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201-097
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/4/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240404 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 19RD 50133205790100 219188 2/23/2024 YELLOW JACKET GPT-PERF BRU 241-23 50283201910000 223061 11/25/2023 AK E-LINE Perf HV B-13 50231200320000 207151 3/11/2024 YELLOW JACKET GPT KALOTSA 6 50133206850000 219114 3/2/2024 YELLOW JACKET PERF KU 13-06A 50133207160000 223112 3/13/2024 YELLOW JACKET GPT-PERF KU 21-06RD 50133100900100 201097 3/19/2024 YELLOW JACKET GPT-PERF END MPI 2-62 50029216480000 186158 2/14/2024 YELLOW JACKET PERF MPU G-18 50029231940000 204020 3/21/2024 READ Caliper Survey MPU G-18 50029231940000 204020 3/9/2024 AK E-LINE HoistCutter MPU I-24 50029237780000 224001 3/11/2024 AK E-LINE CBL NCIU A-18 50883201890000 223033 12/20/2023 AK E-LINE Perf NCIU A-18 50883201890000 223033 12/18/2024 AK E-LINE GPT/Plug/Perf PAXTON 3 50133205880000 209168 3/6/2024 YELLOW JACKET GPT PAXTON 3 50133205880000 209168 3/8/2024 YELLOW JACKET PERF PAXTON 3 50133205880000 209168 3/12/2024 AK E-LINE PPROF PAXTON 7 50133206430000 214130 2/26/2024 YELLOW JACKET PERF PBU 09-52 50029236180000 218168 3/24/2024 HALLIBURTON PPROF SD-06 50133205820000 208160 2/20/2024 YELLOW JACKET PERF SRU 222-33 50133207150000 223100 12/19/2023 AK E-LINE Perf Please include current contact information if different from above T38683 T38684 T38685 T38686 T38689 T38687 T38690 T38691 T38691T38692 T38963 T38963 T38694 T38694 T38694 T38695 T38696 T38697 T38698 KU 21-06RD 50133100900100 201097 3/19/2024 YELLOW JACKET GPT-PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.09 13:48:29 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Re-Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ 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 5,650 feet N/A feet true vertical 4,877 feet 5,510 feet Effective Depth measured 5,563 feet 3,295 feet true vertical 4,803 feet 2,883 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)Tieback 4-1/2" 12.6# / L-80 3,295' MD 2,883' TVD Packers and SSSV (type, measured and true vertical depth)Baker Liner Hanger, N/A 3,295' MD 2,883' TVD N/A, N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: Chad Helgeson, Operations Engineer 324-098 Sr Pet Eng: 7,500psi Sr Pet Geo:Sr Res Eng: WINJ WAG 3819 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A chelgeson@hilcorp.com 907-777-8405 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 361 Size 72' 0 3604040 0 950 96 measured TVD 8,430psi 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-097 50-133-10090-01-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0390821 Kenai / Sterling 6 Gas Storage Kenai Unit (KU) 21-06RD Plugs Junk measured Length Production Liner 5,599' 2,355' Casing Structural 4,851' 4-1/2" 5,620' 5,650'4,877' 72'Conductor Surface Intermediate 20" 10-3/4" 51' 1,261' 2,900psi 1,820psi 4,140psi 1,282'1,238' Burst Collapse 840psi p k ft t Fra O s O 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:29 pm, Apr 02, 2024 Noel Nocas (4361) Digitally signed by Noel Nocas (4361) Date: 2024.04.02 15:10:29 -08'00' DSR-12/30/24 RBDMS JSB 040424 Page 1/1 Well Name: KEU KU 21-06RD Report Printed: 3/20/2024www.peloton.com Alaska Weekly Report - Operations Jobs Actual Start Date: End Date: Report Number 1 Report Start Date 3/19/2024 Report End Date 3/20/2024 Last 24hr Summary PTW/PJSM. MIRU Yellow Jacket e-line. P-test 250/1000psi. SITP 145 psi. RIH with gun #1 and sat down at 5,292'. Guns stuck. Perforate there 5,272 - 5,292'. Worked line and pulled free. RIH with gun #2 and perforate 5,250 - 5,270'. Guns stuck. Worked line and pulled free. RIH with PT logging tool. SITP 147 psi. Stop at 5,250' and flow well for 20 min. SI for 20 min and monitor. POH and LD tools. RDMO. Field: Kenai Gas Field Sundry #: 324-098 State: Alaska Rig/Service:Permit to Drill (PTD) #:201-097Permit to Drill (PTD) #:201-097 Wellbore API/UWI:50-133-10090-01-00 Lease: State: Country:USA ~ 32ºRKB:21' March 20, 2024 4,537' - 4,588' Prepared By:D Ambruz Last Revision Date: November 27, 2001 Angle @KOP and Depth:4º @ 300' MD Perforations (MD):Perf (TVD): Angle @ Perfs: 5,250' - 5,310' Well Name & Number: Date Completed: Kenai Gas Field A-028142 County or Parish:Kenai Penisula Borough Alaska Kenai Unit 21-6 RD Permit #:201-0970 API #:50-133-10090-01-00 Prop. Des:A- 028142 KB elevation:91' (21' AGL) X:270,536.5 Y:2,367,873.6 Lat:60º 28' 31.144" N Long:151º 16' 18.601" W Spud:8/31/2001 TD:9/5/2001 Rig Released:13:00 hrs 9/9/01 Conductor Pipe 20" K-55 78.6 ppf PE Top Bottom MD Surf 51' TVD Surf 51' Surface Casing 10-3/4" H-40 32.75 ppf STC Top Bottom MD 0' 1,282' TVD 0' 1,238' 14-3/4" hole Cmt w/ 750 sks, Class A Production Casing 7-5/8" J-55 26.4 ppf LTC Top Bottom MD 0' 5,620' TVD 0' 4,851' 9-7/8" hole Cmt w/ 700 sks Side Track window @ 3,450' MD KU 21-6RD Pad 34-31 515' FSL, 2,089' FEL, Sec. 31, T5N, R11W, S.M. Tie-Back Tubing 4-1/2" L-80 12.6 ppf IBT-Mod Top Bottom MD 0' 3,295' TVD 0' 2,883' Liner 4-1/2" L-80 12.6 ppf Mod-Butt Top Bottom MD 3,295' 5,650' TVD 2,883' 4,877' 6-1/8" hole cemented w/ 265 sks, Class G, 13.5 ppg TD 5,650' MD 4,877' TVD PBTD 5,563' MD 4,803' TVD Max Inc 37.77 degrees Pool 6 C-1 Sand Baker Liner hanger @ 3,295' MD 10 ft Tie-Back Seal Assembly Fish:Gun anchor@ ~ 5,510' MD (2001) 5/24/23 EL tagged fill @ 5,280' Sterling Pool 6 Perforations: C-1 5,250'-5,310' (11/27/01) Shot w/ 2500psi overbalance, N2 pressure, 2-1/2" Milleneum Stim Gun, 6 spf C-1 5,250'-5,310' Re-perfed (12/6/01) w/ SLB 2 7/8" PJ HSD Guns, 6spf C-1 5,250'-5,270' (3/19/24) C-1 5,272'-5,292' (3/19/24) Pool 5.1 & 5.2 Pool 4 Fish: (recovered 1/2 ring 12/2010) possibility of other dropped CT hanger elements below perfs. See well files for details, desc. photos. SCHEMATIC (12/30/10) Bailed fill to 5,326'kb w/ 2-1/2" bailer. Tight spot @ 5,306'- 5,310' noted when 2.86" tool run. CBL TOC @ 1920' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Re-Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 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? Yes No 9. Property Designation (Lease Number):10. Field: 11.Storage Pool Report Code is 448809. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 5,650'5,510' Casing Collapse Structural Conductor Surface 840psi Intermediate Production 2,900psi Liner 7,500psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Well shall be used only for production from the gas storage pool unless the requirements of SIO 7A and 20 AAC 25.252 are met and sundry approval for injection is obtained. Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Baker Liner Hanger; N/A 3,295' MD/2,883' TVD; N/A 4,877'5,563'4,803' Kenai Sterling 6 Gas & Sterling 6 Gas Stor 20" 10-3/4" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Unit (KU) 21-06RDCO 510C Sterling 6 Gas Storage 4,851'7-5/8" ~168psi 5,599' N/A Length February 27, 2024 5,650'2,355' Tie Back 4-1/2" 4,877' 5,620' Perforation Depth MD (ft): 4-1/2" See Attached Schematic 1,820psi 72'72' 1,282' Size 51' 1,261' MD Hilcorp Alaska, LLC Proposed Pools: 12.6# / L-80 TVD Burst 3,295' 4,140psi 1,238' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028142 201-097 50-133-10090-01-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Chad Helgeson, Operations Engineer AOGCC USE ONLY 8,430psi Tubing Grade: chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: m n P s 66 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:08 pm, Feb 20, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.02.19 16:48:10 - 09'00' Noel Nocas (4361) 324-098 DSR-2/21/24 ADL0390821 SFD Re-Perforate BJM 2/27/24 10-404 SFD 2/20/2024*&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.27 16:30:28 -09'00'02/27/24 RBDMS JSB 022824 Well Prognosis Well: KU 21-06RD Date: 2-12-24 Well Name: KU 21-06RD API Number: 50-133-10090-01 Current Status: Storage Prod/Inj Permit to Drill Number: 201-097 First Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Second Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Maximum Expected BHP: ~ 300 psi @ 4587’TVD (Pool 6 Max pressure in 4 years) Max. Predicted Surface Pressure:~ 168 psi (Current Pool 6 SI pressure) Brief Well Summary KU 21-06RD was sidetracked as a Pool 6 storage well and was perforated and brought online in November 2001. In 2016 the well was converted to injector as well as a producer. Well currently produces about 4 mmscfd @ 100 psi. The reservoir model indicates this well is underperforming and the purpose of this work is to reperforate the Pool 6 sands. Notes Regarding Wellbore Condition x 4-1/2” completion x EL tagged fill @ 5280’ (5/24/23) x MIT-IA to 1500 psi (4/6/23) Pool Top in KU 21-06RD based on KU 21-6 reference well in CO 510C - Sterling Gas Pool 6 Top: 5,222’ MD; 4,513’ TVD Pre-sundry procedure 1. MIRU SL, PT to 1000 psi 2. Bail fill to 5320’ 3. RDMO SL E-Line Procedure 1. MIRU E-line, PT lubricator to 250 psi low and 1,000 psi high 2. PU GPT and RIH to ensure well is dry and complete correlation log 3. PU Guns and Reperforate Sterling Pool 6 sands: Proposed Perforated Intervals Pool Sand Top, MD ft Bottom, MD ft Top, TVD ft Bottom, TVD ft Total ft MD Sterling Gas Pool 6 Pool 6 ±5,250’ ±5,310’ ±4,537’ ±4,587’ ±60’ a. Proposed perfs also shown on the proposed schematic in red font. b. Send the correlation pass to the Reservoir Engineer (Daniel Taylor), and Geologist (Daniel Yancey) for confirmation. c. Verify PTs are open to SCADA before perforating. Record tubing pressures at 5, 10 and 15 minutes after each perforating run. d. These sands are in the Sterling Gas Pool 6 per CO 510C. Well Prognosis Well: KU 21-06RD Date: 2-12-24 4. RDMO e-line. 5. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Lease: State: Country:USA ~ 32ºRKB:21' Well Name & Number: Date Completed: Kenai Gas Field A-028142 County or Parish:Kenai Penisula Borough Alaska Kenai Unit 21-6 ReDrill January 4, 2011 4,537' - 4,588' Prepared By:Mike Sulley Last Revision Date: November 27, 2001 Angle @KOP and Depth:4º @ 300' MD Perforations (MD):Perf (TVD): Angle @ Perfs: 5,250' - 5,310' Permit #:201-0970 API #:50-133-10090-01-00 Prop. Des:A- 028142 KB elevation:91' (21' AGL) X:270,536.5 Y:2,367,873.6 Lat:60º 28' 31.144" N Long:151º 16' 18.601" W Spud:8/31/2001 TD:9/5/2001 Rig Released:13:00 hrs 9/9/01 Conductor Pipe 20" K-55 78.6 ppf PE Top Bottom MD Surf 51' TVD Surf 51' Surface Casing 10-3/4" H-40 32.75 ppf STC Top Bottom MD 0' 1,282' TVD 0' 1,238' 14-3/4" hole Cmt w/ 750 sks, Class A Production Casing 7-5/8" J-55 26.4 ppf LTC Top Bottom MD 0' 5,620' TVD 0' 4,851' 9-7/8" hole Cmt w/ 700 sks Side Track window @ 3,450' MD KU 21-6RD Pad 34-31 515' FSL, 2,089' FEL, Sec. 31, T5N, R11W, S.M. Tie-Back Tubing 4-1/2" L-80 12.6 ppf IBT-Mod Top Bottom MD 0' 3,295' TVD 0' 2,883' Liner 4-1/2" L-80 12.6 ppf Mod-Butt Top Bottom MD 3,295' 5,650' TVD 2,883' 4,877' 6-1/8" hole cemented w/ 265 sks, Class G, 13.5 ppg TD 5,650' MD 4,877' TVD PBTD 5,563' MD 4,803' TVD Max Inc 37.77 degrees Pool 6 C-1 Sand Baker Liner hanger @ 3,295' MD 10 ft Tie-Back Seal Assembly Fish:Gun anchor@ ~ 5,510' MD (2001) (12/30/10) Bailed fill to 5,326'kb w/ 2-1/2" bailer. Tight spot @ 5,306'- 5,310' noted when 2.86" tool run. Sterling Pool 6 Perforations: C-1 5,250'-5,310' (11/27/01) Shot w/ 2500psi overbalance, N2 pressure, 2-1/2" Milleneum Stim Gun, 6 spf C-1 5,250'-5,310' Re-perfed (12/6/01) w/ SLB 2 7/8" PJ HSD Guns, 6spf Pool 5.1 & 5.2 Pool 4 Fish: (recovered 1/2 ring 12/2010) possibility of other dropped CT hanger elements below perfs. See well files for details, desc. photos. Lease: State: Country:USA ~ 32ºRKB:21' Well Name & Number: Date Completed: Kenai Gas Field A-028142 County or Parish:Kenai Penisula Borough Alaska Kenai Unit 21-6 RD February 12, 2024 4,537' - 4,588' Prepared By:Chad Helgeson Last Revision Date: November 27, 2001 Angle @KOP and Depth:4º @ 300' MD Perforations (MD):Perf (TVD): Angle @ Perfs: 5,250' - 5,310' Permit #:201-0970 API #:50-133-10090-01-00 Prop. Des:A- 028142 KB elevation:91' (21' AGL) X:270,536.5 Y:2,367,873.6 Lat:60º 28' 31.144" N Long:151º 16' 18.601" W Spud:8/31/2001 TD:9/5/2001 Rig Released:13:00 hrs 9/9/01 Conductor Pipe 20" K-55 78.6 ppf PE Top Bottom MD Surf 51' TVD Surf 51' Surface Casing 10-3/4" H-40 32.75 ppf STC Top Bottom MD 0' 1,282' TVD 0' 1,238' 14-3/4" hole Cmt w/ 750 sks, Class A Production Casing 7-5/8" J-55 26.4 ppf LTC Top Bottom MD 0' 5,620' TVD 0' 4,851' 9-7/8" hole Cmt w/ 700 sks Side Track window @ 3,450' MD KU 21-6RD Pad 34-31 515' FSL, 2,089' FEL, Sec. 31, T5N, R11W, S.M. Tie-Back Tubing 4-1/2" L-80 12.6 ppf IBT-Mod Top Bottom MD 0' 3,295' TVD 0' 2,883' Liner 4-1/2" L-80 12.6 ppf Mod-Butt Top Bottom MD 3,295' 5,650' TVD 2,883' 4,877' 6-1/8" hole cemented w/ 265 sks, Class G, 13.5 ppg TD 5,650' MD 4,877' TVD PBTD 5,563' MD 4,803' TVD Max Inc 37.77 degrees Pool 6 C-1 Sand Baker Liner hanger @ 3,295' MD 10 ft Tie-Back Seal Assembly Fish:Gun anchor@ ~ 5,510' MD (2001) 5/24/23 EL tagged fill @ 5,280' Sterling Pool 6 Perforations: C-1 5,250'-5,310' (11/27/01) Shot w/ 2500psi overbalance, N2 pressure, 2-1/2" Milleneum Stim Gun, 6 spf C-1 5,250'-5,310' Re-perfed (12/6/01) w/ SLB 2 7/8" PJ HSD Guns, 6spf C-1 5,250'-5,310' (TBD) Pool 5.1 & 5.2 Pool 4 Fish: (recovered 1/2 ring 12/2010) possibility of other dropped CT hanger elements below perfs. See well files for details, desc. photos. PROPOSED (12/30/10) Bailed fill to 5,326'kb w/ 2-1/2" bailer. Tight spot @ 5,306'- 5,310' noted when 2.86" tool run. Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230728 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-23 50133206350000 214093 7/16/2023 HALLIBURTON PPROF BCU-24 50133206390000 214112 7/15/2022 HALLIBURTON PPROF BRU 223-34 50283201880000 223041 7/9/2023 HALLIBURTON RMT3D KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON EPX KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON MFC KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON EPX KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON MFC KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON EPX KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON MFC MPU B-24 50029226420000 196009 7/24/2023 HALLIBURTON WFL-TMD3D MPU B-34 50029235690000 216139 7/23/2023 HALLIBURTON WFL-TMD3D MPU B-50 50029232400000 204252 7/21/2023 HALLIBURTON WFL-TMD3D MPU E-23 50029225700000 195094 6/17/2023 HALLIBURTON COILFLAG MPU F-17 50029228230000 197196 7/2/2023 HALLIBURTON COILFLAG MPU L-13A 50029223350100 223017 6/21/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON RBT PBU 11-07 50029206870000 181177 6/28/2023 HALLIBURTON RMT3D SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON EPX SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON MFC SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON EPX SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON MFC Please include current contact information if different from above. T37886 T37887 T37888 T37889 T37889 T37890 T37890 T37891 T37891 T37892 T37893 T37894 T37895 T37896 T37897 T37898 T37898 T37899 T37900 T37900 T37901 T37901 KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON EPX KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON MFC Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.01 10:05:02 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, May 11, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 21-06RD KENAI UNIT 21-06RD Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/11/2023 21-06RD 50-133-10090-01-00 201-097-0 G SPT 2883 2010970 1500 417 450 450 450 0 0 0 0 4YRTST P Adam Earl 4/6/2023 MIT IA 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:KENAI UNIT 21-06RD Inspection Date: Tubing OA Packer Depth 510 1733 1727 1726IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230412102949 BBL Pumped:0.5 BBL Returned:0.5 Thursday, May 11, 2023 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, April 29, 2019 TO: Jim Regg P.I. Supervisory/ Q''Cq SUBJECT: Mechanical Integrity Tests l 11 HILCORP ALASKA LLC 21-06RD FROM: Guy Cook KENAI UNIT 21-06RD Petroleum Inspector Ste: Inspector Reviewed By: P.I. Supry dtp— NON -CONFIDENTIAL Comm Well Name KENAI UNIT 21-06RD Insp Num: mitGDC190423172235 Rel Insp Num: API Well Number 50-133-10090-01-00 Inspector Name: Guy Cook Permit Number: 209-097-0 Inspection Date: 4/15/2019 ' Packer Depth Pretest Initial I5 Min 30 Min 45 Min 60 Min Well I 21-06RD "Typelnj a'TVD 2381 Tubing 410 4c 415 - 415 PTD I 2010970 Type Test s", Test psi 1500 IA �'-5 n62 1744 - 1140 BBL Pumped: 0.5 - BBL Returned: 0.5 - OA 0 - U " 0 - U Interval 4vRTST P/F P Notes: Testing performed with a triplex pump and calibrated gauges. Monday, April 29, 2019 Page I of I 111 Seth Nolan Hilcorp Alaska, LLC �� v GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 tt;ir�p lla.kn.t.t... Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 09/18/17 To: Alaska Oil & Gas Conservation Commission RECEIVED Meredith Guhl Petroleum Geology Assistant SEP 18 2017 333 W 7th Ave Ste 100 Anchorage, AK AOGCC 99501 DATA TRANSMITTAL KU 21-06RD Production profile and digital data Email Attachments: KU_21-06RD DRILLING-DYNAMICS.pdf 9/18/2017 9:58 AM PDF Document 901 KB KU 21-06RD_DRILLING-DYNAMICS.tif 9/18/2017 9:29 AM TIF File 4,607KB AO KU 21-06RD FORMATION-LOG.pdf 9/18/2017 9:58 AM PDF Document 5,833 KB Lj KU 21-06RD_FORMATION-LOG,of 9/18(2017 9:31 AM TIF File 36,750 KB Please include current contact information if different from above. scow MAR 1 3 '2:61'3 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Recei ed B • Date: 9/i / � • -re Well Prognosis (00 KU 21-06RD Date: 10/11/16 Ililrorp Alnrkn,I L Well Name: KU 21-06RD API Number: 50-133-10091-01 Current Status: Storage Production/Injection Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 201-097 First Call Engineer: Taylor Nasse (907) 777-8354 (0) (907)903-0341 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907)229-4824(C) Brief Well Summary: Kenai Gas Field well KU 21-06RD was sidetracked as a Pool 6 storage well and was perforated and brought online in November 2001. The purpose of this work/sundry is to leave the piping in place to permanently allow for injection and production (this work was originally approved in sundry 311-046, and the test procedure and piping was submitted as a 10-404 on 6/21/16). Facility Information KU 21-06RD has been used as only an injector since 2012.The spool connecting the well's flowline was physically removed from the two production lines in this time. In order to increase deliverability from Pool 6, this spool was reinstalled and the well was returned to production as a test. During this test,the well was flowed through one flowline at a rate of 3.0 MMSCFD to the production header and through the test separator for three days.The SSV is controlled by logic in the PLC along with pressure readings from pressure transmitters on the flowline and separators to meet the requirements of 20 AAC 25.265(h)(9). Attachments: 1. Current Well Schematic 2. Sketch of production piping 3. Well house photo 4. Meter run photo SCANNED MAY 1 9201Z • ®, KU 21 -6 R D Permit#: 201-0970 API#: 50-133-10090-01-00 Pad 34-31 Prop.Des: A-028142 515' FSL, 2,089' FEL, KB elevation: 91' (21'AGL) n_ Sec. 31,T5N, R11W, S.M. x: 270,536.5 Y: 2,367,873.6 IIilcorp Alaska Lat: 60°28'31.144"N Long: 151°16' 18.601"W Spud: 8/31/2001 Conductor Pipe TD: 9/5/2001 20" K-55 78.6 ppf PE Top Bottom Rig Released: 13:00 hrs 9/9/01 MD Surf 51' TVD Surf 51' K-r- Surface Casing 10-314" H-40 32.75 ppf STC Top Bottom MD 0' 1,282' - TVD 0' 1,238' 14-3/4"hole Cmt w/750 sks,Class A Production Casing Baker Liner 7-5/8" J-55 26.4 ppf LTC hanger 10 ft Top Bottom @ 3,295' MD Tie-Back TMD o' a,620 Seal 9-7/8"hole Cmt w/700 sks Assembly Side Track window @ 3,450'MD \ i. - �i 4---.1 / Tie-Back Tubing 4-1/2" L-80 12.6 ppf IBT-Mod Top Bottom MD 0' 3,295' TVD 0' 2,883' Liner 4-1/2" L-80 12.6 ppf Mod-Butt Top Bottom Max Inc 37.77 MD 3,295' 5,650' degrees TVD 2,883' 4,877' 6-1/8"hole cemented w/265 sks, Class G,13.5 ppg • Lu LII -: ' Sterling Pool 6 Perforations: .a y^1 TI. :._ Pool 4 C-1 5,250'-5,310' (11/27/01) • - - I Shot w/2500psi overbalance, ' i r - N2 pressure,2-1/2"Milleneum '� �� I i _•1 ., Pool 5.1 Stim Gun,6 spf ,_ &5,2 Cl- 5,250'-5,310'Re-perfed (12/6/01) r . 1 w/SLB 2 7/8"PJ HSD Guns, 6spf 0 b I Pool 6 • i. C-1 Sand Fish: (recovered 1/2 ring 12/2010)possibility of other dropped CT hanger elements below perfs. 12130110)Bailey mi is �mss � See well files for details,desc.photos. 326'kb w/2-112"bailer „`.... Tight spot @ 5,306'-5,310' noted when 2.86"tool run. ® I Fish:Gun anchor@ 5,510'MD(2001) TD PBTD 5,650'MD 5,563'MD 4,877'TVD 4,803'TVD Well Name&Number: Kenai Unit 21-6 ReDrill Lease: Kenai Gas Field A-028142 County or Parish: Kenai Penisula Borough State: Alaska I Country:I USA Perforations(MD): 5,250'-5,310' Perf(TVD): 4,537'-4,588' Angle @KOP and Depth 4° @ 300'MD Angle @ Perfs: -32° RKB: 21' Date Completed: November 27,2001 Prepared By: Mike Sulley Last Revision Date: January 4,2011 • • o lt Lam, -a W t a-t o o= T } 41 o� :- < 11,--,,S tt v v • lam.... ... _ o L17a 111 i _ y r o' ® . : of 'Z''-' C _ w ... - a3 ra • 1 4 2 I I o : • t V• a q l e,, 9 d T o I c, ( 'e 1. 4 1 ..- a� ® �� I Z Y e N 0 o z , H _ .� 7" ._. ��— '- S�fpm-1m C a o a i r44,\ X00 049-1z Q H CL i _ .... p -4 X 0 g LL3 Z• Zg w W oZ CT) _. a c� . .., . ... 0 (i) ,.. # ' ' '5' ) I , 1, ..../, ,- , I y 4' ' jr •:44 1 ‘, , I'. ... A' --,---=.. iTlim v. - .'41111 t ma ..... AMY MM. ...71• MR ...........)...- ‘.. 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' • __ STATE OF ALASKA AliDA OIL AND GAS CONSERVATION COM 'ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing LI Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Connect to production❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 2 Exploratory ❑ 201-097 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-10090-01 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA-028142 Kenai Unit 21-O6RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kenai Gas Field-Sterling 6 Gas;Sterling 6 Gas Storage 11.Present Well Condition Summary: Total Depth measured 5,650 feet Plugs measured N/A RECEIVED true vertical 4,877 feet Junk measured 5,510 feet j IJ N 2 2016 Effective Depth measured 5,563 feet Packer measured 3,295 feet true vertical 4,803 feet true vertical 2,883 feet AoGGC Casing Length Size MD TVD Burst Collapse Structural Conductor 51' 20" 72' 72' Surface 1,261' 10-3/4" 1,282' 1,238' 1,820psi 840psi Intermediate Production 5,559' 7-5/8" 5,620' 4,836' 4,140psi 2,900psi Liner 2,355' 4-1/2" 5,650' 4,877' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic d°t� �t True Vertical depth See Attached Schematic s4.i'��t®ED FEE, 0 6 LC17 Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 3,295'MD 2,883'ND Baker Liner Hanger 3,295'MD 2,883'ND Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 -12,740 0 117 416 Subsequent to operation: 0 2,773 0 156 182 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 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❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑✓ WINJ p WAG ❑ GINJ ❑ SUSP❑ 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: N/A Contact Taylor Nasse-777-88354 Email tnasset hilcorp.com Printed Name 0 ' O 6 Tor Chad Helgeson Title Operations Manager / i Signature i .l�/ Ak ir.4 Phone 907-777-8405 Date 6-21-1b 1 Form 10-404 Revised 5/2015 � � �G+Z���y/ RBDMS JAN 1 2 2016 �`�l // � Submit Original Only • • Well Prognosis Well: KBU 21-06RD Date:6/8/16 Elilcora Alaska,LL Well Name: KU 21-06RD API Number: 50-133-10091-01 Current Status: Storage Production/Injection Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 201-097 First Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(C) Brief Well Summary: Kenai Gas Field well KBU 21-06RD was sidetracked as a Pool 6 storage well and was perforated and brought online in November 2001. The purpose of this work/sundry is to reinstall the piping spool to the production flowlines to allow for injection and production (this work was originally approved in sundry 311-046). Facility Information KU 21-06RD has been used as only an injector since 2012.The spool connecting the well's flowline was physically removed from the two production lines in this time. In order to increase deliverability from Pool 6, this spool was reinstalled and the well was returned to production as a test. During this test, the well was flowed through one flowline at a rate of 3.0 MMSCFD to the production header and through the test separator for three days.The SSV is controlled by logic in the PLC along with pressure readings from pressure transmitters on the flowline and separators to meet the requirements of 20 AAC 25.265(h)(9). Attachments: 1. Sketch of production piping 2. Well house photo 3. Meter run photo • • Y. 0 ,nV .4 a P w a- A.- Q G o sL I— i., Z p o, L off'/� �C� 1/4` 0 a i i % a d oc r� v 4 W a 1 3 LL J t r .R, o a C r . d 3 0 I J a.1 4,, 4> J ` O �� y f 0. GW J w Y .s444L I cc 0 '''&,. \ S \1 r , 0 -o�9-tz o W trX g ; 0 W o z4W Z W o = r - i . , 117 A rlY a� y 7 µd1' 4/ ir. ---'1'''f-'''' ', . . w t,:1 r,.'. • .. ::1 =° , . J,�416, „sugarFeu, � � .t • "'�" - If ' .." _._ " lir ifil i 4— " *; ----4 - - it., /x4'1 '' A '1/4.4-."..• :,...�10.4.,r '�+` ' f t'i r ,,. 4 •.. 0 -----. A ''.W iiiiiiiii4 ft. 4A ,.... g ," 4 S., _. _. .. 4 t. ,i ,., .. ty, '4.' SOL * 1 - ''': '. N't" tstl, r. ' ' ICI° ' • . (1.) 3 , 0 0Z a� i.. LL • ti A. ,.,, , --v' a o Eo � o :. 0 3 r. )111, - ., Itill:, ..,,.- - -..,,,,..:1,;,,,,:,:-. 4 r . , ... NA „,, 'II” A, I t 1 ,,1 4 eie POW • a ••,..:..•,••,,. .,-,•,,i.,,,.,••!,,.,,,1:..,:,,,..::::,. kr-rr- , w,. '�- w .. aea .,; .. . `N. I' . ,OP i IF ' l' :71 ''' .i I:''''''L'''''''' ti4 ' ilitlaNir; ,, ,.,,,,,,, , , 6' . , ,, : fir, \ .... -IIIWl ate'^""_ - .a E mos. r ,,a ;P -, C r{fit, • • 1 o t, L.11 •64...414.1 �! _ , 1� 1 i 'moi 1 s VI N., 16 , ..., , . , ; _ ......„.. .., ., .. ,41.,, , 3) )1)! :..t.'\ --) ./ . ..- 3 s ..,� . < z o. o 0 i fi .' . R 4 ..• ••..•?.qy� �+ 4101101.1.11.1110011M01.11"4 " P .,..7.,,,,,,.....7.......,,,,,....,„,,,,,......"............ 1� iwrimt 3 " 1111 c ` M 1 filiwitAillik loll* . a / .-. . , i -14., F s AA t O -.1„ , > N U N P.G d m > a`) as a > N 40tifit . c CI) fir.. O F s , ....... *.?.. 4 • ..t• 41011 ' f,� t` o O 112 E n . ,.., I ,‘I , • . a• ' ''''''' ..,' ''„,,,,,.,,, • " , :, ,• , / ) ,/ ' ' 'gip 1 ••• ' ''''Zi•1 /.• dllri ,..AM , , ' - i''• '' , I . • ' 1 K ....a... ' . . . . , "-- --. If ''' --- • ' . V r; "N I S. r . Wing Valve ,44 , ..i.' ' .. ... SSV • 4.1 ' .--..' . .., .'•' , , .: ik., . "•\., 1 ..,,,,,, -. : , 4 A , , . . . .%. ' , . 4 , . . . . . . To Blinded . ,. . - . Flowpath (Closed) .. - ..., .,,, , ,-, i'•• _. To Described ;, .. ., Flowpath(Open) ' i .., , .. . . r , ... . . ..... ....,.. ,_ ,. , , , . , . ,....,..........i,...i..., ' . ' —- - . .'t S. • ' - 1 , , .. 11 f l''' • ..,i - - ,-,II6-;1-,,,,,,-• -- . .,,„, . ., . ..• . ..... , '1 N'••••'... , .,, Z.:-','!••7'' •,.. - -- • ..• ','+.,From Injection , . , , 11‘.. :-••-•- - , k.,,,,,,,, . •-:.,,• , .,....,;:•. • . •, . • .(Closed) . .,'. ... ,,,. ..t. . , -...': . ...•. . ............. c-. •N.--- : › ,k'' 'ii';. '::': ).;4''.4#' .' ' '' ee' C''' e. ..'...•.'...> .....'`,.. .i.e..".... "e'i;,e' '•-,''., ' ,l,ee',. .'...•":„...::.„;;'.•"'-'" * .„„,... ',.,'..,,•,„.'<;;;:r•"., ,....... ”.7...,........,.. le.".. '''',..,...., ,;;:..e, ........e. ......',,, .•.".." „.... ..;,,,,, 'e• .1,:',..•, . :4i1,1r.::::.101. . e'.. ...e, ,I•....-. ''''. .. .... '':•..;' e• .:.'''",',.," 41.''-111040,01: ••:',.., ';'•'' "•••;;., ''. . . ;',,,;;•''.., l'',,!.' ••..' 0...",' "e,... .......0.•*". , ,' '1441* ''•, •,.." e' , e .....'' ,,--,,. -,..-,.-...,, ,, ,,-,.--..,.‹...,,,,,,, -..-,,,-,,, ,..,--.., ,‘,...,--. *,••:.1,-;,,,,,,*;„ .1.4 . . • s‘ , . ,... MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,May 04,2015 TO: Jim Regg 1-Z qo P.I.Supervisor ! I SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 21-06RD FROM: Jeff Jones KENAI UNIT 21-o6RD Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 2 NON-CONFIDENTIAL Comm Well Name KENAI UNIT 21-06RD API Well Number 50-133-10090-01-00 Inspector Name: Jeff Jones Permit Number: 201-097-0 Inspection Date: 4/21/2015 Insp Num: mtJJ150501074230 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well' 21-06RD Type Inj N?TVD 2883 Tubing 210 210 210 210 - PTD 422 97 Type Test SPT Test psi 1500 j IA 200 1720 1720" 1720 - Interval 0P/F P I OA o zo 20 zo Notes: < 1 BBL methanol pumped 1 welll inspected,no exceptions noted - SCANNED MAY 2 2 2015 Monday,May 04,2015 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, July 01, 2011 TO: Jim R 1 P.1. Supervisor lj I SUBJECT: Mechanical Integrity Tests MARATHON OIL CO 2I -06RD FROM: Matt Herrera KENAI UNIT 21 -06RD Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON- CONFIDENTIAL Comm Well Name: KENAI UNIT 21 - 06RD API Well Number: 50 133 - 10090 - 01 - 00 Inspector Name: Matt Herrera Insp Num: mitMFH110629072720 Permit Number: 201 - 097 - Inspection Date: 6/27/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 21 -06RD' Type Inj. G TVD 1 2883 • IA i 80 1710 , 1700 1700 P.T.D 2010970 'TypeTest SPT Test psi 1500 ' OA I 0 108 108 105 Interval INITAL P/F P , Tubing 360 360 360 360 Notes: Minimun required pressure was 1500 psi, IA was pressure tested to 1700 psi - Friday, July 01, 2011 Page 1 of 1 • • Marain Alaska Production LLC Alaska Asset Team Marathon P.O. Box 1949 MARA THON Alaska Production LLC Kenai, AK 99611 ® Telephone 907/283 -1371 Fax 907/283 -1350 March 7, 2011 R Mr. Tom Maunder MAR 0 8 MI Alaska Oil & Gas Conservation Commission 333 W 7 Ave &S Gems ssion Anchorage, Alaska 99501 Ancnormgs Reference: 10 -404 Report of Sundry Well Operations. Field: Kenai Gas Field Well: Kenai Unit 21 -6RD Dear Mr. Maunder: $t $NE MAC Attached for your records is the10 -404 Report of Sundry Well Operations for KU 21 -6RD well. This report covers the work performed to replace the 1 -3/4" velocity string with 4 -1/2" tie -back tubing. Work on this well started in late 2008 and proceeded until December of 2010. Bailing operations were delayed until a determination of a /' wellbore obstruction was resolved. After identifying the obstruction, bailing of the wellbore fill, along with the missing tool components, resumed until the Sterling perforation interval was cleared on December 31, 2010. Marathon recently sought approval to convert KU 21 -6RD into a gas injection well. With the well's change of ropose there is no longer a need to add the proposed perforations. