I ~ 68 0000000000 ATR b.,~D 0 ~ ~4 ~ 599379 O0 000 O0 O 1 I 1 4 68 0000000000 PSR L~D 0 H ~',~ i~s 599379 O0 000 O0 0 1 I 1 4 68 0000000000 ['~ f {~ L%~D 0 H' :~ ~,~ 599379 O0 000 O0 0 1 ~ ~ 4 68 0000000000 ROP)~ L,~D F/d~ 599379 O0 000 O0 0 I 1 1 4 68 0000000000 G~ T.,:~ O GAPI 599379 00 000 00 0 1 I 1 4 68 0000000000 . LWD 999.250 DRHO.LWD D~PT 10344.500 ~OS2.LWD -999.250 ~HOB, . PiSV. L:{D -999.250 DCA.[.,. LwD -999,250 DPHI.L~D :999.250 DPOR.LWD TNPN.LW~D -999.250 ATR. LV~D -999.250 PSR.LWO -999.250 DER.LWD RFlPF. L;~F) 3~. 462 t%R. i, WO -999,250 10300.000 Rt)S2.LWD -999.250 RHOB.LW[) -999.250 DRHO.LWD . 5~ SCAb Lt~O -999 250 [::)PHI,L:~D 999.250 DPOR LWD -999,250 ~.,.~x.~""'~ L~.,,"~ -999.250 PSR.Lw'D. -g99.250 DER.L~D 19,331 GR, Lt4IT~ -999,250 Df:PT. 10200.000 ROS2. L~L} 2.48I RUOB. L~,~O 2.481 DRMO.LWD ' PEV L{,~D 4.0()3 DCAL.LW,O 0.485 DPHI.:L~,~D I0 200 DPOR.LWD T%P~:I,~D 46.500 ATR. L~D 2.593 PSR,LW'D 2:811 DER.LWD ROp[~: 1,~0 7q.646 GR L~,~ 92,348 0 .... [,T I(~)i00,000 Rrna2 'b~t> 2.541, R?iOB.i.,WD 2.541 DRHO.LWD g~':~ LWD 3.722 DC~L.LV~O 0.215 DPHI..L~D 6 600 DPOR.LWD pOP~' L,::~[> i53 940 GR L~D 58.227 DV. PT, 1.0000,000 ~052, b~'~O 2,226 ;~HOB. bWn 2 226 DRHO.bWD PEF. [.,~,~ P 2,771 OCAL. I,~D 0,336 DPH [ * [5~7 25~700 DPOR,LWD T:'~pN. I, ~JD ~[~.900 ATR. LW[) 31 .140 PSR. L~ [) 41.478 DER.LWD ~999,250 999,250 -999,250 -999.. 250 -999,250 -999.250 0,g26 1,0, O0 2.723 O,'02g 8 14 25, 41.372 0,'007 19.500 5.771 E.I$ 'Pa~'~e Yeriflcati.()n [..istinq 5chlumberqer Alaska Computfnq Center 2~-,]AN-1992 06:49 PAGE: DFiPT. 9700.o00 ~052.1,~D PEF.L~D 3.860 OCAL.L~D TNpN.LWD 36.200 ATR,LWD ROP~,L~D 5~,998 GR,LWD DFPm. 9600,000 R(~S2,I~WD PEF,LWD 3,489 DCAL,LWD TNP~,LNO 36,900 ~TR,bWD R~PE,L~D 83.053 GR,LWD DKP'r. 0500,000 RO$2,LWD PEF.LWO 3,531 DCAL,LWD TNPN'I.~D 46,700 ATR,LWD ROPE.LWD 74.999 GR.LWD DEPT. 9400.000 ROS2.LWD PE~.!.,WD 3.8~3 DCAb. LwO TNPN.L~D 46.900 ATR.L~D ROP~,LWD ~8,372 GR,LWD DFPT, 9300,000 ROS2,LWD PEF,LWD 4,3?5 DCAL,bWD TNP~,~D 43,500 ATR,LWD ROPE.LWO 1.46,344 GR.bWO DFPT,LwD 9200.000 ROS2.LWD PEF, 4,920 DCAL.LwD 7'NPH,LWD 52,700 ATR.LWD ROPK.L~D 40.2~4 GR,LWD DEPT 9100.000 ROS~ I,WD TNPN,LWD 45,200 ATR.bwD ROPF.