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, -RNv�^ -r v & - tfi Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS RECEIVEC ,./6.4_ • STATE OF ALASKA ALASKAIDAND GAS CONSERVATION COMMISSI MAR 0 8 20' /q i i '" REPORT OF SUNDRY WELL OPERATIONS ska Oil & Gas Cons. Connissiort 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U Other U ;And tie - back Performed: Alter Casing ❑ Pull Tubing El Perforate New Pool ❑ Waiver Time Extension ❑ tubing Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Alaska Production LLC Development Ei Exploratory • 201 -0970 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 a 50- 133 - 10090 -01 -00 7. Property Designation (Lease Number): „ 8. Well Name and Number: FED A- 028142 • Kenai Unit 21 -6RD 9. Field /Pool(s): Kenai Gas Field / Sterling Pool -6 q+ GAs s`T,A �'ct € �p 1 ..11,y, y� 10. Present Well Condition Summary: r Total Depth measured 5,650' feet Plugs measured NA feet true vertical 4,877' feet Junk measured 5,510' feet Effective Depth measured 5,563' feet Packer measured 3,295' MD feet true vertical 4,803' feet true vertical 2,883' TVD feet Casing Length Size MD TVD Burst Collapse Structural Conductor 51' 20" 72' / 72' Surface 1,261' 10 -3/4" 1,282' 1,238' 1,820 psi 840 psi Intermediate Production 5,599' 7 -5/8" 5,620' 4,836' 4,140 psi 2,900 psi Liner 2,355' 4 -1/2" 5,650' 4,877' 8,430 psi 7,500 psi I Perforation depth: Measured depth: 5,250' - 5,310' / feet True Vertical depth: 4,544' - 4,595' feet Tie - back 4 - 1/2" L - 80 3,295' / TVD Tubing (size, grade, MD & TVD): Capillary String 0 TVD Packers: Baker Liner Hanger 3,295' MD MD 2,883' TVD TVD Packers and SSSV (type, MD & TVD): SSSV: NA NA MD NA TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Removed 1 -3/4" Velocity String. Installed 4-1/2" tie -back tubing. Cleaned fill below Sterling perforations. Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 - 56 Subsequent to operation: 0 0 0 - 53 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development El r Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil H Gas U 4 WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. 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: 308 -368 Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature Phone (907) 283 -1371 Date March 7, 2011 RBDMS MAR 08 Form 10 -404 Revised 10/2010 Submit Original Only KU 21 -6RD Permit #: 201 -0970 API 50-133-10090-01-00 Pad 34 -31 Prop. . Des: A- 028142 515' FSL, 2,089' FEL, KB elevation: 91' (21' AGL) Sec. 31, T5N, R11W, S.M. x: 270,536.5 MARATNOM Y: 2,367,873.6 1 III Lat: 60° 28' 31.144" N Long: 151 °16'18.601 "W Spud: 8/31/2001 x TD: 9/5/2001 20 Top Bottom 51' PE Rig Released: 13:00 hrs 9/9/01 MD Surf 51' TVD Surf 51' 32.75 ppf STC 1 \ Conductor Pipe Surface Casing II 10-3/4" H -40 I Top Bottom MD 0' 1,282' TVD 0' 1,238' 14 -3/4" hole Cmt w1750 sks, Class A Production Casing Baker Liner 7 -5/8" J -55 26.4 ppf LTC hanger 10 ft Top Bottom @ 3,295' MD . Tie -Back MD 0' 5,620' Seal TVD 0' 4,851' 9 -7/8" hole Cmt w1700 sks Assembly Side Track window @ 3,450' MD 1 I:I L I,I Tie -Back Tubing ' , , 4 -112" L -80 12.6 ppf IBT -Mod Top Bottom MD 0' 3,295' TVD 0' 2,883' Liner 4 -1/2" L -80 12.6 ppf Mod -Butt Top Bottom Max Inc 37.77 MD 3,295' 5,650' degrees TVD 2,883' 4,877' . ' 6 -1/8" hole cemented w/ 265 sks, Class G, 13.5 ppg - 'ill Ij II Sterling Pool 6 Perforations: a ( :_ Pool 4 C -1 5,250'-5,310' Shot w/ 2500psi psi overbalance, alance, g! ? r - N2 pressure, 2 -1/2" Milleneum ‘ : ==m ' I I Pool 5.1 r. Stim Gun, 6 spf -W • , - 1 " " & 5.2 _ C 1 5,250'- 5,310' Re- perfed (12/6/01) N - _ N ` w/ SLB 2 7/8" PJ HSD Guns, _ 6spf t. ; ii ! , Pool6 " 0 C-1 Sand ' k _ a ..c. Fish: (recovered 1/2 ring 12/2010) possibility of 12/30110 Bailed fill to 5,326'kb w/ 2 - 1/2" bailer ther dropped CT hanger elements below perfs. ( ) = See well files for details, desc. photos. r Tight spot @ 5,306'- 5,310' noted when 2.86" tool run. ! 4 , ;' _ I Fish: Gun anchor@ - 5,510' MD (2001) I TD PBTD 5,650' MD 5,563' MD 4,877' TVD 4,803' TVD Well Name & Number: Kenai Unit 21 -6 ReDrill Lease: Kenai Gas Field A- 028142 County or Parish: Kenai Penisula Borough State: Alaska I Country:I USA Perforations (MD): 5,250' - 5,310' Perf (TVD): 4,537' - 4,588' Angle @KOP and Depth: 4° @ 300' MD Angle @ Perfs: - 32° RKB: 21' Date Completed: November 27, 2001 Prepared By: Mike Sulley Last Revision Date:_ January 4, 2011 Marathon O tions Summary Report by Job • r maRanio N Oil Company ell Name: KENAI UNIT 21 -6 Qtr /Qtr, Block, Sec, Town, Range Field Name Li cense No. State /Province Country 6031005N011 W01 KENAI ALASKA USA Daily Operations Report Date: 10/18/2 Job Category: WORKOVER 24 Hr Summary set slickline plug in XN profile in 1.75 inch velocity string. Bleed pressure off velocity string and verify plug is holding. Rig down slickline unit Ops Trouble l Start Time End Time Dur (hrs) Ops Code Activity Code Status Code I Comment 14:00 15:00 1.00 MOB RIG AF Spot Pollard Wireline Equipment to run slickline inside V string and set plug in XN profile 15:00 15:30 0.50 SAFETY MTG AF PJSM - Simultaneous operations, slips trips falls, rig crew putting matting boards down will be finished by the time crew rigged up, put up pylons around cellar, along route where forklift will be working, active gas production pad, red lights, blue lights, sirens, muster area, emergency calls, job assignments from JSA, windy, stopping crane if wind strength increases 15:30 16:00 0.50 RURD SLIK AF Rig up lubricator, tool string 16:00 17:00 1.00 RURD EQIP AF flange above swab valve bolts had to be tightened. Borrowed hammer wrench and hammer from rig and tightened bolts. 17:00 17:30 0.50 TEST BOPE AF PT wellhead and lubricator to 500 psi - passed 17:30 18:00 0.50 RUNPUL SLIK AF Run in hole with Gauge Ring - 1.30 OD. Set down @3312' slickline depth. Bottom sticky - grease and sand in GR when back to surface 18:00 18:30 0.50 RUNPUL SLIK AF Run 1" gauge ring to verify BST nipple or XN profile. 1 " went through, therefore XN profile 18:30 19:00 0.50 RUNPUL SLIK AF Run in hole with XN plug, Set in profile at 3313' slickline depth 19:00 19:30 0.50 RUNPUL SLIK AF RIH with prong to seal equalizing ports. POOH 19:30 20:00 0.50 BLOWDN COIL AF Bleed off pressure in velicity string to verify XN plug is sealing - pressure bled down to 0 psi in 10 minutes. Seal verified 20:00 20:30 0.50 RURD SLIK AF Rig down slickline unit, secure wellhead, sign out and turn in work permit Report Date: 10/19/2008 Job Category: WORKOVER 24 Hr Summary Bring in BJ coil, rig up - perform BOP test Ops Trouble Start Time End Time Dur (hrs) Ops Code Activity Code Status Code Comment 16:00 16:30 0.50 SAFETY MTG AF PJSM - topics - active gas production pad, red lights for fire, blue lights for gas emission, sirens , muster area in #1 operators office area, sumultaneous operations with adjacent rig, overhead loads, pinch points, need to cover cellar, slips trips, and falls, job assignments, pressure testing 16:30 19:00 2.50 RURD COIL AF spot equipment, rig up BOP's, hydraulic controls, coil unit, control cab, fluid pump truck, connect to methanol tank, fluid supply tank, light plants, manlifts, crane 19:00 21:00 2.00 TEST BOPE AF Test BOP equipment for coil unit, fill out state form 21:00 21:30 0.50 SECURE WELL AF Secure wellhead for evening, turn in workpermit, sign out for evening. Report Date: 10/20/2008 Job Category: WORKOVER 24 Hr Summary Rig up CTU, pull Velocity String Ops Trouble Start Time End Time Dur (firs) Ops Code Activity Code Status Code Comment 08:30 09:00 0.50 SAFETY MTG AF Obtain work permit- PJSM - topics - active gas production pad, red lights for fire, blue lights for gas emission, sirens, muster area, simultaneous operations, slips, trips, falls, overhead loads, PPE, three second rule, buddy rule, job assignments,etc. 09:00 11:30 2.50 RURD COIL AF start equipment, make up flange on injector, make up tubing connectors, replace stripping rubber, make up tool string, remove nite cap, make up Bowen adapter, lubricator, install tool string, set injector on wellhead / BOP'S , 11:30 12:00 0.50 TEST BOPE AF Shell test wellhead equipment 12:00 12:30 0.50 RUNPUL COIL AF RIH, latch onto velocity string hanger, pull test, prepare to release velocity string from hanger 12:30 14:00 1.50 RUNPUL COIL AF Vetco realeases hanger bolts, pull velocity string up above BOP's, set pipe rams, lock rams, attach pipe clamp and plate, cut coil below spear, drop assembly down from injector head, cut off spear assembly and landing assembly for velocity string. Prepare coil to dimple on connector. Wait on methane sniffer prior to deburring flashing inside coil. 14:00 17:00 3.00 WAITON REGS CS change of scope from previous operations. Waiting on waiver for hot permit. Load 350 feet of water in coil while waiting for waiver. 17:00 17:30 0.50 SECURE WELL CS secure wellhead for evening, sign out and turn in permit www.peloton.com Page 1/8 Report Printed: 3/1/2011 AA Marathon Otions Summary Report by Job AZ A OilCorrmpany Well Name: KENAI UNIT 21 -6 Casing Flange Elevation (ft) Ground Elevation (ft) 'KB- Casing Flange Distance (ft) 'KB- Ground Distance (ft) Spud Date 'Rig Release Date 0.00 I 59.00 80.00 21.00 8/22/2001 2/26/2008 Daily Operations Report Date: 10/21/2008 Job Category WORKOVER 24 Hr Summary Pull velocity string, rig crane and injector head out of way, prepare to set plug in 4 1/2" string, load hole with water. Ops Trouble Start Time I End Time Dur (hrs) Ops Code Activity Code Status Code _ Comment 09:00 10:00 1.00 SAFETY MTG AF Obtain work permit - review hot work waiver, PJSM - topics - gas production pad, red lights for fires, blue lights for gas emission, sirens, muster area in Admin bldg. , simultaneous operations, slip trips falls, pinch points, overhead loads, job assignments, review of work to be done etc. 10:00 13:00 3.00 RURD COIL AF warm up equipment, remove nite cap from wellhead, remove external connector, grind v string coil for internal dimple on connector, install connector, walk injector down to bowen lubricator, pull test v string connection, unlock slips / rams, equalize pressure, open BOP's / slips / rams 13:00 15:00 2.00 RUNPUL COIL AF pull velocity string out of hole 15:00 16:00 1.00 RURD COIL AF rig down injector head, remove Bowen lubricator, drain fluid from Vstring into container, prepare to blow tubing dry 16:00 16:30 0.50 RURD COIL AF Rig up N2 unit, cool unit down, rig up hard iron and flowback iron to flowback tank 16:30 17:00 0.50 JAR N2 AF Jet nitrogen through velocity string to dry out coil 17:00 17:30 0.50 SECURE WELL AF Open quad ram, blow down N2 from velocity string, close master valve and swab valve, install nite cap, double block all flow lines. Secure wellhead for evening. Report Date: 10/22/2008 Job Category: WORKOVER 24 Hr Summary set plug, fill hole with KCL H2O, rig down Ops Trouble Start Time End Time Dur (hrs) Ops Code Activity Code Status Code Comment. 08:00 09:00 1.00 SAFETY MTG AF Obtain work permit, PJSM - topics - active gas production pad, red lights for fires, blue lights for gas emission, sirens, muster areas, explosive safety, slips, trips, falls, overhead loads, pressure testing to 500 #, job assignments, manlift spotter, review of job to be performed ff, simultaneous operations, drill rig, gravel trucks etc 09:00 11:00 2.00 RURD ELEC AF spot equipment, rig up wireline BOP, lubricator, grease tubes, packoff 11:00 11:30 0.50 TEST BOPE AF PT wireline BOP and lubricator, CTU BOP's to 500 psi.- passed 11:30 12:30 1.00 RUNPUL ELEC AF Run 3.80 gauge ring, tie in SWS PDC / GR log. 12:30 14:00 1.50 RUNPUL ELEC AF Run Weatherford retrievable 3.77 OD bridge plug, set at 3500 feet. POOH. 14:00 15:00 1.00 RURD ELEC AF rig down electric line 15:00 15:30 0.50 SECURE WELL AF secure wellhead, turn over to BJ SERVICES to fill hole with KCL water. 15:30 16:00 0.50 RURD PIPE AF Rig up BJ Services pump truck, flow lines, KCL water tank 16:00 17:00 1.00 PUMP WTR AF Pump 161 BBL 6% KCL water, pressure test 500 # after filling hole. Very slight bleedoff in pressure at packing nuts to velocity string hanger. 17:00 18:00 1.00 RURD COIL AF Finish rigging down coil unit, secure location. 18:00 18:30 0.50 SECURE WELL AF Secure wellhead, turn in work permit, sign out Report Date: 10/29/2008 Job Category: WORKOVER 24 Hr Summary set sub rig up on KU 22 -6X WO - Ops Trouble Start Time End Time Dur (hrs) Ops Code Activity Code Status Code Comment 12:00 19:00 7.00 MOB ''' RIG AF PJSM; Move in and set sub base and center over well . Scope up sub. Set generator, boiler and water tank. Set mud boat pump and pit trailers. Rig up walk way to pump trailer. Run electrical lines. 19:00 20:00 1.00 RURD RIG AF Scope up mast. Run control and electrical lines to sub floor. Fire up boiler 20:00 03:00 7.00 RURD RIG AF PJSM; With crane operator and crew discuss cold weather and crane operations. Set fuel tank, bop conex, stairs, back landing gray iron, Dog and choke houses. Crane up wind walls. Run control lines to choke and dog houses. Install brake linkage. R/U driller console, Run gai- tronics. 03:00 06:00 3.00 RURD RIG AF PJSM; Scop up mast secure gudelines. Spot beaver slide and rig up. Rig up suction lines in pits J Report Date: 10/30/2008 Job Category: WORKOVER 24 Hr Summary R/U torque tube and top drive N/U bope - _, www.peloton.com Page 2/8 Report Printed: 3/1/2011 • M Marathon OS ations Summary Report by Job • MARATHON Oil Company Well Name: KENAI UNIT 21 -6 Ops I Trouble Start T End Time ' Dur (hrs) 1 Ops Code Activity Code Status Code Comment 06:00 18:00 12.00 RURD RIG AF PJSM; Install torque tube. Repair safety cables on torque tube rail. Rig up top drive and service loop R/U high pressure mud manfold 18:00 00:00 6.00 RURD RIG AF Hang tongs and spinners R/U floor. Install bails R/U shock hoses. Set Pipe racks 00:00 01:00 1.00 NUND TREE AF Nipple down tree and puff tubing hanger. Make run with test plug 01:00 06:00 5.00 NUND BOPE AF N/U BOPE. Install 11X5000 X 13 3/8 x5000 adapter spool. Nipple bop stack and kill lines. Install panic and bleeder line. R/U flow line and riser. Daily Operations Report Date: 10/31/2008 Job Category: WORKOVER 24 Hr Summary Test BOP, Clean cellar, M/U polish mill, RIH __ _ ' Ops I Trouble Start Time End Time Dur (hrs) Ops Code Activity Code Status Code Comment 06:00 12:00 6.00 TEST BOPE AF PJSM; Test BOPE and all related components 250/2500psi . for 10min(Blm - requirement) Test gas alarms LEL and H2s. Test Flow and pvt system. Preform accumulator drawdown test. Witness waved by Jim Regg AOGCC 10 -29 -2008. Called Tim Lawlor BLM 10 -29 -2008 0930hrs. Install wear bushing 12:00 13:00 1.00 PULD BHA AF PJSM; Make up Baker 5.73 polish mill. 13:00 15:30 2.50 CLEAN RIG AF PJSM; Mousehole 3' off floor. Use vac. truck to clean out cellar for mousehole. Put mouse hole flush with floor. 15:30 19:00 3.50 PULD DP PJSM: Make up Baker 5.73 polish mill assy and Strap Drift and P/U 3300' of 4" S135 Drillpipe and run in hole. Total of 106jts P /U. Note Hole fill took 8bbs to fill prior to running in hole. 19:00 19:30 0.50 TRIP DP AF Tag top of PBR at 3304.83' Circulate at 4bbls per min 90psi. Pressure increased to 120psi as mill entered PBR wash and mill down to 3313.35 9.35swallow) set 3000Ibs down on no go ring. Work mill into PBR 4X times. with rotation. Stop rotation and set down 10klbs on no go ring. Up wt. 61 klb Dn. Wt. 51klbs 19:30 20:30 1.00 PULD DP 'AF Blow down mud lines and top drive . Rig up to lay down Drillpipe. POH and lay Down Drillpipe. KLC started flowing out of drillpipe 20:30 21:30 1.00 CIRC CFLD CS Circulate to balance fluid in well. Note saw 14bbl loss/ Losses stopped. Well static. Brine wt 8.7ppg 21:30 01:30 4.00 PULD DP AF POH and lay down drilipipe total of 106jts. Lay down polish mill assy. No Gain / Loss 01:30 02:00 0.50 RUNPUL WBSH AF Pull wear Bushing 02:00 04:30 2.50 RURD RIG AF Rig down all drillpipe handling tools. Lay down tongs spinners Change out bails Clean clear rig floor 04:30 06:00 1.50 PULD TBG AF Rack and drift 81jts 4 1/2 IBT 12.60 L -80 Tubing. Report Date: 11/1/2008 Job Category: WORKOVER 24 Hr Summary Load pipe on pipe racks and measure and rabbit, Service rig, Wait on tubing hanger.Recive hanger make dummy run, P/U 80 jts 3302', 4 1/2 -12.6# Iiner.Land seals test csg to 2000 psi 5 min. test tubing 500 psi 10 min.Space out hanger, spot inhibitor, land hanger, test backside to 2000 psi, test tubing to 500 psi 10 min. test top of tubing hanger with blinds closed to 3000 psi, All test good. nipple down BOP Ops Trouble Start Time End Time Dur (hrs) Ops Code Activity Code Status Code Comment 06:00 10:30 4.50 PULD TBG AF PJSM;Load 4 1/2 liner on pipe racks, rabbit, and measure, rig down spinners.and lay down subs and handling equip. 10:30 11:30 1.00 SERVIC RIG AF PJSM; Service rig and top drive. - 11:30 14:30 3.00 WAITON EOIP AF PJSM; Wait on tubing hanger, Serv. choke manifold, valves, repair steam line on rig floor, Serv. gun lines on pits, rig down MI living quarters and inteq. 14:30 15:30 1.00 PULD TBG AF PJSM; Received tubing hanger. Make dummy run with hanger, no issues. 15:30 19:30 4.00 PULD TBG AF PJSM; Make up Baker Tie back seal assy., RIH with 78jts of 4 1/2 -12.6# Liner. Sting in liner set 20K on locator. @3295'. 19:30 21:00 1.50 TEST CSG AF Rig up and test annulus to 2000 psi for 5 min. no leaks. Rig up and test tubing to 500 psi for 10 min. 21:00 22:30 1.50 RUNPUL TBG AF Space out and make up hanger and landing joint,Locator 2' off top of liner top at 3295' Total of (78) jts.4 1/2 -12.6# IBT tie back liner. 22:30 23:30 1.00 CIRC CFLD AF Spot SMB inhibitor on backside.50 bbls. - _ www.peloton.com Page 318 Report Printed: 3/1/2011 M Marathon Oleations Summary Report by Job • MARMON � OiICompany Well Name: KENAI UNIT 21 -6 _ — — _-_ Ops Trouble 7 1 Start Time End Time Dur (hrs) Ops Code Activity Code Status _ i. Code Comment 23 :30 03:00 3.50 RUNPUL TBG AF Land hanger and run in lockdowns.Rig up and test annulus to 2000 psi for 5 min. no leaks, rig up and test tubing to 500 psi for 10 min.no leaks. Install two way check. Lay down landing joint, close blind rams and test tubing hanger to 3000 psi for 10 min.Pull two way check and install BPV © 0300 hrs. 03:00 06:00 3.00 NUND BOPE AF PJSM; Flush and blow down mud lines, nipple down kill line, choke line, bleeder, R/D trip tank and fill up line. Install plug in annular preventer, R/D Turnbuckles, Hook up bridge cranes, Nipple down BOP. Daily Operations Report Date: 11/2/2008 Job Category: WORKOVER 24 Hr Summary Nipple up tree test void/ Tree to 5000 /10min Test Good, Rig down GD -1 Ops Trouble Start Time End Time Dur (hrs) Ops Code Activity Code Status Code Comment 06:00 08 ;00 2.00 NUND TREE AF PJSM: Nipple up Tree. Test Void to 5000psi /10 min Test tree to 5000psi /10min. test good 08:00 00:00 16.00 RURD RIG AF PJSM: Rig down service loop and top drive, Pickle pumps, and draworks, Rig down long bails, and top drive, remove dresser sleeves, clean pits, lay down "U" tube for poor boy, UD choke hose, kill line, and bleeder. Rig down manifold, snubbing posts, trip tank gauges,pickle test pump, PJSM; Rig down torque tube, turn buckles, "T" bar, PJSM; Lay down top drive, load out baker and epoch shacks, remove cylinder tarps, rig down gas buster, panic lines, shock hoses, cmt. line, mud line, load out BOP stack, rig down cuttings tank, prep derrick to scope down, blow down water lines, repair cotto box, 00:00 06 :00 6.00 RURD RIG AF PJSM; Prep derrick for laying over, rig down brake linkage,drillers console, shut down boilers, and blow down steam lines, rig down service lines, pull wires for carrier to choke house and pump room. Report Date: 11/3/2008 Job Category: WORKOVER 24 Hr Summary Complete Rig down and load out of rig. Release rig to SD -6 ©0000 hrs. Ops Trouble Start Time End Time Dur (hrs) Ops Code Activity Code Status Code Comment 06:00 18:00 12.00 RURD RIG AF PJSM: Crane down back landing, stairs Dog and choke houses. Crane down Gray iron. Remove Windwalls and stairways to conex and rig floor. Remove flow line. Crane down Fuel tank./ Move out misc. loads and ship to SD -6. Move carrier off mud boat. Split pits. Note had 30gal diesel spill on the pad pumping out rig fuel tank. 18:00 00:00 6.00 RURD RIG AF PJSM;Load out trailers, unplug pump room, pits, carver, cooling towers, chain derrick,prep carrier for transport, drive carrier off mud boat, and plug in block heaters,flip mud boat ramp, rig down service lines, rig down sky walk, rig down exterior lights, on pits,and pumproom, Lower sub empty water tank, repair and reinstall gai- tronics in derrick house, load out trailers.Release Rig to SD -6 ©0000 hrs. Report Date: 11/17/2008 Job Category: WORKOVER 24 Hr Summary Set tree, rig up to pressure test CTU BOP's Ops Trouble i Start Time End Time Dur (hrs) Ops Code Status Code Comment 12:00 12:30 0.50 SAFETY MTG AF PJSM - Topics discussed: JSA - assigned jobs, PPE, active gas production pad, red light for fires, blue lights for gas emission, sirens for audible, buddy rule, three second rule, muster point, pinch points, overhead loads, review of todays job. 12:30 15:30 3.00 1NSPCT WLHD AF Install wellhead, remove back pressure valve - Vetco wellhead services, spot coil tubing unit, install flow lines. prepare for BOP Test 15:30 18:00 2.50 RURD COIL AF Continue installing coil tubing unit, BOP, Spool adapters to wellhead, flowlines to pumps and flowback equipment. 18:00 18:30 0.50 SECURE WELL AF secure wellhead for evening, shut down BJ CTU, turn in work permits, sign out for evening Report Date: 11/19/2008 Job C ategory: WORKOVER . 24 Hr Summary Rig up BJ coil unit, pressure test BOP's, pressure test Tree, Jet out water in wellbore above plug set at 3500', latch onto plug, equalize pressure, pull plug. Jet in well from existing perforations. www.peloton.com Page 4/8 Report Printed: 3/1/2011 t> Marathon O�ations Summary Report by Job • „ N OiICompany Well Name: KENAI UNIT 21 -6 - — - ------- -T_Ops Trouble- -- -- -__ - --- ...----- - - -- -- _ --- -- _ - ' i Start Time End Time j Dur (hrs) Ops Code Activity Code Status j Code Comment 08:30 09:00 0.50 SAFETY MTG AF PJSM - Topics discussed: JSA - assigned jobs, PPE, active gas production pad, red light for fires, blue lights for gas emission, sirens for audible, buddy rule, three second rule, muster point, pinch points, overhead loads, review of todays job. 09:00 10:30 1.50 RURD COIL — AF Temp is -4 deg. F. Trying to get diesel engines started , using heaters etc. 10:30 11:30 1.00 TEST BOPE AF Pressure test tree - Vetco - passed 11:30 13:00 1.50 TEST BOPE AF Pressure test CTU BOP's. Test good 13:00 15:00 2.00 RURD PIPE AF Rig up Arctic Iron fiowback equipment while BJ Coil thawing out airlines to transfer N2 15:00 19:00 4.00 PUMP N2 AF Run in hole to jet out 53.3 BBL of 6% KCL Water on top of plug. 16:45 pm - Depth 2508, pump pressure - 1215#,WHP - 1 #, N2 Rate - 575 SCF/ min 17:00 pm - Depth 2587 , pump pressure - 1469 #, QGO - 333 #, N2 Rate - 575 SCF / Min 17:30 pm - bump plug at 3482 feet measured coil depth 17:45 pm - start out of hole, Pump pressure - 808 #, WHP - 96 #, N2 Rate 700 SCF / Min, Returns 46.6 BBL 18:15 pm - Returns 53.3 BBL, Calc. Vol - 53.3 BBL 17:00 Out of Hole. 227 # of N2 cap left in hole. Shut in well. Start Rig Down of coil unit 19:00 20:00 1.00 RURD COIL AF rig down BJ CTU injector head, Pull BOP's and spindle adapter off tree. Nipple up tree flange to top of tree 20:00 21:00 1.00 RURD SLIK AF Rig up Pollard wireline to pull Weatherford Bridge Plug 21:00 00:00 3.00 RUNPUL SLIK AF Nite cap on flange atop tree frozen. Swab valve frozen closed. Three hours spent on acquiring a heater, starting heater and heating tree. 00:00 04:00 4.00 RUNPUL SLIK AF Attempt to pull Weatherford retrievable bridge plug from 3500 feet. First Attempt set down at 3503 slickline depth. Latched on and jarred down on plug to equalize pressure. Multiple attempts. Pressure would not equalize. Tried to pull up on plug and fishing tool came loose. Came out of the hole and still had tool intact. 2nd attempt - bridge plug at 3503 - latched onto fishing neck and jarred down on tool to equalize pressure multiple times. No success. G tool released when pulled. Pulled out of hole and replaced brass shear pin which was slightly worn. Dogs in G tool, similar to collett in Weatherford fishing tool appear to be worn. Quite a bit of grease on tool, no sand. 3rd attempt - Set G tool down onto Weatherford fishing tool and re- attached. Made 3 jar atttempts and Weatherford tool came loose. Back on surface, inspected Weatherford tool full of sand. Redressed tool and running in for forth attempt. 4th attempt - Multiple attempts to latch onto bridge plug, pressure at surface has dropped down to 250# N2 cap. Some of the drop is due to bleeding off lubricator for multiple runs but it is thought that the rest of the drop was due to pressure equalization below the plug. The tool appeared to pick up appox. 25 # of weight so tool brought back to surface for inspection. 04:00 06:00 2.00 RUNPUL SLIK AF Run in with dump bailer to clean out on top of bridge plug. First run got approx. 2 gallons fluid, mud, grease and sand. Approx. 1 pint of hard packed sand in bottom guide of bailer. 2nd run - approx. 2 gallons muddy water and hard packed sand in bottom guide of bailer. Daily Operations Report Date: 11/20/2008 Job Category: WORKOVER 24 Hr Summary Retrieve Weatherford RBP. RIH w/ 3.68" GS to tag fluid level. Fluid level @ 4981' KB. RD BJ Coil. Ops Trouble Start Time End Time Dur (hrs) Ops Code _ Activity Code Status Code Comment 06:00 06:30 0.50 SAFETY MTG AF Operations in progress. Obtain SWP. Change out w/ Craig Rang. Transfer Sundries, WBD, and Precedure. 06:30 07:00 0.50 RUNPUL SLIK AF RIH(1) 4.5" GS to fish Weaterford RBP. Tag at 3503' KB. Latch plug. Three good jar licks (1500 #) and the plug moves 4'. GS pulls free. POOH. Tool sheared. www.peloton.com Page 5/8 Report Printed: 3/1/2011 AA Marathon O ations Summary Report by Job • nu►wnxoir � OilCo 1panS Well Name: KENAI UNIT 21 -6 -- ,— Ops i Trouble - - - -- -- -- --- -- - -- — I Start Time End Time Dur (hrs) Ops Code Activity Code Status Code Comment_ 07:00 08:00 1.00 RUNPUL SLIK AF Re -pin GS. RIH(2) w/ 4.5" GS. Tag at 3500' KB. latch plug. PUH to 3247' WLM. Hit a tight spot plug pulls free. Falls to 3346' WLM. POOH. Tool sheared. 08:00 09:18 1.30 RUNPUL SLIK AF Re -pin GS w/ steel shear stock. RIH(3) w/ 4.5" GS. Latch plug @ 3346' WLM. POOH slowly. OOH w/ plug. 09:18 09:39 0.35 RUNPUL SLIK AF RIH(4) w/ 3.68" OD GS to tag fluid level. Tag fluid @ 4981' KB. POOH. 09:39 10:39 1.00 RUNPUL SLIK AF OOH. RD Pollard Slick line unit. _ 10:39 16:39 6.00 RURD COIL AF Secure WH. RD BJ Coil. 16:39 16:54 0.25 SECURE WELL AF Secure location. Turn in permit and leave loc. Daily Operations Report Date: 2/26/2009 Job Category: WORKOVER _ 24 Hr Summary Rig up wireline truck to re- perforate C1 Pool 6 Sterline sand from 5250' - 5296' MD correlated to Schlumberger Reservoir Saturation Tool log run 8 Sept. 2001. Run in hole with 3.75" OD gauge ring /junk basket. Unable to get below existing perforations at 5250' MD. POOH. Run in hole with 3.625" OD JB /GR. Unable to get below 5250' MD. POOH. Run in hole with open ended 2.80" OD gauge ring, Spang Jars, Oil Jars, Got to 5256' MD. Tried to spud, couldn't get below 5256' MD. POOH. Sterline sand and mud in gauge ring. Rig down.Turn in work permit. Ops Trouble Start Time End Time Dur (hrs) Ops Code Activity Code Status Code Comment 07:30 08:45 1.25 SAFETY MTG AF PJSM - Review JSA's for simultaneous operations to remove well house (Udelhoven) and Expro - Eline. Review slips, trips, falls, red lights for fires, blue lights for gas emissions, sirens, muster areas, emergency numbers and procedures, three second rule, buddy rule. Went through job description for day, assigned jobs to work assignments. 08:45 12:30 3.75 RURD ELEC AF Rig up crane to remove well house. Remove well house. Rig up Expro wireline crane, lubricator, wireline truck, perforating guns and JB / GR. 12:30 13 :30 1.00 RUNPUL ELEC AF Run 3.75" OD Junk basket / Gauge Ring (JB / GR ) to 5250' MD as correlated to Schlumberger Reservoir Saturation Tool log run on 08 Sept. 2001. Couldn't get past top perforation in C1 Pool 6 interval of Sterling Sand. POOH 13:30 14:45 1.25 RUNPUL ELEC AF Run 3.625" OD JB / GR down to 5250' MD. Couldn't get below 5250' MD. POOH 14:45 15:45 1.00 RUNPUL ELEC AF Change out to open ended gauge ring with 2.80 "OD. Got down to 5256' MD. Slightly deeper than previous runs. POOH. Gauge ring full of Sterline sand and mud. POOH 15:45 16:45 1.00 RURD ELEC AF Rig down Expro wireline unit, lubricator and crane truck. 16:45 17:00 0.25 SECURE WELL AF Secure wellhead for evening, turn well over to operations, turn in work permits, leave location. Report Date: 3/10/2009 Job Category: WORKOVER 24 Hr Summary MIRU Pollard slickline unit to bail fill from 5252' to 5266'. Recover 5 -1/2 gallons of sand and clay. Ops Trouble Start Time End Time Dur (hrs) Ops Code Activity Code Status Code Comment 07:30 07:45 0.25 SAFETY MTG Hold site PJSM w/ operations and crews on 41 -7 pad. Discuss simultaneous work on this pad. Discuss alarms, muster area, and emergency response. Obtain SWP. 07:45 08:15 0.50 SAFETY AF — Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss Pollard JSA and make job assignments. 08:15 08:30 0.25 PREP LOC AF Remove well house 08:30 10:00 1,50 PREP LOC AF Wait on number 2 operator to plow snow berm from around outside of were well house was. 10:00 10:39 0.65 RURD SLIK AF Cut 20' of wire. Re -head line and change packing. PU lubricator. MU tool string- rs, kj, 1 -3/4" x 10' stem, kj, oj, Issj, 2 -1/4" DD Bailer. 10:39 11:03 0.40 TEST EQIP AF Carry lubricator to WH. Test lubricator to 1000 psi. Test good. Wing valves and upper master valve closed. _ 11:03 11:39 0.60 BAIL FILL AF RIH(1) w/ 2 -1/4" DD bailer w/ circular bottom. Tag fill @ 5252' KB. POOH. OOH. Full bailer. Recover 2 quarts dry gray sand. 11:39 12 :09 0.50 BAIL FILL AF RIH(2) w/ 2 -1/4" DD bailer w/ circular bottom. Tag fill @ 5254' KB. POOH. OOH. Full bailer. Recover 2 quarts dry gray sand. 12:09 12:57 0.80 BAIL FILL AF RIH(3) w/ 2 -1/4" DD bailer w/ circular bottom. Tag fill @ 5254' KB. POOH. OOH. Full bailer. Recover 2 quarts dry gray sand Add 3' to 2 -1/4" bailer. Now 6' over all. www.peloton.com Page 6/8 Report Printed: 3/1/2011 AA Marathon Options Summary Report by Job 0 MARATHON Oil Company Well Name: KENAI UNIT 21 -6 T Ops ! Trouble Start Time I End Time Dur (hrs) Ops Code I Activity Code V Status � Code Comment 12:57 13:33 0.60 BAIL FILL AF RIH(4) w/ 2 -1/4" DD bailer w/ circular bottom. Tag fill @ 5256 KB. POOH. OOH. Full bailer. Recover 1 gal dry gray sand. 13:33 14:06 0.55 BAIL FILL AF RIH(5) w/ 2 -1/4" DD bailer w/ circular bottom. Tag fill © 5259' KB. POOH. OOH. 7/8 full bailer. Recover 3 quarts. Mostly sand w/ a quart of slurry. PU 2 -1/2" DD bailer 5' long. 14:06 14:48 0.70 BAIL FILL AF RIH(6) w/ 2 -1/2" DD bailer w/ circular bottom. Tag fill @ 5252' KB. Work down to 5259'. POOH. OOH. Bailer 213 full. Recover 3 quarts mostly sand and some clay. 14:48 15:24 0.60 BAIL FILL AF RIH(7) w/ 2 -1/2" DD bailer w/ circular bottom. Tag fill @ 5261' KB. POOH. OOH. Recover 3 quarts sandy gray solids. PU 2 -1/4" bailer. 15:24 16:03 0.65 BAIL FILL AF RIH(8) w/ 2 -1/4" DD bailer w/ circular bottom Tag fill @ 5261' KB. POOH. OOH. Recover 2 quarts thick "soupy" gray slurry. . 16:03 16:45 0.70 BAIL FILL AF RIH(9) w/ 2 -1/4" DD bailer w/ circular bottom Tag fill @ 5264' KB. POOH. OOH. Recover 2 quarts thick "soupy" gray slurry. 16:45 17:27 0.70 BAIL FILL AF RIH(10) w/ 2" Pump bailer w/ mule shoe. Tag fill @ 5266' KB. POOH. OOH. Recover 2 quarts thick "soupy" gray slurry. 17:27 18:12 0.75 RURD SLIK AF OOH. Bleed down lubricator. RD for the night. 18:12 18:27 0.25 SECURE WELL AF Close all valves of WH. PTest tree cap. Test good. Secure well. Notify operator we have finished. Turn in Permit. Sign out. Leave location. Daily Operations Report Date: 3/11/2009 Job Category: WORKOVER 24 Hr Summary MIRU Pollard slickline unit to bail fill from 5266' to 5270' KB. Recover 5 gallons of sand and clay. It appears that csg is collapsed inward to less than 2" ID @ 5270'. Suspend operations. Ops Trouble Start Time End Time Dur (hrs) Ops Code Activity Code Status Code Comment 07:30 07:45 0.25 SAFETY MTG Hold site SimOps SM w/ crews on 34 -31 pad. Discuss simultaneous work on this pad. Discuss alarms, muster area, and emergency response. Obtain SWP. 07:45 08:15 0.50 SAFETY AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss Pollard JSA and make job assignments. 08:15 08:45 0.50 RURD SLIK AF Spot mast truck. Cut 20' of wire. Re -head line and change packing. PU lubricator. MU tool string- rs, kj, 1 -3/4" x 10' stem, kj, oj, Issj, kj, 3" x 3' DD Bailer. 08:45 09:09 0.40 TEST EQIP AF Carry lubricator to WH. Test lubricator to 1000 psi. Test good. Wing valves and upper master valve closed. 09:09 10:03 0.90 BAIL FILL AF RIH(1) w/ 3" DD bailer w/ mule shoe bottom. Tag fill @ 5268' KB. POOH. OOH. Full bailer. Recover 1 gal. gray sand slurry. 10 :03 10:45 0.70 BAIL FILL 'AF RIH(2) w/ 3" DD bailer w/ mule shoe bottom. Tag fill @ 5268' KB. POOH. OOH. Recover 2 quarts gray sand slurry. 10:45 11:33 0.80 BAIL FILL AF RIH(3) w/ 3" DD bailer w/ mule shoe bottom. Tag fill @ 5270' KB. POOH. OOH. Recover 2 quarts gray sand slurry. PU 2 -1/2" DD bailer w/ flat bottom. 11:33 12:09 0.60 BAIL FILL AF RIH(4) w/ 2 -1/2" DD bailer w/ flat bottom. Tag fill @ 5269' KB. POOH. OOH. Full bailer. Recover 3 quarts gray sand slurry. 12:09 12:42 0.55 BAIL FILL AF RIH(5) w/ 2 -1/2" DD bailer w/ circular bottom. Tag fill @ 5269' KB. POOH. OOH. Recover 3 quarts. Mostly sand w/ 3 quarts of slurry. Bottoms of bailers continue to come back w/ scares and metal marks on outer edges. PU 2.80" LIB. 12:42 13 :24 0.70 BAIL FILL AF RIH(6) w/ 2.80" LIB. Tag @ 5269' KB. Tap down once and POOH. OOH. LIB has inprint of a smooth edge. The side of LIB is very torn up. Appears that the 4 -1/2" csg in collapsed to less than 2 -3/8 ". www.peloton.com Page 7/8 Report Printed: 3/1/2011 AA Marathon OSations Summary Report by Job • NuRanoor Oil Company Well Name: KENAI UNIT 21 -6 Ops Trouble Start Time End Time Dur (hrs) Ops Code Activity Code Status Code Comment 13:24 14:00 0.60 BAIL FILL AF RIH(7) w/ 1 -3/4" DD bailer w/ flat bottom. Tag fill @ 5270' KB. POOH. OOH. Recover 1quart sandy gray solids. PU 2 -1/4" bailer. 14:00 14:39 0.65 BAIL FILL AF RIH(8) w/ 2 -1/4" DD bailer w/ circular bottom Tag fill @ 5271' KB. POOH. OOH. Recover 1 quart thick "soupy" gray slurry. 14:39 15:21 0.70 BAIL FILL AF RIH(9) w/ 2 -1/4" DD bailer w/ circular bottom Tag fill @ 5271' KB. POOH. OOH. Recover 1 quart thick "soupy" gray slurry. Not making hole. Still seeing metal marks on outer edges of bailer. PU 2" LIB. 15:21 16:03 0.70 BAIL FILL AF RIH(10) w/ 2" LIB. Tap down once. POOH. LIB has damage to outer edge in two places. Each about an inch long. Indicates evidence of further pinching in of the csg. Decision was made to shut down operation and shut down. 16:03 16:54 0.85 RURD SLIK AF OOH. Bleed down lubricator. RD S/L unit. 16:54 17 :09 0.25 SECURE WELL AF Close all valves of WH. PTest tree cap. Test good. Secure well. Notify operator we have finished. Turn in Permit. Sign out. Leave location. www.peloton.com Page 8/8 Report Printed: 3/1/2011 Marathon Cations Summary Report by Job • atxoK O ilCompany W Name: KENAI UNIT 21 -6 ituta Qtr /Qtr, Block, Sec, Town, Range Field Name 'License No. State /Province Country 6031005N011 W01 KENAI ALASKA USA Daily Operations Report Date: 12/22/2010 Job Ca gory_ R &M MAINTENANCE 24 Hr Summary MIRU Pollard W/L to bail fill and possibly fish out 2 -3/8" V string hanger pack off rings, Possible fish include V string hanger packing element rings(3) and four split rings and four aluminum plugs from 2 -3/8" and 1 -3/4" V string BHA's. Bailed fill from 5284' KB to 5294' KB. Ops Trouble Start Time End Time Dur (hrs) Ops Code Activity Code Status Code I Comment 07:30 08:06 0.60 SAFETY MTG Hold PJSM. Discuss emergency response, alarms -red flashing strobe for fire alarm, blue flashing strobe for gas alarm, muster area, wind direction, and specific job hazards. Obtain SW Permit. 08:06 10:30 2.40 RURD SLIK Spot equipment. Set fight plant. Start man lift. MU 4 -1/2 lubricator and install on WH. Rehead line. MU tool string- RS, KJ, 1 -3/4" x 10' stem, KJ, OJ, LSSJ, KJ, 1 -3/4" X 3' stem, 3" DD bailer. 10:30 11:00 0.50 TEST EQIP PT lubricator to 500 psi. Test good. 11:00 12:00 1.00 RUNPUL SLIK RIH (1) w/ 3" DD Bailer to 5284' KB. Work tools to 5287'. POOH. OOH. Recover full bailer of water and some sand and grit. 12:00 13:06 1.10 RUNPUL SLIK RIH (2) w/ 3" DD Bailer to 5287' KB. Work tools to 5290'. POOH. OOH. Recover bailer full of water and sand sl;urry. 13:06 14:12 1.10 RUNPUL SLIK RIH (3) w/ 2" DD Bailer to 5290' KB. Work tools to 5293'. POOH. OOH. Recover 1/2 bailer full of hard sand w/ water 14:12 15:18 1.10 RUNPUL SLIK RIH (4) w/ 2" DD Bailer to 5293' KB. Work tools to 5294'. POOH. OOH. Recover 1/2 bailer full of hard sand w/ water 15:18 16:18 1.00 RUNPUL SLIK RIH (5) w/ 3" DD Bailer to 5292' KB. Work tools to 5294'. POOH. OOH. Recover 1/2 bailer full of hard sand w/ water 16:18 17:03 0.75 RURD SLIK RD slickline unit for the night. Install night cap. PT cap. Test good. 17:03 17:18 0.25 SECURE WELL Secure well head. Turn in permit and sign out. Leave loc. Report Date: 12123/2010 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Pollard W/L to bail fill and possibly fish out 2 -3/8" V string hanger pack off rings. Possible fish include V string hanger packing element rings(3) and four split rings and four aluminum plugs from 2 -3/8" and 1 -3/4" V string BHA's. Bailed fill from 5293' KB. to 5308' KB. Ops Trouble Start Time End Time Dur (hrs) Ops Code Activity Code Status Code Comment 07:30 08:00 0.50 SAFETY MTG Hold PJSM. Discuss emergency response, alarms -red flashing strobe for fire alarm, blue flashing strobe for gas alarm, muster area, wind direction, and specific job hazards. Obtain SW Permit. 08:00 08:30 0.50 RURD SLIK Start man lift and light pliant. Start equipment. MU tool string- RS, KJ, 2.30" x 5' stem, 2 -1/8" x 9' stem, KJ, OJ, LSSJ, 1 -3/4 " X 3' stem, 3" DD bailer. 08:30 08:45 0.25 TEST EQIP PT lubricator to 500 psi. Test good. 08:45 09:45 1.00 RUNPUL SLIK RIH (1) w/ 3" DD bailer. Tag @ 5293' KB. Work tools. POOH. OOH. Recover 1/2 bailer full of sand, the rest water. 09:45 10:15 0.50 RUNPUL SLIK RIH (2) w/ 2 -1/4" DD bailer. Tag @ 5293' KB. Work tools to 5295' KB. POOH. OOH bailer empty. Switch from flapper syle bottom to a ball check. 10:15 11:00 0.75 RUNPUL SLIK RIH (3) w/ 2 -1/4" DD bailer w/ ball check bottom. Tag @ 5295' KB. Work tools to 5296' KB. POOH. OOH. Recover full bailer of sand and slurry. 11:00 12:00 1.00 RUNPUL SLIK RIH (4) w/ 2 -1/2" DD bailer w/ ball check bottom. Tag @ 5297' KB. Work to 5299' KB. POOH. OOH. Recover 3/4 bailer full of sand and slurry. 12:00 13:00 1.00 RUNPUL SLIK RIH (5) w/ 2 -1/2" DD bailer w/ ball check bottom. Tag @ 5299' KB. Work tools to 5300' KB. POOH. OOH. Recover 3/4 of bailer full of sand and slurry. 13:00 14:00 1.00 RUNPUL SLIK RIH (6) w/ 2 -1/2" DD bailer w/ ball check bottom. Tag @ 5299' KB. Bridge fell in on us. Work tools to 5300' KB. POOH. OOH. Recover full bailer of sand and slurry. 14:00 15:00 1.00 RUNPUL SLIK RIH (7) w/ 2 -1/2" DD bailer w/ ball check bottom. Tag @ 5200' KB. Work tools to 5302' KB. POOH. OOH. Recover full bailer of sand and slurry. 15:00 16:00 1.00 RUNPUL SLIK RIH (8) w/ 2 -1/2" DD bailer w/ ball check bottom. Tag @ 5202' KB. Work tools to 5304' KB. POOH. OOH. Recover full bailer of sand and slurry. 16:00 16:36 0.60 RUNPUL SLIK RIH (9) w/ 2 -1/2" DD bailer w/ ball check bottom. Tag @ 5204' KB. Work tools to 5308' KB. POOH. OOH. Recover full bailer of sand and slurry. 16:36 17:06 0.50 RURD SLIK Lay down lubricator for the night. Plug in equipment. Install night cap. PT night cap. Test good. 17:06 17:21 0.25 SECURE WELL Close all valves on the tree. Secure well and location for the night. Turn in permit. Sign out and leave loc. www.pefoton.com Page 1/4 Report Printed: 3/1/2011 M Marathon Ofations Summary Report by Job • Nuttatxoa 6 OiICompany Well Name: KENAI UNIT 21 -6 Casing Flange Elevation (ft) Ground Elevation (ft) KB- Casing Flange Distance (ft) KB- Ground Distance (ft) Spud Date 'Rig Release Date 0.00 59.00 80.00 21.00 8/22/2001 f Daily Operations Report Date: 12/24/2010 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Pollard W/L to bail fill and possibly fish out 2 -3/8" V string hanger pack off rings. Possible fish include V string hanger packing element rings(3) and four split rings and four aluminum plugs from 2 -3/8" and 1 -3/4" V string BHA's. Bailed fill from 5303' KB to 5308' KB. Solids seem to be falling in on us. Ops Trouble Start Time End Time Dur (hrs) Ops Code Activity Code Status Code Comment 07:30 08:00 0.50 SAFETY MTG Hold PJSM. Discuss emergency response, alarms -red flashing strobe for fire alarm, blue flashing strobe for gas alarm, muster area, wind direction, and specific job hazards. Obtain SW Permit. 08:00 08:18 0.30 RURD SLIK Start man lift and light pilant. Start equipment. MU tool string- RS, KJ, 2.30" x 5' stem, 2 -1/8" x 9' stem, KJ, OJ, LSSJ, 1 -3/4 " X 3' stem, 2 -1/2" DD bailer w/ ball check bottom. 08:18 - - -- - — 8 08:30 0.20 TEST EQIP PTest lubricatoro to 500 si. Test good. P 9 08 :30 09:15 0.75 RUNPUL SLIK RIH (1) w. 2 -1/2" DD bailer. Tag @ 5303' kb. Work tools to 5305' kb. POOH. OOH. Recover bailer full of thick sand slurry) 09:15 10:09 0.90 RUNPUL SLIK RIH (2) w. 2 -1/2" DD bailer. Tag @ 5304 kb. Work tools to 5305' kb. POOH. OOH. Recover bailer full of very thick sand slurryl 10:09 11:15 1.10 RUNPUL SLIK RIH (3) w. 2 -1/2" DD bailer. Tag 5304 kb. Work tools to 5305' kb. 9@ POOH. OOH. Recover 1/2 bailer full o packed and 1/2 full very thick sand slurry) ry 11:15 12:03 0.80 RUNPUL SLIK RIH (4) w. 2 -1/2" DD bailer. Tag @ 5306 kb. Work tools to 5308' kb. POOH. OOH. Recover 1/2 bailer full o acked and 1/2 full very thick sand slurryl slur p ry 12:03 12:57 0.90 RUNPUL SLIK RIH (5) w. 2 -1/2" DD bailer. Tag @ 5307 kb. Work tools to 5309' kb. POOH. OOH. Recover full bailer of packed sand.. 12:57 14:09 1.20 RUNPUL SLIK RIH (6) w. 2 -1/2" DD bailer. Tag @ 5308 kb. Work tools to 5309' kb. POOH. OOH. Recover full bailer of packed sand.. 1 1 I 14:09 15:09 1.00 RUNPUL SLIK RIH (7) w. 2 -1/2" DD bailer. Tag @ 5308 kb. Work tools to 5309' kb. POOH. OOH. Recover full bailer of packed sand.. 15:09 16:09 1.00 RURD SLIK RD unit for Tuesday. Re -head line and repack stuffing box. Night cap. PT night cap. Test good. 16:09 16:24 0.25 SECURE WELL Secure well. Secure location. Turn in permit. Siign out and leave loc. Report Date: 12/29/2010 Job Cate•o : R &M MAINTENANCE 24 Hr Summary MIRU Pollard W/L to bail fill and possibly fish out 2 -3/8" V string hanger pack off rings. Possible fish include V string hanger packing element rings(3) and four split rings and four aluminum plugs from 2 -3/8" and 1 -3/4" V string BHA's. Bailed fill from 5310' to 5314' kb. Recover one 1/2" "split ring" from the 2 -3/8" V string hanger that was lost in July of 2007. Pressure test 4 -1/2" annulus to 1500 psi for 30 min. Test good. Ops Trouble Start Time End Time Dur (hrs) Ops Code Activity Code Status Code Comment 07:30 08:15 0.75 SAFETY MTG Hold PJSM. Discuss emergency response, alarms -red flashing strobe for fire alarm, blue flashing strobe for gas alarm, muster area, wind direction, and specific job hazards. Obtain SW Permit. 08:15 09:00 0.75 RURD SLIK Start man lift and light pilant. Start equipment. MU tool string- RS, KJ, 2.30" x 5' stem, 2 -1/8" x 9' stem, KJ, OJ, LSSJ, 1 -3/4 " X 3' stem, 2 -1/2" DD bailer w/ ball check bottom. 09:00 09:12 0.20 TEST EQIP PTest lubricator to 500 psi. 09:12 09:57 0.75 RUNPUL SLIK RIH (1) w. 2 -1/2" DD bailer. Counter stopped working. POOH. OOH. Recover bailer full of thick sand slurry! 09:57 10:57 1.00 RUNPUI : SLIK RIH (2) w. 2 -1/2" DD bailer. Tag @ 5310' kb. Work tools to 5312' kb. POOH. OOH. Recover bailer full of thick sand slurry! 10:57 11:27 0.50 TEST TBG PTest 4 -1/2" X 7 -5/8" annulus to 1500 psi Time Pressure Comments 10:00 50 psi Annulus was full and had 50 psi. 10:05 1500 psi Pressured up with 32 gals 50/50 MEOH 10:15 1500 psi Holding pressure 10:25 1500 psi Holding 10:35 1500 psi Holding 10:40 500 psi Released pressure to 500 psi. 11:27 11:57 0.50 RUNPUL SLIK RIH (3) w. 2 -1/2" DD bailer. Tag @ 5311' kb. Work tools to 5312' kb. POOH. OOH. Recover bailer full of thick sand slurry w/ small sand plug. 11:57 12:57 1.00 RUNPUL SLIK RIH (4) w. 2 -1/2" DD bailer. Tag @ 5312' kb. Work tools to 5313' kb. POOH. OOH. Recover bailer full of soupy sand slurry) www.peioton.com Page 2/4 Report Printed: 3/1/2011 M Marathon O tions Summary Report by Job OilCompany Well Name: KENAI UNIT 21 -6 Ops i Trouble - - -.. --- -- -- - -- Start Time End Time Dur (hrs) Ops Code ! Activity Code Status Code Comment 12:57 13:57 1.00 RUNPUL SLIK RIH (5) w. 2 -1/2" DD bailer. Tag @ 5311' kb. Work tools to 5314' kb. POOH. OOH. Recover bailer full of soupy sand slurry) 13:57 14:45 0.80 RUNPUL SLIK RIH (6) w. 2 -1/4" DD bailer. Tag @ 5313' kb. Work tools to 5314' kb. POOH. OOH. Recover bailer full of soupy sand slurry. Metal marks on bailer bottom. Possible fish. Elect to run magnet. 14:45 15:33 0.80 RUNPUL SLIK RIH (7) w/ 2 -1/4" magnet. Tag © 5313' kb. Tap down twice. POOH. OOH. NO recovery. 15:33 16:33 1.00 RUNPUL SLIK RIH (8) w. 3" DD bailer. Tag @ 5306' kb. Work tools. Cann't get below 5306' kb. POOH. OOH. Recover bailer full of soupy sand slurry. Recover one "C" ring packer element. Mule shoe bailer bottom has metal marks and has been deformed. It is now egg shaped 16:33 17:03 0.50 RURD SLIK RD unit for the night. 17:03 17:18 0.25 SECURE WELL Close all valves and secure the well. Secure location. Turn in permit. Sign out and leave loc. Daily Operations Report Date: 12/30/2010 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Pollard W/L to bail fill and possibly fish out 2 -3/8" V string hanger pack off rings. Possible fish include V string hanger packing element rings(3) and four split rings and four aluminum plugs from 2 -3/8" and 1 -3/4" V string BHA's. Fishing for metal rings. None recovered today. Ops Trouble Start Time End Time Dur (hrs) Ops Code Activity Code Status Code Comment 07:30 08:00 0.50 SAFETY MTG Hold PJSM. Discuss emergency response, alarms -red flashing strobe for fire alarm, blue flashing strobe for gas alarm, muster area, wind direction, and specific job hazards. Obtain SW Permit. 08:00 08:18 0.30 RURD SLIK Start man lift and light pliant. Start equipment. MU tool string- RS, KJ, 2.30" x 5' stem, 2 -1/8" x 9' stem, KJ, OJ, LSSJ, 1 -3/4 " X 3' stem, 3 prong wire grab. 08:18 08:30 0.20 TEST EQIP PTest lubricator to 500 psi. 08:30 09:00 0.50 RUNPUL SLIK RIH (1) w/ 3.28" three prong wire grab. Tag @ 5283' kb. Work tools but cann't get below 5283'. POOH. OOH. NO recovery. 09:00 10:00 1.00 RUNPUL SLIK RIH (2) w/ wire grab spear to 5312' kb. Work tools. POOH. OOH. Nothing caught on spear. 10:00 11:24 1.40 RUNPUL SLIK RIH (3) w/ 3" DD bailer w/ muleshoe bottom. Tag @ 5305' kb. Work tools. Sticky. Having to jar free. POOH. OOH. 11:24 12:24 1.00 RUNPUL SLIK RIH (4) w/ 4 prong wire grab. Tag @ 5307' kb. Work tools but cann't get below 5307' kb. POOH. OOH. 12:24 13:15 0.85 RURD SLIK Having line problems. Repack stuffing box. Re -head line. 13:15 14:15 1.00 RUNPUL SLIK RIH (5) w/ 2 -1/4" magnet. Tag @ 5313' kb. Slowly work tools from 5300' to TD. POOH. OOH. 14:15 15:45 1.50 RUNPUL SLIK RIH (6) w/ 3" DD bailer w/ muleshoe "clocked" to the low side. Tag @ 5308' kb. Work tools. Sticky. Having to spang and jar free. POOH. OOH. 15:45 16:45 1.00 RUNPUL SLIK RIH (7) w/ 2 -1/4" DD bailer w/ flat bottom. Tag @ 5313' kb. Work tools to 5314' kb. Sticky. POOH. OOH. Recover full bailer of very solid clay. 16:45 17:15 0.50 RURD SLIK RD unit for the night. Install night cap w/ well pressure tp 135 psi. 17:15 17:30 0.25 SECURE WELL Close all tree valves. Secure location. Turn in permit. Sign out and leave loc. Report Date: 12/31/2010 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Pollard W/L to bail fill and possibly fish out 2 -3/8" V string hanger pack off rings. Possible fish include V string hanger packing element rings(3) and four split rings and four aluminum plugs from 2 -3/8" and 1 -3/4" V string BHA's. Bail from 5313' to 5326' kb. Bottom pert 5310' kb. Tight spot in the casing 5306'- 5310' kb. Final SITP 145 psi. Ops Trouble Start Time End. Time Dur (hrs) Ops Code Activity Code Status Code Comment 07:30 08:00 0.50 SAFETY MTG Hold PJSM. Discuss emergency response, alarms -red flashing strobe for fire alarm, blue flashing strobe for gas alarm, muster area, wind direction, and specific job hazards. Obtain SW Permit. 08:00 08:12 0.20 PREP LOC Shovel snow and prepare work area. Spread sand for traction. 08:12 08:27 0.25 RURD SLIK Start man lift and light pliant. Start equipment. MU tool string- RS, KJ, 2.30" x 5' stem, 2 -1/8" x 9' stem, KJ, OJ, LSSJ, 1 -3/4 " X 3' stem, 2 -1/4" DD bailer w/ flat bottom and flapper. - 08:27 08:39 0.20 TEST EQIP PTest lubricator to 500 psi: Test good. www.peloton.com Page 3/4 Report Printed: 3/1/2011 • �-A Marathon Oations Summary Report by Jo Job It AZ= Oil any Well Name: KENAI UNIT 21 -6 Ops Trouble Start Time End Time Dur (hrs) Ops Code j Activity Code Status Code Comment 08:39 09:33 0.90 BAIL FILL RIH (1) w/ 2 -1/4" DD bailer w/ flat bottom and flapper. Tag @ 5313' kb. Work tools to 5315'. POOH. OOH. Recover full bailer of dry sand and clay. 09:33 10:33 1.00 BAIL ALL RIH (2) w/ 2 -1/2" DD bailer w/ flat bottom and flapper. Tag @ 5310' kb. Work tools to 5317'. POOH. OOH. Recover full bailer of dry sand and clay. 10:33 11:33 1.00 BAIL FILL RIH (3) w/ 2 -1/2" DD bailer w/ flat bottom and flapper. Tag @ 5318 kb. Work tools. Tight spot in casing 5306' to 5310'( 2 -1/2" bailer will pass but not 3 "). POOH. OOH. Recover full bailer of dry sand and clay. 11:33 12:33 1.00 BAIL FILL RIH (4) w/ 2 -1/2" DD bailer w/ flat bottom and flapper. Tag @ 5318' kb. Work tools to 5321'. POOH. OOH. Recover full bailer of sand and slurry. 12:33 12:48 0.25 REPAIR EQIP — Shut down to grease Swab and upper master valves. Tighten stem packing on 4 -1/2" annulus valve. 12:48 13:48 1.00 BAIL FILL RIH (5) w/ 2 -1/2" DD bailer w/ flat bottom and flapper. Tag @ 5321 kb. Work tools to 5326'. POOH. OOH. Recover full bailer of sand and sand slurry. 13:48 14:36 0.80 RUNPUL SLIK RIH (6) w/ 4" braided line brush to 5326' kb. Work brush thru perfs. 14:36 15:21 0.75 RIH (7) w/ 2 -1/4" magnet on a 2.86" fluted centralizer. Set down @ 5306' kb. Couldn't get below. POOH. 15:21 16:21 1.00 RURD SLIK 16:21 16:36 0.25 SECURE WELL www.peloton.com Page 4/4 Report Printed: 3/1/2011 7 KU 21 -6RD Conversion to Gas Injection- Production Notice Page 1 of 2 Maunder, Thomas E (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, March 01, 2011 12:54 PM To: Maunder, Thomas E (DOA) Subject: FW: KU 21-6RD Conversion and Storage Plan of Operations Update for LOCI 06 -001 Attachments: KGF Pad 34 -31 As- Built.pdf; Kenai Gas Storage - Final CD.pdf Tom, ( 'l you aware of oe 1 Steve D. vs itt i tip MAR (1 5 'at From: Havelock, Brian E (DNR) Sent: Tuesday, March 01, 2011 12:44 PM To: Skiba, Kevin J.; Brudie, Nina M (DNR) Cc: gwilliams @borough.kenai.ak.us; Ostrovsky, Larry Z (DNR); Sonnier - Laden, Angela 3 (DNR); Frazier, Jeanne M (DNR); Blanche, Paul M (DFG); Snow, Candice S (DNR); Plett, Kristina A (DNR); DNR, Parks OHA Review Compliance (DNR sponsored); Davies, Stephen F (DOA); Litchfield, Virginia P (DFG); Palmer, Sean P (DEC); Roche, Frances E (DEC); Russell, Pamela 3 (DNR); Walton, Michael L (DNR); Buzby, Bruce 3 (DNR); Chambon, Katrina M (DNR) Subject: RE: KU 21 -6RD Conversion and Storage Plan of Operations Update for LOCI 06 -001 All c ` C7G See email thread below plan update from Marathon for on -pad work on an existing facility (KU 34 -31 Pad) at the federally managed Kenai gas field. See also attached As -Built highlighting the well location in question, and the 2006 Final ACMP consistency determination for the original project. The Division approved the project to store natural gas underground in the Kenai Sterling 6 Pool (DOG permit #LOCI 06 -001) on May 8, 2006. This activity falls within the scope of the original project to store natural gas at Pool 6. The Division does not foresee any additional impacts to a coastal use or resource, and finds this activity is within the scope of the original authorization, consistent with 11 AAC 110.820(k). Confidential portions of the update have been removed per AS 38.05.035(a). If you have any questions, call me at the number below or Bruce Buzby at 907 - 269 -8801. Brian PS. I will be out of the office from March 3 -15 on spring break. Brian Havelock Division of Oil & Gas, Permitting Section Alaska Department of Natural Resources 550 W 7th Ave. Suite 800 Anchorage. Alaska 99501 Ph: direct 907- 269 - 8807 /main office 907- 269 -8800 From: Skiba, Kevin J. [mailto:kskiba @marathonoil.com] Sent: Monday, February 21, 2011 1:37 PM To: Havelock, Brian E (DNR) 3/1/2011 KU 21 -6RD Conversion to Gas Injection- Production Notice Page 2 of 2 • Subject: KU 21 -6RD Conversion to Gas Injection - Production Notice «KU 21-6RD Injection Conversion Information 2011.zip» Brian, Marathon Oil is requesting an amendment to the Pool -6 Storage Lease Plan of Development. With an increased need for gas storage, Marathon proposes to convert KU 21 -6RD from a production well to an injection- production well. KU 21 -6RD is a Sterling Pool -6 production well, located on Kenai Gas Field Pad 34 -31, and requires no additional wellbore modifications. The scope of this project involves redeploying one of KU 21 -6RD's current production flow lines. The original KU 21 -6RD, (KU 21 -6), was one of the early Sterling Pool - 6 wells. It was spud in May of 1965 and was equipped with three flow lines to handle the Sterling formation capabilities of that time. We intend to convert one of these existing flow lines to an injection line. The minimal piping modifications required for this project will all be made above ground resulting in no surface disturbance. This project requires approval from the AOGCC and the BLM. Please advise me if the DNR also needs to approve this project before we can proceed. Attached is an As -Built of the KGF Pad 34 -31 along with three draft diagrams depicting the proposed piping modifications. I can be contacted at the numbers listed below if you have any questions or require additional information. Thanks again, Kevin Skiba Regulatory Compliance Representative Marathon Alaska Production LLC Office (907) 283 -1371 Cell (907) 394 -1880 Fax (907) 283 -1350 3/1/2011 • 1 SOLE 200 .° avQ-� KU 22-6X AS BUILT WEL 1 0 °. ° ,/ (12" DIA. CONDUCTOR) FEET 1 G��•% 'c,:,9 NAD83 ASP ZONE 4 B 13 \ ' oQ`. N:2367932.367 o m .../ / E:1410822.780 0 `m 0 �' LAT: 60 °28'32.052" N NORTH / LONG: 151 °16'21.417" W Mw , ^-• / • - CAUTION' ELEV. 59 FT. (MSL) KDU 61 ®I v 1833' FEL • • —.0 / HIGH PRESSURE 1833' FEL N= 2367955.851. , 1. / ('j / LATERAL GAB E= 1410913.53 / PIPELINE 70 A.P.L. 825' FSL q _ , METAL CONTAINMENT AREA r DRUM STORAGE ENCLOSURE �� {, AND TANK / _ BLDG. 16.1x30.3' , / ` KDU 14 -32 1 ..J f COMPRE l } � - SSOR < N= 2367846.19 1 Q 1 • . BUILDING E=141089723 ® , 0 REBOILE - ' «e MW #11 4, WASTE • BUILDING ® MW 013 0 WATER `' 1 1-- / TANK WATER BUILDING WASTE O.H. PIPES - .,,,.....^-, TBM ELEV. # 7 . ^, 0 1.1 58.63' 1 O ICONTACTOR— / ■ BL i p � rt 4 �® 1 Z • KDU 5 WO OVER MV �{f2 1 f TYPICAL ... : N= 23 6779733 Mi / #6 BLDG. Y,� Z Ji PIPE E= 1410933.67 A Mwp1 ! J / M4Wi�! O.H. PNV id / M W' i � - -�S PPD'' POOL 6 Z 1 • TANKS , t .,•• - r ! +��) 10.3X20.8 O e „! ENVIROMENTAL 1 2AND3 METER ❑ F y q � VALVE PIT BUILDING I V so M. • W F ,, r. ILDIN , Q 14.3 ' X18 2'L7MW#1 WELL E" el 1 W W.D. NO.1 No � - WASTE WASTE I WATER 4 MW#5 Mw#4 ❑ i' BLDG. STORAGE l INJECTION CONTROL BUILDING MW #1 • EMERGENCY BUILDING 8.7 'X12.5' I.R. BLOWDOWN N 2367723.71 GENERATOR TOP EDGE PAD (APPROX. E 1410357.01 14.4' X 20.4' LOCATION) KU 34-31 / ' • 10'X10' WELL HOUSE K 21-06 / n ../ • * 1.I. H.N ) N= 236763920 N • STORAGE = 2367627.47 / 1 in (Cr-L4sts -- 1, --A--... I BUILDING E= 1410522.41 E= 1410564.11 J " • 1 (y 12'x 24' , CO • " • - . RGF PAD 34 -31 - �,��� KU 11-6 BALL FIELD �`�N I OF A4 ' `' 1010' 'X WELL I AND OUTFIELD FENCE' g + FLAGPOLE E= 1410560.46 �i • + P� • • ' • , , i L 7 , � •..- N - •' *y `' 49I t(% '• *�� • SHOP CONTROL ,. / ' �•+� / ,.0), ...... ., 714* ......„ -` ROOM OFFICE w , �_L �j�- 1 L� �/ .:.,. „....,_ 0L- COMM. Ylf D o ' • M. SCOTT MCLANE _ AI 0 E TOWER � 928- i 1) OPUS SOLUTION FROM CONTROL GS COORDINATES STATIONS1 EH1 CORS ARP, „ ' ikIN1I/b. • TEA ANCHORAGE CORS ARP”, AND •ZAN1 ANCHORAGE WAAS 1 CORS ARP TO ESTABUSH THE POSRION OF KGF1. THE GEODETIC POSITION OF KGFI ' WAS DETERMINED TO HAVE A LATITUDE OF 6018'41.15256'N AND A LONGITUDE OF 151 THE ALASKA STATE PLANE COORDINATES • , (ASP) ZONE F 4 ARE: Nw236879 IS 4.183 E= 1414074.562 EL 61.63' (MSL) 2) BASIS O VE D MEAN SEA LEVEL OCAL DA TUM ) 81 3) SOUTHEAST CORNER SEC. 31 COORDINATES DETERMINED FROM DRECT 1) i•• SURVEY TIE TO THE TO EXISTIIIG BLM SECTION CORNER RECOVERED AND ( NOT THE PROTRACTED SECTION CORNER VALUES. • SECTION 31, TSN, R11 W, S.M., AK • N 2367073.132 SECTION LINE 71 1 NOT TO SCALE E 1412641.8S3 MARATHON PROJEcT REVS _ M DAZE: 10-0608 OIL COMPANY KU 22-6X WELL ON KGF PAD 34 -31 DRAMSY: Nail • ALASKA NEM AS -BUILT SURFACE LOCATION DIAGRAM SCALE: 1'*1O' PROJECT NO. 083063 ENGINEERING IMAPPINO 'SURVEYING ( TESTING 1110010.0. 0803 Consult' Inc P.O. BOX 488 BOLOOTNA AK 00000 LOCATION SHEET " EMAIL: SALANE.®A� . MC S31 T5N R11 W SEWARD MERIDIAN, ALASKA 1 OF 1 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, March 01, 2011 4:46 PM To: 'Skiba, Kevin J.' Cc: Aubert, Winton G (DOA) Subject: RE: KU 21 -06RD (201 -097) Thanks Kevin. The documents that need to be submitted are 10 -404 plus attachments. Tom Maunder, PE AOGCC From: Skiba, Kevin J. [mailto:kskiba @marathonoil.com] Sent: Tuesday, March 01, 2011 3:37 PM To: Maunder, Thomas E (DOA) Cc: Aubert, Winton G (DOA) Subject: RE: KU 21 -06RD (201 -097) 5,4140/ED WAR 0 2 1U11 Tom, Work was placed on hold after the tie -back tubing was installed in this well. A tag indicated that the well had fill in it above the perforation target. Bailing attempts were unsuccessful with indications of metal in the well. We believed that the well had experienced some form of casing damage. Work on the well was placed on hold until we could better determine the extent on the damage. We were recently notified, by one of our venders, that some metal rings from there down -hole equipment had fallen off while they were on the well. We recently re- established bailing activities and successfully retrieved the missing components while cleaning out the wellbore. Marathon has decided to forgo adding the additional perforations that were approved in Sundry #308 -368. With this decision, I will close out this activity with a 10 -403. Thank you for your help, Kevin Skiba Regulatory Compliance Representative Marathon Alaska Production LLC Office (907) 283 -1371 Cell (907) 394 -1880 Fax (907) 283 -1350 From: Maunder, Thomas E (DOA) [mailto:tom.maunder©alaska.gov] Sent: Tuesday, March 01, 2011 2:43 PM To: Skiba, Kevin J. Cc: Aubert, Winton G (DOA) Subject: KU 21 -06RD (201 -097) Kevin, I was just forwarded some project information regarding the conversion project for this well. I spoke to Winton and he indicated that the sundry had been approved. I was just checking the file. A sundry 308 -368 to workover and re- perforate the well was approved 10/20/2008. I don't find a 404 and operations summary in the file. Could you check and see if that was filed? Thanks in advance. Tom Maunder, PE AOGCC 3/2/2011 t • • TrETE gy, ELAEKKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Kevin J. Skiba Regulatory Compliance Representative Q I Marathon Alaska Production, LLC P.O. Box 1949 Kenai, AK 99611 -1949 Re: Kenai Gas Field, Sterling Pool, Kenai Unit 21 -6RD Sundry Number: 311 -046 AliatifieD F R3 2 5 2011 Dear Mr. Skiba: 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 rovided in AS 31.05.080, within 20 days after written notice of this p � Y decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission 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, Ai* Daniel T. Seamount, Jr. Chair � f DATED this 2.4 day of February, 2011. Encl. • MaraZTfon Alaska Production LLC Alaska Asset Team Marathon P.O. Box 1949 MARATHON Alaska Productian LLC Kenai, AK 99611 Telephone 907/283 -1371 Fax 907/283 -1350 February 18, 2011 RECEIVED FEB 2 Z 011 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission M & Ges Cow Comm 333 W 7 Ave Anchong Anchorage, Alaska 99501 Reference: 10 -403 Application for Sundry Approvals Field: Kenai Gas Field Well: Kenai Unit 21 -6RD Dear Mr. Aubert: Enclosed please find the 10 -403 Sundry Application to permit KU 21 -06RD as a Sterling Gas Pool 6 gas injector and producer, consistent with Storage Injection Order No. 7a — (henceforth referred to as SIO 7a). The well is currently completed to Sterling Gas Pool - 6 and is classified as a producer (referenced in the current KU 21 -06RD welibore schematic attachment). No downhole wellwork is required to convert KU 21 -06RD to production /injection. With approval, Marathon will reconfigure the surface system for injection and production metering (referenced in KU 21 -06RD surface injection and production system attachment) and will install a gas meter for injection metering. An unofficial / un- witnessed MIT test was performed 12/28/2010 (referenced in KU 21- 06RD MIT test attachment). Consistent with SIO 7a Rule 3, an MIT will be scheduled with the AOGCC and performed once injection conditions have stabilized. To insure well integrity and confinement consistent with SIO 7a Rule 4, Marathon will maintain continuous pressure and flow rate data acquisition, and will include KU 21 -06RD production and injection data in the annual performance report as per Rule 7. The Kenai Gas Field is monitored 24/7 by operations. Injected gas will be compatible with Pool 6 consistent with SIO 7a. Wells within the 1/4 mile area of review (1/4 mile from KU 21 -06RD Sterling Pool 6, top perf) are: KU 11 -06, KU 22 -06x and KDU -5. • KU 11 -06 was drilled only to the Sterling Pool -4 reservoir and did not penetrate Pool -6, and was included in the initial Pool -6 review for containment (referenced in current KU 11 -06 welibore schematic attachment). • KU 22 -06x was drilled and completed into the Sterling Pool -6 in 2008/2009 and is a production well. KU 22 -06x does have 5 -1/2" production casing and does have a CBL dated 1/26/2008 and is adequate. Top of cement at 2,010' MD was picked r from the CBL (re - .ed in current KU 22 -06x wellbore schematic attachment). • KDU -5 is ju outside ►e area of review and was included in the initial Pool -6 review for c• • .n.':• -nt (referenced in current KDU -5 wellbore schematic attachment). Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, a ted . 1 Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -403 Application for Sundry Approvals cc: AOGCC KU 21 -6RD Well Schematic Houston Well File KU 22 -6x Well Schematic Kenai Well File KU 11 -6 Well Schematic KJS KDU -5 Well Schematic Unofficial MIT Test Surface Equipment Diagram KU 21 -6RD'/ Mile Plate voit- � �j. L.CEt j 5/2"/ STATE OF ALAS AND GAS CONSERVATION OMMI Il .G4 APPLICATION FOR SUNDRY APPROVALS FED �� °�'�°? "» 20 AAC 25.280 s (`,�p�. • 1. Type of Request: Abandon ❑ Plug for Redrill E] Perforate New Pool ❑ Repair well ❑ ° CT ppTove rog a Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ , Ichgrage Extension ❑ Operational shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter casing ❑ Other: Convert to Injection /Prod. - 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Alaska Production LLC Development 0 Exploratory ❑ 201 -0970 - 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 50- 133 - 10090 -01 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: - Spacing Exception Required? Yes ❑ No El Kenai Unit 21 - 6RD 9. Property Designation (Lease Number): 10. Field / Pool(s): FED A - 028142 ' Kenai Gas Field / Sterling Pool - 6 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): 5,650' - 4,877' - 5,563' - 4,803'. NA 5,510' Casing Length Size MD TVD Burst Collapse Structural Conductor 51' 20" 72' 72' Surface 1,261' 10 -3/4" 1,282' 1,238' 1,820 psi 840 psi Intermediate Production 5,599' 7 -5/8" 5,620' 4,836' 4,140 psi 2,900 psi Liner 2,355' 4 -1/2" 5,650' 4,877' 8,430 psi 7,500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5,250' - 5,310' 4,544' - 4,595' Tie - back 4 - 1/2" L - 80 3,295' Packers Type: Baker Liner Hanger Packers MD (ft) / TVD (ft): 3,295' MD 2,883' TVD SSSV Type: NA SSSV MD (ft) / TVD (ft): NA NA 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development -e}^ Service R7 1 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: April 2011 Oil ❑ Gas --P" WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ 0 - WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature ..✓Q/{!1ti p2,,,,,,,,e (907) 283 -1371 Date February 18, 2011 V COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 i- O `F/ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: All A.Oe,I' c t, rr si sat Lu. ik. ct• ,t e y d e e t44. ( - 5 = o Alo • l -7 A • Subsequent Form Required: j 0 - C/17 cf . .) APPROVED BY �� COMMISSIONER THE COMMISSION Date: /2- f Approved by: RBDMS FEB 2 4 2011 ORIGINAL Form 10 -403 Revised 1/2010 Submit in Duplicate KENAI UNIT KU _ 44-30 KU 0 -32 b O a KDU_6 5N -11W 5N -11W A 31 32 KU 33 -32 Pad 34 -31 , � V N — K14 -32 KU 34 -31 � ''� KU_WD 4 \ ` o N ti \ 1 7 5250'MD e ‘ v 1 O'TVD 1 KU_34 -32 1 KC -61 U 21 -6R15 a 1 i U_5 KBU 41 -6 KU_21 -6 ,:>/ v \ / 7 5 4N -12W 4N-11W 1 , 6 KU 22 -6X 6 I KBU 22 -6 KBU 42 -6X a s 07 KBU_42 6 KU_13 -6 0 b �j ""°° " A KTU 9 6XR 6 KBU 23X -6 �� ��� a � . U � �� i :,► u2 9 o KBU_33 -6 �! s e KU_43 -6A _ _ KBU ° '° 5 Q 'U-6H � b � b 1 A AREA 6 / ( 5 1U1MM Q O 4 .0.0 V ' ' ° 5 1 5 4 , MARATHON ALASKA PRODUCTION LLC KU 21 -6RD 1:12000 0 0.50 KENAI UNIT MILES 1 1 KENAI PENINSULA, ALASKA NAD27 / Alaska zone 4 (EPSG 26734) Transverse Mercator Clarke 1866 spheroid January 2011 Natural origin: [150 00 00W, 54 00 OON] H.P. WELLS FROM CANNERY LOOP 750 psi Gas BELUGA/TYONEK > H.P. WELLS FROM KENAI GAS FIELD BELUGA/TYONEK > /------\ ■ Ca • ►CO ■ TO KNPL �� LLB PCV MSN 301 HP Slug Catcher E . CANNERY LOOP �_, STERLING > CIal Contactors 1 & 2 BELUGA/TYONEK _ ► —0 100 ► TO KNPL \ MSN 400 ► 50 psi Gas 750 psi Gas ► ► TO APL 750 PSI Gas Centaur #1 ■ ► MSN 500 L.P. WELLS FROM Saturn KENAI GAS FIELD Compressors 50 psi Gas _ 750 psi Gas ► STERLING POOL 3 ► 250 psi Gas STERLING POOL 4 - ".....___./ Injection Flow STERLING POOL 6 Control Valve BELUGA/TYONEK Contactor 4 DEEP TYONEK -►C191\1—• Ultrasonic Meter 750 psi Gas bQ CO Cal ►► IR Compressors Centaur #2 ■ CO Call Well 31 -7X 250 psi Gas Orifice Meter 50 psi bas >1 ►CO N —I Orifice Meter CO Well23- Orifice Meter 1 I ►D1 CO ► •C8] N Orifice Meter 00 4 C■ Well 21-612D Marathon Oil Company Orifice Meter KGF Gas Storage System SIZE ESCIA NO DWG NO REV REV BY CHAD SAMSKAR DRAWN RAYMOND SCHEMANSKI 11X17 AAT- PFD -KGF- ALL -001 01 REV Di DATE: 01 -18 -11 ISSUED 10 -1 -08 SCALE 1:1 I (SHEET 1 OF 1 t. • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg @alaska.gov; tom.maunder @alaska.gov; phoebe.brooks @alaska.gov; doa .aogcc.prudhoe.bay @alaska.gov OPERATOR: Marathon FIELD / UNIT / PAD: 34 - 31 DATE: 12/28/10 OPERATOR REP: Mike Sully AOGCC REP: None - not an official MIT Packer Depth Pretest Initial 15 Min. 30 Min. Well KU 21 -6RD Type Inj. n/a TVD Tubing 60 60 60 60 Interval / P.T.D. 201 -097 Type test Test psi Casing 1,500 1,500 1,500 P/F Notes: Filled with 50/50 McOH. -30 gallons. OA Left 500 prig on annulus. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form PLB 10/26/09 KU 21 -06RD (not official test) MIT Form 12- 28- 10.xlsx • KU 21 -6 R D Permit #: 201 -0970 1 API 50-133-10090-01-00 Pad 34 -31 Prop. . Des: A- 028142 /42 515' FSL, 2,089' FEL, KB elevation: 91' (21' AGL) Sec. 31, T5N, R11W, S.M. x: 270,536.5 MARA111ON Y: 2,367,873.6 Lat: 60° 28' 31.144" N Long: 151° 16' 18.601" W Spud: 8/31/2001 Conductor Pipe `" TD: 9/5/2001 20" K - 55 78.6 ppf PE Rig Released: 13:00 hrs 9/9/01 MD s T u o rf p Bottom TVD - TVD Surf 51' Surface Casing I 10-3/4" H -40 32.75 ppf STC Top Bottom MD 0' 1,282' TVD 0' 1,238' 14 -3/4" hole Cmt w/ 750 sks, Class A Production Casing Baker Liner 4 ' 7 -5/8" J -55 26.4 ppf LTC hanger 10 ft Top Bottom @ 3,295' MD t Tie -Back MD 0' 5,620' Seal TVD 0' 4,851' Assembly 9 -7/8" hole Cmt w/ 700 sks Side Track window @ 3,450' MD \ Y r � Tie -Back Tubing 4 -1 /2" L -80 12.6 ppf IBT -Mod Top Bottom MD 0' 3,295' TVD 0' 2,883' Liner 4 -1/2" L -80 12.6 ppf Mod -Butt Max Inc 37.77 Top Bottom MD 3,295' 5,650' degrees TVD 2,883' 4,877' 6-1/8" hole cemented w/ 265 sks, Class G, 13.5 ppg • + II L 11; Sterling Pool 6 Perforations: . Pool i C -1 5,250 %5,310' (11/27/01) " ! F Shot w/ 2500psi overbalance, l . ° ' 6 N2 pressure, 2 -1/2" Milleneum 11 �- - Pool 5.1 4 , Stim Gun, 6 spf Q. •' & 5.2 4 C -1 5,250'- 5,310' Re- perfed (12/6/01) , ® w/ SLB 2 7/8" PJ HSD Guns, , ' , - 6spf ' ' - Li - I Pool 6 A C -1 Sand ` tE.�' y Fish: (recovered 1/2 ring 12/2010) possibility of r (12/30/10) Bailed fill to other dropped CT hanger elements below perfs. ( ) See well files for details, desc. photos. N 5,326'kb wl 2 -1/2" bailer, \ : Tight spot @ 5,306'- 5,310' r . noted when 2.86" tool run. 1S 4 ,,. a '^ta' I Fish: Gun anchor@ - 5,510' MD (2001) TD PBTD 5,650' MD 5,563' MD 4,877' TVD 4,803' TVD Well Name & Number: Kenai Unit 21 - 6 ReDrill Lease: Kenai Gas Field A 028142 County or Parish: Kenai Penisula Borough State: Alaska 1 Country:' USA Perforations (MD): 5,250' - 5,310' Perf (TVD): 4,537' - 4,588' Angle @KOP and Depth: 4° @ 300' MD Angle @ Perfs: - 32° RKB: 21' Date Completed: November 27, 2001 Prepared By: Mike Sulley Last Revision Date: January 4, 2011 • SARAH PALIN, GOVERNOR -7~ ®iJy tml~il ~ ~ ~ 333 W 7th AVENUE, SUITE 100 ~7 1~~TT~~++~~11ri~7 ` 1 T C®is-7i~is`Aii®is ~®~~rIIS` 7`I®1~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 FAX (907) 276-7542 Craig Rang Senior Completions Engineer Marathon Oil Company PO Box 1949 ~'~`v~Uat~~~ ~ ~.f ` ' ~ ~i i Kenai AK 99611-1949 Re: Kenai Gas Field, Sterling Pool-6, Kenai Unit 21-6RD ~ D Sundry Number: 308-368 ~~ Dear Mr. Rang: ~/ 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this2~ day of October, 2008 Encl. • M Marathon MARATHON Oil Company October 13, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-403 Application for Sundry Approvals Field: Well: Kenai Gas Field Kenai Unit 21-6RD ECEi~VEC~ OCT 1 5 1Q08 .. ail & Gas Cans. Gorr~~~:r~sion Anchorage Dear Mr. Maunder: Marathon requests permission to enhance gas production from KU 21-6RD well by removing the 2-3/8' velocity string and installing 4-1/2" tie-back tubing from the top of the liner to surface. Marathon also plans to reperforate the Sterling Pool 6 C-1 sands upon completion of the tie-back tubing installation. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, Kevin J. Skiba Engineering Technician Enclosures: 10-403 Sundry Notice Work Scope Procedure Well Schematic cc: AOGCC Houston Well File Kenai Well File KJS CLR • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 /~ ,. ~~" I/r , Ic ~ ~' sTATE o>= ALASKA ~ E ~ f ~ 5 ~ i) Cl 8 ALASKA OIL ANI3 GAS CONSERVATION COMMISSION ~~I ~~, APPLICATION F4R SUNDRY APPROVAL~ya~~a ~6i ~ ~~, rt-;~;, (;ommission n nc non 1. Type of Request: Abandon^ Suspend^ Operatlonalshutdown^ Aerforate0~ Waiver ° ~ Other Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Instal) Tie-Back Change approved program^ Pull Tubing Q Perforate New Pool ^ Re-enter Suspended Well ^ Tubing ' 2.Operator Name: an Marathon Oii Com 4. Current Well Class: 5. Permit to Drill Number. 970 y p Development ^ , Exporatory ^ 201-0 3. Address: PQ BOX 9949 Stratigrdphic ^ Service ^ 6. API Number. Kenai Alaska, 99619-1949 50-133-10090-01-00 1. If perforating., closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: " Kenai Unit 21-6RD ^ No ^ Spacing Exception Required? Yes 9. Properly Designation: 10. KB Elevation (ft): 11. Field/Pool(s): _ ,~~ A - 028142 91' (21' AGL) Kenai Gas Field /Sterling Pool-6 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD {ft): Effective Depth fVID {ft): Effective Depth TVD {ft): Plugs (measured): Junk (measured): 5,650° ~ 4,884' ~ 5,563' - 4,803' - NA 5.510' Casing Length Size MD TVD Burst Collapse Skructural Conductor 51' 20" 51' S1' SurFaw 1,261" 10-314" 1,282' 1,238' 1,820 psi 840 psi Intermediate Production 5,599' 7~/8" 5,520' 4,836' 4,140 psi 2,900 psi Liner 2,355' 4-1/2" 5,650' 4,$77' 8,430 psi 7,500 psi Perforation Depth MD (ftj: . Perforation Depth TvD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5,250' - 5,310' 4,544' - 4,595' 2-3/8° HO-70 3,290' Packers and SSSV Type: Packers and SSSV MD (ft): NA NA 13. Attachments: Description Summary of Proposal Q 14, Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q ~ Service ^ 75. Estimated Date for 16. Well Status after proposed work: October 22, 2008 Commencing Operations: OII ^ Gas Q , Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18.1 hereby certify that the foregoing Is true and correct to the best of my knowledge. Contact Kevin Skiba (901) 283-1371 Printed Name Craig L. Rang T'de Senior Completions Engineer Signature ~ One (907) 283-1372 Date October 13, 2008 COMMISSION USE ONLY 3 Q j Sundry Number: O~~U r~~ i tness Conditions of approval: Notify Commission so that a representative may w anical Integrity Test ^ Location Clearance ^ Plug Integrity ^ BOP Test ~ Mech " Other. ~~LJ~ ~ 5 l JH:~+~,.~.;tv"~ ~J~ ~1c'~ ``y~ Subsequent form Required: ~~ APPROVED BY r Q ~ ~ ~ I Approved ~: COMMISSIONER THE COMMISSION Date: L - i .,. R~~~~F~; QC ~ ~ 2008 Form 10-403 Revised 06!2006 ~ ' Submit in Duplicate ' i ~ ~3 !~ `~ G • • MARATHON OIL COMPANY M ALASKA REGION MARATHON KU 21-6rd Workover Procedure MIRU Pollard slickline. Hold PJSM. Set 1.187" Blanking Plug (No-go) @ 3290'. Bleed off Coil Tubing and verify installation with a Negative Test. RDMO Pollard slickline. 2. MIRU BJ coiled tubing unit with a 2-3/8" coiled tubing stinger string. Rig up fluid and N2 pumps. RU pumping iron and flow back iron. Function test BOP. Stab 2-3/8" CT into. injector. Install G&G Coil Tubing BHA and pull test. Nipple up injector to WHA. 3. Pressure test surface lines and CT equipment with 6% KCL water. Pressure test pump iron (200 low/4500 high psi). Pump fluid to load CT. Pressure test CT, WHA and flow back iron to choke manifold (200/4500 psi). Pressure test BOP rams (200/4500 psi). Purge pressure test fluids w/ N2 to flowback tank and vent N2 pressure to flowback tank. 4. MU Baker GS Running Tool. Swing Injector and lubricator away from WH. BJ CoilTech to connect Baker GS tool string assembly to coil on reel trailer. Dimple-on a 2-3/8" CT connector. Pull test CT connector (25,000 lbs.) using a pull plate. 5. Nipple up injector to WHA. Pressure test WHA using CT kill line (200/1500 psi). Bleed WHP to flow back tank. Prior to next Step, ensure that flowback line from WHA through choke manifold to gas buster is ready and available to keep TP at or below 1500 psi while RIH to eliminate possible CT collapse. This would serve as a backup if flow through the production flow line was unexpectedly curtailed or ceased. 6. RIH with 2-3/8" coil tubing stinger string and latch Vetco Coil Tubing Hanger Assembly. Well is able to flow to sales up annulus (if desired). 7. Latch GS spear to Vetco mandrel and pull additional weight to verify GS is latched. Per BJ and Vetco Procedures: Loosen Lock Screws and PU Mandrel. Pull String up hole and through BOPE's. 8. Set CT in BOP tubing/slip rams. Lock tubing/slip rams. Slack off injector chain traction and roll chains to verify slips are set. Release WHP above tubing rams to the flowback tank. Nipple injector off of WHA. Walk injector up CT. Install C plate above BOP and 2- 3/8" polish rod clamp on CT. Remove CT connector, hanger mandrel, and GS Spear. Connect roll-on connector and pull test to verify. 9. Reel 3290' of 2-3/8" coil onto work reel. Close well at swab valve. Release WHP above swab valve to the flowback tank. Nipple injector off of WHA. RDMO BJ CoilTech. 10. MIRU Expro wireline, pressure test lubricator and BOPE to 4500 psi. RIH w/ 3.800 gauge ring and junk basket to PBTD @ 5563' MD. NOTE: If gauge ring doesn't make it to bottom, prepare to RIH w/mill and motor on CT to clean out during post-rig activities. Gauge ring must be run to at least 3500' MD to set RBP in next step. 11. RIH w/ 4-1/2" 12.60 Ib/ft. HES Retrievable Bridge Plug (RBP), set @ 3450 ft. Bleed off all pressure in the annulus to flow line. Dump bail 20 ft. of sand on RBP. RDMO Expro wireline. 12. Mix 500 bbl of 6% KCI and fill hole using vacuum truck. Pressure test wellbore to 500 psi and hold for 10 minutes. Shut-in well. • • 13. MIRU Glacier Drilling Rig #1. Tie into casing valve with rig pumps and be ready to bullhead well if pressure is observed at surface. Monitor well and make sure well is completely dead. ~a-~~e~-s ~~ ~~+~ ~,~ ~~ ~~~ ~ ~~~ ,. r, 14. ND tree and existing Vetco tubing head, send to Vetco for inspection and repair. ~ ~~ ((~, 15. NU new Vetco tubing head with 4-1/2" tubing hanger profile. Test tubing head per Vetco recommendations. 16. NU 7-1/16", 5M BOP's with 2.875-5.5" variable bore pipe rams. Test BOPs to 5000 psi. 17. RIH w/ 4" DP and Baker polish mill to TOL @ 3295' MD. Dress tie back receptacle per Baker Oil Tools recommendation. POOH w/ DP sideways, lay down in singles. 18. TIH w/ 4-1/2" 12.60 Ib/ft. tubing and 4-1/2" Baker tie back stem (5.25" seal OD) to TOL @ 3295' MD. Sting in seals and set down 20k pounds on locator. Test backside to 2000 psi, hold for 5 minutes. Test down tubing to 500 psi, hold for 10 minutes. 19. Space out to land seals 1 ft. high. Install space out pups and M/U tubing hanger. R/U landing joint and land hanger, run-in lockdown screws. Test backside to 2000 psi for 10 minutes. Test down tubing to 500 psi for 10 minutes. Remove 4-1/2" landing joint. 20. Install BPV in 4-1/2" tubing hanger. ND BOPE, NU tree. Pull BPV, install 2-way check in tubing hanger. Test tree to 5000 psi using methanol water. Pull 2-way check, reinstall BPV. RDMO Glacier Drilling Rig #1. POST RIG 1. MIRU BJ Coil Tubing, nitrogen units. M/U coil connector and pull test to 10,000 Ib. Pressure test connector to 250/4500 psi for 10 and 10 minutes respectively. M/U bridge plug retrieving head on end of coil tubing. Test all BOPE and CT with methanol water to 250/4500 psi for 10 and 10 minutes respectively. 2. RIH to Retrievable Bridge Plug (RBP) @ 3450' MD while washing sand and debris above plug using commingled 6% KCI water/N2. Continue washing sand and begin to jet well over to nitrogen. Once well is jetted in above RBP, engage external fishing neck. Pull 5k over and release RBP. POOH w/ RBP and CT. 3. MU 2" OD bull-nose jetting nozzle on end of coil tubing. RIH to PBTD @ 5563' MD while cleaning out wellbore and jetting remainder of well in. POOH. RDMO BJ CoilTech. 4. MIRU MOC flowback iron including choke, gas buster, and an open top tank. 5. MIRU Expro E-line, pressure test lubricator and BOPE to 4500 psi. RIH w/ 3.800" gauge ring and junk basket to PBTD @ 5563' MD. POOH. 6. Perforate Pool 6 (C1 and C2) intervals 5415-5445, 5330-5380, 5255-5308 utilizing Expro 3-3/8" HSD, 6 SPF, 60 degree phased charges. Monitor tubing for signs guns have fired. POOH. RDMO electric line. 7. Flow well to tank, recording pressures and water volumes per production engineer. Flow the Pool 6 until anticipated rate has been obtained; several days of production performance may be needed for thorough reservoir assessment. 8. RDMO MOC flow back iron and associated items. 201-0970 ration: 91' (21' AGL) 270,536.5 2,367,873.6 60° 28' 31.144" N 151°16'18.601"W 8/31 /2001 :: 9/5/2001 KU 21-6RD Pad 34-31 515' FSL, 2,089' FEL, Sec. 31, TSN, R11W, S.M. Baker Liner hanger at 3,295' Sterling Pool 6 Perforations: 5,250'-5,310' (11/27/01) Shot w/ 2500psi overballance, N2 pressure 2-1/2" Milleneum StimGun, 6 spf 5,250'-5,310' Re-perfed (12/6/01) w/ SLB 2 7/8" PJ HSD Guns, 6spf Surface Casina 10-3/4" H-40 32.75ppf STC Top Bottom MD 0' 1,282' ti TVD 0' 1,238' 14.3/4" hole Cmt w1750 sks of Class A Velociri String Tubing 2.3/8" Hang•Off 70 Top Bottom MD 0' 3,290' TVD 0' 2,879' BHA: BST Lift Profile nipple wl 1.187" No-go 8 Profiles for blanking plug or standing valve. Production Casing 7-5/8" J-55 26.4 ppf LTC Top Bottom MD 0' 5,620' TVD 0' 4,851' 9-7/8" hole Cmt w/ 700 sks Side Track window @ 3,450' MD Liner 4-112" L-80 12.6 ppf Mod Butt Top Bottom MD 3,295' 5,650' TVD 2,883' 4,877' 6-1/8" hole Cmt wl 265 sks C I Pool6 C C-1 Sand Fish: Gun anchor @-5510' ~+ TD PBTD 5,650' MD 5,563'MD 4,877' TVD 4,803' TVD Well Name & Number: Kenai Unit 21-6RD Lease: A-028142 County or Parish: Kenai Peninsula Borough State: Alaska Country: USA Angle @KOP and Depth: Angle/Perfs: KOP ND: 3,400' Date Completed: 11/27/01 Ground Level (MSL): 70' RKB above GL: 21' Revised by: Kevin Skiba Last Revision Date: 10/10108 M ~uw-nioN Conductor 20" K-55 78.6 ppf PE Top Bottom MD Surf 51' TVD Surf 51' KU 21-6RD Verbal Approval to Remove V-String Page 1 of 2 • • Maunder, Thomas E (DOA) From: Skiba, Kevin J. [kskiba@marathonoil.com] Sent: Friday, October 17, 2008 2:23 PM To: Maunder, Thomas E (DOA) Subject: RE: KU 21-6RD Verbal Approval to Remove V-String ~ Q ~ ~ ~~ Thank you Kevin Skiba Engineering Technician Marathon Oil Company Office (907) 283-1371 Cell (907) 394-1332 Fax (907) 283-1350 ~. ~ ..:~.~~rr~~~v.~ ~r~ From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska,gov] Sent: Friday, October 17, 2008 2:22 PM To: Skiba, Kevin J. Subject: Rt: KU 2i-6RD Verbal Approval to Remove V-String Kevin, You have correctly captured our conversation. CaN or message with any questions. Tom Maunder, PE AOGCC From: Skiba, Kevin J. [maiito:kskiba@marathonoil.com] Sent: Friday, October 17, 2008 2:19 PM To: Maunder, Thomas E (DOA) Subject: KU 21-6RD Verbal Approval to Remove V-String Tom, As per our conversation, Marathon has been granted verbal approval to set a plug in the velocity string and rig up coil tubing unit and remove the velocity string in preparation for working the well over. Kevin Skiba Engineering Technician Marathon Oil Company Office (907) 283-1371 10/24/2008 • Marathon MARATHON Oil Company May 15, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Submittal List Dear Mr. Maunder: ~~~~P~2 ~~~°F*~ ~~ n ~' ~~:_JT ~5 ~ ti,,~ :+~ s u MAY ~ ~ 2008 •Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~ons. C~~n~~~E~~ ~1~~~ Oil ~ G~ ~ ~ ~ (~ ~ ~ ~chor~~ ~- ~, ~~~CScc~~ c~.3 ~i~~ t~~ ~~'V~ ~~~ t (~ ~~ ~~ ~,~ ~.~L.C~~J~'~ ~; s ~ ~ ~~ ~'~~~ ~.°~~~~~-I~.h00SE~i\~6`ocS. ~o ~..~,~- ~~5~~~- ~.~«~,~~ ~e ~~~v~.<~~~-~L--~~.~ ~ Marathon and the AOGCC have had discussions on the follow-u re ortin needed to `/ ~-~ p P 9 close out 10-403 Sundry approved well work activities. Work has been ongoing to ~/ac~ o~ identify the suspect well activities and complete the appropriate reporting. Submitted for your records is a list of the completed reports along with the indicated 10-404 Sundries. I am continuing to work on the remaining sundry reports and plan to submit them upon their completion. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, - ~~ ~.~~~~~~?~~~~ .~`~,~~~~ .. ~~~~ yeu~~ ~ ~ Kevin J. Skiba Engineering Technician Enclosures: 10-404 Sundry Submittal List cc: Houston Well Fife Accompanying 10-404 Sundries Kenai Well File KJS ~ . M Marathon MARATHON Oil Company January 23, 2008 • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 98611 Telephone 907/283-1371 Fax 907/283-1350 ~~~~~~~~ Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Kenai Gas Field Well: KU 21-6 RD Dear Mr. Maunder: ~~'~ ~ ~ 1~08 ~la~ka ~ii ~ Ua~ ~or~s. Commission Ancr~orage Attached for your records is the 10-404 Sundry completion report for well KU 21-6 RD. This sundry covered the shortening of the velocity string from the original depth of 5255' up to 3290' MD. This work was completed under sundry #303-247. Please contact Kevin Skiba at (907) 283 -1371. If you have any questions or need additional information. Sincerely, 4 Wayne Cissell Work Over Supervisor Enclosures: 10-404 Sundry Report cc: Houston Well File Operation Summary Kenai Well File Current Well Schematic KJS KDW ~-e~~ ~~ t~ ~/ 1.... t v L.~ L~ ,~,, ~ STATE OF ALASKA `s'~O~Od~~ (~aY ~ ~ 1~10$ , ALAS IL AND GAS CONSERVATION COMMI ION REPORT OF SUNDRY WELL OPEF~~(~MJ~Gas Gons. Commission Anchora e 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Raise Tubing Performed: AlterCasing ~ Pull Tubing~ Perforate New Pool ~ Waiver^ Time Extension ^ Tail Change Approved Program ~ Operat. Shutdown ~ Perforate ^ Re-enter Suspended Weil ~ 2. Operator 4. Well C~ass Before Work: 5. Permit to Drill Number: Name: Marathon Oil Company Development ~^ Exploratory^ 201-097- 3. Address: Stratigraphic ^ Service ~ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-10090-01 7. KB Elevation (ft): 9. Well Name and Number: 80 KU 21-6rd - 8. Property Designation: 10. Field/Pool(s): F~'D A- 028142 Kenai Gas Fieldl Sterling Pool 11. Present Well Condition Summary: Raised coil tubing up to 3290' MD Total Depth measured 5,650 - feet Plugs (measured) true vertical 4,$$4 - feet Junk (measured) Gun anchor at - 5,510' Effective Depth measured 5,563 _ feet true vertical 4,7g7 feet Casing Length Size MD ND Burst Collapse Structural Conductor 51' 20" 51' 51' Surface 1,282' 10-3/4" 1,282' 1,237' 1820 psi 840 psi Intermediate Production 5,620' 7-5/8" 5,620' 4,836' 4140 psi 2900 psi Liner 2,254' 4-1/2" 5,650' 4,884' 8,430 psi 7500 psi Perforation depth: Measured depth: 5,250 - 5,310' True Vertical depth: 4,544' - 4,595' Tubing: (size, grade, and measured depth) 2-3/8" HO-70 3,290' Packers and SSSV (type and measured depth) N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1,227 0 N/A N/A Subsequent to operation: 0 1,141 2 N/A N/A 14. Attachments: 15. W ell Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^~ Service ~ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas Q WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exemp • ~ 303-247 Contact Kevin Skiba (907) 283-1371 P ~h~~~~ rinted Name Wayne E. Cissell Title Well Work Over Supervisor Signature • Phone (907) 283-1308 Date January 23, 2008 Form 10-404 Revise 04/2006 6~ ~~~ J~l. ~~ 2009 Submit Original Only ...r .-. ~. ~ w .. ~., ~ ~ ~- • ~ Mara#hon ~7i1 Company P~~~ ~ ~? Operations Summary Report Legal Well Name: KENAI UNIT 21-6 Common Well Name: KENAI UNIT 21-6 Spud Date: 8/22/2001 Event Name: RECOMPLETION Start: 8/20/2003 End: 9/1/2003 Contractor Name: Rig Release: Group: Rig Name: Rig Number: ' Date Frorn - Tn Hours Code ~ d~ Phase Description crF Operations 8/21/2003 12:00 - 19:30 7.50 Spot and RU BJ 2-3/8" unit w/ MOC owned CT (0.125" wall thickness) 19:30 - 21:30 2.00 Failed CT connector pull test. Upon inspection, pipe was crimped by Baker grapple. Rig back to investigate failure and options. 8/24/2003 8/29/2003 05:30 - 06:30 1.00 NULL COIL CMPPUL Check in, start and warm up equipment. 06:30 - 07:30 1.00 NULL COIL CMPPUL PU injector head and MU tools. MU injector head to well. 08:00 - 09:30 1.50 NULL COIL CMPPUL Pump to fill CT. 09:30 - 11:00 1.50 NULL COIL CMPPUL Pressure test to 200/1500psi through CT. Test good. Displace CT with N2 and bleed pressure off to tank. Zero pipe at injector head. 11:00 - 12:00 1.00 NULL COIL CMPPUL RIH w/ assy. Tag up in work window. Open window and centalize CT. Close window, equalize pressure, and RIH to bottom of tree to engage hanger. 12:00 - 12:15 0.25 NULL COIL CMPPUL Latch into CT hanger w/ Baker GS pulling tool. Back out mandrel hanger screws and slack off to neutral wt (18K Ibs string weight). Unseat mandrel pulling 28K Ibs (10K overstring weight) 12:15 - 12:45 0.50 NULL COIL CMPPUL PU string approx 6ft. Tag assembly in BOP stack. Run back in hole to hanger spool. 12:45 - 13:45 1.00 NULL COIL CMPPUL Attempt to run hanger lock screws back in. Unable to engage all lock screws. PU and slack off to various weights in an attempt to re-land hanger. 13:45 - 14:00 0.25 NULL COIL CMPPUL PU again in an attempt to drift BOPs. Hear audible motion in tree. PU string approx 9ft (gained 3' from first PU). Unable to PU futher. Pull 27K. 14:00 - 14:30 0.50 NULL COIL CMPPUL RIH 7' staying above hanger spool. PU and bump up x2 at 9' (27k Ibs and 28k Ibs respectively). Decide to discontinue PUs as 2-3/8" H070 stinger string is not intended for repeated cycling. 14:30 - 15:00 0.50 NULL COIL CMPPUL RIH to mandrel hanger spool. Use lock pins to centralize hanger. Slackoff pipe and run in lock screws. All screws engaged at appropriate depth. Pipe hanging off in hanger. 15:00 - 16:10 1.17 NULL COIL CMPPUL Hammer up line from pump to CT reel. Pump 1.0 bpm to load CT. Once CT loaded, increase pump rate to 1.25 bpm. SO and PU. Still latched. Increase pump rate to 2.0 bpm. Pump off of fish and PUH. Close master valve. 16:10 - 17:00 0.83 NULL COIL CMPPUL Cool down N2 unit. Pump N2 to void CT taking coil volume returns through choke to flowback tank. 17:00 - 17:40 0.67 NULL COIL CMPPUL Bleed N2 pressure off of reel and rig back injector head. 9/6/2003 09:00 - 13:00 4.00 Finish rigging up BJ CT unit including rentaf DS 7-1/16" 5k BOPs. Crossovers have all been drifted and altered if necessary to drift a minimum of 4.1". Cut 17' of pipe from 2-3/8" hangoff string (string was previously worked over gooseneck). MU CT connector and pull test to 30k Ibs. MU centralizers, check valve, and hydraulic GS pulling tool. 13:00 - 14:15 1.25 Pressure/ftn test to 300/3000psi. Test good. 14:15 - 14:45 0.50 Hold operational meeting to discuss job. 14:45 - 15:00 0.25 RIH with fishing assy. Open 7" window to guide tool string into 4-1/8" WHA section, Latch into hanger at 18.1ft. PU to string weight and release hanger lock screws. 15:00 - 16:00 1.00 PU string. String not coming up. PU to 21 K Ibs. Still no motion. PU to 29K Ibs. w/o motion from string. Work hanger being mindful of pipe limitations. 16:00 - 16:30 0.50 Decide to attempt to reset string in hanger. Slack off and run in lockscrews. All bottom lockscrews running in, but top lock screws will not bury. PU and slack off while adjusting lock screws. Inability to run in lockscrews indicates that hanger travelled up within spool. PU and Printed: 12/27/2007 11:12:19 AM ~ • ~ Marathon'Oil Company ~'~~~:~. ~? Operations Summary Report Legal Well Name: KENAI UNIT 21-6 Common Well Name: KENAI UNIT 21-6 Spud Date: 8/22/2001 Event Name: RECOMPLETION Start: 8/20/2003 End: 9/1/2003 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code ~~~~ Phase Description of Clperat~ons . 9/6/2003 16:00 - 16:30 0.50 SO in attempt to set hanger. Hanger placed. Lock screws run in to appropriate positions. Hanger is reset. 16:30 - 17:30 1.00 Begin pumping to load CT. Pump CT volume plus amount required to pump off of hanger. PU string. 17:30 - 18:30 1.00 Close master valve and purge pipe with N2. 18:30 - 00:00 5.50 RDMO CT equipment Printed: 72/27/2007 11:12:19 AM . ~ ~ ~ 201-097 21.5' M M~runioN 20" 78.6 # DrvPipe @ 51' PBTD = 5,563'MD TD 5,650' MD 4,884' TVD Well Name & Number: KU 21-6RD Lease: A-028142 County or Parish: Kenai Peninsula State/Prov: Alaska Country: USA Angle @KOP and Depth: Angle/Perfs: KOP TVD: Date Completed: Ground Level (MSL): RKB above GL: 21.5' Prepared By: Kevin Skiba Last Rev!sion Date. 11(02I07 2-3/8" CT velocity string to 3,290' CTM BHA: BST Lift Profile nipple w/ 1.187" No-go and Profiles for blanking plug or standing valve. KU 21-6rd Pad 34-31 Baker Liner hanger at 3,295' =~ Shot w/ 2500psi overballance (N2 pressure) 2 1/2" Milleneum StimGun, 6 spf ,: Re-perfed 12/6/01: 5250'-5310' w/ SLB 2 7/8" PJ HSD Guns, 6spf ~ ~ 10 3/4", 32.75#, H-40, STC @ 1282' cmt w/ 750 sx class A 7 5/8", 26.4 #, J-55, LTC csg (exited at 3450') 4 1/2" 12.6 ppf L-80 Mod Butt Cemented Liner I Pool 6 I C-1 Sand Fish: Gun anchor @-5510' ~, • M Marathon MARATHON Oil Company November 2, 2007 b~ ~ ~,(~1 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Kenai Gas Field Well: KU 21-6 2~~~``,~ Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 .~ ~~' V NOV 0 6 2007 Alafkll Oi! & Gas Cons. Commission Anchorage o°~`~ ~p~ In an effort to help unload fluids from the Kenai Unit 21-6 wellbore, Marathon replaced the 2-3/8" coil tubing string with a 1-3/4" coil tubing string. The setting depth of the previous 2-3/8" tubing string was 5,255'. The 1-3/4" string is set at a measured depth of 3,290'. If you have any questions or need further information please call me at (907) 283-1371. Sincerely, ~c~~~R~~ NOV ~- ~ 2007 Kevin Skiba Production Technician Enclosures: 10-404 Sundry cc: Kenai Well File Well Schematic Houston Well File Operations Summary DMD KJS ORIGINAL STATE OF ALASKA ~~~~ ~~~ ~ Gov a s 2007 ALASKA OIL AND GAS CONSERVATION COM117RSSION ~~~ REPORT OF SUNDRY WELL OPERATIONSAIaska Oil & Gas Cons. Commission Anchorage 1.Operations Abandon Repair Weil ~ Plug Perforations Stimulate Other ~ Replaced 2-3/8" Performed: Alter Casing ^ Pull Tubing ®'~ A~ Perforate New Pool ^ Waiver^ Time Extension ^ tubing with Change Approved Program ^ Operat. Shutdown ^ 1~~ Perforate ^ Re-enter Suspended Well ^ 1-3/4" tubin 2.Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development^ Exploratory^ 201-097 3. Address: Stratigraphi~ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-10090-01-00 7. KB Elevation (ft): 9. Well Name and Number: 21.5' ' KU 21-6RD 8. Property Designation: 10. Field/Pool(s): A - 028142 Kenai Gas Field / Sterlin Pool 6 11. Present Well Condition Summary: Total Depth measured 5,650', feet Plugs (measured) NA true vertical 4,gg4' - feet Junk (measured) NA Effective Depth measured 5,563' feet true vertical 4,803' feet Casing Length Size MD TVD Burst Collapse Structural 0 0 0 0 0 0 Conductor 51' 20" 51' 51' 0 0 Surface 1,282' 10-3/4" 1,282' 1,237, 1,820 psi 880 psi Intermediate 0 0 0 0 0 0 Production 5,620' 7-5/8" 5620 4,836' 4,140 psi 2,890 psi Liner 2,200' 41/2" 5,650' 4,884' 7,780 psi 7,010 psi Perforation depth: Measured depth: 5,250' - 5,310' True Vertical depth: 4,536' - 4,585' Tubing: (size, grade, and measured depth) 1-3/4" QT-800 3,290' Packers and SSSV (type and measured depth) NA NA 12. Stimulation or cement squeeze summary: I t l t d t d p ~~ ~ vCt W ~~ ~ `1QS n erva s rea (measure e ): NA ~ T S1 ~« 3 3~'O~ Treatment descriptions including volumes used and final pressure: r,~}~ ~,~~` ~. IV (r!f El 10Di 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 1 Subsequent to operation: 0 130 0.25 0 70 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-246 Contact Kevin Skiba (907) 283-1371 Printed Name Dennis M. Donovan Title Production Engineer Signature ~/~. Phone (907) 283-1333 Date November 2, 2007 Form 10-404 Revised 04/200 ~~ (~~}fit 4c 7D~, ~ ~ N A L ~~~~ ~ Submit Original Only • M MARATNOM 20" 78.6 # DrvPipe @ 51' 2-3/8" CT velocity string to 3,290' CTM BHA: BST Lift Profile nipple w/ 1.187" No-go and Profiles for blanking plug or standing valve. Baker Liner hanger at 3,295' _i Fish: Gun anchor @-5510' PBTD = 5,563'MD TD 5,650' MD 4,884' TVD Well Name & Number: KU 21-6RD Lease: A-028142 County or Parish: Kenai Peninsula State/Prov: Alaska Country: USA Angle @KOP and Depth: Angle/Perfs: KOP TVD: Date Completed: Ground Level (MSL): RKB above GL: 21.5' Prepared By: Kevin Skiba Last Revision Date: 11/02/07 • Marathon Oil Company Operations Summary Report Legal Well Name: KENAI UNIT 21-6 Common Well Name: KENAI UNIT 21-6 Event Name: WORKOVER Contractor Name: BJ SERVICES Rig Name: BJ SERVICES Date From - To '~ Hours Code Sub ~ phase _ Code` 7/20/2007 08:00 - 09:00 1.00 SAFETY MTG_ WRLN 09:00 -10:00 I 1.001 RURD I SLIK I WRLN 10:00 - 12:00 2.00 RURD- SLIK WRLN 12:00 - 12:30 0.50 RUNPU SLIK WRLN 12:30 - 13:30 1.00 RUNPUL SLIK WRLN 13:30 - 14:00 0.50 RURD_ SLIK WRLN 7/23/2007 13:00 - 13:30 0.50 SAFETY MTG CTBG 13:30 - 17:00 3.50 RURD COIL CTBG 17:00 - 17:30 0.50 SECUR WELL CTBG 7/24/2007 07:00 - 08:00 1.00 SAFETY MTG CTBG 08:00 - 08:30 0.50 NUND WLHD CTBG 08:30 - 09:00 0.50 RUNPU COIL CTBG 09:00 - 11:00 2.00 RURD_ COIL CTBG 11:00 - 12:30 1.50 TEST BOPE CTBG 12:30 - 13:30 1.00 RURD COIL CTBG 13:30 - 16:30 3.00 RUNPU COIL CTBG 16:30 - 17:30 1.00 RUNPU COIL CTBG 17:30 - 19:00 1.50 RUNPU COIL CTBG Start: 7/20/2007 Rig Release: Rig Number: CT2 Page 1 of 4 Spud Date: 8/22/2001 End: Group: Description of Operations Obtain permit. Held Pre-Job safety meeting and job specific tasks (JSA). MIRU Pollard Slickline. Held PJSM to review JSA and Safe Work Permit conditions. Move in to spot Coil Tubing equipment on KU 21-6 location. RU Crane and Move Well House off of Well Head Tree. Spot coil unit and equipment around well head. MU tool string and lubricator. Pressure Test Lubricator to 500 psi. Held Pressure. RIH with 1"tool string and 1-1/4" Gauge Ring. Tag Top of Profile Nipple in 2-3/8" Coil Tubing @ 5255' KB. POOH with tool string. RIH with 1" tool string and BST Plug (1/2 of 1" Dummy Valve). Set Plu pressure. Plug Held._ RDMO Pollard Wireline. Arrive on location, sign in, obtain work permit and hold pre job safety meeting for Rigging Up Coil Tubing Equipment and Installing BOPE. MIRU equipment, spot coil tubing unit and equipment around well head. Stab in 2.375" coil tubing in Coil Tubing Injector. Contacted Jim Regg with AOGCC @ 08:00 hrs 7!23/2007 about the ROPE Pressure Test on the KU 21-6rd. Jim gave us a waver from the commission witnessing the BOPE Test. Jim told me to go ahead and test the BOPE when I was ready and write on the form I file with the commission that he gave me a waver. Safe out location and suspened operations for the night. Arrive on location, sign in, obtain work permit and hold pre job safety meeting for Installing and Testing Lubricator, and coil tubing operations. Lock out/ Tag out Flow line valves. Remove 4-1/16" Swab Valve, Flowing Tee, and Wing Valve. Vetco Gray Released Lock in screws on Tubing Hanger so we could pull coil tubing. Install Tubing Hanger Connection on Coil Tubing. Install GS Pulling Tool on Coil Tubing on Coil Tubing Unit. Nipple up BOPs on top of wellhead and RU Flow back Manifold. Contacted Jim Regg with AOGCC @ 08:00 hrs 7/23/2007 about the BOPE Pressure Test on the KU 21-6rd. Jim gave us a waver from the commission witnessing the BOPE Test. Jim told me to go ahead and test the BOPE when I was ready and write on the form I file with the commission that he gave me a waver. Function test BOPS. Pressure test BOPs. Hi h 4500 si .Low 500 si .Held Pressure. PU Coil Tubing Injector and lubricator. Install GS Pu ing ool on Coil Tubing on Coil Tubing Unit. Install Coil Tubing Injector and lubricator on BOPE Stack. Shell pressure test lubricator to 1500 psi. Held Pressure. Latch GS Pullin tool on to Tubing Hanger. Close 2-3/8" Pipe Rams and 2-3/8" Slips. Pull Test Connections to 30,000 # pull (14,000 # over Coil Tubing String Wt). Release BOPE Pipe Rams and Slips. PUH 10' wl Coil Tubing pulling 26,000# (10,000# over pipe wt). Close BOPS 2-3/8" Pipe Rams and Slips. Bleed off Pressure. Remove Lubricator. Remove Tubing Hanger Connection from Coil Tubing. Install Demple on Coil Tubing Collar Connection to connect 2-3/8" Coil Tubing velocity String in Well to 2-3/8" Coil on Coil Tubing Unit. Set Lubricator down on BOPE Stack. Pull Test Connections to 20,000 # pull (4,000 # over Coil Tubing String Wt). Release BOPE Pipe Rams and Slips. POOH w/ 5255' KB 2-3/8" Printed: 11/2/2007 12:58:28 PM • • Marathon Oil Company Operations Summary Report Legal Well Name: KENAI UNIT 21-6 Common Well Name: KENAI UNIT 21-6 Event Name: WORKOVER Contractor Name: BJ SERVICES Rig Name: BJ SERVICES Date From - To Hours Code Code Phase 7/24/2007 117:30 -19:00 ! 1.501 RUNPULI COIL I CTBG 19:00 - 20:00 I 1.001 RUNPULI COIL I CTBG 20:00 - 21:30 1.50 SECUR WELL CTBG 7/25/2007 07:00 - 07:30 0.50 SAFETY MTG_ CTBG 07:30 - 12:30 5.00 RURD_ COIL CTBG 12:30 - 13:00 0.50 SECUR WELL CTBG 8/19/2007 09:30 - 10:00 0.50 SAFETY MTG_ XMBO 10:00 - 12:00 I 2.001 NUND I TREE I XMBO 12:00 - 12:30 0.50 SECUR WELL XMBO 8/22/2007 08:30 - 09:00 0.50 SAFETY MTG_ MIRU 09:00 - 15:00 I 6.00 I RURD_ I COIL I CTBG 15:00 - 17:00 ~ 2.00 ~ TEST_ ~ BOPE ~ CTBG 17:00 - 17:30 I 0.501 SECURE WELL I CTBG 8/23/2007 ~ 07:00 - 08:40 ~ 1.67 ~ SAFETY ~ MTG_ ~ CTBG 08:40 - 09:20 0.67 RURD_ COIL CTBG 09:20 - 10:40 1.33 RURD COIL CTBG 10:40 - 11:45 1.081 RURD I COIL CTBG 11:45 - 12:45 1.00 RURD COIL CTBG 12:45 - 14:30 1.75 RURD_ COIL CTBG 14:30 - 15:15 0.75 RURD COIL CTBG 15:15 - 16:15 1.001 RURD I COIL I CTBG 16:15 - 17:00 I 0.751 RURD I COIL I CTBG 17:00 - 17:30 0.50 RURD_ COIL CTBG 8/24/2007 07:00 - 07:30 0.50 SAFETY MTG CTBG Page 2 of 4 ~ Spud Date: 8/22/2001 Start: 7/20/2007 End: Rig Release: Group: Rig Number: CT2 Description of Operations Coil Tubing. Close Master Valve. Bleed off Pressure from Lubricator. Remove Lubricator. Remove BHA from Coil Tubing. Shut in Master Valve on Flowing Christmas Tree. Remove Injector from Lubricator and Remove BHA from 2-3/8" Coil Tubing. Reinstall Injector and coil tubing on lubricator. Blow water out of Coil Tubing through choke into gas buster tank. Remove and Laydown Lubricator. Set Down Coil Tubing Injector. Secured well for night. SDFN. Signed out for the night. Arrive on location, sign in, obtain work permit and hold pre job safety meeting. RD BOPE Stack. RDMO Coil Tubing and Crane. Secured well. Leave Well Shut in. Arrive on location, sign in, obtain work permit and hold pre-job safety meeting. RU Vetco Gray. Remove Swab Valve. Install Flowing Tree Tee, and Wing Valves. Reinstall Swab Valve. Pressure Test All Tree Connections to 5000 psi. Held Pressure. RD Vetco Gray. Secured well. Leave Well Shut in. BJ Coil tech crew on location. Uptained work permit, discussed procedure with crew and held PJSM with all crew members. Contated Jim Regg with AOGCC @ 5 pm Monday Afternoon 8/20/2007 for BOPE Test on the KU 21-6rd at 5 pm Tuesday Afternoon 8/21/2007. Jim waived Witnessing BOP Test Tuesday @ 5 pm on the KU 21-6rd. Move in and unload equipment, spot coil tubing unit and equipment around well head. Install ROPE and surface equipment. Prepair Equipment for BOPE Test. Test BOP's. 250 psi/3500 psi. Both Blind Rams and Pipe Rams Test good. Perform Test on Accumulator. Tested Ok. Install Night Cap on BOP's. Stab 1.75" Coil Tubing in Injector. Install night cap on BOP's. Safe out location and suspendd operations for the night. Arrive on location, sign in, obtain work permit and hold pre-job safety meeting for coil tubing operations. Install G&G external grapple type coil tubing connector (CTC) Pull tested CTC, unable to locate pull test plate, utilize pump-out plug centralizer to pull against injector quick union, pull 5k, good test. Still unable to locate test plate, send BJ hand to shop to look. Have G&G start manufacturing new test plate. Informed that new test plate is at least 2 hours away, send hand to BOT and Weatherford to look for some way to x-over. Waiting on G+G Machine to finish building CT pressure test plate. Test plate on location, PT CTC. CTC leaks at both low and high (250 psi and 1500 psi) Pipe is out of round, 1.70" od to 1.73" od. Start cutting coil to look for good pipe. 100' of coil cut, no change. Discuss options. Decision made to cut 2100' +/-and remove field butt weld, get to good pipe. Secure location and well for night. Arrive on location, sign in, obtain work permit and hold pre-job safety meeting for coil tubing operations. Review JSA for blowing down coil w/ Printed: 11/2/2007 12:58:28 PM I • • Marathon Oil Company Page 3 of 4 Operations Summary Report Legal Well Name: KENAI UNIT 21-6 Common Well Name: KENAI UNIT 21-6 Spud Date: 8/22/2001 Event Name: WORKOVER Start: 7/20/2007 End: Contractor Name: BJ SERVICES Rig Release: Group: Rig Name: BJ SERVICES Rig Number: CT2 I Date I From - To Hours Code Code Phase Description of Operations 8/24/2007 07:00 - 07:30 0.50 SAFETY MTG_ CTBG n2 and cutting coil w/ elec. Ports-band saw w/ BJ crew. The purpose of cutting the coiled tubing is to remove the field butt weld from the remaining portion of the string before it is installed in the well as a velocity string. The secondary purpose is to find a portion of this used string that is not as oval and will accept a grapple coil connector to form a pressure seal. 07:30 - 08:45 1.25 RURD_ COIL CTBG Pull night cap, p/u injector and go to well to blow down coil. 08:45 - 09:00 0.25 RURD_ COIL CTBG Online w/ n2, 500 scf/m for 11 min. 5700 scf total. 09:00 - 10:00 1.00 RURD_ COIL CTBG Bleed off n2 from coil. Set up to cut coil. 10:00 - 13:15 3.25 RURD_ COIL CTBG Start cutting coil into 20' lengths with ports-band saw 13:15 - 13:30 0.25 RURD_ COIL CTBG Field butt weld @ horses head @ 2,062' 13:30 - 13:45 0.25 RURD_ COIL CTBG Cut out butt weld, pull up to 0' point. Counter reads 2,126' + 100' cut previously (2,226' cut and 3,890' still on reel). 13:45 - 14:00 0.25 RURD_ COIL CTBG Set up to install G&G external type 1.75" CTC. Pull test CTC to 5k. 14:00 - 14:20 0.33 RURD_ COIL CTBG Fill coil w/ fresh H2O to test CTC using 7.8 bbls. total. PT CTC 200# low, 2000# high, good test. 14:20 - 16:00 1.67 RURD_ COIL CTBG Cool down n2 unit to blow down coil. Go to well w/ injector. Online w/ n2, 500 scf/m for 5 min. 2500 scf total. S/D n2, bleed off coil. 16:00 - 16:30 0.50 RURD_ COIL CTBG Pop off stack, secure well and location for night. 8/25/2007 07:00 - 07:30 0.50 SAFETY MTG_ CTBG Arrive on location, sign in, obtain work permit and hold pre-job safety meeting for Installing and Testing Lubricator, and coil tubing operations. 07:30 - 08:15 0.75 RURD_ COIL CTBG Nipple down night cap. Pick up injector head. 08:15 - 09:00 0.75 RURD_ COIL CTBG Make up BHA, LxO.D.xI.D. Pump out Plug - .166' x 2.4" x n/a Centralizer - 1' x 3.5" x 1.437" No-Go - .729' x 2.5" x 1.437" Straight Bar - 10' x 2.5" x 1.9" G&G CTC - .687' x 2.63" x 1.5" 09:00 - 09:30 0.50 TEST_ BOPE CTBG Go to well w/ injector head. PT stack down the backside. 09:30 - 10:30 1.00 TEST_ TBG_ CTBG Misc. leaks at x-over flanges, chase down and tighten all. 10:30 - 12:00 1.50 RUNPU COIL CTBG Well head open with 129 psi. RIH w/ BHA and 1.75" Coil Tubing Velocity String to 3290' MD. 12:00 - 12:30 0.50 WAITON EOIP CTBG Wait on Vetco wellhead personnel. Held PJSM. 12:30 - 14:00 1.50 RUNPU COIL CTBG Proceed with cutting coil to install hanger assembly. 14:00 - 15:00 1.00 RUNPU COIL CTBG M/U 1.75" dimple connector, 3.80" centralizer and GS spear to coil. 15:00 - 16:00 1.00 RUNPU COIL CTBG Stab GS spear into hanger assembly, walk injector down, and nipple up to BOPE's. Land hanger @ 3,285.5', hanging wt. = 5,700#. Run in lock down pins, pull 10k, pins not in yet. P/U, get wt. back and RIH to 3,285.9', run in pins and pull 10k#, looks good. PT hanger to 5k psi, hold for 10 min. Bleed off to 4,900#, good test. 16:00 - 17:30 1.50 RUNPU COIL CTBG On line down coil to release spear, stack 5k down, psi to 700#, /p u and release from han er. Pop off well, lay down GS spear, go back to well w/ injector. Set up to displace water from coil to flow back tank. 17:30 - 19:30 2.00 RUNPU COIL CTBG N2 pump overheated, shut down, regroup. Close blind shear rams, line up to shear pump-out plug. On-line w/n2 @ 500 scf/m, whp= 130#. Well head won't pressure up, check things out. N2 line is froze from check valve to ground, put heat on to thaw enough to be able to safely break down hardline. Printed: 11/2/2007 12:58:28 PM . • M • Marathon Oil Company Operations Summary Report Legal Well Name: KENAI UNIT 21-6 Common Well Name: KENAI UNIT 21-6 Event Name: WORKOVER Contractor Name: BJ SERVICES Rig Name: BJ SERVICES Date ~i From - To I Hours I Code it Code Phase i 8/25/2007 19:30 - 20:00 0.50 RUNPU COIL CTBG ~~ 20:00 - 20:30 I 0.501 RUNPULI COIL I CTBG Page 4 of 4 ~ Spud Date: 8/22/2001 Start: 7/20/2007 End: Rig Release: Group: Rig Number: CT2 Description of Operations All gauges reading zero, have communication from pump to flowback tank. Break down and clear out remaining ice and water. PT lines to 2k, open up to well and pump @ 500 scf/m, whp = 130#. Plug sheared out @ 1,075#. Close swab, open blind shears and use remaining n2 psi to purge coil to flow back tank. ND injector head. Secure well and location for the night. Printed: 11/2/2007 12:58:28 PM . . MEMO WELLS PRODUCING IN KENAI, STERLING POOL 6 AS NATIVE & STORAGE GAS WELLS Reference letter in file dated October 25, 2006 about wells producing from the Kenai, Sterling 6 Pool (pool code 448568) and the Kenai Pool 6 Gas Storage (pool code 448809). Storage Injection Order 7 A has a report, 2007 Annual Gas Storage Performance Evaluation dated March 2, 2007 which has a statement with an official start date of May 8, 2006 where storage started in the pool. There was no formal paperwork submitted about this change so this letter is for the official well status date change for the well status or date it was accomplished by AOGCC. The following is a list of wells that is reported with both pool codes 448568 and 448809: APD No. 201-097 201-231 159-013 165-007 178-055 168-071 181-092 181-154 182-015 182-085 184-109 185-181 200-148 Well No. 21-6RD 43-6RD 34-31 33-32L 44-30L DU5-L 14X-6AN 34-32L 14-32L 13 -6L 23X-6SAN 33-7S 31-7X I 0 ?y/l -O~ r!: J.-. ,,-( ;) Co SCANNED JUL 272001 . . SARAH PALIN, GOVERNOR AIJASIiA. OILAl'O) GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dennis M. Donovan Production Engineer Marathon Oil Company P.O. Box 1949 Kenai, Alaska 99611-1949 Re: Kenai Gas Field, Sterling Pool 6, KU 21-6RD Sundry Number: 307-246 SCANNED JUL 2 3 2007 Dear Mr. Donovan: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, o Daniel T. Seamount Commissioner DATED this2 Ó day of July, 2007 Encl. dDl-cP\1' , . . Marathon Oil Company Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AI< 99611 Telephone 9011283-1326 Fax 907/283-1350 July.18,2007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7111 Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice Field: Kenai Gas Field, Pad 34-31 Well: Kenai Unit 21-6rd RECEIVED JUL 1 9 Z007 Alaska Oil & Gas Commìzsion Am::hQfat¡ø Dear Mr. Maunder: KenallJnit2h6îs a Conventional Well with Pool 6 Sand op$n to production. Production has notb~en strong enough to keep the well unloaded at the Baker liner Hanger @\3295' while flo\Aiinø . up the annulus. Currently there is .a 2-3/8" CT String @ 5255'; this is used occasionally to unload fluid. We intend to remove this string and replace it with a 1.75" String rurl to +/-3290'. This will aid the liquid loading problems at the hanger, due to the large unload rate heeded to de-water 7-5/8" casing. We hope that We~reable to $tart this work within the next week. I n order to complete this jobwe needed to rent a 1"BOP from out of state. As of this week, the BOP has come in. Oncestarted,thework should not take more than one week's time. If you have any que$tions or need further information please call me at (907) 398-1362. Dennis M. Donovan Jr. Production Engineer Enclòsures; 10-403 Sundry co: AOGCC Current Well Schematic Houston Well File Proposed Well Sçhematic Kenai Well File KU 21-6 V-string Replacement Program DMD KJS CPI1/¡Ø-1fI ~ REC IVED STATE OF ALASKA f JUL 1 9 7 ALASKA 011.. AND GAS CONSERVATION COMMISSION ~ IJo ' APPLICATION FOR SUNDRY APPROVALS i~! ,;ka Oil &. Gas Cons. CommisslOo 20 MC 25.280' 3", Operational shutdown 0 Perforate 0 Waiver 0 i ".' Other 0 Plug Perforations 0 Stimulate Time Extension 0 Perforate New Pool 0 Re-enter Suspended Well 4. Current Well Class: 5. Permit to Drill Number: Development 0 Exploratory 0 201.097 '" Stratigraphic 0 Service 0 6. API Number: 5G-133-100go..,o1.o0 /' . Abandon 0 Alter casing 0 Change approved program 0 2. Operator Name: Marathon Oil Company PO Box 1949, Kenai Alaska, 99611·1949 7. If perforating. closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 9. Property Designation: A- 028142 Description Summary of Proposal 0 $ Program BOP Sketch 0 Date for Commencing Operations: 17. Verbal Approval: Commission Representative: 18. I hereby cerIify that the kJregoing is true and correct to fue best of my knowledge, Contact Printed Name Dennis M. Donovan Title Production Engineer Signature Phone Date (907) 283-1333 1. Type of Request: 3. Address: 12. Total Depfu MD (ft): 6,660' ' Casing Structural Conductor Surface Intermediate Production liner Perforation Depfu MD (ft): 5,250'.. 5,310' Packm and SSSV Type: 13. Attachments: Suspend Repair well 0 Pull Tubing 0 Install 1-314" Tubing 8, Well Name and Number: KU 21-6RD / Total Depfu TVD (ft): 4.884' . Length No [;2] 10. KB Elevation (ft): 11, FieldlPooI(s): 21.6' Kenai Gas Field 1 Sterling Pool 6 r PRESENT WELL CONDITION SUMMARY Effective Depfu MD (ft): Effective Depfu TVD (ft): 6,563' - 4.803' Plugs (measured): Junk (measured): NA NA Collapse Size TVD Burst 61' 1,282' 51' 1,237, 1,820 psi 880 psi 20" 51' 1,282' 10-3/4" 5,620' 7.518" 2,200' 4-1/2" Perforation Depfu TVD (ft): Tubing Size: 4,536' - 4,585' 2-318" 5,620 4,836' 5,650' 4,884' Tubing Grade; 4,140 psi 2,890 psi 7,780 psi 7,010 psi Tubing MD eft): HQ-70 5,255' NA Packers and SSSV MD eft): NA Service 0 Abandoned 0 0 WDSPl 0 71221200 14, Well Class after proposed work: Exploratory 0 Development 16. Well Status after p~ work: Oil 0 Gas[;2] WAG 0 GINJ 0 o Date; Plugged WINJ Kevin Skiba (1107) 283-1371 7/1912007 COMMISSION USE ONLY Conditions of approval: Notify Commission so fuat a representative may wilness Sundry Number: ~~ ., cfJ.% PlUg '~tegrity 0 BOP Test 'þll. Mechanícallntegrity Test ~ Other. 4.50 0 ~") \ {S'êJ V' -\e:~-\- û..~ ?\o.."N;J Location Clearance 0 RBDMS 8Fl JUl 2 3 2ßD7 Sub$equent Form Required: 40,-\ Approved by: COMMISSIONER Form 10-403 Revised 0612006 ORIGINAL ì Liner at 3295' No- . . ~ MARATHON Oil COMPANY AlASKA REGION Kenai Gas Field KU 21..6rd 2001 Velocity String Removal and Hangoff ProœdureC07-17-2007} WBS# Notes: · This proCf3durøcòvers WOrk to remove a 2-3/8" co.íI tubing velocitystling and install a 1.75" coil tubing velocity string at a shallow~r depth to alleviate liquid loading. · COntact Vetcopri~r to ¥IR\J to verify maximum hanger he~d ID & mandrel 00 measurements. BJ goUTech su~rvisorwill drift all WH connections prior to rig up to insure drift 10 of individual connections. · Gand GMachinewill build a 1..3/4» BHA with Pump-off plug~nd Shear Plug Installed 1. Ta~ Fill and Bail Sand If Needed. MIRU Pollard Wireline. Hold PJSM. Set 1.187" Blanking Plug (No-go) @ 5255'. Bleed off Coil Tubing and verify installation with a Negative Test. 2. Concentric Coil Tubing Head. Is installed 3. Flowline modifications for coil tubina strina. Is installed 4. MIRU MOC flow back eaui )ment including open-top flowback tank, choke skid, gas buster, and flow back iron. MIRV closed-top 500 bbl Rain-for-Rent fluid supply tank. Lay liner and berm area around tank. Load fluid supply tank with 6% KCI and heat as necessary. Deliver diesel fuel manlìft and two light plants. Remove well house and lock out electrical connections. Removal of 2-3/8" CT 5. MIRtJl3Jc6iled<tubiriaUnit wíth a 2-318" coiled tubing stinger string. Rig up fluid and N2 pumps. RU pumping iron and flow back iron. .6. Ni~øle.u~BJCTwélJheådas$emblv{WHA). WHA to includØ 4-1/8·.. 5M X..7-1/16" -10M DSA. 4- 1/16"-10i\ß )(5' Flan~~? Riser. 7.,1116" - 10M flow cross. and 7-1/16" ..10M Dl.Ial-Combi BOP (dressed for 2-3/8" CT).Functiontest BOP. Stab 2-3/8" CT into injector. Install G&G Coil Tubing BHA and pull test..· Nippl~l.!p injøctor to WHA. PréSSure test surf œ/lnésand CT..e ui tnent with 6%KCL water. Pressure test pump iron (200 hiShpsi).Pl.!rnpfh.iidtg loadcr, Pressl.!r~ te$t CT, WHAand flow back iron to choke manifold /4500 psi). Pressu~ test~OP rams (200/4500 psi). Purge pressure test fluids wI N2 to floWback tank and vent N~pressure to flowback tank. 8. MU. Saker GS Runnin~ToOI. Swing InJector and lubricator away from WHo BJ CoilT ech to connect Baf<er GS tool string assembly to coil 0.0 reel trailer. Dimpl~-on a 2-318" CTconnector. Pull test CT connector (25,000 Ibs.) using a pull plate. . . Page 2 of3 9. Nipple UP injector to WHA. Pressure test WHA using CT kill line (200/1500 psi). Bleed WHP to flow back tank. Prior to next Step, ensure that flowback line from WHA through choke manifold to gas buster is ready and available to keep TP at or below 1500 psi while RIH to eliminate possible CT collapse. This would serve as a backup if flow through the production flow line was unexpectedly curtailed or ceased, 10. RIH with 2-318" coil tubing stinger string and latch Vetco Coil Tubing Hanger Assembly. Well is able to flow to sales up annulus (if desired). 11. latch GS spear to Vetcc? mandrel and pull additional weight to verify GS is latched. Per BJ and Vetco Procedures: Loosen Lock Screws and PU Mandrel. Pull String up hole and through BOPE's. 12. Set CT in BOP tubing/slip rams. Lock tubing/slip rams. Slack off injector chain traction and roll chains to verify slips are set. Release WHP above tubing rams to the flowback tank, Nipple injector off of WHA. Walk injector up CT. Install C plate above BOP and 2-3/8· polish rod clamp on CT. Remove CT connector, hanger mandrel, and GS Spear. Connect roll-on connector and pull test to verify. 13. Reel 5255' of 2-318" Coil onto Work Reel. Close well at Swab Valve. Release WHP above Swab Valve to the flowback tank. Nipple injector off of WHA. Installation of 1.75" CT 14. ~IRU BJ coiled tubing unit with 3800' of 1.75" coiled tubing (Old BJ CT Work String), 15. MU CT 1.75" CT BHA. Nipple injector offWHA. PU 10' of 4-1/16" CO lubricator. MU velocity string BHA to end of CT. 16. RIH with 1.75" Ç9i1 tubing velocity string and BHA with well flowing to sales up Casing by 1,75" annulus (if desired). 17. Cut coil tubing. PUH to span WHA for final landing depth of +/- 3290' Lock tubing/slip rams. Slack off injector chain traction and roll chains to verify slips are set Release WHP above tubing rams to the flowback tank. Nipple injector off of WHA. Walk injector up with Boom. Install C plate above BOP and 1.75" polish rod clamp on CT. Cut CT above BOP high enough to allow Vetco to install CT connector and hanger mandrel assembly. 16. MU Vetco CoiJ Tubing Hanger and Baker GS Running Tool. Swing Injector and lubricator away from WHo Vetco to connect VGCT Coil Tubing Hanger to hanging coil tubing with coil grapple. While Vetco is making up CT hanger, BJ CoilTech to connect Baker GS tool string assembly to coil on reel trailer. Dimple-on a 1-3/4" CT connector. Pull test CT connector (25,000 Ibs.) using a pull plate. 19. Latch GS spear to Vetco mandrel after PU injector. Remove 1-314" polish rod clamp and C-plate from top of BOP. Walk injector down CT and nipple injectorllubricator to top of BOP. Pull test CT mandrel connection/GS spear assembly to CT string weight plus 5,000 Ibs. Slack off weight to CT string weight. Equalize WHP across tubing rams. Unlock tubing/slip rams. Open BOP tubing/slip rams. 20. RIH and land Vetco CT hanaer per Veteo procedures. Verify string and hanger are landed and secured per Vetco procedures. Slack off string weight to neutral. Tighten Lock $crews. Pressure test hanger between Seals to 5000 psig with hand pump pressure test unit (Vetco Supplied). Tighten Lock Screws. 21. Release (is Running Tool. Sit down weight on Hanger. Start pumping 6% KCL water at approximately 2 BPM through CT to release GS spear. Watch for weight change to vetify release and pickup to unlatch spear. Stop pumping when spear is unlatched and above mandrel. GO#3 CT Velocity String Hangoff Procedure DMD perKDW -7/18/2007 10:41:54AM . . Page 3 of3 . 22. Pumo N2 down 1-3/4" Velocity String until both plugs shear and fall to bottom of well. Vent the N2 to a Flowback tank and monitor the LEL When methane is detected send well to production facility. 23. Pume KCL water from CT remaining on reel trailer with nitroaen. Allow N2 to vent to flowback tank. 24. RDMO and release eauipment. RD flowback iron. Release tanks and all rental equipment to vendors, CONTACTS Dennis Donovan: 907-283-1333 (w) 907-398-1362 (cell) Lyndon Ibele: 907-565-3042 (w) 907-748-2819 (cell) ER ENCY CONTACTS: o erators: 907-283-1305 Emeraencv Dial 911 GQ#4CT Velocity Sbing Hangoff Procedure David Martens: 713-296-3302 (w) 832-4 72-6249( cell) DMD per KDW - 7/18/2007 10:41:54 AM e (.M~ Marathon MARATHON Oil Company e Alaska Asset Team United States Production Operations P.O. Box 3128 Houston, TX 77253 Telephone 713-296-3597 Fax 713-235-6322 July 2, 2007 FEDERAL EXPRESS Alaska Oil & Gas Conservation Commission Attn: Howard Okland 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RECEIVED JUL 0 3 Z007 RE: Marathon KU #21-06RD - API 50-133-10090-01 CONFIDENTIAL Alaska Oil & Gas Cons. eommission Anchorage Dear Mr. Okland: 1Þ ) )~~O Enclosed is one CD containing confidential digital well data for the above referenced well, as described on the attached CD Contents document. Please indicate your receipt of this data by signing below and returning one copy to my attention at the letterhead address or fax to 713-235-6322. Thank you, ~~ sCANNED JUL 0 5 2007 Courtney McElmoyl Received by: VðJ1A 3 Jlu~ l~ 7 '" Date: Enclosures ~O{-ocr7 Directional Data: ~ . iku_21-6rd_diu:ur ,dat : ...... .........................................................". Mudlog Data: I!ffi...........................................................................' . m~~..?.~.~~~..~.~.~ð.~..~~~º~.!.:.~g.~..j [ KU21-6X Remar~, txt ~KU21-6x,las e e KU 21-06RD API 50-133-10090-01 CD CONTENTS Confidential · AlaSka. Team Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 October 25,2006 Alaska Oil and Gas Conservation Commission Attn: Steve McMains 333 W. 7th Street, Suite 100 Anchorage, AK 99501 ,~ (" (:,,t . ...;c ~,t..\~ ,C.~"'\ ""·",,,;~rcn;.e.;.,.,,! RE: Wells Completed in Pool Codes 568 and 448809 Dear Steve, Per your request, this letter is being provided to the AOGCC to identify wells completed in the Kenai Sterling Pool 6 (Pool Code 568) and the Kenai Pool 6 Gas Storage (Pool Code 448809). As you are aware, the above pool codes refer to the same geologic reservoir, a partially depleted gas reservoir which is being used for gas storage operations. Subsequent to the initiation of storage operations in May 2006, all future production from this reservoir is allocated between the remaining native gas and the injected/stored volumes, per written agreements between Marathon Oil Company and both the ADNR and the BLM. Therefore, any production from the wells completed in Pool 6 will be reported monthly on Form 10-405 under both pool codes. The wells appearing on Form 10-405 will appear the same for both pool codes. Per your request, the following is a list of wells which will be reported on Form 10-405, for both Pool Code 568 and 448809: Well No. 21-6RD 43-6RD 34-31 33-32L 44-30L DU5-L 14X-6AN 34-32L 14-32L 13-6L 23X-6SAN 33-7S 3 1- 7X API No. 5011331009001 5011331009101 5011331009700 5011331009800 5011332013900 5011332031900 5011332034200 5011332034800 5011332035100 5011332035600 5011332037100 5011332038000 5011332049500 APD No. 201097 201231 159013 165007 178055 168071 181092 181154 182015 182085 184104 185181 200148 . . Please advise if you have any questions or need any additional information. I can be reached at 907.565.3041 or lcibele@marathonoi1.com. yndon Ibele, PE Production Coordinator Cc Randy Jindra, IBM, Tulsa Ken Walsh, MOC, Kenai Marathon Houston Central Files Brian Havelock, ADNR, Anchorage Greg Noble, BLM, Anchorage e e r . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marlœr.doc Jî DLv DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 Permit to Drill 2010970 Well Name/No. KENAI UNIT 21-06RD Operator MARATHON OIL CO Sflu.J. ,J / ~ ~ I API No. 50-133-10090-01-00 MD 5650 ,.. TVD 4884 -- Completion Date 11/27/2001 /'- Completion Status 1-GAS Current Status 1-GAS UIC N --------~_-___n__~ REQUIRED INFORMATION ---------~--- ---- Mud Log No Samples No Directional Survey ---- --- ~y .--.... DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: -- ---- - ---n (data taken from Logs Portion of Master Well Data Maint) ~" Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Log Log Run Scale Media No Interval Start Stop OH/ CH Received Comments Well Cores/Samples Information: me Interval Start Stop 3470 5650 Sent Received Sample Set Number Comments Cuttings 1110 --- ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? ~.' N - Daily History Received? '&)/N ŒJN Formation Tops Analysis Received? ~ -""""'ho Comments: --- ---~- --- ----- .-- -n- --- Compliance Reviewed By: p -- - ___n_- Date: ~Å_Ù ~ > ~~ b v'Z - .¡z ~T' - tc.. t.- ~~ ~ ~ AUG-20-2003 WED 02:14 PM MARATHON OIL COMPANY r {, FAX NO, 907 283 6175 P, 03 ( O_\EXCCLIAOCCW¿¡' "1ì~/ ÙfJ() 3 8T ATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon - Su$pend - Operation Shutdown - Re-enter Suspended Well- Alter Casing - Repair Well - Plugging - Time Extension - Stimulate ~ Change Approved Program - Pull Tubing - Variance - Perforate - Other l ¡/' 6. Type of Well: 6. Datum Elevation (DF or KB) Development X Exploratory ~ Stratigraphic -- Service -- - 1. Typ~ of Request; 2. Name of Operator MAI~THON OIL COMPANY 3. AddreS!