[,,,~'~ 22.305 GR.L~D . ..... ~S2 LWD DFP'T 9 O00.0¢)() PE~.L~4D 3.842 DCAL.LWD T ~ PFI'. L ~'~ 9 45. 300 ATR. ROP~. [,~D 139. 544 GR. I.,~D [)EPT, 8900,000 POS2,LWD PEv.[..~D 2,878 DCAL.L~D TNPN,~,~D 38,400 ATR.LWD ROPE.LwB i55,253 GR.LWD DEPT. RSOO,UO0 PEF.L~D 2,857 OCAL. L~D T ~'.~ P N. I,,~W 0 38. 400 ATR. ROPE, LWi) 77,702 GR. 2.247 1,098 12.3~6 PSR.LWO 49,790 2.54~4 RH[~.[],bWD O. 555 DPH [, NFO 2 .475 PSR.bWD ! 0g: 57 ~ 2,614 0.5°1. DPHI,b~O 2.685 PSR,bWD ~06,306 2,479 RHOB.LwO 0,255 DPHI.LWO 1,821 PSR~LwO 112.542 2,442 RHOB.LWD 0,231 DPHI,bWD 1.395 PSR,bWD 103.441 2,4.96 R~DB,L~D 0,158 DP~I,L~D 2,022 PSR.LWO 94,413 2,391 RH~B,LWD 0,595 DP~I,LWD 2.984 PSR.LWO 1.28,1,05 2,393 RNOB,LwD 0.518 DP~I.LWD 1.520 PSR,L~D 165.969 2,479 RHOB.LWD a.481 DPgI.LWD 2.435 PSr.bWO 1,43.1.69 2.443 RHOB,LWD 0.227 DPFii.LWD 1.713 87,901 0,066 DPM!,b~D 1,826 PSR.L~D 81,923 2.247 24.400 15.909 2,544 6,400 2.578 2 614 2i200 3 134 2.479 I0,400 2,245 2,442 12,600 1,737 2 496 9:400 2.312 2.391 15,700 3.318 2 393 15: oo ~.~46 2.479 0 400 2.443 12.600 1..772 2 388 15[900 1,765 ORHO.LND DPOR LND DER:L~D DRHO,LWD DPOR.LWD DER.LWD DRHO,LWD DPOR.LWD DER.LWD DRHO.LWD DPOR.LWD DER.LWD DRMO.LW'D DPOR.LWD DER.LWD DRHO.LWD DPOR.LWD DER,LWD DRHO.LWD DPOR.LWD DER.bwD DRHO.LWD DPOR.LWD DER,LWD DRHO.LWD DPOR.LWD DER.LHD DRHO,LWD DPOR.LWD DER.LWD DRHO,LWD DPBR,LWD DER.LWD 0,035 24,400 15.443 2,538 0,007 2,200 2,940 0,034 10,400 2,039 0 013 ,563 0.025 9' 400 2.183 0,024 15,700 3,184 o,oo 15,600 1,474 0,019 t :4oo 642 0,014 12,600 1'748 0 014 15:900 1.788 LiS Tane verification bistinc~ Schlu~berqer AlasKa Computing Center 211-dA~-] 992 06:49 PAGE: i)FP~. 860(.,.000 ROS2.b~O PEF.L~D 2,723 T?PM.bWD 33,500 RGPE.Ib~ 276.046 GR.LWD DEPT. 8400.000 ROS2,I,~D PEF,L~D 2.726 TNP~.L~D 35.500 ATR,L~D ROPW.L~5 255,722 GR.L~D DEPT. 8300.000 ROS2.LWD PE~.LWD 2.72!, DCAL,L~D TNPN.L~D 35.900 ATR.LWD ~OPF.[.,~h 310.30!, GR.LWD DEPT. ~I00.000 RGS2.bWD PEF.L~O 2.945 DCAL.LWD TNpN.L~ 33,700 ATR.LWD ROPE.b~D 331.795 GR.LbD . ..... ,-.. ~000 000 PO$2.LWQ PEF. bi~'D 2:765 OCAL.LWD Tt,~PH. L~D 33,900 ATR. LWD ROPE. L~D 31 O. 646 GR, L~'D D, FPT. 7900.000 PEF.I.,WB 2.829 DCAL.L~O T~PH,LWD 35.000 ATR.LWD ROpF,LWD 240,862 GR.LwD DFPT. 7800.000 ROS2.t,~O 'PEF,LWD 2.701 OCAL,LWD TNPH.L~D 35,200 ATR.L,W[> ~OPW,b!