> ~. O. Box 195~68, Anchora~e, AK 99519-6168 4. Location of Well at Surface 5151 N & 2089' W of SE Corner of Sec. 31, T5N, R11W, S.M. At top (If ProductìvB Interval 900' S & 22051 E Of surface At EffeGtive Depth Raise Tubing Tail Al Total Depth 989' S Be 24571 E of surface 12. Present Well Condition Summary Total Depth: mQasured true vertical 5650 feet 4884 feet Effective Depth: rneasured true vertical 5563 fe~t 4797 feet Casinø Structural Conductor Sur'face Intermediate Pmduction LIner Perforation Depth; Length Size 51' 1282' 20" 10-3/4" 84 feet 7, Unit or Property Name Kenai Unit 8. Well Number ("'" KU 21-6rd 9, Permit Number "" 201-097 / 10. API Number so~ 133-10090-01 11. Field/Pool KenaI Gas Field, pool 6 .¡' Plug$ (measured) Junk (measured) Gun anchor at 5510' Cemanted Measured Depth True Vertical Depth Driven 750 sks 51' 1282' 51' 1237' meç:lsured 56201 7-6/8" 700 sks 2264' 4-1/2" 265sks Starling Pool 6 Sand: (11/27/01) 5250'.5310'MD w/Z-1/2" Milleneum StimGun, 6spf, 60 deg & 2 7/8" PJ HSD Guns, 6spf, 60 deg 4544'.4595'TVD true vertical 5620' 5650' 4&.36' 4884' ¡ 2-3/8",0,134" wall thîckne$s, HO-70 coiled tubing @ 6255' MD II '!,,' : 'I"', , Nam(~ of Approver Date Approved Service 17. I hef('by ce '\tifY mat the foregoinQ Is true and correct to the best of my knowledge. . \ I' - ,~~ ) ~ 1\ /. ~ -- Title Production Engineer '; "I '7 FOR COMMISSION use ONLY Conditions of Approval: Notify Commis$Ion so representative may witness Plug Integrity BOP Test Location Clearance Mechanicallnte;lty Test Subsequent Form Required 1 Q- ~ Test "ßo~ E To ~SDo P Ç. ~ Mkl»tL,{Ui.. ApprOV~,d by Order of the CommissIon J ~ ~ ~~ ~ Fornj 10.~O~~ Rev, 06115168 Tubir'i1 (size, grade, and measured depth) F'acl<.f:rs and SSSV (type and measured depth) N/A 13. Altachrncnts Description Summary of Proposal- 14. Estirñ~ted Date for Commencing Operation 8/21/2003 16. If ~roposal WàS Verbally Approved Signed RtBDMS arl AUG 2 u '2mB Detailed Operations Program 2.. BOP Sketch - 15. Status of Well Classification as: Oil Gas X Suspended - -- ~ Date 8/20/2003 Approval No. 303- ;(147 Commissioner Date ~ /lit OJ Submit in Triplicate ORIGINAL AUG-20-2003 WED 02:14 PM (^qATHON OIL COMPANY FAX NO, 9(7 283 6175 P, 04 BJ Coiltech Kenai, AK Marathon Oil Co. Kenai Gas Field, Pad 21-6 Well KU21-6rd Objective Well KU21-6 is currently conlpleled as a 9-5/8" production casing (PBTD = 5580' MO) with a 2-3/8" coiled tubing (WT = 0.134") velocity string set at 5285' MD. The 2-3/871 velocity string will be pulled up hole 2000' +/- and re.htlng using existing ABBNetco hat1gcrhead. Procedure L MIRV BJCT. Spot spooling unit al1d load wooden spool containing 200' (minimutn requirenlCtÜ) of 2.3/8" coiled tubing (CT) tailpipe. CT on wooden spool will be equipped with 3" )502 WECO thread ha1fto allow pumping operations through CT. Spot Control Cab unit, fluid pnn1p and rig in hose packs. 2, Nipple up wetlhead assel11bIy and slab 2-3/8" CT. PU i1'ljeetor t\nd spot 50 BBL catch tank below injector with pig catcher set-up at tank top hatch, Pump c]eaning and po lishing Hippo pigs through coiled tt.lbing stinger string according to pig manufactures specifications 3. Make lLp OS prolílc tool string. PlLll test CT connector (30,000 Ibs 4. Pressure test BJ pump iron and flow back equiplnent (200/2500 psi). BOP will be tested at BJCT yard prior to CTU nl0bili1.ation (200/5000 psi) using test bar and ../ stand. 5. Rig injector to WH and pressure test WHA. (200/1500 psi) Release pressure to flow back tank. Opel'!. swab valve and release velocity string pressure to flow back tank. (2- 3/8" velocity string is isolated frO111 BHP, prior to CTU rig up with a wireline deployed dart) ó. RIH and latch \lP GS profile retrieval string to ABB/Vetco nlandrcl. pun test to01 string to string weight + 10,000 Ibs. (27,000 Ibs. +/-). 7. Release ABB/Vetco ll1alîdrcl, pick up (PU) 2-3/8" string until mandrel assembly is across 7" window access area. Set BOP slip/tubing rams. Slack off string weight and ved(y slips arc holding 2/38" CT. Bleed WHP to flow back tank and verify tubing ranlS are iso1ating WHP. 8. Open 7" window. Install slip bow] and 2-3/8" spider sUps with 2-3/8" dog collar backup. Cut 2-3/8" CT with pipe cutters bclow Vetco mandrel grapple connector. Njpple down injector and too) string assen1bly. Remove as tool string ar\d Vetco ]Tlandrel ass01ubly fro111 CT. (Vetco personnel will redress mandrel assembly and BOT will redress OS too1sLring). 9. Make up BJCT dimple-on spoolablc connector at injector end of CT. Nipple up injector to WHA. 10. Reconnect CT cnds with alCT dimple-on spoolablc connector. Pull test spoolabJe connector (27,000 lbs.) (verify pjpe wall thickness at each end). AUG-20-2003 WED 02: 14 PM(ß"qATHON OIL COMPANY FAX NO. {~~ 283 6175 P, 05 11, Remove dog collar, slips and slip bowl from 7" window. Close window. Pl\l1 test ~poolable connector (27,000 Ibs.). Equalize pressure across slip/tubing ranlS, PU to string weight. Open s1ip/tubing rams. 12. POOH 2000 fl +/- plus Hanger Hcad to Window height. 13. Set BOP slip/tubing rams. Slack off string weight and verify slips are holding 2/38" CT. Bleed WHP to flow back tank and verify tubing rams are isolating WHP. 14. Open 7" window. Il1stall slip bowl and 2-3/8" spider sJips with 2-3/8" dog collar backup. Cut 2-3/8" CT with pipe cutters. Nipple down injector fronl WHA. IS. Install ABB/Vetca mandrel on WH end of CT. Make up OS profile toolstring on injector end of CT. Pressure and Pull Test GS profile toolstring. 16, PU injector. Nipple to WHA. RlH and latch Abb/Vetco nlandrel assen1bly. pun test (27,000 lbs or to ABBNctco specifications). 17. Remove dog collar, spider slips and s1ip bowL Close 7" Window. 18. Equalize across slip/tubing raIns. PU to string weight. Open slip/tubing rams. 19. RIH slow1y lowering CT until nlandrel scats 111 hanger head. Secure Inandrcl in hanger head. Pressure test hanger head/mandrel assembly according to n1anufaciurcrs t'L11d Marathons speclfieatiol1s. 20. Rig up pUll1ping iron to CT at wooden spool window, Pump 0.25 - 0.50 BPM to release OS profile, PUH above swab valve. Sf Swab valve. Unload CT wi N2 to flow back tank. 21. RDMO. 20" 78.6# DrvPipe @ 51' I 103/4",32.75#, H-40, STC @ 1282' cmt wi 750 sx class A 7 5/8", 26.4 #, J-55, LTC csg (exited at 3450') Pool 6 [C-1 Sand] L ~ :( (M) KU 21-6rd Pad 34-31 Alaska Region I Baker Liner hanger at 3295' 2-3/8" CT velocity string to 5255' CTM w BHA: BST Lift Profile nipple wi 1.187" No- '." go and Profiles for blanking plug or , , standing valve. "..' 1i.} ;~. ..i~ ,. ~ ': -.' í~~ Perforated 11/27/01: 5250'-5310' d~~~ Shot wi 2500psi overballance . ~-'--- (N2 pressure) v :1::: 2 1/2" Milleneum StimGun, 6 spf ~,:~ Re-perfed 12/6/01: 5250'-5310' /i wi SLB 2 7/8" PJ HSD Guns, 6spf :~ :::", ,," :4' ~ñI! l' ':i; ~!~ 4 1/2" 12.6 ppf L-80 Mod Butt Cemented Liner .~: ,,<'" . ' ",,':' .~.. "" -::~i :"" ,. Fish: Gun anchor @-551 0' ',"~~. ~~: ~..: i'l:ï .~.. ~.II < ... "~¡: o:~,:" PBTD=5563'MD TD=5650' M 0/4884 TVD 20" 78,6 # DrvPipe @ 51' I 10 3/4", 32.75#, H-40, STC @ 1282' cmt wI 750 sx class A if 7 5/8", 26.4 #, J-55, LTC csg (exited at 3450') Baker Liner hanger at 3295' Pool 6 [C-1 Sand] ::, ":I~'I',,:i':."""'I'~t'::""" ,: " ,.:,...,..:',.:,.,:~ I '""',:"',, :",..::,":;,<"""1,::;':"',:,, .",:::, ,Perforated 11/2:101: 5250'-5310' I.'",.',.: ,',' ",:..""'~":::""~I:,:,,,:, :..,.': .¡~r,' .. Shot wI 2500psl overballance '" ."; ",':: 'I"::,""'" ::"iI:"},' '(N2pressure) " ¡~ 2 1/2" Milleneum StimGun, 6 spf t Re-perfed 12/6/01: 5250'-5310' !.:s wI SLB 2 7/8" PJ HSD Guns, 6spf ,,~ I~ ~ :)i!II ~: ~ J: 'j\ 4 1/2" 12.6 ppf L-80 Mod Butt ,:.ï c Cemented Liner Fish: Gun anchor @-5510' ,::( ~, 'M') KU 21-6rd PROPOSED Pad 34-31 Alaska Region I 2-3/8" CT velocity string to 3290' CTM BHA: BST Lift Profile nipple wI 1.187" No- go and Profiles for blanking plug or standing valve. PBTD=5563'MD TD=5650'MD/4884'TVD AUG-20-2003 WED 02:13 PM ~ARATHON OIL COMPANY ( FAX NO. ~D7 283 6175 P, 02 ~ ¿~) Marathon MARATHON Oil Company Alaska Business Unit Domestic Production P,O. Box 196168 Anchorag91 AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 August20,2003 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 Reference: KU 21..6rd Dear Mr. Aubert: Enclosed is the 10-407 Well Completion or Recompletion Report and Log for work which will change the existing configuration of the KU 21-6rg,wellbore. The scope of the procedure will be to pull and shorten the existing velocity string. The 2-3/811 coiled tubing is thought to act as a choke in the 4-1/2" liner section of the well. The end of the coiled tubing velocity string will be just above the liner hanger. This work is expected to begin 8/21/03. If you need any additional information~ I can be reached at 907-283-1333 or by a-mail at dmtitus@marathonoil.com. s¡nr Denise M. Titus Production Engineer Enclosures ..-, : . ~"'" 11 0',' ,,', (,'" ' (¡ '," ~_:,I}] ""~ (',',) ORIGINAL ..",' ~f l Alaska ~ less Unit Marathon Oil Company P.o. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 September 20, 2002 Alaska Oil & Gas Conservation Commission Attn: Howard Oakland 333 w. ih Avenue, Suite 100 Anchorage, AK 99501 VIA COURIER RE: Marathon Kenai Unit #21-6X - CONFIDENTIAL Accompanying this letter are four (4) boxes of CONFIDENTIAL well samples for the above referenced well, as described below Box # Depth To Depth 1 3470 - 4080 2 4080 - 4760 3 4760 - 5460 4 5460 - 5650 Please review the enclosed data, sign and return one copy of this transmittal. Thank you, f(t~/~ Kaynell zema1~ð " Technical Assistant Attached (4 boxes) Received by: Date: tJJLJ ~~\- ~0 7 1:\ II ¿r(; Environmentally aware for the long run. wJ.(, ~' (t- ( aol-OCf 7 (' Alaska Region Domestic Production Ma rathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 February 7, 2002 RECEIVED Steve McManes AOGCC 333 West 7th Ave. Suite 100 Anchorage, AK 99501 FEa 0 8 2002 Alaska Oil & Gal ConI. Commiasìon Andlorageô Re: KU 21-6rd (formerly KU 21 x-6) Subject: Well re-naming Dear Mr. McManes: Marathon Oil Company requests that Well KU 21-6x be re-named as KU 21-6rd. This name is consistent with our new convention for naming sidetracked wells. If you have any questions concerning this matter, please contact me by phone at 564-6317 or email at DMTitus@Marathonoil.com. Sincerely, L~JÞ Denise M. Titus Production Engineer ~~ ~ ~ ~ ~ Me- fÝ/~ r:é.h ~J Od I (' ~J¿.O ~-. -e'l]:7 Alaska Region Domestic Production Ma rathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 February 8, 2002 RECEIVED ~ E:S 0 R 2002 Alaska Oil & Gas COOS. CcrøI8Iiam Anchorcve ~ Î'-, ¿- ('" ~ ~é/ ~- -p ~ i C. ( t) \ ~ ~: Mr. Steve Davies Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: KU 21-6rd Permit Number: 201-097 Dear Mr. Davies: ^ \.. Enclosed is the form 10-407 WELL COMPLETION OR RECOMPLETION REPORT AND LOG form for Marathon well KU 21-6rd. If you need any additional information, I can be reached at 907-564-6317 or bye-mail at dmtitus@marathonoiLcom. S~eIY~ Denise M. Titus Production Engineer ) if " ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OILD GASŒ] 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 515' FSL, 2089' FEL, Sec. 31, T5N, R11W, S.M. At top of Producing Interval 900' Sand 2265' E of surface SUSPENDEDD ABANDONEDD ,_'0.0- _--_0' ,...-,.. - , ' , ¡ :,,',"":, \ ..1L:?? ~ 9.1. :, t, "'\'~~,:'r::.,:'" " \ 'I. , .' ,"0 ' , " ~~=:~ :~..::~':::::,: At Total Depth 989' Sand 2457' E of surface 5. Elevation in feet (indicate KB, DF, etc.) 21.5' DF-GL Classification of Service Well SERVICED 7. Permit Number 201-097 8. API Number 50-133-10090-01 RF;CE~\IE. [~. Unit~~~:~~~i~ame 10. Well Number KU 21-6rd , , ""';, !! ,- '/,)! ,/ - 11. Field and Pool it.i._L ,(,¡ìlfl,r..",~('!'\m: ¡' 6. Lease Designation and Serial ~ A-028142 on Kenai Gas Field, Pool 6 12. Date Spudded 8/31/2001 17. Total Depth (MD+ TVD) 5650' MD, 4884' TVD 13. Date T.D. Reached 9/5/2001 18. Plug Back Depth (MD+TVD) 5563' MD, 4811' TVD 14. Date Camp., Susp..or Aband. 15. Water Depth, if offshore 1I~'b7' ~( ~001 <!b N/A feet MSL one 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost YeS~NO D N/A feetMD N/A 22. Type Electric or Other Logs Run GR-RST-CCL 16. No. of Completions 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED CASING SIZE WT. PER FT. GRADE 20" 78.6 K-55 0 51 10-3/4" 32.75 H-40 0 1282 7-5/8" 26.4 J-55 0 5620 4-1/2" 12.6 L-80 3295 5649 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) Sterling Pool 6 Sand: (11/27/01) 5250'-531 O'MD \ 4544'-4595TVD 2-1/2" Milleneum StimGun, 6spf, 60 deg wi 2500 psi overbal (N2) Reperforate Pool 6: (12/6/01) 5250'-5310'MD \ 4544'-4595'TVD 27/8" PJ HSD Guns, 6spf, 60 deg phase, ballanced 27. Date First Production 9-Dec-01 Date of Test 12/6/2001 Flow Tubing Pres. 161 Hours Tested 24 Casing Pressure 0 01 L-BBL 0 01 L-BBL 0 N/A 14-3/4 9-7/8 6-1/8 25. SIZE N/A Driven 750 sx 700 sx 265 sx N/A NlA NlA TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE GAS-MCF 5700 GAS-MCF 5700 WATER-BBL CHOKE SIZE GAS-OIL RATIO 0 64/64" N/A WATER-BBL OIL GRAVITY-API (corr) 0 N/A 28. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) flowing PRODUCTION FOR TEST PERIOD ---þ> CALCULATED 24-HOUR RATE---þ> N: \d rlg\kgf\we IIs\KBU 33- 6\AOG CO M P Lxls C-1 lithology is interbedded fine to medium grained sandstone, with minor siltstone shale, and coal. (No core taken in well) Porosity ranges from 22 - 30% in the Sterling C-1 sandstone. The Sterling C-1 sandstone is depleting gas (C1 methane) reservoir. _. Submit in Triplicate RBDMS 8Fl ~f :"çp I ~ 2m? , "., ~' \ ( 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS. DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sterling 4182 3629 31. LIST OF ATTACHMENTS Daily operations summary, wellbore schematic, directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed b.)~ Denise Titus Title Production Engineer Date 12/18/2001 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other- explain. Item 28: If no cores taken, indicate "none". Form 10-407 N :\drlglsterlinglsu32-9\AOG COM P L.xls ( (' WELL NAME KU 21-6RD SUPERVISOR Je Lorenzen CURRENT STATUS Movin to Location 24 HR FORECAST Ri u on well FIELD NAME Kenai AFE NO. 9206501 DAILY WELL COST % 20 665.00 LAST SAFETY MTG. 8/19/2001 1 AFE COST 643 000 CUM WELL COST 20 665.00 BOP PSI TEST ST A TEIPROV Alaska COUNTY/OTHER Kenai LEAKOFFPPG OP COMMENTS: Break down components. Haul legal loads to location. Ready to transport heavy loads @ 8:00 am. OPERATIONS SUMMARY FROM TO HRS DEPTH FM' DEPTH TO 'SUB PHASE' DESCRIPTION: 06:00 06:00 24.00 MIRU Break down rig and move all legal loads - transporter, sub-base, pumps, pits, generators and boilers. Ready to move at 8:00 am. , COMPANY Glacier Drilling Marathon SERVICE PERSONNEL DATA, NO. HOURS CQMPANY 17 216.00 MI 1 24.00 SERVICE, " NO. ' HOURS 24.00 Printed: 8/24/2001 11:38:36AM ( ( WELL NAME KU 21-6RD SUPERVISOR Je Lorenzen CURRENT STATUS Move in and ri U .. 24 HR FORECAST Ri U on well. FIELD NAME Kenai OP COMMENTS: FROM :' TO HRS 06:00 06:00 24.00 COMPANY Glacier Drilling Marathon ST A TEJPROV Alaska MARATHON. OIL COMPANY Daily Drilling RQPort ST KB OH 80.00 RIG NAME & NO. GLACIER DRILLING 1 AFE NO. 9206501 DAILY WELL COST % 20 000.00 LAST SAFETY MTG. 8/19/2001 REPT NO. 2 AFE COST 643 000 CUM WELL COST 40 665.00 BOP PSI TEST LEAKOFF PPG Move all components from Falls Creek #1. Set all modules. Raise derrick. Move camp and remaining small loads from locatio. DEPTH, FM DEPTH TO SERVICE COUNTY/OTHER LAST CASING Kenai in OPERATIONS SUMMARY SUB ' PHASE DESCRIPTION MIRU Move all rig modules and camp to KU21-6. Set all rig modules in place. , PERSONNEL DATA, NO. HOURS COMPANY 17 216.00 MI 1 24.00 , SERVICE NO. 1 HOURS' 24.00 Printed: 8/24/2001 11:38:32 AM DESCRIPTION' ': Level carrier. Cont. Modification on mud pump engine and radiators. Install back landing and windwalls. Inspect latch pin for derrick. Inspect derrick board fingers. Set catwalk and beaver slide. Cont. to modify mud pump engines and radiators. Extend derrick and adjust guide wires. Insta rotary motor. Hang torque tube and "T" bar for TD. Set BPV in short string and 2-way check in long string. P/U Topdrive. Install desilter dump. Install choke chute and hose. Complete TD installation. Install koomey hoses between pump room and sub base. Cont. modification to mud pump engine and radiators. (: WELL NAME KU 21-6RD SUPERVISOR RC. Lawson CURRENT STATUS R/U ri and modi 24 HR FORECAST Com lete ri u on well. FIELD NAME Kenai TMD N/D tree and N/U BOP. Test BOP. STATBPROV COUNTY/OTHER Alaska Kenai OP COMMENTS: Rig up rig. FROM TO HRS ' DEPTH FM DEPTH TO 06:00 12:00 6.00 OPERATIONS SUMMARY, SUB PHASE MIRU 12:00 00:00 12.00 MIRU 00:00 06:00 6.00 MIRU .. PERSONNEL DATA, NO. 'HOURS COMPANY 17 216.00 MI 1 24.00 ,COMPANY Glacier Drilling Marathon SERVICE, ( TVD DFS AFE NO. 9206501 DAILY WELL COST % 16800.00 LAST SAFETY MTG. 8/19/2001 SERVICE: REPTNO. DATE 3 8/22/2001 AFE COST 643 000 CUM WELL COST 57 465.00 BOP PSI TEST LEAKOFFPPG , , .., .." .., 'NO. ' ,HOURS' .. 1 24.00 Printed: 8/24/2001 11 :38:41 AM <I' " ( , ," ' : ,, ',,' " ',' MARATHON OILCÖMPANY 'Pagè,tof'1'" "," . D"ilyDrilUrigReport ,,' '," : ,',', ,', " ", " WELL NAME ST IKB GL 24 HRS PROG TMD TVD IDFS REPT NO. DATE KU 21-6RD OH 80.00 59.00 4 8/23/2001 SUPERVISOR RIG NAME & NO. I~RIG PHONE AUTH MD AFE NO. AFE COST RC. Lawson GLACIER DRILLING 1 907 -283-131 5650 9206501 643 000 CURRENT STATUS ~ MOC WI NRI DAILY WELL COST CUM WELL COST SliD and cut drill line. 100.00 (% 87.50 (% 25 852.00 83317.00 24 HR FORECAST I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST ComDlete riQ UD on well. N/D tree and N/U BOP. Test BOP. None 8/19/2001 FIELD NAME I STATEIPROV 1 COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFFPPG Kenai Alaska Kenai 7.625 (in) ~ (ft) 4.500 (in) ~ (ft) OP COMMENTS: Cont. to rig up rig. Cont. to modify radiators for mud pump engines. Run water line from rig to water well. Slip and cut drill line. OPERATIONS SUMMARY FROM TO HRS DEPTH FM DEPTH TO SUB' PHASE DESCRIPTION : 06:00 12:00 6.00 MIRU R/U Geronimo line. R/U Geolograph line. R/U choke line to Degasser. R/U flo line. R/U drill floor spill protection. Raise derrick wind walls. Inspect derrick tri~ tank gauge. Cont. modification of mud pump engine radiators. 12:00 15:00 3.00 MIRU R/U shale shaker slides. Clean and organize rig floor and choke manifold room. Move BOP stack near sub base. Cont. modification of mud pump engine radiators. 15:00 16:30 1.50 MIRU R/U kill and bleed line to tubing x csg annulus. Cont. Mud pump engine radiato modification. 16:30 19:00 2.50 MIRU Bleed annulus f/40psi to Opsi in 15minutes. Pump 150bbls drillwater down annulus. Well on slight vaccum. Monitor annulus. Cont. Mud pump engine radiator modification. 19:00 22:00 3.00 MIRU N/D 13 5/8" 5K single gate ram from BOP stack. N/U 9" 3K X 11" 3K DSA and 11"3K X 13 5/8" 5K adaptor spool to BOP stack. Cont. mud pump engine radiator modification 22:00 00:00 2.00 MIRU Pump 75bbls drill water down tbg x csg annulus. Well on slight vaccum. Cont. mud pump engine radiator modification. 00:00 04:00 4.00 MIRÙ Run water line from rig to water well. Weld brackets and X/D's f/water line. Mount pallet jack in mud pitts Cont. mud pump engine radiator modification. 04:00 06:00 2.00 MIRU Slip and cut drill line. Cont. mud pump engine radiator modification. PERSONNEL DATA ' , u u :: COMPANY' SERVICE, NO. " HOURS COMPANY , ,SERVICE NO: : HOURS' Glacier Drilling 17 216.00 MI 1 24.00 Marathon 1 24.00 Printed: 8/24/2001 11:38:46 AM ( ('" ,', ,'" " " '. '. . " , ,,' . , MARATHON.OIL COMPANY P¿¡ge 1 'oft " ' " " ., DaHyDrilUngReþórt " ",.' WELL NAME ST IKB GL 124 HRS PROG TMD TVD DFS REPT NO. DATE KU 21-6RD OH 80.00 59.00 5 8/24/2001 SUPERVISOR RIG NAME & NO. I~IG PHONE AUTH MD AFE NO. AFE COST RC. Lawson GLACIER DRILLING 1 907-283-131 5650 9206501 643 000 CURRENT STATUS I MOC WI NRI DAILY WELL COST CUM WELL COST Weld on mouse hole frame while waitina on BJ services unit. 100.00 (% 87.50 (% 38.697.00 122014.00 24 HR FORECAST ¡ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST Attempt to fill well. NID tree and N/U BOP. Test BOP. None 8/19/2001 AELD NAME I ST A TEIPROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFFPPG Kenai Alaska Kenai 7.625 (in) lã>. (ft) 4.500 (in) @ (ft) OP COMMENTS: Cont. to modify pump engine radiators. Pull BPV from SS and LS RIU riser from ss to rig floor. Pump 234bbls drill water down SS wIno returns. " OPERATIONS :SUMMARY : FROM" TO HRS' DEPTH FM DEPTH TO SUB PHASE' DESCRIPTION 06:00 08:30 2.50 PLUGAB Remove plug from annular BOP. Remove riser boot from annular BOP. Cont. modification on mud pump engine radiators. 08:30 11:00 2.50 PLUGAB Clean and organize parts trailer. Cont. modification on mud pump engine radiators 11:00 12:00 1.00 PLUGAB Service rig. Cont. modification on mud pump engine radiator. 12:00 00:00 12.00 PLUGAB Install protective covers for hydraulic cylinders on derrick. Run cable for mud logging data. Layout and strap 2-43/4" collars, 1- 43/4" jars, 25-3 1/2" HWDP. P/U and rack back in derrick. Set and level living quarters for service personel. Cont. modification on mud pump engine radiator. Take 300bbls water into pit#3. Pull BPV from LS and SS. 00:00 02:00 2.00 PLUGAB Service rig. Cont. mud pump engine radiator modification. 02:00 02:30 0.50 PLUGAB RIU 2 7/8" riser from x-mas tree short string to rig floor. 02:30 03:30 1.00 PLUGAB Pump 234bbls drill water down short string. Max 7.5BPM w/850psi. No returns up csg but slight blow. Pump engine#2 over heated and ruptured hose due to radiator fan shut down. Shut down pumping. Csg x tbg went on vaccum as soo as pumps shut down. Slight blow up LS. 03:30 04:30 1.00 PLUGAB Change hose and fill cooling system on pump#2 engine. 04:30 06:00 1.50 PLUGAB Test run fans for pump engines. Fans stoped running after 1 hr. Rig pumps down can not run without fans. Mobilize BJ services unit. , PERSONNEL DATA .. COMPANY SERVICE NO. HOURS .. ' , COMPANY SERVICE : 'NO. HOURS ' Glacier Drilling 17 216.00 MI 1 24.00 Marathon 1 24.00 Printed: 8/24/2001 11:38:51 AM ( (' ',', " : ,', ,", ' : MARATHON 01 LCOMPANY Paget oft ' I,',,' ',....' DäHyDrillin9 Report ' ":, :" ,' " " " "",' " , "' ,' ,'" ',: '" " " WELL NAME ST KB GL 24 HRS PROG TMD TVD IDFS REPT NO. DATE KU 21-6RD OH 80.00 59.00 6 8/25J2001 SUPERVISOR RIG NAME & NO. I!RIG PHONE AUTH MD AFE NO. AFE COST RC. Lawson GLACIER DRILLING 1 907-283-131 5.650 9206501 643.000 CURRENT STATUS I MOC WI NRJ DAILY WELL COST CUM WELL COST Testina BOPE. 100.00 (% 87.50 (% 23 139.00 145 153.00 24 HR FORECAST ¡ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST Test BOP. Pull dual strinQs of 27/8" TBG. None 8/24/2001 FIELD NAME I STATEIPROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Kenai Alaska Kenai 7.625 (in) (â). (ft) 4.500 (in) lã) {to OP COMMENTS: Pump LCM pills. Fill Long String, Short string and CSG X TBG. N/D tree. N/U BOP. Begin Test BOP. OPERATIONS SUMMARY FROM' TO HRS DEPTH FM DEPTH TO SUB PHASE DESCRIPTION 06:00 08:00 2.00 PLUGAB Trouble shoot mud pump engine radiator fans. 08:00 09:30 1.50 PLUGAB RlU BJ pumping unit. Cont. to trouble shoot mud pump engine radiator fans. Found problem wlradiator fans and repaired. 09:30 10:00 0.50 PLUGAB Trouble shoot mud pump#2 charge pump. 10:00 12:00 2.00 PLUGAB PJSM prior to mixing and pumping LCM pill. Mix 30bbls 5ppb HEC pill. Pump 30bbls HEC LCM pill and chase w/20bbls drill water down short string. Cont. to trouble shoot mud pump#2 charge pump 12:00 15:00 3.00 PLUGAB PJSM with crew coming on tower. Pump 250bbls drill water down CSG X TBG annulus. Attempt to circ w/100bbls drill water down short string. No fluid to surface. Cont. to trouble shoot mud pump#2 charge pump. 15:00 19:00 4.00 PLUGAB Mix 55bbls 4ppb Flowvis w/CaC02 LCM pill. Remove, grease and replace one t a time flange bolts on X-mas tree. Trouble shoot and repair mud pump#2 charg ~ pump. 19:00 21:00 2.00 PLUGAB Pump 45bbls Flowvis w/CaC02 LCM pill down short string and chase w/1 Obbls drillwater. Fill CSG x TBG annulus w/125bbls drill water. Bleed 60psi off of lon~ string and top off with water hose. Break circulation from short string to CSG x TBG annulus. 21:00 21:30 0.50 PLUGAB RID riser from X-mas tree to rig floor. 21:30 22:00 0.50 PLUGAB Set BPV in short string and long string. 22:00 22:30 0.50 PLUGAB N/D X-mas tree. 22:30 04:00 5.50 PLUGAB N/U 135/8" 5k S,Rd,A BOP stack. N/U choke and kill line. Fill up and bleed Trip tank air lines. RlU air boot and Koomey lines. Function test BOP. 04:00 05:00 1.00 PLUGAB Change out 4.0"pipe rams to dual 2 7/8" rams. 05:00 05:30 0.50 PLUGAB Pull BPV's and set 2-way checks. 05:30 06:00 0.50 PLUGAB Begin pressure test BOP. Repair leaking valves from choke manifold. PERSONNEL DATA COMPANY SERVICE NO. HOURS' COMPANY SERVICE NO. .. ,HOURS Glacier Drilling 17 216.00 MI 1 24.00 Marathon 1 24.00 Printed: 8/25/2001 9:57:14 AM ( (" I ' ", ", ' ',,' ". ,:' "'C. ' : " :',' ," ', ' ,,' :,,' " I',', ,MARATHON, 01 LCO MP ANY. Pagø,1ofJ " DaHyPrilUOQ" e.øþort ,"'" "" ,'::':,: : .. :: c' ' "",' ,': :,' WELL NAME ST KB IGL 124 HRS PROG TMD lVD DFS REPT NO. DATE KU 21-6RD OH 80.00 59.00 7 8/26/2001 SUPERVISOR RIG NAME & NO. I!RIG PHONE AUTH MD AFE NO. AFE COST RC. Lawson GLACIER DRILLING 1 907-283-131 5,650 9206501 643.000 CURRENT STATUS I MOC WI NRI DAILY WELL COST CUM WELL COST CBU on lona strina. 100.00 (% 87.50 (% 18340.00 163.493.00 24 HR FORECAST I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST Cut 2 7/8" lona strina. POOH and UD 2 7/8" tubinq. None 8/26/2001 8/25/2001 FIELD NAME I STATEIPROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Kenai Alaska Kenai 7.625 (in) @ (ft) 4.500 (in) lã>. (ft) OP COMMENTS: Test BOP. RlU tbg handling tools and attempt to pull dual 2 7/8" tbg string. CBU on short string. OPERATIONS SUMMARY FROM TO' HRS DEPTH FM DEPTH TO SUB PHASE DESCRIPTION ,: 06:00 12:00 6.00 PLUGAB Test choke manifold valves 10,11,12,5,7,2,6,9,8 (valves 7 and 12 failed test. Service valves 7 and 12 and passed retest), Blind Rams, lower TD valve, inside kill valve 250psi/10min 3000psi/10min. H2S detector at bell nipple failed. Service and retest OK. H2S Warning light on rig floor requires replacement (no replacement available). Repair Epoch PVT system at Driller's console. Test 2-floor valves and IBOP to 250psi/10min 3000psi/10min. 12:00 23:00 11.00 PLUGAB Outside kill valve leaking C/O twice. Retest OK. Upper TD valve leaking RID Ion ~ bails and C/O. Retest OK. RlU dual 2 7/8" test joint and test outside kill valve, upper and lower TD valves, Choke manifold valves 1,2,3,4, (Valve 1 failed test. Service and retest OK)2 7/8" Dual rams 250psi/10min 3000psi/10min. RID 2 7/8" dual test joints and RIU 4" test joint and test Annular, Choke HCR, inside choke valve to 250psi/10min 3000psi/10min. 23:00 23:30 0.50 PLUGAB RID 4" test joint and pe'rform Koomey test. 23:30 00:00 0.50 PLUGAB RlU long bails. 00:00 00:30 0.50 PLUGAB Pull 2-way check from short string and long string. 00:30 03:00 2.50 PLUGAB RlU Weatherford dual tubing string handling tools. 03:00 05:00 2.00 PLUGAB M/U landing joints and screw into dual hanger. PJSM prior to pulling tbg. BIO lockdown screws and release hanger. Pull 90K over block weight. Tbg will not pull free. Work tubing w/90K over block weight. 05:00 06:00 1.00 PLUGAB Hold 90K over block weight and CBU on short string 6BPM @ 475psi. CBU long string. 79BPM @ 51 Opsi. 'DENSITY(ppg) 'I 8.34 I PP IECDI I MUD DATAl, DAILY COST I 625.00 ' CUM, COST 5,678.00 "FV" PVlYfI GELS ,WUHTHP FCrr.SOL OiL/WAT ' %Sand/MBT ',: Ph/pM Pf/Mf CI ' Ca H2S LIME : ES: 27 I I I I I I I I , , PERSONNEL DATA-', ' , .. COMPANY , ' SERVICE NO. HOURS, COMPANY SERVICE' , NO. ' HOURS Glacier Drilling 17 216.00 MI 1 24.00 Marathon 1 24.00 Printed: 8/26/2001 9:36:34 AM ( ( , , ",' , " , " ,'.. ' , '" ::, " ::,' WELL NAME KU 21-6RD SUPERVISOR RC. Lawson CURRENT STATUS POOH and LID 2 7/8" dual strino. 24 HR FORECAST POOH LID tubinQ. CIO rams test BOP. Run Bit and scraoer. FIELD NAME I STATEIPROV I COUNTY/OTHER 1 LAST CASING Kenai Alaska Kenai I 7.625 (in) (â) , ' , ',.' , .. , '., MARATHONOIL:COMPANY " ',',', ',',: " " " "" .. , , ..' ,c, ,.. , , Daily DtillingReport ,'" ST KB IGL 124 HRS PROG TMD OH 80.00 59.00 I RIG NAME & NO. TRIG PHONE AUTH MD AFE NO. GLACIER DRILLING 1 1907-283-131' 5650 9206501 I MOC WI NRI DAILY WELL COST 1100.00 (% 87.50 (% 31.643.00 ¡ACCIDENTS 24HR LAST SAFETY MTG. I None 8/27/2001 TNEXT CASING (ft) 1 4.500 (in) @ (ft) TVD '" IDFS 1 Pagelof1, :,,', " ,,' ' '.' ,': REPT NO. DATE 8 8/27/2001 AFE COST 643 000 CUM WELL COST 195.136.00 BOP PSI TEST 8/25/2001 LEAKOFF PPG OP COMMENTS: Attempt to pull TBG free. RlU EL and cut LS @ 3484'. Pull TBG free. POOH wfTBG. 27 I OPERATIONS' SU MMARY PHASE ' , DESCRIPTION PLUGAB Circulate long string w/.3BPM @490psi and work TBG while wait for Schlumberger EL. PLUGAB R/U to run TBG cutter. Pull 20k over string wt @ cut point and set slips. PLUGAB Clean and organize rig while wait on Schlumberger to mobilize the radio safe explosive system. PLUGAB R/U Schlumberger EL. PJSM prior to cutting long string. PLUGAB M/U 21/8" jet cutter. RIH and cut long string @ 3484'. POOH w/Schlumberger EL. PLUGAB Pull TBG free w/15k over string wt. RID Schlumberger EL. PLUGAB PJSM prior to pulling TBG. Pull hanger above floor and B/O. PLUGAB CBU on long string. PLUGAB PJSM with crew coming on prior to pulling TBG. Pull and LID 27/8" 6.4ppf N-80 BTC dual TBG string (130Jnts of app 226). IEcol IMUD DATAl DAILYCOST,' 625.00 I CUMCpST. 6,303.00 FCIT.SOL OluWAT ',%Sand/MBT ' , ' " Ph/pM Pf/Mf CI ,Ca' , H2S 'LIME ES, I I I I I .. F~OM TO HRS 'DEPTH FM DEPTH TO SUB 06:00 08:00 2.00 08:00 09:00 1.00 09:00 18:00 9.00 18:00 19:00 1.00 19:00 21 :00 2.00 21 :00 22:00 1.00 22:00 23:30 1.50 23:30 00:00 0.50 00:00 06:00 6.00 , DENSITV(ppg) 8.34 I PP ,,' FV,PVIYP ,GELS WUHTHP I I SERVICE PERSONNEL DATA:" NO. HOURS COMPANY 17 216.00 Weatherford 1 24.00 Vetco 1 24.00 .. , , , .. .. , COMPANY' Glacier Drilling Marathon MI SERVICE NO., HOURS 2 24.00 1 12.00 Printed: 8127/2001 10:07:47 AM ( ( " " " 'MARÄTHOr..fOIL c':or~lPANY Page 1 of 1 " '.. ' ' ""',, " .. , ,Daily:Driilin'g ~eport .. " WELL NAME KU 21-6RD SUPERVISOR RC. Lawson CURRENT STATUS Preoare to POOH. 24 HR FORECAST Set 7 5/8" EZSV. Test CSG. SQueeze below EZSV. FIELD NAME I STATEIPROV I COUNTY/OTHER ¡LAST CASING Kenai Alaska Kenai 7.625 (in) @ 51 IKB IGL OH 80.00 159.00 RIG NAME & NO. GLACIER DRILLING 1 124 HRS fROG TMD TVD I RIG PHONE AUTH MD AFE NO. 1907-283-131 5650 9206501 1 MOC WI NRI DAILY WELL COST 1100.00 (% 87.50 (% 34177.00 I ACCIDENTS 24HR LAST SAFETY MTG. I None 8/27/2001 ¡NEXT CASING 5 620.0 (ft) 4.500 (in) /á) 5650.0 (ft) DFS REPTNO. DATE 9 8/28/2001 AFE COST 643 000 CUM WELL COST 229.313.00 BOP PSI TEST 8/25/2001 LEAKOFF PPG OP COMMENTS: Complete LID 2 7/8" TBG. CIO to 4"DP rams and test. RIH w/6 3/4" Bit and 7 5/8" Scraper PIU 4" DP. Circ @ 3484 while P/U 4"DP and rack back. POOH. ;; :'::':;};;;;,i~:j:,}>:'/,::'\:::,;;!:::,';;:;,:,:,,:::::':;::::)"",:,,":J,'::',~,:;::;:,": :':':i:,;;: ,;:'::-:;~::::i;'::'::OP'ERÅTIONS::-SU:MMARY;':;,,:,:':<::;::,,::,":::::;>,':,,:;':',;::'::{:::::,;i::;i>,:::';'::::i~:¡-:::":-:r¡<::::!:: ,:::;<:;>\,:t/:¡,':,:-/~,:::i;:: ,FR~iIIi" ~:::-:,tö,'; :-,::H~S :': D~pfH'FM: 'h~PT,H:fo' :.::' ::~(Jlf,::, ':'PHÁ~Ë::', !,;:::,,::\<,:::.',:>\,:,:-:,:,.,:::,,::,::,::,::~:,;<::,-¡<;:-,:::::.;:;",:';':;:::¡j)E$è:~,~:ti(jN;¡::::,;t:,::::: ::;,\:<>:,::::"':;':::i,:',:~',::,':¡:':>::i::/-¡:;i 06:00 12:00 6.00 PLUGAB Cont. POOh and LID 2 7/8" 6.4ppf N-80 BTC dual TBG string (total app 226 joints). PLUGAB RID Weatherford TBG running tools. PLUGAB CIO Dual 2 7/8" pipe rams to 4.0" pipe rams. Run test plug and test 4" pipe rams to 250/3000psi 10min. Pull test plug. Install wear bushing. PLUGAB CIO bales and elevators. Load rack w/4" DP and strap. CIO mouse hole. PLUGAB RIH w/6 3/4" bit and 7 5/8" csg scraper BHA. PLUGAB R/U to P/U DP. PLUGAB RIH P/U 4" DP. Tag TOF @ 3484'. PLUGAB Circ @ 3484' while P/U 4" DP and rack back in derrick (total 160joints 4" DP picked up). PLUGAB Prepare to POOH. Saver sub would not break out of DP. Remove saver sub clamp and B/O saver sub from top drive made up on top joint of DP. Mouse hol top joint of DP and B/O saver sub from DP. M/U new saver sub to top drive ant install connection clamp. :pï:NsiTŸ'(PP9),::, 8.34 I p~: 1,,!~Ú;Dl I MUD, DA'tAkþ~i~Y'Có.$T': 625.00 1":c;m;JI':ÞOsr:-:, 6,928.00 :>~.v'; i-:'.p,yJ;Yp, /GE~S:;:' ,¡:WUHrH'p:;: ':!i,FCrr.~~O~:': :" ÖI~IWAr>:: ':.:,D/~$ðndJIIiIBJ<):' ::::¡'::/P~/pM::::¡<r':>,:'~fINlf,,: ';.' >:,:c¡,.:/\> ::;::;':C'ë{;::!¡ ::',("'2$,\,: ',liME': :H;,E$,:'¡: 27 I I I I I I I I " ':':-:.:::,:,:>~",::<:::<,:,',::" "'" ':"::,;':"",::;:,:,::,:";,,',,,":,,'::',';:,!,:;:";:;;,':,::':,::Éuts::':,:::'..:.:¡',:'~:::',,:,:-,,:,,':,'.-'::::::';:¡;:::¡;::,r:::':,'::::::':u,,::,,::;,:,,;",::,:""':';":':'::;:,":::':':':,,:,,":,,::;:::::'::>\'/': ;BI,l/Rl)N" ,::;":SIZE:,::'-:': ::':"'ï\II~N~,F~'.. ::: ;",::,,:::'TY~I:':::;>:; ":'SEß.i~iNÖ'-:,: !':,::'\,":JET!;,qR)'FÁ':',:"::, :::'..~::'DË~.r"';IN':'D,~!~:IN::->; :;':\<'('FO~D~(~B~G,~q,;~,;!..:~::::' 1RR 11 6.750 Smith XR20TDGPS L Y9527 3,484.0 8/27/2001 0-0------ BIT I RUN WeB I RPM I GPM I PRESS P BIT I HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH CUM ROP 12:00 12:30 0.50 12:30 14:30 2.00 14:30 17:00 2.50 17:00 18:00 1.00 18:00 18:30 0.50 18:30 21 :30 3.00 21:30 04:30 7.00 04:30 06:00 1.50 ":":" ;':,:',':, ":'<).i::',:':,:,'::,',:,":::';>:-'-::':',:,-:'::';::::,:;;':':',:' aHA';:':'),::,:", "":"",," ,-; " .., ,,<,:':» ';',:<',",,"~,:,/,,'-",::;!"':;"':!-!:, ,B,f: Å:Nþ:Y", L~f\JGJH' EFi="w-r,:::',lp:ICK'UP':.:I:~,LAck Þi=~ ~QtWT'.':", ,TqRqUE,'(m~j(¡m¡n) ,BHAHRà'::, 'JA~:'HRS¡.":;:lfI.1WD}:i'~S;: MTf{,H~Si, 'Ssi;HF:S'::'\' 1 856.62 0 r I I I BHA DESCRIPTION XR20TDGPS BIT 7 5/8" CSG SCRAPER, 3 1/2"REG X 3 1/2"IF BIT SUB, 4 3/4" DRILL COLLARS (2), 3 1/2"HWDP (4), 4 3/4" DAILY HYDRAULIC JARS 3 1/2" HWDP (21), 3 1/2" IF-P X 4" HT-38-B ," "',: ,,"',," :"PE"RSON'NEL"D'A'T'A""':' , ,,": " , ", ',' 'm, .," ','.'" .., , ' , ,;' " , ",' ",', ,.. ';' " " :," '" " ,,' ,,:,,:.., ", :'" ,,;; " , ' " "," "~--,_.- :COMpÀNŸ ,," ,,:,::',S$RVI,d:::,:': ::<NÖ:'=':'"", HóLi~s:, ':: ,"';::::,':CÒrw":~A.NY: P" Glacier Drilling 17 216.00 Weatherford Marathon 1 24.00 Vetco MI 1 24.00 " " " " ",,' ",',' " " , , ,," :,SERVlëE:::: :-;:, NO~:j,H9L1R;s .. 2 24.00 1 12.00 Printed: 8/28/2001 9:52:57 AM ( (' " ,,' .. ", " " " , .. , , " .., " , " " , '" ",. ' .., MARATHON'ÖILCÖNfpANY " Daily Drilling Report .. .., .. .',- ,Page",1of'2:';",.',:,'; .. , . .. .. .. ",', WELL NAME KU 21-6RD SUPERVISOR RC. Lawson CURRENT STATUS POOH. 24 HR FORECAST POOH. NID BOP. FIELD NAME Kenai ST KB GL OH 80.00 59.00 RIG NAME & NO. GLACIER DRILLING 1 124 HRS PROG TMD TVD I RIG PHONE AUTH MD AFE NO. 1907-283-131 5.650 9206501 MOCWl NRI DAILY WELL COST 100.00 (% 87.50 (% 49934.00 ¡ACCIDENTS 24HR LAST SAFETY MTG. I None 8/29/2001 ¡NEXT CASING 5620.0 (ft) 4.500 (in) @. 5 650.0 (ft) DFS REPT NO. DATE 10 8/29/2001 AFE COST 643 000 CUM WELL COST 279247.00 BOP PSI TEST 8/25/2001 LEAKOFF PPG NIU SSA and sinale aate BOP. Test BOP. I STATEIPROV COUNTY/OTHER LASTCASING Alaska Kenai I 7.625 (in) @. OP COMMENTS: Set EZSV @ 3476'. RIH w/stinger. Test CSG. Perform Squeeze Job. 06:00 09:00 3.00 PLUGAB POOH (yVear bushing came out on scraper). 09:00 09:30 0.50 PLUGAB Run wear bushing. 09:30 11 :00 1.50 PLUGAB RlU Schlumberger EL. PJSM prior to EL operation. RIH w/6.5" Gauge ring jun. basket tag @ 3486'. POOH. PLUGAB RIH w/7 5/8" Halliburton EZSVon EL. Set EZSV @ 3476'. POOH. RID Schlumberger. PLUGAB Test 75/8" CSG. Pressure up to 500psi. Pressure bled off to 100psi in 9.0 min. Verify no surface leaks. Retest 2 more times with same results. PLUGAB M/U Halliburton stinger and RIH w/4" DP to 3450'. PLUGAB R/U long bails and cement line. PLUGAB RIH and sting into retainer@ 3491'. SIO 30K down on retainer. PLUGAB PJSM prior to pumping operations. Break circulation w/BJ unit down choke line. Test BJ line against choke line valve to 3500psi/5min. Close pipe rams and test csg to 1500psi/30min. Open rams and sting out of retainer. Break circulation down DP and test BJ lines to 3500psi/5min and test CSG to 1500psi/10min. Open pipe rams and sting into retainer. Inject down DP wlfresh water .5BPM w/1100psi. PLUGAB PJSM with crew coming on. Inject down DP 2BPM @ 1300psi. PLUGAB R/U washup/reverse line. PJSM prior to squeeze job. PLUGAB Pump 5bbls fresh water ahead. Mix and pump 275sxs class"G" cement w/.4%BWOC FL-33, .25%BWOC CD-32, 19a1/100sx FP-6L, 43.9%Fresh water to yield 56bbls 15.8ppg slurry. Displace w/44bbls fresh water. PLUGAB Sting out of EZSV and close annular. Reverse out 2XDP volume. Open annula and CBU X 2 the long way. No cement to surface. 04:00 05:30 1.50 PLUGAB RID cement line. RID BJ unit. cIa to short bales 05:30 06:00 0.50 PLUGAB POOH(8LM). '::j,bENŠJrY{I)pgr;: 8.40 :i~p", I ECP'! IMUD"ÐATAI:'D~I~'(C,os;r.:, 625.00 1::Cl)rvtcq,~T::I 7,553.00 ',:::;:¡::y,¡ : ,::'i'pvijp::', ,:GE~,$:::: ;'::WL;JHTHf:' "Fctr;$OL: ,;' ,:'::ÓI~JWÅT',<: :>::,oi:,~a:o~iM~T<' ::::;'0::: "PhlþJi.(:: ,',,: ::: ,':::;:'Pf/M(: Y ::: ': /ci : ,/ :,; ,::,:>,;câ:":':: ':<,.H2S :;~, ;::~~~I$> ,! ..I:S.:;: 28 I I I I I I I I ':>:',"::"':"':"',::'-,:,<':::;,/,,:,.,;:-: -...,:,':::" ...,',,: ,," u ~.:,~~~~:,,~",:':'BITS"",,:":',:,":':,":"):',,:'"'",:,>':::::::;u::,:::>:,:';',;,,:,::,:'<:::,, ,..' ,,',:;':::;:',,1'\";',;:; ,8tl)~U~:: '::,>$iZE':;:: ";::: ,'MANJJf~":: ':,,:'TVPE:',:: ::'~,E~IAL.,~O~:: ;,::::::',:JETS.oR.TFA:::;:: ,,' ,:':'::;:D,~PTH:IN ljATEjN':"~ ,j: """;--::,,i~O~D-L~~~Gëó.~R:",,",>; 1RR 11 6.750 Smith XR20TDGPS L Y9527 3,484.0 8/27/2001 0-0------ 11:00 13:30 2.50 13:30 15:30 2.00 15:30 17:30 2.00 17:30 19:00 1.50 19:00 19:30 0.50 19:30 00:00 4.50 00:00 01 :00 1.00 01 :00 02:00 1.00 02:00 03:00 1.00 03:00 04:00 1.00 BIT I RUN 1 RR 11 WOB I RPM I GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP " ": .., :.. "",," '" "..,':", 'BHA,':' "':'u::",'" "u BHANO., LENGT~, EFFvVT> PIC,K,UP SLACKOF~ROTw'r." , TORQIJE(rriaJurTiin)¡BHAHRS:,: JAR;HRS : MWO:I-jRS: MTRHR$::, $S"H~$":" 2 7.38 I I I BHA DESCRIPTION EZSV cement stinqer, 3 1/2" IF X 4" HT-38 XIO ,4" 14PPF 8-135 HT-38 DP Printed: 8/29/2001 9:02:02 AM (' (' MARATHON Oil COMPANY Page 2 of2 . Daily Drilling Report WELL NAME 1ST IKB IGL 124 HRS PROG íTMD TVD IDFS I REPT NO. DATE KU 21-6RD OH 80.00 59.00 10 8J29/2001 " ' , PERSONNEL DATA ',' : . ,'". ',CbMP~NY' " ---. ! I. HO.URS 'L._...._........~ERV~~E I NO. COMPANY i SERVICE NO. HOURS.' ..... .. ---.- --- -----. .. Glacier Drilling 17 216.00 Schlumberger 3 15.00 Marathon 1 24.00 Halliburton 1 24.00 MI 1 24.00 Baker Inteq 2 48.00 BJ 4 48.00 Printed: 8/29/2001 9:02:02 AM ( (' " ", ': " , ; ,' :' ""':' " MARAtHON ,OIl.~COMPANY J?age:1of2, ',:: '" [)ållyDrill ingR.øþórt ;' , ",," ,"",' '~ ,', , , ",',' " .., "',',, " ,', "" " " ",, : ',,: " WELL NAME ST KB GL 24 HRS PROG TMD TVD DFS REPT NO. DATE KU 21-6RD OH 80.00 59.00 3,477.0 3,477 3,044 11 8/30/2001 SUPERVISOR RIG NAME & NO. I!RlG PHONE AUTH MD AFE NO. AFE COST RC. Lawson GLACIER DRILLING 1 907-283-1312 5,650 9206501 643 000 CURRENT STATUS IMOCWI JNRI DAILY WELL COST CUM WELL COST RIH W/Whipstock/Mill Assv. 100.00 (% 87.50 (% 31 781.00 311 028.00 24 HR FORECAST ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST Set Whipstock. Mill window. Perform EMW test. None 8/29/2001 8/25/2001 FIELD NAME I STATEIPROV I COUNTY/OTHER LAST CASING NEXT CASING LEAKOFFPPG Kenai Alaska Kenai 7.625 (in) lâ>. 5,620.0 (ft) 4.500 (in) ~ 5 650.0 (ft) OP COMMENTS: POOH. N/D BOP. N/U BOP and test. RIH w/bit and scraper. POOH. P/U Whipstock BHA. RIH. OPERATIONS SUMMARY .. FROM TO" HRS DEPTH FM DEPTH TO' SUB PHASE DESCRIPTION 06:00 08:00 2.00 PLUGAB Cont. POOH(SLM -8' correction top of EZSV@3483'). 08:00 09:00 1.00 PLUGAB Test CSG to 1000psi/30min. 09:00 09:30 0.50 PLUGAB Pull wear ring. Run test plug. 09:30 12:30 3.00 PLUGAB N/D BOP. 12:30 13:30 1.00 PLUGAB N/D 8" 3K X 11" 5K SSA and 11" 5K X 13 5/8" 5K adaptor spool. N/U 8" 5K X 135/8" 5K SSA w/combination flange and combination studs. N/D 8"5K X 13 5/8"5K SSA (Single gate studed ram could not N/U due to lockdowns on tubing spool interfearing with studs on single gate). 13:30 16:30 3.00 PLUGAB Service and clean rig. Clean mud pits. 16:30 20:30 4.00 PLUGAB N/U 8" 3K X 11" 5K SSA and 11" 5K X 13 5/8" 5K adaptor spool. N/U S,Rd,A 135/8" 5K BOP. 20:30 22:00 1.50 PLUGAB Test Blind Rams, outside kill valve, choke manifold valve 3,4,7 250/3000psi 10min. Pull test plug and install wear bushing. 22:00 01:00 3.00 PLUGAB M/U 6 3/4" BIT and 7 5/8" CSG scraper assy. RIH(SLM). Tag EZSV@3483'. 01:00 01:30 0.50 PLUGAB CBU x2 @ 3483'. 01:30 04:00 2.50 PLUGAB POOH. 04:00 05:30 1.50 PLUGAB P/U Whipstock/Mill BHA. Orient MWD. 05:30 06:00 0.50 PLUGAB RIH. ,DEN~ITY(ppg) 8.40 I PP ECDI MUD DATAl DAILV:COST I 625.00 I CUM cost I 8,178.00 : FV: PYNP, GELS WUHTHP ' ,Fclt .~OL : OIL/WAT" ,'o¡"Sand/MBT' 'Ph/pM., :, , : ,Pf/Mf, ,CI " Ca'" H2S" : LIME' ',ES, , 28 I I I I I I I I BITS,' .. " -- BIT I RUN, SIZE MANUF. : ,',TYPE SERIAL NO.. JETS ORT¡:A , DEPTH IN DATE IN 'I-O~D-L-~-G-O~R .. 1RR/2 6.750 Smith XR20TDGPS L Y9527 3,484.0 8/29/2001 0-0------ 2/1 6.125 Baker Starter Mi 16/16/16/16/161 3,463.0 8/30/2001 0-0------ BIT I RUN I WOB I RPM I GPM I PRESS P BIT HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH CUM ROP BHA ' , , ,' , " 0.._- BHA NO. LENGTH EFF WT. ¡PICK UP I SLACK OF ROTWT. ' TQ,ROUE' (maxImin) BHA HRS JAR HRS I MWD HR5 MTR AR8 :185 HRS 3 856.62 I I I I I BHA DESCRIPTION XR20TDGPS BIT, 7 5/8" CSG SCRAPER, 3 1/2"REG X 3 1/2"IF BIT SUB, 4 3/4" DRILL COLLARS (2), 3 1/2"HWDP (4),4 3/4" DAILY HYDRAULIC JARS, 31/2" HWDP (21), 31/2"IF-P X 4" HT-38-B, 4" 14PPF S-135 DP PUMP I HYDRAULIC -DATA .. " , NO. MAKE OF PUMP ' ' STROKE (in) LINER (in)' SPM' , Q (gpm) PRESS. (psi) TOTAL Q KILL,SPM I PRESSURE' , 1 OILWELL 8.000 4.500 100 155.33 310.66 2 OILWELL 8.000 4.500 100 155.33 310.66 Printed: 8/31/2001 2:29:56 PM ( ( , '", '. " ,', ' '.',,:' ' MARATHON OIL COM PANY' Page:Øòf? ' Daily Drilling Reriorf , : "":' ':, ':':,. ' , ,, ':' , ,,' ,,' '" WELL NAME ST IKB GL 24 HRS PROG TMD 1~044 IDFS I REPT NO. DATE KU 21-6RD OH 80.00 59.00 3477.0 3.477 11 8/30/2001 " '" '" ,"" ,"', "':,' ':"',::::",,;,,:..,'" ,,' SURVEY DATA' ':; ."':""," ",,: ,,;;,,',,', " ":,,, "':,""::" "':""':::""',,'), . ,',: M.D. INCL. All T.V.D. NIS CUM ElW CUM SECTION M.D. INCL. All T.V.D. NIS CUM ElW CUM 'SECTION 0 0.00 0.00 0.00 0.00 0.00 0.00 2,653 36.50 113.00 2,349.86 -384.22 977.97 1,049.47 94 0.25 330.00 94.00 0.18 -0.10 -0.17 2,809 34.25 114.00 2,477.06 -420.21 1,060.79 1,139.76 150 0.25 46.00 150.00 0.37 -0.08 -0.22 2,964 32.75 113.00 2,606.30 -454.33 1,139.24 1,225.30 196 0.25 24.00 196.00 0.53 0.04 -0.18 3,118 31.75 115.00 2,736.55 -487.73 1,214.31 1,307.46 251 1.25 96.00 250.99 0.58 0.68 0.39 3,244 31.25 115.00 2,843.98 -515.56 1,273.98 1,373.29 312 4.00 100.00 311.92 0.14 3.44 3.08 3,402 31.00 117.00 2,979.24 -551.35 1,347.37 1,454.92 374 4.25 97.00 373.76 -0.52 7.85 7.37 3,557 30.75 117.00 3,112.27 -587.46 1,418.25 1,534.37 435 5.00 112.00 434.57 -1.79 12.56 12.18 3,680 30.25 118.00 3,218.25 -616.28 1,473.62 1,596.69 497 6.25 112.00 496.27 -4.07 18.19 18.26 3,904 29.50 115.00 3,412.50 -666.08 1,573.43 1,708.15 561 7.50 112.00 559.81 -6.94 25.30 25.91 4,053 29.00 114.00 3,542.50 -696.28 1,639.67 1,780.95 623 9.00 107.00 621.16 -9.87 33.69 34.77 4,205 28.50 118.00 3,675.78 -728.29 1,705.36 1,853.99 654 10.00 111.00 651.74 -11.54 38.52 39.86 4,231 28.75 122.00 3,698.60 -734.52 1,716.14 1,866.38 746 11.00 106.00 742.20 -16.83 54.41 56.52 4,263 30.00 119.00 3,726.49 -742.48 1,729.66 1,881.98 836 13.25 110.00 830.19 -22.72 72.36 75.30 4,293 29.50 119.00 3,752.53 -749.69 1,742.68 1,896.82 898 15.25 111.00 890.28 -28.07 86.65 90.53 4,323 30.00 118.00 3,778.58 -756.79 1,755.77 1,911.66 996 19.25 110.00 983.85 -38.22 113.88 119.52 4,387 31.50 120.00 3,833.58 -772.67 1,784.38 1,944.27 1,090 24.00 111.00 1,071.21 -50.38 146.30 154.08 4,417 32.50 119.00 3,859.02 -780.49 1,798.21 1,960.10 1,181 29.25 110.00 1,152.53 -64.62 184.50 194.76 4,479 34.75 120.00 3,910.64 -797.41 1,828.09 1,994.28 1,281 34.50 108.00 1,237.42 -81.74 234.43 247.31 4,579 35.00 118.00 3,992.69 -825.12 1,878.09 2,051.26 1,374 35.00 112.00 1,313.85 -99.88 284.21 300.15 4,711 35.25 119.00 4,100.65 -861.36 1,944.83 2,127.00 1,529 35.25 112.00 1,440.62 -133.29 366.90 389.26 4,897 35.50 119.00 4,252.31 -913.57 2,039.01 2,234.31 1,683 35.75 114.00 1,566.00 -168.23 449.20 478.65 5,051 35.50 121.00 4,377 .69 -958.27 2,116.45 2,323.28 1,840 35.50 113.00 1,693.62 -204.70 533.06 570.09 5,198 35.50 113.00 4,497.43 -996.95 2,192.37 2,408.39 1,996 35.50 112.00 1,820.62 -239.36 616.76 660.63 5,377 35.25 112.00 4,643.38 -1,036.6 2,288.10 2,511.96 2,181 35.75 110.00 1,971.00 -277.97 717.35 768.20 5,496 35.50 113.00 4,740.42 -1,062.9 2,351.75 2,580.82 2,346 36.50 112.00 2,104.28 -312.84 808.15 865.31 5,678 35.50 113.00 4,888.58 -1,104.2 2,449.03 2,686.48 2,472 37.25 113.00 2,205.07 -341.78 877.99 940.88 .. " " PERSONNEL DATA", . , " " ' , " ,COMPANY, ,SERVICE NO. HOURS COMPANY , " SERVICE" "NO. " HOURS, " : Glacier Drilling 17 216.00 BJ 4 48.00 Marathon 1 24.00 Baker I nteq 4 60.00 MI 1 24.00 Epoch 4 48.00 Printed: 8/31/2001 2:29:56 PM ( ill' ( :, , ", ,"" , " " ': ,,' ", .- , MARATHON OIL CO:MPANY 'Page1of2.. :" :" ':"l',', ".. ',','..'" ", , , ',"', Daily DriU ingRøport , .- ' , ,',:" ,',,', " "" :':" " , '" ' , , " ' WELL NAME ST I KB GL 24 HRS PROG TMD TVD DFS REPT NO. DATE KU 21-6RD 01 80.00 59.00 21.0 3.498 3062 1 12 8/31/2001 SUPERVISOR RIG NAME & NO. I!RlG PHONE AUTH MD AFE NO. AFE COST RC. Lawson GLACIER DRILLING 1 907-283-1312 5,650 9206501 643 000 CURRENT STATUS IMOCWI JNRI DAILY WELL COST CUM WELL COST P/U Directional BHA. 100.00 (% 87.50 (% 119 378.00 430406.00 24 HR FORECAST ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST Drill directional hole. None 8/29/2001 8/25/2001 FIELD NAME I STATEIPROV COUNTY/OTHER LAST CASING I NEXT CASING LEAKOFFPPG Kenai Alaska Kenai 7.625 (in) @ 5620.0 (ft) 4.500 (in) @ 5,650.0 (ft) OP COMMENTS: Set whipstock and mill window. CIO 4" rams to 2 7/8" X 5"variable rams. P/U Directional BHA. , , OPERATIONS SUMMARY SUB PHASE' " FROM TO,' I:IRS, DEPTH FM 'DEPTH TO .. , .. DESCRIPTION 06:00 07:00 1.00 SIDET P/U whipstocklmillout BHA. Test MWD. 07:00 09:00 2.00 SIDET RIH w/4" DP 10 stands. Test MWD. 09:00 10:00 1.00 SIDET Cont. RIH w/4" DP to 3450'. 10:00 11:00 1.00 SIDET Orient whipstock and set @ 3483'(45deg left of high side). 11:00 13:30 2.50 SIDET Organize and clean rig while condition mud in pits. Change shaker screens. 13:30 14:00 0.50 SIDET Displace hole to mud. 14:00 20:00 6.00 SIDET Mill window f/3463' to 3477'. Drilled new hole 3477'-3498'(window is 3463' to 3477') 20:00 21:00 1.00 SIDET Pump 25bbl sweep and circ. out 21:00 22:00 1.00 SIDET Pump 25bbl sweep and circ. outPerform FIT to 12.5ppg EMW(500 psi surface pressure). 22:00 01:00 3.00 SIDET POOH wI window mill assy. 01:00 02:00 1.00 SIDET UD window mill assy. 02:00 02:30 0.50 SIDET Pull wear bushing. 02:30 03:30 1.00 SIDET CIO 4" Pipe rams to 2 7/8" X 5" Variable rams. 03:30 04:30 1.00 SIDET Test variable rams 250/3000psi 10min w/4" and 3 1/2" test string. 04:30 05:00 0.50 SIDET Pull test plug install wear bushing. 05:00 06:00 1.00 SIDET P/U 6 3/4" bit and directional BHA. DENSITY(ppg) , 9.20 i PP ECDI MUD,DATAI DAILY COST I 7,378.00 I CUM COST 15,556.00 ': ,FV :'PVNP' GELS WLlHTHP' 'Fcrr.SOL OILIWÄT, ", °i..Sand/MBT, :,:'" Ph/pM ' Pf/Mf ,', . ',' 'C/" ',', Ca H2S ' LIME 'ES' 54 9/20 8/12 9.21 2.017.0 I 0.25/5.0 9.00/0.1 0.110.9 19,000 BITS, ' , , .. , '" , , .. .. '" BIT / RUN SIZE' MANUF.-, TYPE:' SERIAL NO., ,JETSORTFA " ,'DEPTH IN DATE IN "I-O-D.L.B.G-O.R' ; 2/1 6.125 Baker Starter Mi 16/16/16/16/161 3,463.0 8/30/2001 0-0------ BIT / RUN WeB RPM GPM PRESS P BIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 2/1 4/15 80/120 249 1,000 2.50 20.0 8.00 2.50 20.0 8.00 'BHA BHA NO. LENGTH EFF WT. PICK UP SLACK OF~ ROTWT. TORQUE (maximin) BHA HRS JAR HRS MWD,HRS MTR HRS " S5 H R5 - 4 875.59 20 73 55 60 4,000 / 6,000 BHA DESCRIPTION 6 1/4" Starter Mill , 6 1/4" Lower Window Mill , 6 3/4" Upper Window Mill , 3 1/2" HWDP , 4 3/4" Bumper Sub, Non Mag XIO MWD Tool, Restrictor Sub 43/4" DRILL COLLARS (2), 31/2" HWDP (24),31/2" IF-P X 4" HT-38-B ,4" 14PPF 5-135 DP PUMP I HYDRAULIC :DAT A .. : " , , .. , , .. .. NO. ' MAKE OF PUMP '" STROKE (in) ,LINER (in) SPM'" Q,(gpm) PRESS. (psi) TOTAL Q , KILL SPM:I PRESSlJRE -- -- - 1 OILWELL 8.000 4.500 80 124.26 1,000 248.52 2 OILWELL 8.000 4.500 80 124.26 1,000 248.52 SURVEY DATA N/S CUM EIW, CUM SËCTION M.D. INCL. AZI TN.D. N/S CUM EIW CUM SECTION i M.D. INCL. All T.V.D. 0 0.00 0.00 0.00 0.00 0.00 0.00 - Printed: 8/31/2001 2:29:50 PM ( ( MARATHONOIL.'COMPANY. , , , Daily:Dri Iii ngRep()rt COMPANY Glacier Drilling Marathon MI SERVICE 24 HRS PROG 21.0 GL 59.00 PERSONNEL DATA NO. HOURS COMPANY 17 216.00 Baker Inteq 1 24.00 Epoch 1 24.00 SERVICE NO. HOURS 4 60.00 4 48.00 Printed: 8/31/2001 2:29:50 PM MARATHON Oil COMPANY ( DAILY WELL OPERATIONS REPOR(' PAGE 1 OF 1 DATE: 12/11/2001 FIELD: Fill DEPTH/DATE: PBTD 5563' TUBING: WORK DONE: Run 2 3/8" Velocity String PRESENT OPERATION: Complete OTH ER: Zero at Tubing Hanger Kenai Gas Field WEll #: 4 1/2" l 80 Buttress, cemented liner CASING: TREE CONDITION: CREW: KU 21-6rd 75/8" New Dowell Hrs. SUMMARY OF OPERATIONS 9:00 Hold PJSM. PU Injector head. MU tool string 10:00 Prepare to pressure test. Lines are freezing up (Temp=9 degrees F). 12:00 Call out for methanol to pressure test 13:00 load vac truck wI methanol and water 14:00 Pressure test BOP body and CT plug to 2000psi. Test good 15:00 RIH w/2 3/8" CT velocity string 15:40 Test rebuilt slip rams at 25501. Rams held. RIH to 52551. Measure from lock screws to above BOPs. PU 14.41. Engage slips and pull test.Bleed 16:00 through packott, break lubricator and walk up injector head to expose pipe. 16:30 Cut weephole in pipe to ensure no gas. Rough cut CT. 16:45 Dress CT and Vetco install 2 3/811 seal assembly. MU CT connector and GS to spool side CT. Stab GS pumpoff tool into hanger profile. Remeasure from seal assy groove to lock screws (15.11) Walk 17:00 injector head down and close lubricator 17:30 Pull test connector against rams to 18K# (Pipe weight -18K#) RIH. Weight indicator dropped off at 14.61. (about 0.51 high). Run in lock screws on hanger. At one 18:00 point, regain weight, then dropped off again. 19:00 Finish running lock screws. Pressure test between seals wI hydraulic oil. Test no good. Pump plastic 19:45 Plastic would not hold pressure. Decide to pull hanger. 20:00 Inspect hanger. lock screw marks show It did not seat on load shoulder (-.51 high). Redress and modify. 22:50 MU redressed hanger and measure 13.751 to lock screws. Pull test 18K# 23:00 RIH to 13.31. PU and attempt to run deeper. Suspect hanger is not adequately centralized in wellhead. Rllockscrews. Observe increase in CT weight. Run out lockscrews (Iockscrews centralized hanger). 23:50 RIH additional 0.51 to load shoulder. Rllockscrews again. 0:00 Pressure test seals. Test unsuccessful. 1:00 Pump plastic between seals. 1 :30 Bleed pressure above CT hanger and observe 1:45 Pressure remains at Opsi above hanger (250 psi below) 2:00 Pump off GS. PUH. Blow CT dry. Rig back injector head. Install night cap 3:00 SDFN Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. Crew/Unit/Tools $0.00 Dowell N2, pump, crew $0.00 Veco Vac Truck $0.00 Doyles Methanol $0.00 Costs Forward...... $0.00 DAI l Y COST: $0.00 CUM: $0.00 REPORTED BY: Titus MARATHON OIL COMPANY (' DAILY WELL OPERATIONS REPOF( PAGE 1 OF 1 DATE: 12/7/2001 FIELD: Kenai Gas Field FILL DEPTH/DATE: PBTD 5563' TUBING: 4 1/2" L 80 Buttress CASING: WORK DONE: Continue Re-perforate Pool 6 w/ E-line TREE CONDITION: PRESENT OPERATION: Complete CREW: OTHER: Zero at Tubing~er WELL #: KU 21-6rd 7 5/8" w/4 1/2" liner New Schlumberger Hrs. SUMMARY OF OPERATIONS 11 :00 13:00 13:55 14:45 15:00 16:40 17:30 18:00 Schlumber arrives, cut and re-tie head from previous run's line damaqe RIH w/ 20' gun #2 Correlate on depth and shoot 5270'-5290'. PUH immediately in effort to prevent line damage in the event of blow-up. Drop down, shoot again to be certain guns are fired At surface. Arm gun #3 RIH w/20' gun #3 Correlate on depth and shoot 5250' -5270'. Noticeable shake in van. POOH At surface. Beqin RD SLB Pwh-260 psi. Plan to inject meter gas through evening and turn well to system in AM. SDFN Vendor Equipment Daily Cost Cumulative Cost Schlumberger E-Line and Perf Guns $16,000.00 $16,000.00 Costs Forward $17,000.00 $33,000.00 $33,000.00 $0.00 CUM: REPORTED BY: DAILY COST: Titus MARATHON OIL COMPANY ( DAILY WELL OPERATIONS REPOR( PAGE 1 OF 1 WELL #: KU 21-6rd 7 5/811 wI 4 1/211 liner at 3295' New Schlumberger DATE: 12/6/2001 FILL DEPTH/DATE: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field PBTD 5563' TUBING: 4 1/211 L 80 Buttress CASING: Re-perforate Pool 6 wI E-line TREE CONDITION: 1 run complete, 2 remaining CREW: Zero at Tubing Hanger Hrs. SUMMARY OF OPERATIONS 11 :00 12:30 15:30 17:30 18:30 18:45 18:50 19:15 20:00 20:30 21:00 22:00 22:50 23:10 23:20 0:00 0:10 Schlumber arrives, layout equip begin RU. Wait to pull well house RU Scaffolding Continue RU Schlumberger PU 511 lubricator PJSM. Discuss procedure and weather issues P-test lubricator wI wellhead pressure. No leaks detected RIH wI Gamma Ray to correlate Log up At surface Safety Mtg Arm guns RIH wI 1st gun Correct delpth at liner hanger Correlate on depth Shoot 5290' -5310'. POOH At surface. Stuck in lubricator, but able to close all tree valves. Hold brief meeting PU lubricator and tool. Tether carrier end and pull out of lubricator wI crane. Line is kinked from carrier jumping up hole when shot. SDFN Vendor Equipment Daily Cost Cumulative Cost Schlumberger E-Line and Perf Guns $16,000.00 $16,000.00 Udelhoven Scaffold, Pull Wellhouse $1,000.00 $17,000.00 $17,000.00 $0.00 Titus REPORTED BY: DAI L Y COST: CUM: MARATHON OIL COMPANY ( DAILY WELL OPERATIONS REPOR( PAGE 1 OF 1 DATE: 11/27/2001 FILL DEPTH/DATE: PBTD 5563' DATE LAST WL WORK: WORK DONE: Fire modular StimGun w/ nitrogen, run gauges PRESENT OPERATION: Complete OTHER: Zero at Tubing~er SUMMARY OF OPERATIONS 0900 MIRU Pollard Wireline, BJ Services N2 pump, and MOC flowback equipment. 1100 Add KCI water to wellbore as tamp fluid 1130 RIH wI swage. Tag fluid at 3390'. POOH. Perform firing head calculations: Nominal firing pressure: 2800 psi. Hydrostatic Fluid Head: 690 psi Required N2 pressure: 2000 psi Engage battery on Fast gauge, install in carrier, and MU to tool string RIH wI Fast gauge. Place on top of gun assembly. POOH Rig back lubricator. RU BJ N2 lines to Pollard pump in sub. Hold Safety meeting. P- Test N2 lines to 3000psi. Test good Open well and begin pumping nigrogen. Pressure at 2000psi. Block in pressure and shut down pump. Wait on 12 min. firing head. Detected guns going off on sound recorder. Observed minimal pressure drop at wellhead. Continue to watch pressure. Decide to pump nitrogen to max firing pressure (2200 psi). Formation seems to be taking some pressure while pumping. Shut down at Pwh=2150 and observe pressure. Pwh=2025psi Pwh=2000psi Pwh=2000psi Fairly rapid drop to 1350 psi Pwh=950psi Continues to drop to 500psi Begin RDMO BJ pumping svc. RU Pollard lubricator to grab Fast gauges. Pwh=300 RIH wI pulling tool. Engage carrier @ 5440' KB and POOH .., At surface wI Fast gauges. Remove gauges from carrier and prepare to ship to Bob Daly at PIC. RDMO PWS. Prepare to turn well to open top tank via surface flowline at wing. Surface flowline flanges leaking. Shut well in. Pwh=250psi SDFN plan to hammer up flanges in AM to flowback. 1200 1215 1330 1400 1410 1415 1455 1507 1515 1520 1526 1531 1536 1539 1541 1544 1549 1600 1620 1730 1800 1815 1830 FIELD: TUBING: Kenai Gas Field 4 1/2" L 80 Buttress CASING: TREE CONDITION: BENCHES OPEN: CREW: Pollard, Halliburton, BJ Services Hrs. 16 WELL #: KU 21-6rd 51/2" New 1-" Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. Crew/UnitfTools $3,502.50 $3,502.50 BJ Services N2, pump, crew $9,950.00 $13,452.50 Halliburton Guns, crew $41,800.00 $55,252.50 R&K Vac truck $300.00 $55,552.50 Costs Forward...... $14,722.50 $70,275.00 DAILY COST: $55,552.50 $70,275.00 CUM: REPORTED BY: Titus MARATHON OIL COMPANY ( /'" DAILY WELL OPERATIONS REPORt PAGE 1 OF 1 DATE: 11/16/2001 FILL DEPTH/DATE: PBTD 5563' DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: TUBING: Kenai Gas Field 4 1/2" L 80 Buttress CASING: TREE CONDITION: BENCHES OPEN: WIRELINE CREW: Hrs. WELL #: KU 21-6rd 5 1/2" New Reposition Hanger, run Perf Guns Complete Zero at Tubing Hanger Barrow/Biggsrrh. Doherty/W. Easling 16 SUMMARY OF OPERATIONS 08:00 Travel wI W/L Truck to KGF Office 08:30 Checked in, held brief safety meeting, spotted equipment, twist tested wire - 24 & 24 09:30 Stand-by, preparing well, R/U scaffolding, secure well 13:00 R/U W IL wI 36' of 4 1/2" Lub, 4 1/2" WL V, Pump-in-Sub, and regular 30' x 3 1/2" Lub 14:00 Stand-by for Halliburton 15:00 Ran 21' of Halliburton Perforating Guns to Hanger at 5303' WLM, sat down, Jarred down several times unable to Shear and release Guns, POOH Checked tools, added Knuckle Joint above Pulling Tool, repinned JD PIT Reran Perf Guns to 5303', sheared, released, POOH Ran 2nd Perf Guns to 5282', sheared, released Guns, POOH Ran 3rd Perf Guns to 5256', sheared, released Guns, POOH Ran 4th Perf Guns to 5210', sheared, released Guns, POOH RID W IL, secured well, cleaned tools and work area, made report Travel to Shop 16:30 17:30 18:35 20:00 21 :10 22:15 24:00 Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. 3" JDS Pulling Tool $100.00 $100.00 Pollard Wireline Inc. Supervisor $1,200.00 $1,300.00 Pollard Wireline Inc. 12 hrs $2,080.00 $3,380.00 Pollard Wireline Inc. 4 add hrs $600.00 $3,980.00 $3,980.00 CUM: $3,980.00 REPORTED BY: DAILY COST: S. Bookey ( f' \ Page 1 of 1 Shannon, L F (Leonard) From: Berga, Peter K. Sent: Friday, August 31, 2001 5:36 To: Shannon, L F (Leonard) Subject: FW: BOPE test extention Trip assembly. -----Original Message----- From: Tom Maunder (mailto:tom_maunder@admin.state.ak.us] Sent: Friday, August 31, 200110:55 AM To: Lawson, Rowland C. Cc: jef(Jones@admin.state.ak.us; Berga, Peter K. Subject: Re: BOPE test extention Row land, As we talked earlier, you have obtained the variable bore rams and successfully conducted a low/high pressure test on them. Your request to extend the test until you trip this assembly is acceptable. Good luck. Tom Maunder, PE AOGCC "Lawson, Rowland C." wrote: Tom....! would like to request an extention to the test date for our next full BOPE test. We will have one week since our last BOP test on 1-Sept 23:30. I have just got on bottom with a new bit and feel I shold be good to drill for the next 2.5 days. If given the extension I will test on my next trip out. Thanks.......Rowland Lawson 8/31/2001 ( ( " .' '" , '. : I:, MARATHON OIL COMPANY PagEt 1 ,of2' , ' ,,' " , '" ,,'.', . ,': , :,' :.. , ,'" ' """ DailyDliliingRéport ,',::,: .. ' " , ~ WELL NAME ST KB GL 24 HRS PROG TMD TVD IDFS2 REPT NO. DATE KU 21-6RD 01 80.00 59.00 I 772.0 4,270 3,652 13 9/1/2001 SUPERVISOR RIG NAME & NO. I!RlG PHONE AUTH MD AFE NO. AFE COST RC. Lawson GLACIER DRILLING 1 907-283-1312 5.650 9206501 643 000 CURRENT STATUS IMOCWl ]NRI DAILY WELL COST CUM WELL COST Drillina ahead lã>. 4270'. 100.00 (% 87.50 (% 50416.93 497 629.93 24 HR FORECAST ACCIDENTS 24HR LAST SAFETY MfG. BOP PSI TEST Wiper trip to CSG shoe. RIH. Drill ahead. None 8/29/2001 8/25/2001 FIELD NAME I STATEIPROV I COUNTY/OTHER LAST CASING I NEXT CASING LEAKOFFPPG Kenai Alaska Kenai 7.625 (in) @. 5 620.0 (to 4.500 (in) lã>. 5 650.0 (ft) 12.42 OP COMMENTS: Dir drill and survey f/3498' t03529'. POOH and change MWD. RIH. Dir drill and survey f/3529' to 4270'. , OPERATIONS SUMMARY FROM "'TO' HRS ': DEPTH FM DEPTH ,TO , 'SUB PHAsE' ,, 'DESCRIPTION: " " 06:00 07:00 1.00 SIDET RIH w/Directional BHA test motor and MWD. 07:00 09:00 2.00 SIDET Cont. RIH w/4" DP. 09:00 09:30 0.50 SIDET Break circulation and open hole f/3480' to 3498'. 09:30 12:00 2.50 3,498 3,529 SIDET Dir drill and survey f/3498' to 3529'. ART .5hrs. MWD tool failure. 12:00 12:30 0.50 SIDET Mix and pump dry job. 12:30 14:00 1.50 SIDET POOH. 14:00 15:00 1.00 SIDET CIO MWD tool. 15:00 17:00 2.00 SIDET RIH. Test MWD. Cont. RIH. 17:00 06:00 13.00 3,529 4,270 SIDET Dir. Drill and survey f/3529' to 4270'. AST=2.5hrs ART=6.9hrs. : Q,ENSITY(ppg),:, 9.00 I,pp:: E(:p I MUD':DATAI:,DAILY,COST ,I 5,970.93 j, CUM COS:r ': 21,526.93 FV : : PVIYP GELS ,, : WLlHTHP, .' F,CIT.SOL C)ILIWAT ;' 'DfaSand/MBT" Ph/pM Pf/Mf ,CI ",Ca' H2S LIME: ":ES 43 9/19 8/11 8.81 2.0/6.0 I 14.0 9.001 10.9 15,000 '" .. " "::BITS '.. .. .. .. BIT I RUN SIZE' , "MÁNUF.: .. , TYpE' SERIAL NO.: JETSORTFA, ':' DEPTHIN,DATE,IN', ' : ; 'I.O.D.L.B~G.O~R .. 2/1 6.125 Baker Starter Mi 16/16/16/16/161 3,463.0 8/30/2001 0-0------ 3/1 6.750 Smith XR+ MH7390 12/12/12/11 3,498.0 8/31/2001 0-0------ BIT / RUN WOB RPM GPM PRESS P BIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 3/1 4 110 40/45 300 1,800 679 9.40 772.0 82.13 9.40 772.0 82.13 " BHA " , , ' , , , " ,, ' , -- I PICK UP, I SLACK OF~ ROT WT. TORQUE (maxImin) : " BHA HRS, JAR HRS' : ,I MWD HRS' MTR HRS' , SS I-jRS : BHA NO. ,LENGTH, EFF.WT. 6 859.80 21 I 85 I 55 65 4,500 I 4,200 22 22.00 I 22 22 22 BHA DESCRIPTION 63/4" XR+ BIT, M. MOTOR W/6 5/8"UBHS/1.2 AKO, 6 5/8" IBS, NON-MAG XJO, COLLAR MWD, RESTRICTOR SUB, 31/2"HWDP (4), 4 3/4" DAILY HYDRAULIC JARS, 31/2" HWDP (21), 31/2" IF-P X 4" HT-38-B 14" 14PPF S-135 DP PUMP I HYDRAULIC DATA NO., ' , ,MAKE OF' PUMP STROKE (In) LINER (in) "SPM Q (gpm) , PRESS. (psi) TOTAL Q, ',KILLSPM I PRESSt)RE " ---- .-------, ,,---, 1 OILWELL 8.000 4.500 95 147.56 1,800 295.12 2 OILWELL 8.000 4.500 95 147.56 1,800 295.12 SURVEY DATA M.D. INCL.' All T.V.D. N/S CUM EIW CUM SECTION M.D. INCL. All T.V.D. N/S CUM EIW CUM SECTION --'- -,- ,--,..--.