~D 190.864 GR.bWE) 69 2.390 R~OB.hNO O.183 OPHi,L~O 2.630 PSR.5~D 8.819 2.405 RHOB.L~O 0.108 DPHI.LaO 2.455 PSR.L~D 8.745 2.415 RHOB.b~O 0.000 DPH!. I,~'~D 2. 045 PSR. bWO .726 2 0 1 6a 2 0 2 2 0 3 97 2 0 2 93 2 0 2 94 2 0 3 91 2 0 2 89 2 0 3 72 ,415 RHOB,L~D ,076 DPHI,LWD ,997 PSR.b~D ,938 ,4i7 RHOB,bWO ,143 DPHI.LWD ,487 PSR.LWD ,259 ,456 RHOB.bWD ,091 DPHi,bWO ,134 PSR.LWD ,250 ,400 RHOB,LWD ,000 DPHI,LWD ,604 PSR,DWD ,459 .456 RHOB.LWD .105 DPHI,LWD .585 PSR,LWD .275 ,434 RHOg,LWD .107 DPMI,LWO ,076 PSR.L~D ,258 ,455 RHOB.LWD .140 DPMI.LWD .947 PSR,h~f:) .652 .267 DPMI.L~D ,6~3 PSR.L~O ,793 2.390 i-5,800 2.765 2.405 14.800 2.696 2 415 141300 2,077 2,415 14,300 2.04i 2.417 14 100 2 .456 :8oo 3.197 2.400 15 2OO 2.456 II,800 2,755 2 434 3.105 2.455 11,800 2.980 2.484 10 100 3:6'72 DRHO.LWD DPOR.LWD DER.LWD DRHO.L~D DPOR.LWD DER,LaD DRHO.LWD DPOR.LWD DER.bwD DRHO,LWD DPOR,LWD DER,LWD DRHO,LWD DPOR,I.,WD DER.L~D DRHO LWD DPOR:LWD DER,LWD DRMO LWD DPOR:LWD DER.LWD DR~O.LWD DPOR · LWD DER, L ~D DRHO LWD DPOR!LWD DER LWD DRHO,bWD DPOR,LWD DBR,LWD DRHO.LWD DPOR.L~D DER.LwD 0 O06 7~3 0,009 597 0,013 064 008 2,023 !003 100 524 O, O01 1 '/5 -0 003 5~: 200 2,620 :oos · 1 O0 3,095 0.019 11,800 2,968 014 3.669 LIS Tape verificat,Jon l',istino Scblumberqer AlasKa Co:~utt, n.q Center i)?PT. 7600. 000 R r~lF, L>~D 2.625 %?~pH. L~{O ~ 3.7 O 0 ATR PFPT, 7500.009 R P E,F, [., ~=; P 2.667 DCAL.LWD ROpF'., L~O 160,2 lb GR, LWD PELF. Lv.~D 2.700 DCA~.LbD 7'~.~PN. LwD 33. 900 ATR. RNp?, [,;~'D I95.038 GR. LWD [)EpT. 7300.000 ROS2.LWD PEF.L~D 2.754 DCAL.LWD ROPE, [,~P 123,21 .% GR, L~D DEPT, 7200,0()0 ROS2.L, WD Pg~, . L~F).. 2. 771 DCAL.L%.~F,. T~PN, LW[) 36,800 ATR ~'OP~. L;{D 135. 074 Ga. T~pN, LwD 37 ~ 800 ATR. LWD ROPE. L~D 157.015 GR. D~PT. 7000.000 ROS2.LWD PEF.LWD 2,886 DCAL,L~D TNpN, I.,~P 35,300 ATR, ROPE. Li4D 139,531 GR. LWD DEPT. [,~'0 6900. 000 ggS2. LWD PEK. 2.847 DCAb.bWD TNPN, LWD ,i0,400 ATR. L~D ROPE, L{,~D 128. 569 GR. LWD t')KPq'. 6800,000 ROS2. LWD PEF.L~ 2,8!0 DC~L,LWD T~PH. LWD 41,500 ATR. LWD ROPE, LWD i..79. 594 GR. DF:P'T. 6700.000 ROS2,Li~D PEF.LWD 2.847 DCAL'.LWD I'~pM. LWD 38, bO0 ATR. POPK, bi:~D 2a8. 995 GR. DEPT. 6600,000 ROS2,L~D DEF.LND 2.695 TNPN. LWD 39,400 ATR, kOPE, L.:.:D 253.5~5 GR 2.475 0.211 DPMI.I.,WD 2.969 PSR.L~D 85.720 2.391 0.081 DPHI,bWD 3,052 ~,905 2.351 RHOB.bWD 3.561 PSR,b~O 93.7t9 2.417 0.226 DPHI,LWD 2.g69 PSR.LWD 2.450 RHOB.LWD 0.242 DPMI.LW!> 3.3~1 PSR.L~D ~8.694 2.440 0.227 DPHI L D 2.877 93.376 2,4~8 RHOB.LWD 0.1 3 DPHI,LWO 2.456 PSR.SWQ 87,813 2,400 RHOB.LWD 0,22~ DPMI.LWO 2.638 2.372 RMOB,L~D 0,083 DPMI,L~D 2.726 PSR,SWD 82,670 2.328 RHO~,LWD 0,033 DPNI,L~D 2.955 PSR,LWO ~7.794 2.317 RHOB,LwO 0,035 DPMI,L~O 2.897 PSR,L~O 78,264 2.475 10.600 2.867 2.39! 15.700 3.024 2.351. 18 2OO 2.417 14,100 3,111 2,45O 1~.!.00 .473 2 440 2,993 2.448 2,530 2 40O ts: oo 2.787 2.372 16,900 2.8:33 2.328 19.500 3.027 2.3~7 20,.200 2.995 DRHO.LWD DPOR.LmD DER.LWD DRHO.LWD DPOR.LWD DER.LWD DRHO.LWD DPOR.LWD DER.LWD DRHO.LWD DPOR.L~D DER.bWD DRHO,LWD DPOR.LWD DER.LWD DRMD.LWD DPOR,SWD DER.LwD DRHO.LWD DPOR,LWD DER.bWD DRHO,LWD DPOR,LwD DER.LWD DRHO.LWD DPOR.bWD DER,LWD DRHO.L~D DPOR.LWD DER.L~D DR}tO,LWD DPOR.LWD DER,bWD PAGE: 0.039 10600 2:902 0,016 15,700 3,034 0,025 18,200 3,551 0 3,058 0,015 I: oo 42.5 0,~0~3 1~'I00 2,729 0,006 16,900 2,792 200 2,958 verification Listinq ;chlumberger AlasKa Computin-,6 Cent. er D~.TPT, 6500,000 ROS2.LWD PEF.I.wD 2.680 '1',~.i p H, [~WD 39. 300 ATR ROPV. LS~D 25b. ! 18 GR.DWD f>FpT. 6400. 000 gO$2 PEW.LWb 2.595 ,[, i,: p Ft. [,~n 38. 700 ATR. L~D ROPE. L~,D 162,602 GR. LWD DEPT. 6300.000 ROS2.LwD PEF.I.,WD 2.852 OCAL.bWD TNPM.L~D 43,500 ATR.L~D ROPF.LWD 240,723 GR.LWD DEPT, 6200.000 RO$2,bWD PEF,LWD 2,760 'ITNP~. L~D 39,,i00 ATR. bwO ROPF, LWD 201,890 GR.i.,WD DEPT. 6100,000 R052 LwO P~:F. L%~O 2,777 DCAL :L~,~D TNPH. [.,~D 43.900 ROPF. L~D 23S. 894 GR DEPT. 6000.000 ROS2,LWD PEF,I,WD 2,765 DC~L,LMD TNpN. I.~.~O 39. I00 ATR, ROP~. [., ~.~ D 243. 086 GR, DEPT. 5900,000 ROS2.bWD DEF. L,~D 2. 786 DCAG.bwD TNPH.L~D 41.300 ATR DWD Rop~. LWD 298. 305 (;R ~ bW~ D~PT. 5800,000 PEF.I.WD 2,862 DCAL.LWD TNPN.LWD 44.800 ATR,LWD ROPF.LWD 335,601 GR,LWD DEPT, 5700,000 RO$2,LWD PEF.L~D 2,540 DCAL.LWD '£'~P~'~.f.,WD 55.500 ATR,LWD POPE.L~D -999.250 D~PT. 5600.000 RO$2.bWD PE~.LM~ 100.000 DCAL.LWD T~PP.I,~D -999.250 ATR,LwD kOPF,I,~D -999,250 GR.I.~[> DEPT. 5588.00t ROS2. Li,~D PEr. h~?P -999.250 DCAL.L~'D TNP~. I.,:;D -999,250 ATR. LWD ROPF:. L~;[7) -999,250 GR, 21-JAN-1 99P 06:49 2,365 RtiOB.DWO 0.119 DPH!.DWD 2.8il PSR.LWO ~2.268 2,350 RHOe. LWD 0,!97 DPNI.LWD 2.822 PSR.LwD 76.220 -99 -99 -99 -99 2.380 RHOB.baD 0.033 OPMI.b~O 3.059 PSR.b~D 81.7i6 2.315 R~O~.bWD 0,159 DPHI.LWD 2,946 PSR,bWD 69,645 2.309 RHOB.bWD 0.0~5 DPHI.LWD . ~ LWD 3 5 2 ~$R, 80.t07 2,340 R~OB.LWD 0.237 DPHI.L~D 3.146 PSR,LW~ 76,646 2.320 RHOB,bWD 0.022 DPHI'bWD 2,808 PSR,D~D 78.064 2,311 ~HOB,bWD 0.356 OPHI,bWD 3,326 PSR.DWD 73.874 2,165 RHOB,bWD 1.582 DPHI,LWD 3,!,i9 PSR.LWD ~9.085 2.346 R!{OB,LwD 0,472 DPHI,bWD 9.250 .PSR.L~D 9.250 2.365 17.300 2.865 2.350 18.200 2.826 2.380 1,6 400 3:125 2 315 2o: oo 3.058 2,369 !7.000 3,668 2.340 18,800 3.136 2.320 20 00 0 i TM 2 50O 264 2.165 29.400 2.994 2 346 18i400 -999 250 9.250 R[iOB,B~D -999.250 9,250 DPHI.LWD -999.250 9,250 PSR.LWO -999,250 9.250 DRHO.LWD DPOR.LWD DER.LWD DRHO.b~D DPOR.LWD DER,LWD DRHO.L~D DPOR.LWD DER,LWD DRHO.LWD DPOR,bWD DER,LWD DRHO.LWD DPOR LWD DRHO.bWD .DPOR,LwD DER,LWD DRHO.LWD DPOR,LWD DER.LWD DRHO.LWD DPOR,LWD DER,LMD DRHO.LWD DPOR,bwD DER.LWD DRNO.LWD DPOR.LWD DER.LWD DRMO.LWD DPOR.LWD DER.LWD PAGE: 0,007 17,300 2,845 01.5 2OO 0 037 16~400 3,101 0,008 20,300 3,016 0,046 17'000 3'623 o.llg ,139 -0 005 20 000 2 936 Ol 8 · '0,2'54 18;400 -999. 250 ",999,250 :999,250 999 ' 250 ils Ta~e verlf.lcatJ, on !.istin~ ~chltt:~!~erger Alaska Co~pt3tInO Center 06:49 PAGE: **** FIbE ~RA!LER **** PiIjE F:AaE ! MOlT ,001 S~VIC~i : FblC ~ ~EC SIZ~ : lo24 F!LF TYPE i LO [~$T FILE : **** TAPE TRAILER SERVICE NAN~ : EOIT DAT~ : 92101/21 'r~P~ aia~g : 74934 COaTI~UATIOM ~ : PPEVIOUS TAPE CO~sE~iT ~ ARCO ALASKA INC,, IR-17, KUPARUK FIVER, 50-029-22212-00 **** REEL TRAILER SERVICe: NAME : EDIT DATR : 92/0I/~1 O~IGI~} : FLtC 9FEI, ~,:A~E : 74934 pREVIO(i$ REEL Cn~!ENT : ARCO ALASKA I~C,, IR-17, KUPARUK RIVER, 50-029-22212-00