--, -----, .. .. -~- 3,452 30.92 117.00 3,021.35 -563.48 1,371.31 0.00 3,928 33.20 100.10 3,420.83 -628.88 1,620.29 1,738.05 3,681 34.00 103.70 3,214.80 -605.42 1,486.11 1,604.42 3,990 32.40 103.20 3,472.95 -635.65 1,653.17 1,771.17 3,747 33.20 99.10 3,269.78 -612.65 1,521.89 1,640.40 4,048 32.00 105.70 3,522.03 -643.36 1,683.10 1,801.86 3,805 33.60 99.40 3,318.20 -617.78 1,553.40 1,671.65 4,111 31.80 108.00 3,575.51 -653.00 1,714.95 1,835.05 3,867 33.50 99.10 3,369.87 -623.29 1,587.22 1,705.19 4,173 31.40 112.20 3,628.33 -664.16 1,745.45 1,867.52 PERSONNEL DATA ' .. COMPANY SERVICE NO. HOURS: COMPANY SERVICE NO. HOURS ----, Glacier Drilling 17 216.00 Marathon 1 24.00 Printed: 9/1/2001 10:33:15AM (" ( .... .. ~ ~, ,~ - Daily DrilliOQ <Report GL 59.00 COMPANY SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 24.00 Epoch 4 60.00 SERVICE NO. HOURS 4 48.00 MI Baker Inteq Printed: 9/1/2001 10:33:15 AM ( ( :- ' -c- -c- ", "" ,," ' " ' MARATHON OIL COMPANY Pa~e1of2 ,/ ",','" " Daily DriliingRE)p,ort ' .'",', ,'c ,,', '.,' .' ..",' ,", '.. ,',',' .','.'.":'~ WELL NAME ST IKB IGL [24 HRS PROG TMD TVD DFS REPT NO. DATE KU 21-6RD 01 80.00 59.00 4.579 3976 3 14 9/2/2001 SUPERVISOR RIG NAME & NO. I!RIG PHONE AUTH MD AFE NO. AFE COST RC. Lawson GLACIER DRILLING 1 907-283-1312 5650 9206501 643 000 CURRENT STATUS ~ MOC WI ;~ NRI DAILY WELL COST CUM WELL COST DrillinQ ahead @ 4579'. 100.00 {% 87.50 (% 42 103.00 539.732.93 24 HR FORECAST ¡ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST Drill ahead. None 8/29/2001 8/25/2001 FIELD NAME I STATEIPROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFFPPG Kenai Alaska Kenai 7.625 (in) (â) 5 620.0 (ff) 4.500 (in) @ 5.650.0 (ft) 12.42 OP COMMENTS: Dir Drill and survey f/4270' to 4579'. Pump LCM Pills to reduce lost circulation. Lost 480bbls mud to hole in last 24hrs. .. OPERATIONS SUMMARY , , FROM . TO HRS .DEPTH FM 'DEPTH TO SUB PHASE ' DES,CRIPTION . .. 06:00 06:30 0.50 4,270 4,271 SIDET Dir Drill and survey f/4270' to 4271'. Lost returns. 06:30 07:30 1.00 SIDET Spot 27bbls LCM pill(29ppb Safecarb Med, 11 ppb Safecarb Course). 07:30 08:30 1.00 SIDET POOH to window. 08:30 09:30 1.00 SIDET Service rig. 09:30 10:00 0.50 SIDET RIH to 3489'. Stage pumps up to 250gpm with no losses. 10:00 10:30 0.50 SIDET RIH to 3929'. Stage pumps up to 218gpm with no losses. 10:30 11:00 0.50 SIDET RIH to 4235'. Stage pumps up to 218gpm with no losses. 11:00 11:30 0.50 SIDET RIH to 4270'. Stage pumps up to 218gpm with no losses. 11:30 13:00 1.50 4,271 4,359 SIDET Dir Drill and survey f/4271 , to 4359'. Lost returns(started loosing returns @ 4345' and lost all returns @ 4359') ART=1hr AST=Ohr. 13:00 14:30 1.50 SIDET Spot 15 bbls LCM pill(29ppb Safecarb Med and 11ppb Safecarb course). 14:30 16:00 1.50 SIDET Pull bit to 4194'. Slow rotate and work pipe. Monitor well (well loosing 20bbllhr in static condition). 16:00 17:00 1.00 SIDET Spot 15 bbls LCM pill(29ppb Safecarb Med and 11 ppb Safecarb course). 17:00 18:00 1.00 SIDET Spot 15 bbls LCM pill(29ppb Safecarb Med and 11ppb Safecarb course).Monito well (losses 4bbl/hr). 18:00 18:30 0.50 SIDET Stage pumps to 250gpm(very slight losses). RIH to 4359'. 18:30 23:00 4.50 4,359 4,544 SIDET Dir Drill and survey f/4359' to 4544'. (Losing mud at a rate of 150bbls/hr last 30min of drilling) ART=3.5hrs AST=.5hrs. 23:00 00:30 1.50 SIDET Spot 15 bbls LCM pill(29ppb Safecarb Med and 11 ppb Safecarb course). Well staic with pumps off. Losing 120bbls/hr @ 200gpm. 00:30 03:00 2.50 SIDET Spot 15 bbls LCM pill(29ppb Safecarb Med and 11ppb Safecarb course). Lost 60bbls/hr while pumping pill @ 110gpm. Observe well lost 1.5bbls/hr. 03:00 05:30 2.50 SIDET Spot 15 bbls LCM pill(29ppb Safecarb Med and 11 ppb Safecarb course). Lost 60bbls/hr while pumping pill @ 110gpm. Observe well lost 1.0bbls/hr. 05:30 06:00 0.50 4,544 4,579 SIDET Dir Drill and survey f/4544' to 4579. ART=.5hrs AST=Ohrs. DENSITY(ppg) 8.85 : PP ,ECDI I MUD:DATAI DAILY cOST ,I 10,212.00 I CUM,COST I 31,738.93 'FV' PVNP GELS WL/HTHP FCIT.SOL OILIWAT %SandfMBT , Ph/p'M Pf/M,.' CI . Ca', "H2S LIME , 'ES' 43 8/20 7/11 9.61 2.0/6.0 I 15.0 9.001 10.8 14,500 BITS .. " .. BIT IRUN, SIZE MANUF. TYPE SERIAL NO. ' JETS ORTF:A DEPTH IN DATE IN ' l.cj.D-L.B:-G.O-R 311 6.750 Smith XR+ MH7390 12/12/12/// 3,529.0 8/31/2001 0-0------ BIT f RUN WOB RPM GPM PRESS P BIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 3/1 6 114 45/45 250 1,100 464 5.63 309.0 54.88 15.03 1,050.0 69.86 BHA . BHA NO. LENGTH EFF ~T: --I~IC~~~--+~~~~_~..?~R ROTWT. TORQUE (maxImin) BHA HRS JAR HRS MWD HRS MTR HRS , SS'HRS -,------ --- 6 859.80 72 3,000 I 5,500 44 44.00 44 44 44 BHA DESCRIPTION 63/4" XR+ BIT, M. MOTOR W/6 5/8"UBHS/1.2 AKO , 6 5/8" IBS , NON-MAG XIO , COLLAR MWD , RESTRICTOR SUB, 31/2"HWDP (4), 4 3/4" DAILY HYDRAULIC JARS, 3 1/2" HWDP (21), 31/2" IF-P X 4" HT-38-B , 4" 14PPF S-135 DP Printed: 9/2/2001 7:20:14 PM ( (' " "," '" ", "< ,,' ' , ' , ' .., ' , I, , MARATHON OIL COMPANY Rage,2of:2'.~i' , " :DailyDriUing Repørti' ;, " ,".." , , "',", " ," ,," ,"' ..",', ' ' """ ..', " ,,.", WELL NAME ST KB GL 24 HRS PROG TMD ITVD DFS REPT NO. DATE KU 21-6RD 01 80.00 59.00 4579 3,976 3 14 9/212001 i' ' ~ " ,',,"" ,"", ','. ,',""" '"," ,: ""i'PlJMPrHYDRÄutlcDATA ' :, ,':,: :'-,:",:..', .,:".,' , :,'," ,-,,",.," NO. MAKE OF PUMP STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q KILL SPM I PRESSURE 1 OILWELL 8.000 4.500 70 108.73 1,100 217.46 2 OILWELL 8.000 4.500 70 108.73 1,100 217.46 SURVEY DATA' M.D. INCL. All T.V.D. N/S CUM EIW CUM 'SECTION M.D. INCL. All T.V.D. N/S CUM EIW CUM SECTION' 4,235 31.50 113.20 3,681.22 -676.64 1,775.29 1,899.85 4,425 31.70 112.50 3,843.05 -715.62 1,866.89 1,999.35 4,299 31.50 113.10 3,735.79 -689.79 1,806.04 1,933.27 4,487 31.60 110.00 3,895.83 -727.41 1,897.21 2,031.87 4,363 31.70 113.20 3,790.30 -702.97 1,836.87 1,966.78 PERSONNEL DATA, ' , .. COMPANY SERVICE NO:: :'HOURS COMPANY SERVICE 'NO. , HOURS , ' Glacier Drilling 17 216.00 Baker Inteq 4 60.00 Marathon 1 24.00 Epoch 4 48.00 MI 1 24.00 Printed: 9/212001 7:20:14 PM (' f :" ',', ,', ' ", :", ,c." , ':' ,"" """ , , : MARATHON OIL ,COMPANY ,Pé19E! : 10[2 ' :', ':,: , .. r)"'"ID"-U"":":"'R""" ,"'" d: ' , "êU,Y. ",n ,'fig ,epö . " : "" , ', ',' .. ,< ,':, :, " ",' ,'" WELL NAME ST \KB GL 24 HRS PROG TMD TVD DFS 4 REPT NO. DATE KU 21-6RD 01 80.00 59.00 451.0 5,030 4,358 15 9/3/2001 SUPERVISOR RIG NAME & NO. I!RlG PHONE AUTH MD AFE NO. AFE COST RC. Lawson GLACIER DRILLING 1 907-283-1312 5650 9206501 643.000 CURRENT STATUS IMOCWI JNRI DAILY WELL COST CUM WELL COST Drilling ahead @ 5030'. 100.00 (% 87.50 (% 54 977.00 594,709.93 24 HR FORECAST I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST Drill ahead to 5200'. CIO mud and drill production zone. None 8/29/2001 9/212001 FIELD NAME I STATEIPROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Kenai Alaska Kenai 7.625 (in) cw. 5.620.0 (ff) 4.500 (in) @ 5 650.0 (ft) 12.42 OP COMMENTS: Drill f/4579' to 4661'. CBU. POOH and C/O bits. RIH. Drill f/4661' to 5030'. ,OPERATIONS SUMMARY " FROM TO HRS DEPTH FM DEPTH TO SUB,' PHASE ': ' ',DESCRIPTION 06:00 09:00 3.00 4,579 4,661 SIDET Dir DRill and survey f/4579' to 4661'. ART=2.5hrs AST= 0 hrs. 09:00 10:30 1.50 SIDET CBU X 2. 10:30 11:30 1.00 SIDET POOH(wet) to the window. Observe well. 11:30 14:00 2.50 SIDET POOH (wet) 14:00 14:30 0.50 SIDET Pull wear bushing. Run test plug. 14:30 17:30 3.00 SIDET Test 27/8" x 5" variable rams w/4" and 3.5" test joints, annular, blind rams, all choke manifold valves. Upper and lower kelly cock valves. Floor safety valve and IBOP to 250psi/3000psi 5min. Pull test plug. 17:30 19:00 1.50 SIDET Run wear bushing. M/U 6 3/4" PDC bit and RIH w/directional BHA. 19:00 21:30 2.50 SIDET Test MWD. RIH(had to orient bit through window, lost returns while RIH but gained them back before reaching bottom). 21:30 06:00 8.50 4,661 5,030 SIDET Dir Drill and survey f/4661 I to 5030'. ART=4.2 hrs AST= 1.4 hrs. ,DENSITY(ppg) 8.80 I PP ECDI I MUD DATAl 'DAILY COST I 8,861.00 I CUM cOST' 40,599.93 FV, PVNP : GELS: WLlHTHP , FCrr.SOL' OllIWAT" '%Sa.,d/M~T, Ph/pM 'Pf/Mf " ',CI: " ,:--Ca" HZS LIME :, ES 46 8/19 8/10 8.8/ 2.0/4.0 / 15.0 9.00/ /0.9 15,000 ':BITS " , , ' , .. .. , .. " , , BIT / RUN SIZE' :,MANUF; TYPE ' SERIAL: NO. JETS OR TFA DEPTH IN DATE IN' :: ' I~O.D-L.B.G,O-~" 3/1 6.750 Smith XR+ MH7390 12/12/12/11 3,529.0 8/31/2001 3-3-WT-A-E- I-SD-PR 4/1 6.750 Smith C71:;PV .IR1984 10/10/10/10/101 4,661.0 9/2/2001 0-0------ BIT I RUN WOB RPM ~Hr ROP CUM HRS CUM DEPTH CUM ROP 3/1 5/10 45/41 ~f+' '3 32.80 17.53 1,132.0 64.58 4/1 2/3 45/4 ~ÓJ\ 70.96 5.20 369.0 70.96 I V) D (' : \ \ "",:'.) ~~~,W1<J" ' i BHA NO~' LENGTH' EFF WT.' IpIC~ :JAR HRS, I MWD HRS MTR HRS,', SSHRS 7 861.35 21 I 1 (p ).S ¡.J.) c\ r 0 ¡, 56.00 I 56 56 56 "'" "".,,", ,:.',/" ;\;;'<" ",I, 5' \ '~, r.""'" BHA DESCRIPTION 6 3/4" Smith PCI '-.1\ 3 XIO , COLLAR MWD , RESTRICTOR SUB , 3 1/2"HWDP ( Q I ,1/2" HWDP (21), 3 1/2" IF-P X 4" HT-38-B , <~{;ì>.o'.I 4" 14PPF S-13f ",,$ . (3) \. ( ç,;,/ ("" l' "~:\ ' 1 'I \ ,.... ~,éŸ. ~f ' . ',., , ,", ,",', ,~, q )" -- ' NO. MAKE OF PUMp : "If) (psi) TOTAL Q: KILL SPM / PRESSURE' 'c'" '\ f" " 1 OILWELL : "\ "\ "J ".I. 300 248.52 \",,' '".)I 2 OILWELL I 300 248.52 : ---,-- -- M.D. INCL. AZI T.V I T.V.D. N/S CUM EIW CUM SECTION 4,550 31.70 110.20 3,9¡ ~.50 4,162.78 -787.49 2,051.22 2,197.19 4,604 31.70 110.40 3,9bv."1'v -, -rv.v<- . ,-- ..-. -,- - ~.80 4,216.46 -800.18 2,081.64 2,230.14 4,672 31.80 112.10 4,053.23 -761.59 1,988.21 2,129.08 4,926 31.90 113.00 4,269.24 -812.84 2,111.61 2,262.65 4,739 32.00 112.40 4,110.11 -774.99 2,020.98 2,164.48 Printed: 9/3/2001 11:08:29 AM f l ~ MARA T H? N~OI LCO MPANY .l)ailyDrïllingJ~.eport , COMPANY Glacier Drilling Marathon MI SERVICE GL 59.00 24 HRS PROG 451.0 ',' PERSONNEL DATA NO. HOURS COMPANY 17 216.00 Baker Inteq 1 24.00 Epoch 1 24.00 HOURS 60.00 48.00 Printed: 9/3/2001 11:08:29AM (' ( " " " " , ' MARA THON,OIL'"(;OMPANY :..:"..,1,:,:"',:....,::';,',,--,.,,, ,t;)aHy' PrUling,,~~þort, " Page, t of-,1 " .. .... ." ,.. , " -- " '.. , .. WELL NAME KU 21-6RD SUPERVISOR RC. Lawson CURRENT STATUS Mixina Mud. 24 HR FORECAST Complete mixina mud. FIELD NAME Kenai ST KB GL 01 80.00 59.00 RIG NAME & NO. GLACIER DRILLING 1 24 HRS PROG TMD TVD 170.0 5 200 4.503 I RIG PHONE AUTH MD AFE NO. 1907-283-1312 5650 9206501 IMOC WI INRI DAILY WELL COST 100.00 (%~ 87.50 (% 37263.00 ACCIDENTS 24HR LAST SAFETY MTG. None 8/29/2001 NEXT CASING 3.463.0 (ft) 4.500 (in) Câ>. 5 650.0 (ft) DFS 5 REPT NO. DATE 16 914/2001 AFE COST 643 000 CUM WELL COST 631 972.93 BOP PSI TEST 9/2/2001 LEAKOFF PPG 12.42 Drill ahead to TD @ 5650'. I STATEJPROV I COUNTY/OTHER LAST CASING Alaska Kenai 7.625 (in) Câ>. OP COMMENTS: Drill f/5030' to 5200'. POOH to just below window. Mix new mud for C/O. ::"~:f(('i~:¡>;\)::'::';::,'¡::;.::",.\t:::'::-:;,::>:::;,,:,:::¡:::,:<::,:;:::,~-::,:::,:,;¡:::.'<;:,::,.:,,','!:':::\::::':;<'\:OPERATld'NS::;SUMMARY:,:;¡::::..;:,:>:;\:"<~:::/:<'::"';'0::,:'::: ~::;':::¡~,';::,/,:>"',!:,>:: ::,,-¿,:', ::",<;i::":,;: <~;::::J,A:¡::: ~~~o,.,:::);jÞ:it :!}~R.$,':::: ::ii~~H::~~' !'D'ep-rH:-TC:>:' "'-)~4Ø::;/( ~:':Þ.~s:~::;: ::;/+'ij<:?(;::::1:~¡::';!:'~):i;:;y:'t':1:::;;:::':':i'":,';,;:'::;::+:(;::~,Esë,RI~Ï'IPR:¡~)«r:;,::,,'::,::/:',:::::{:!:::::h::/:':r::,-",'j~'::/¡:i~<~:: 06:00 12:00 6.00 5,030 5,200 SIDET Dlr drill and survey f/5030' to 5200' ART=2.3 hrs AST=2.5 hrs. 12:00 13:00 1.00 SIDET CBU X 2. 13:00 14:00 1.00 SIDET POOH to 3515'. 14:00 18:00 4.00 SIDET Dump Mud and Clean pits. 18:00 06:00 12.00 SIDET Clean and organize rig while mix 550bbls flopro mud. Hole loosing 1bbl/hr. D:~:~~~ltYh?pgt,¡: 8.80 I¡~~~:', ',E~D I I:Mú'D:!,bÄTA;'I¡~):?,t\iLÿ',çq~r::;1 1,162.00 i:ç~~iift~9St.:: 41,761.93 :T:);:,y;:;:::t::pv(i,P.[!-: ::;'::ØE¡j~,:; ,;::;VvL~HrHP"; :::::'F~n:~~91:-:' :;::'::~PI~iW~r:'r;:; ~;'j¡¡:-%$~"~~'V(ij:I\¡;¡j: ::!\>i(~þip.1\f:/,:;;:: ';~:~::P~!NI~):;:; ?;;;,!:<:þ( )¡~:: ~;'::~:;,}iä:,;~f <b,~2,~,~¡! qil,~I?' ¡¡!!:E~\; 46 8/19 8/10 8.81 2.0/4.0 I 15.0 9.001 10.9 15,000 4/1 6.750 Smith S75PX JS1984 10/10/10/10/101 .. 4,661.0 91212001 0-0------ BIT I RUN 4/1 WOB 3/18 RPM 45/45 GPM 250 PRESS 1,300 P BIT 344 HRS 5.80 24Hr DIST 170.0 24Hr ROP 29.31 CUM HRS CUM DEPTH CUM ROP 11.00 539.0 49.00 ¡:¡'\:::':,):'t::;'f:';:j/¡:;¡j';.;iÞl'::;(:>' ,>::Y/:','::hr:':::'::;:;:';::,::::;.::-t::?,~>':::::', '~i:!:;':i:":::::::;¡:;':;i::::\.;:;:<::::"::::'¡:-BHA,;,O;:.,;\::¡:::;:;" ::;:::}:: [;,S:L,::,;'::¡,::::(;;¿::,:;:¡:::: :>::,:¡:,::;'::;/:--" ,";:"": :,;;"':¡::"::'::::':::!:',;::':'\f';: ;«:~:;r;:,::¡¡':;di;); 'àHÄ:,~þ£ ';'i;: ;L,~~ç;TH;;:;-, E,FF"::WT;'i ~:: lp)(:::,Kl!P::,::': I :S,P\Çi$Þ.F ' 'RotYi!t)::;:. :TdRQ~~:{~~Xl.n*'} :~¡j:Y~H~;ïjR,S,:: :,Ji\R'H,RS ;,H.' ,MWP' ~,R~1! ,~t~':HR.§:: :SS:,'i:;IF'à?';::~ 7 861.35 21 I 100 I 60 75 3/8 58 58.00 58 58 56 BHA DESCRIPTION 63/4" Smith PDC , M. MOTOR W/6 5/8"UBHS/1.2 AKO , 65/8" IBS , NON-MAG X/O , COLLAR MWD , RESTRICTOR SUB ,3 1/2"HWDP (4), Float sub w/survey ring, 4 3/4" DAILY HYDRAULIC JARS, 3 1/2" HWDP (21), 31/2" IF-P X 4" HT-38-B , 4" 14PPF S-135 DP ":,',, ::'/""':::-';"'::'--::':<:':';:'¡:U;""" ':::':';:::::i':';":::-:'/';"-':"':'.-',"';::;"""':"""'þUMp:::rHYDRÄOUC';[)ATA:'\';'::':',:",i:::,:,;:¡;:;¡,::::::,':--:::-;-';,;:, ,,¡,'::-;:;' "':',' ;:1-",:,:'.i,:";""'",:,,,, :::;,';~ø;:;:';:/!i:,:¡>",:T~"':"¡'~;':':~:':@A~è'~~:;~ÜM~/'::::",;:,:-,:: ':;:,!:,,: '~~~ÓkE,(in) :)~'I~g~j¡ii),!' '::!"$~M:,:':' ;';1Cf(§p~).':":Þ~~s~;'(Þ~i)' >T,Ò;~¿:ø~;' Y":',~I~L;~P'M"";:~'~~~~:~~:~':\::;; 1 OILWELL 8.000 4.500 80 124.26 1,300 248.52 2 OILWELL 8.000 4.500 80 124.26 1,300 248.52 4,988 32.20 112.60 4,321.79 -825.59 2,141.94 2,295.54 5,115 31.80 113.00 4,429.73 -851.95 2,203.45 2,362.42 5,052 31.60 113.60 4,376.13 -838.85 2,173.05 2,329.34 :'" --:"':"Y""":-'"",..,,,' ,""":':,.. ","",' ":'::!'::PERSÖNNEL'DATA":<::,::<,"'-:>,:\: :,,"" ',::::,,',:';: ;-«:: ,;:,,::,;",:: !~:'::,::>:; , : C'.O"M"P'A'-N7"y-,7'- "'SERVICE"'" "'N'O':" "H'O"'U"R'S" ,"','COM'P"A"N'y",:-:""" "" SE'RV'IC"E"""'" "NO"" H"O"U'o's"".': """"':""':::' ",..,,' "':',,..:" '-:", "",::,,:, ..""",'<;-:",' ;:'..~""',.."f\:,,"-:' Glacier Drilling 17 216.00 Baker Inteq 3 60.00 Marathon 1 24.00 Epoch 4 48.00 MI 1 24.00 Printed: 9/4/2001 10:28:13 AM ( ( MARATHON OIL COMPANY Daily Drilling Report WELL NAME KU 21-6RD SUPERVISOR J.C LORENZEN CURRENT STATUS C.B.U. FOR SAMPLES I PREPARE TO SHORT TRIP 24 HR FORECAST SHORT TRIP I P .O.H. FOR LINER I RUN AND CEMENT LINER FIELD NAME I STATEIPROV I COUNTY/OTHER LAST CASING Kenai Alaska Kenai 7.625 (in) (ã} ST KB GL 01 80.00 59.00 RIG NAME & NO. GLACIER DRILLING 1 24 HRS PROG TMD 1VD DFS 6 450.0 5,650 4 884 I RIG PHONE AUTH MD AFE NO. 1907-283-131 5,650 9206501 I MOC WI NRI DAILY WELL COST 1100.00 (% 87.50 (% 59519.00 ¡ACCIDENTS 24HR LAST SAFETY MTG. None 8/29/2001 NEXT CASING 4.500 (in) @ 5 650.0 (ft) 3,463.0 (ft) Page 1 of 1 REPTNO. DATE 17 9/5/2001 AFE COST 643,000 CUM WELL COST 691.491.93 BOP PSI TEST 9/212001 LEAKOFF PPG 12.42 OP COMMENTS: DRILLING TO T.D. (}:",,:~;,:::'L:; ,;::~;:,/'/;:,",::::';;':":::;:;:~!'~,:': ,;:<,:):>¡::;:",::,::';:~)::::,..":\::~!::!;:::»:',:,;,<:::(;!:OP1~RATIONS::,SUMMARY<\,':: ':::,'::::':','::::,:':<":" :;,::<::;>;:~:,:\:';>,;:r:>:'~:«:::' ~,::,:,>:,';,:H::i:::::;;:::~,':,:Y::;!,;-;::; 'F'R"'O."M"", :";"T'O' '~:!,r '!!,'H'R'S/'" 'DEPTt¡'FM ,'DEP.j' H,:,.b :~¡:' :SUS:,::' '::PHAsE":) ,i;:,:',;:;,:::':::::¡i,:',':..:,.;:r:":":¡¡'::;~¡'" ",,:~~,';:/<,:,' " ""',"D'ESCRIPTioN':<',:. '¡:::':"',""',::,"'; ;,:":,;,;,,;,,::,,::'/,,,,:,/:..:;';.,:-,:'::1:'-;:"-::1'.. "';"',..,':-::,:,;""-!:i:,'::':",,\":,,..,""""""'-""",:'"",:""¡"":",:""""'",,,,,,"":"""'-,,.;,'":'~"",.".,::,!..;:",'i<',""""-,<'":,-,,,,:',,,!:,>"","""!",,,,.,', """,-"'",.'.',":,""""':'::":"":"'".."-",,,.:,:.":'::"",::,::":', 06:00 13:00 7.00 5,200 5,200 SIDET Rig Repair, RADIATOR WORK 13:00 14:00 1.00 5,200 5,200 SIDET Tripping 14:00 14:30 0.50 5,200 5,200 SIDET Displace ,CHANGE OVER TO NEW MUD 14:30 04:30 14.00 5,200 5,650 SIDET DRILL TO T.D. OF 5650' 04:30 06:00 1.50 5,650 5,650 SIDET CIRC. FOR SAMPLES ;i','DE'NS,'iTY('p""p"g' )";,:, 9 00 1:";'1':': ,ECO::I 1M' :"U" D"'{D: "A!!T",:^;,:':ÓÃILYJ~Ø$T<I 26428.00 ',::cÚrvfco$t::i: 6818993 """"",,";", "," . "", "",'-1 """1'."",,,.....:1, I"..",.""""", ,. ;¡"HFvd{ ,:,~\j~f :i~;~G:~F~,:¡': ;,;¡WP~TH:W ::~::~~rr;$o~:': i::(,~IWvV"'1:;::i"!! ::j3:~4~#:~'~/~BT.:~!:¡' :ï¡~~:d:iif~(pM>,:k, ::-:;':;;P.fjM~(!:l :;':1\,;'-(:I'~A:'i:1~: ~:H~)~~:;:;;:::, :<:~~St1!: ')~I~:I$': :i;Je.¡~J: 52 8/25 13/16 6.81 1.01 I 0.101 9.3010.1 0.1/0.1 33,000 40 ':';::~:;::;:>;/j/;;,;':::::;:(:::;,i;J;;.:,:!;~:j;J:;,f~:¡!:,::;:¡:¡~::h:;~:,¡::ijd::i.'r::;:þ:!::¡:;:i:;:t;,:;,';';;:~,:'E'{::¡:::::~;':'::::';1::t:r:~;): !¡::1';:::!::;)::;:;¡::~:!:~::¡' )!, BIi:S:i~k,!,~:¡;t::;:;:¡{::\;::::;¡::!\/;i',ir,':,::':::'--::A,;:i:;;:::':',¡:,;::: ;¡;;:!¡': :,¡:btj,:~::¡;>;;:¡;i;;~:;:;¡:~,:':':¡~:i;¡!;;!:;:":';:::;:;::~:,: ?;¡;:if:<";;:~;~:;:~::\::i::;\,;¡::;:)(::; :;,ø'r¡Ni~Q~~i, !t'! ';;§¡Z~~::;1i¡, ¡¡~~;:,~~:¡'r.d~~~:f'~;::¡¡ :1:t;;: :¡~!;E':!::¡;~~¡:1yP~;¡:;~i,U:~H: ~1:iJ~,ER:!~~::~:ø~:;(: !':L:!:;);(~~~~i9f{;:t.,",;~.A;;1';;;:::; i;!;';::::).E~fØ::I~i{D<~ì~;"~;;¡1,,';: ;':1: ;;:;,:,¡':H);.Q~,~~~t~:~P~R;i:~~\f¡~:' 4/1 6.750 Smith S75PX JS1984 10/10/10/10/101 4,661.0 9/2/2001 0-0------ BIT I RUN 4/1 WOB 17,500 RPM 145 GPM 249 PRESS 1,175 P BIT 348 HRS 11.25 24Hr DIST 450.0 24Hr Rap CUM HRS CUM DEPTH CUM Rap 40.00 22.25 989.0 44.45 ,>::,-:' ::t;::':::::::':::':':.;::/:;-;:!~::\tr,\;::':¡;~:;:<,~":<~::::¡':':': )',';::<::!';':::'¡(.'::i,,':'>::¡,::,,"':;, ':::::';::::,>:;",~';L:"":::::;;':.!BHA1::::;,:T').¡\,!::',:::!' ':':::.('::;!:":"::'::,/:\i/:'::>':'(::'jT,::,;::::;':,"~!"::<:¡::';;;;:<;':>::/!:':'! ',>';::¡\<:,:'=::::C:':":.:-:f,~'::'h ~HA:'N9:;V;:¡' L~~$ttf}:i: )~F~;'\i\iT:;:;;:::Jp'ICK-:V,P:;:\:~" ,ŠLAÞK:;þF~,~OTYI,I:r,:;;'~:;:rq'~þqé.:(m~~~I"h, f:.!';, ~HA}~~~/"~ARJ"~~¡;i':.i MWP.:HRS::I M.¡'~H~S ¡! ,$'s.:+:¡:~$;:j;:~¡::. 7 861.35 0 1 120 75 83 I 70 31.00 I 70 70 70 BHA DESCRIPTION 63/4" Smith PDC , M. MOTOR W/6 5/8"UBHS/1.2 AKO ,65/8" IBS , NON-MAG XIO , COLLAR MWD , RESTRICTOR SUB ,3 1/2"HWDP (4), Float sub w/survey ring, 43/4" DAILY HYDRAULIC JARS, 3 1/2" HWDP (21), 3 1/2" IF-P X 4" HT-38-B , 4" 14PPF S-135 DP :: ~~2' "¡::,~,, ,', 'ji:;~~~~~;~~~Þ'.t'!:.-,;'..'?' ~;~¿~: ~" ~~;':~i~ ~~~~ ~;~~r~'>;~~s.(~;.{;~~ii~~ ~:,;,:¡1:~ ¿~ ;~: i~~;~~;J~:';;¡ 1 OILWELL 8.000 4.500 80 124.26 1,175 248.52 2 OILWELL 8.000 4.500 80 124.26 1,175 248.52 ::,;',:,::"¡,';',:C:\..>::' <""<:',¡;::\:::',',:, '::':;::< ":;:,:::..::, ", ,.: .. :;, :iViUb':GAS; " ,. ....' : ., ):"':::;:':;':n, ,,":L/:,::,iJ~ir~ ,,;:1 AVG. CONN: AVG. TRIP: AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRl: 10 45 ; .',.~;:;::::. .. JN~L ,:~. '..'. ..' ,~'V,D, .'~~,~~~ Em c.~M:É~~~NE~ ~~I~.';N~L"'.' ..~r . .:;;,~J:~.,:;'. '~~:c~~ "~.J~~:;~~~C;~~'.¡ 5,173 32.00 112.40 4,478.97 -863.782,231.73 2,393.06 5,491 31.90 115.30 4,749.15 -931.17 2,385.28 2,560.57 5,237 32.00 112.70 4,533.24 -876.78 2,263.05 2,426.96 5,552 31.60 115.00 4,801.02 -944.81 2,414.33 2,592.59 5,299 31.90 113.20 4,585.85 -889.572,293.26 2,459.75 5,588 31.50 113.70 4,831.70 -952.582,431.49 2,611.40 5,362 31.60 114.00 4,639.42 -902.852,323.64 2,492.87 5,650 31.501 113.70 4,884.56 -965.6012,461.16 2,643,76 5,426 31.70 114.70 4,693.90 -916.69 2,354.24 2,526.40 I I ... " " PERSONNELDÀTA':' NO¡: . ' HOURs:.';'..' ,:'COMPANY 17 216.00 Baker Inteq 2 36.00 Epoch 1 24.00 " ,." SERVICE: .. " " '" :,. ,,:;COMPÁNY : Glacier Drilling Marathon MI . SERVICE ., " , " NOi;: HþÚR'S , , , 3 60.00 4 48.00 Printed: 9/5/2001 9:47:16 AM j.i ~ ( ," " ,.. M~RA THqN OIL CpMPANY " Pagé1 ..,of} .. , - , .. .. " pany. D.'r~lIi'rtg ~~PQrt .. -, '. WELL NAME KU 21-6RD SUPERVISOR J.C LORENZEN CURRENT STATUS CIRC ULATING : ON BOTTOM WI LINER: LOSING FLUID 24 HR FORECAST CEMENT LINER IN PLACE/W.O.C. I LAY DOWN DRILLPIPE AELDNAME I STATEIPROV COUNTY/OTHER LASTCASING Kenai Alaska Kenai 7.625 (in) @ ST KB GL 24 HRS PROG 01 80.00 59.00 RIG NAME & NO. GLACIER DRILLING 1 TMD TVD 5 650 4,884 I RIG PHONE AUTH MD AFE NO. 1907-283-131 5.650 9206501 I MOC WI NRI DAILY WELL COST 1100.00 (% 87.50 (% 34,387.00 ACCIDENTS 24HR LAST SAFETY MTG. None 8/29/2001 NEXT CASING 3 463.0 (ft) 4.500 (in) @ 5.650.0 (ft) DFS 7 REPT NO. DATE 18 9/6/2001 AFE COST 643,000 CUM WELL COST 725.878.93 BOP PSI TEST 9/2/2001 LEAKOFF PPG 12.42 OP COMMENTS: P.O.H. WI GYRO SURVEY (NO SURVEYS ABOVE 653') I RIG UP; RUN LINER, CIRCULATING ON BTM. FLUID - PREPARE TO PUMP PILL ;i".:; ': ':',:~: ,:; :';;~)'; ::::':::::t:'\:::!:;:¡:::'::.:::;-,::::,~ :/;:;: <\i/,\/;,);::',,:,,::'::;;::Y:;;"::;;:ì ';¡~\;, ;""::,': ':',.:;:::;:: OP'ERATI'öN'S:;süMMARY/;:'):,::' : :¡::;;-:"::'::::':',::::; ;::):/i ,':;:/: ,,:i:{" ':¡>:>/~;:1~,::!(:~::): :;;;,:;¡.:¡:~¡:,t;:; ,-::',.::: :':,:<: '::::!:j;h:~ :'F.R.qNi:,,::::::~tC>/:':':::':H~S,;:r:; ::OEPTH,;):iM: ::þEPTB"'T-çf::::::$Üë':.,::;¡:. :;::PH~$~¡::: <!,:\':i;:i;.:r;:i::,:):::':<:>::;;'::::':::;;~:'ii;',;:;'::',"',:::,i:i";;'::::¡:: :;.,:'DES:c.filp,rïqN)',:,'",,:;,;':,::,:/;:,:;::;';',;;:;::~¡T;:;;:::;:':\::¡~¡:i;::::':':::i:":!~':~)~H:h 06:00 08:30 2.50 5,650 5,650 SIDET Tripping 08:30 10:00 1.50 5,650 5,650 SIDET CIRC. BOTTOMS UP , PUMP GYRO SURVEY TO BTM. 10:00 14:00 4.00 5,650 5,650 SIDET Tripping OUT TO RUN CASING LOSING :;:;t~ENSlrY(pP~;Jj;;::: 8.95 I;;¡~:~;: )~dD;1 'MÚ[fbATA,I::::PA!LY Ç'Q~!';T 4,029.00 :::;:èÞr.n::çc;jstt¡ 72,218.93 '! >:¡'F\f;:;:;' ,.'::,PYivþ,::: :::~eíø:::;' ::,::WiJi:rrfi:j:i:: ~crr:sql;:i:: :i/!9IûWÂt/¡:¡' ::::\;;:;o/~$ånd).MBt:',;: >:; :¡'~:;P.IiJp;II;":'Y":' : ':::';pf/M':,:'::¡' ;:,:;;<)"::'þ~ ';" !""', :::;,:':'!:::C~'::) i:,:;: H2s.::;:; ,\'(lM~' jpj: :~s::;; 47 7/24 12/15 7.2/ 1.01 I 0.101 9.00/0.1 0.710.7 30,000 40 ': ':'::,/ i::: ';:':::¡:~:,:;;:,:!';:;'::<i':;,):;;¡;;::;::,::: 'i::!I¡'¡:::,:';)i;:U~l::.,>:,;:::ji:::::::::¡:!:::,:,,;'::V¡l:::;:::,;: :¡:;::;:,U'2j4~i,:';¡::';:::;;::::,::r;U :,::{i;;;,;'::):i;::,:::';:;.';:: ;;:'Bit:s:::;::i::::::::¡:,:,::,:::;):,:::"~,/,,j,;,:::¡,;;:':::;~":::"":::!:;::::1¡\;:':':;:;:::':i::';: ::':;,':::::¡:;;:::,:::¡j:¡;::¡¡:;;;i:::,;~¡~,;'¡::;¡¡:m::¡:,(:~::¡;:,,',:;~:::,¡,::~;:;::¡~:~:~',:;;¡';J;jt~¡:~',t1m;;,~ ':'EÏIT' t~~N:: ~:;';:~~::$izÈ::i::;::::: '¡::': ;:"\M~:NUF.;;:::f::::'I,:,}j:~>;;':TY,BE:::<,:;"iV!:;:::::;::~,~RI,AP~ó::'::;: :,:/:;¡: i,';;J.$f,à:,ÔJ:(TF4J::\Ç:;/ ï::,;~~i¡ D:~ )tHr~~::::~4X!=),N!:":>:: :;';I1!;;;it:í~Þ;'~h~ä~~'~ó;Rt@:':¡j!!* 4/1 6.750 Smith I S75PX JS1984 10/10/10/10/101 4,661.0 9/2/2001 1-1-BT-N-1- 1-BT-TD BIT I RUN WOB I RPM I GPM I PRESS P BIT HRS I 24Hr DlST I 24Hr ROP I CUM HRS I CUM DEPTH CUM ROP ~~~~\ :~';:¿l~~~i:::f ~Þ~~~',>~ ~i J~,¿~t:j\~~~'b~Ii'~~~'~,:::':9~~~: ;~1~~;,;:::~}'~~~~~: :~i~!'~~:. ~/~~~~~~:'!:~~ ~~~:;¡¡~~~~;~ 7 861.35 i / 70 BHA DESCRIPTION 6 3/4" Smith PDC , M. MOTOR W/6 5/8"UBHS/1.2 AKa, 65/8" IBS , NON-MAG X/O , COLLAR MWD , RESTRICTOR SUB 3 1/2"HWDP (4), Float sub w/survey ring, 43/4" DAILY HYDRAULIC JARS, 3 1/2" HWDP (21),31/2" IF-P X 4" HT-38-B ,4" 14PPF S-135 DP ~~;m;',;:' t' :i:: ;::~~¿~ ~~~~i;:":' ::\' :,' . i:::::: ~~~d~:~ ~ r~~~~~ tf~:~~~¡:.:~~: ~~~";~~~i~" t: ~~:Z4;¡;',!~Ä~~~~~~'~':1 1 OIL WELL 8.000 4.500 80 124.26 1,300 248.52 2 OILWELL 8.000 4.500 80 124.26 1,175 248.52 .,.: -,. .' ,,':. .., . ....f ...;' ..:","::"'\:.:'P'ERSONí\II:LD"ATA'; :;.: :..:.. : /':i,.:.»':>:::::":;":";:,>:::,;:.::!':."':,,('¡,::,'.,~::b:;:~":':i;¡.:.:;;:'/~:;,::::~;,:'U;t::; ..:.. "..:;.\þO!VIPAr",l.. ..:.;",./.SERVicE'." ".. :'.Nci:;:,:::: J-ÍPI,)R$"'! :.;;::' . :CO~PANV:'::':" .. Î.:. .,:'<":!~Ei:¡viçE;';::":':<:::':::':::':"¡,:'Ng::;".';:.:::;:f:(Þ'Û.fI§:¡CY Glacier Drilling 17 216.00 GYRO - DATA 1 24.00 Marathon 2 36.00 Weatherford 1 12.00 MI 1 24.00 BAKER 1 20.00 Baker Inteq 3 30.00 B -J SERVICES 3 6.00 Epoch 4 48.00 B.L.M. 1 9.00 Printed: 9/6/2001 2:58:16 PM , ' . , ' " ' OPERATIONS SUMMARY , , ". ' FROM,; , T~~ I,' ~_RS -"-1E_EPTH_~ DEr:'TH'TO I_~UB ~,~~~SE _..~-- m.... .., .._.._E.~~C_~I~!~~N - -..-..---.--: "- , .... ~- --..,---:...., ---..:..: 14:00 17:00 3.00 5,650 5,650 CSGPR RlU TO RunlSet Casing I Liner 17:00 21:30 4.50 5,650 5,650 CSGPR MAKE UP FLOAT SHOE, FLOAT COLLAR, LANDING COLLAR ,56 JTS. 4 1/2" CASING, AND HANGERlPKR. CSGPR RID CASERS; CHANGE-OUT BALES, MAKE UP CEMENTING HEAD ON SINGLE CIRCULATE CASING VOLUME RUN IN HOLE WI CASING ON DRILLPIPE CIRC. WI LINER ON BTM. @ 5 1/2 -6 BPM ./LOST APPROX. 50 BBLS. IN 30 MIN. IMIX AND PUMP PILL; SPOT ACROSS OPEN HOLE. ( { -.. MARATHON OIL COMPANY Daily' Drilling Report , . WELL NAME ST IKB IGL 124 HRS PROG TMD TVD IDFS KU 21-6RD 01 180.00 159.00 I 5650 4 884 SUPERVISOR RIG NAME & NO. I RIG PHONE AUTH MD AFE NO. J. C. LORENZEN GLACIER DRILLING 1 1907-283-131 5650 9206501 CURRENT STATUS IMOCW1 NRI DAILY WELL COST PUMPING PILL TO SLOW LOSSES PRIOR TO CEMENTING LINER 1100.00 (% 87.50 (% 10,000.00 24 HR FORECAST ¡ACCIDENTS 24HR LAST SAFETY MTG. CMT. LINER' LAY DOWN D.P.: R.I.H. TO CLEANOUT TOP OF LINER I None 8/29/2001 FIELD NAME I STATEJPROV I COUNTY/OTHER ¡LAST CASING ¡NEXT CASING Kenai Alaska Kenai I 7.625 (in) (ã) 5 650.0 (ft) (in) (ã) (ft) OP COMMENTS: RUN 56 JTS. 4.5 " CASING - 21 :30 23:30 2.00 5,650 5,650 23:30 00:30 1.00 00:30 03:30 3.00 03:30 06:00 2.50 5,650 5,650 5,650 CSGPR CSGPR CSGPR 5,650 5,650 5,650 .. Page 1 of 1 REPT NO. IDATE 1 9/6/2001 AFE COST 444 000 CUM WELL COST 10 000.00 BOP PSI TEST 9/212001 LEAKOFF PPG Printed: 9/6/2001 11 :24:23 AM (" f ~ " ., ". " "', ; , ,', " " .. " ; , :,:;: ". , ' , !", 'MARATHON 'OIL COMPANY Page 1 of 1 ' : .. " " .. .. , ' : ,' : .. , " ,..-::, ,',,: ,: .. " " ,.. .. '" ",-:,' "'," Daily Drilling Report ', : .. " " , ",' ' .. WELL NAME ST IKB GL 124 HRS PROG TMD TVD IDFS REPT NO. DATE KU 21-6RD 01 80.00 59.00 5650 4.884 1 2 9fl 12001 SUPERVISOR RIG NAME& NO. I~RIG PHONE AUTH MD AFE NO. AFE COST J. C. LORENZEN GLACIER DRILLING 1 907-283-131 5650 9206501 444 000 CURRENT STATUS I MOC WI NRI DAILY WELL COST CUM WELL COST CLEANOUT (â) TOP OF LINER 100.00 (% 87.50 (% 139.247.00 149 247.00 24 HR FORECAST ¡ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST CIO TO VC . CHANGE WELLHEAD None 8/29/2001 9/212001 FIELD NAME I STATEIPROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Kenai Alaska Kenai 7.625 (in) @ 5,650.0 (ft) (in) (â) (ft) OP COMMENTS: CEMENTED AND CLEANOUT LINER ~O ~~LHRS OPERATIONS SUMMARY' FROM I DEPTH FM DEPTH TO SUB PHASE DESCRIPTION I . -- ..' ---- ----.., ....- ---..---, - - -, -..- - .' ,- 06:00 07:00 1.00 5,650 5.650 CSGPR MIX AND SPOT LCM PILL 07:00 12:00 5.00 5,650 5.650 CSGPR CIRC. WELV BUILD PIT VOLUME 12:00 13:00 1.00 5.650 5,650 CSGPR P .J.S.M.I TEST SURFACE EQU. TO 5000 PSI I MIX AND PUMP 265 SX. CLASS 'G' CMT. @ 13.5 PPG.I DISPLACEI BUMP PLUG I SET HANGER I FLOATS HELD 13:00 16:00 3.00 5,650 5,650 CSGPR P.O.H. 5 STDS./ CIRC.I SLIGHT INDICATION OF CMT.I RI.H TO LINER TOP AND CIRC. I GOOD CMT. INDICATION @ PITS 16:00 19:30 3.50 5,650 5,650 CSGPR P.O.H.I LAY DOWN STINGER FROM SETTING TOOL I PICK UP HWDP FOR EXTRA STRING WEIGHT \ RI.H. TO SET LINER PACKER 19:30 20:00 0.50 5,650 5.650 CSGPR SET PACKER 20:00 21:00 1.00 5,650 5,650 CSGPR P.O.H. WI SETTING TOOL 21:00 01:00 4.00 5,650 5.650 CSGPR LAY DOWN DRILLPIPE; HWDP : AND SETTING TOOL: PICKUP 6 3/4" BIT AND SCRAPER 01:00 04:00 3.00 5,650 5,650 CSGPR RI.H. TO LINER TOP 04:00 05:00 1.00 5,650 5,650 CSGPR Circulate and Condition Hole 05:00 06:00 1.00 5.650 5,650 CSGPR Tripping '~:qE~'SliY(P'pg)"': 9.10 I:!~~':;; I: 'E~D,d UViOD~;DAtAI,;,:þ~i~Y~,ØST'::,1 8,659.00 h:c:U~::èþ~rt::: 8,659.00 ':::y ~~'~> :(.~vïYpx t::GELSt ::wLiïÜHP,;¡ r'~crt :sÓLi, ':;"::"ÓILiWA~f:':' ': ':' ,,::'oks""" 'd/MBTF:;' ~:'!::':i:,p.~r'M'::;::':::" ';, 'PfïMf'.i', ::'!;j:¡;";'Cr"'!~;,¡: ';c'<';C' ", 'i;' ""'¡':H2S"i': ::'ÜME' ¡>":e'i.!' ,:!,'",..",.. ""."',+ø ¡¡In" ",..".."..""",P..""",""""" "",."""""".,..""',8""",,, '..".. ";..S,,.. ," , ,,"'" ..,..", ...., """""""""""""""""""""""""""'..""'..,.."",,,'..,"" 47 7/24 12/15 6.6/ 1.01 I 0.10/1.2 9.1010.1 0.1/0.7 30,000 80 :¡:'i,:,:""~,<:')(;,':,f':;::';:'> :":;:::!,::::::>:'" :;;;';!i':(,::>,;:;:'~::;:':"'::;'i:'::::'):::;,?::;"::::,:::'}: ":"':.':PEr-t'5ÖNNEL:(jÂTA:V;;,:,;I:':,">?:::::::i\:':'::::,~:;':,\;,,:,:1:j~':'::::;,::::j1i:Y;':'/'\:>\)~,;,t:)::,"'::¡¡::!::!:{::'~:;~::;:¡..tV:,:-'¡:;::!::::;:[ h:<;,<:,::::::,::çOllftp~~:y":,,:':i:\,'::::' ;:;;;,</'::':'::..;::~ER.VIC,Ë :;',::,(,-¡>:,':!:':' r::,::N,p/::: '::~,ÔU~,~':, ::~:;:,.'?!>: ::;'(i:::OM~~t.W;;'(;::,:,""::::'-- <;',:;,,::;:'¡:~:'::SïSRVIÇE:;~:'::':::':::':,":':,:: :':i:;;:~Ö~¡¡!;i':::- ':}Iþ'~~~}}:, Marathon 3 70.00 BAKER 1 24.00 Glacier Drilling 17 216.00 EPOCH 1 12.00 ., B-J 3 36.00 BLM 1 12.00 Printed: 9/7/2001 9:53:56 AM f ( MARATHON OIL COMPANY Page 1 of 1 , Daily Drilling Report WELL NAME ST IKB IGL 124 HRS PROG TMD TVD IDFS REPT NO. DATE KU 21-6RD 01 80.00 59.00 5,650 4,884 2 3 9/8/2001 SUPERVISOR RIG NAME & NO. I!RIG PHONE AUTH MD AFE NO. AFE COST J. C. LORENZEN GLACIER DRILLING 1 907-283-131 5.650 9206501 444 000 CURRENT STATUS MOCWI NRI DAILY WELL COST CUM WELL COST RIGGING UP TO LOG 100.00 (% 87.50 (% 24 393,00 173,640.00 24 HR FORECAST ¡ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST LOG; C/O SPOOL: RI.H. OPEN-ENDED None 9/8/2001 9/212001 FIELD NAME I STATEIPROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Kenai Alaska Kenai 7.625 (in) @ 5,650.0 (ft) (in) @ (ft) OP COMMENTS: CLEANOUT TO LINER TOP; CLEAN OUT TO LANDING COLLAR; CIRC., AND CHANGE OVER TO WATER ,',"',':,'","';:':'::::>::',,::::,:;:>:::,:::,:,,":<";""'----' - OPERATIONS SUMMARY --- -, - 'F,ROII/I, :'::.':J::P> , :~:/~RS/:;:' "D~pr4 'fM: DEPTH TO i SUB i PHASE DESCRIPTION "" --' I 06:00 07:30 1.50 5,650 5,650 CSGPR P.O.H.I LAY DOWN SCRAPER AND BIT 07:30 10:30 3.00 5,650 5,650 CSGPR REPAIR RIG HYDRAULICS 10:30 19:30 9.00 5,650 5,650 CSGPR PICK UP 3 7/8" MILL; SCRAPER ; AND 2 7/8" DRILLPIPE I R.I.H. ;(NO CMT. ON LANDING COLLAR) 19:30 21:00 1.50 5,650 5,650 CSGPR CIRC. ; CONDITION FLUID 21:00 22:00 1.00 5,650 5,650 CSGPR , PUMP 50 BBLS. SAFE-CLEAN ; CHANGE-OVER HOLE TO WATER 22:00 22:30 0.50 5,650 5,650 CSGPR TEST CASING TO 2100 PSI 22:30 23:30 1.00 5,650 5,650 CSGPR CIRC. 23:30 04:30 5.00 5,650 5,650 CSGPR P.O.H. W/ CMT. MILL AND CSG. SCRAPER 04:30 06:00 1.50 5,650 5,650 CSGPR RIG UP LOGGERS; RUN #1 .. -DENSITV(pP9)r-8~34"- ¡:pp--r---' '---E"cD IM-liii DATA "'DAIL.-Y-COSTT- -- -, 3.652.00 ì" CUM,COSTT--- 12,311.ÕÜ-- """ "'-""----"-,- ,---_..".., ,I_r-----....,-,_..... "-'-"'--"-"""'" - , -,.. ...1, "'" ..,.. ,-,_....,- ..---------'.,....." un ....."-----..-'--..-....-'.. _u_""--'-r--"-- -{{--l~¡7P +1~~~:--I-!'.~~;~~"'r'~~7~~~~ I ..~I~~!..__¡, _::~-6~~2~!.u-¡ -, 9;ci~~1"-- ,¡--Ö~;~;' -I- -3Ö~~Ö-'+--' ~; -'-I-,~,~~-~~'Mr~'- .: ::::J:::: ,'t:::; ::'C;~:¡:;;": ..;;t::¡):::¡1i::::,:~<':J/:: '::' ::::J:: :;:~!>::;?'(::::~::,:::,::, :,':'; ':;: <r'::::i:.[. i:r::' '~'> :::;':'::;;¡ PE'A'S'Or,fN E1JOÄTA:: ¡';::/} :,::<i?;'::',:;'r::::,!':, \::<: ;,<:~i,,;/,:::,:! :!\.:/-.i;,:,;:::i'~:;;';,';:'/:::i::'¡ ,:;(:¡.""':~:¡(:;i::¡; :;:1:<:':' ::::::¡;;~:i~:!!i(¡!i~ ,;,-::",:,,"::';:,;\::þþMPAf,j'V:':'};:;,:i:::';:/,: "':";::::::':)/:;;::,SE~Vj~~:'<::':<:::)::"¡:i::: ,::'i::'N,o:<:>, ::~PURS>:; :!:";\i:!i;,<:);þOM,~Å~Y::::;/:\::::;:/:: 'Y:;'::::';':<::l~_~~i=Jvíç~'::,:::::,:>:/L.'::' d::i;'Nq~)~:;;i::,iio:~,ßØ~¡;:;¡t~: Glacier Drilling 17 216.00 Schlumberger 2 6.00 B-J 3 36.00 Printed: 9/8/2001 10:44:58 AM ~:' ('" ¡, : " , ,' , ' "', " " 1 MARATHON OIL COMPANY Page1,.of".t .., :~, , ,1',..," I: , Dally OfiUingR.êpoit , ::', ' """ ., '," ',::: ,"'...',', : ' ", , ", " ..' ' ", , '" , " ,':' WELL NAME ST IKB GL 124 HRS PROG TMD TVD DFS REPT NO. DATE KU 21-6RD 01 80.00 59.00 5650 4,884 3 4 9/9/2001 SUPERVISOR RIG NAME & NO. I!RlG PHONE AUTH MD AFE NO. AFE COST J. C. LORENZEN GLACIER DRILLING 1 907-283-1312 5650 9206501 444,000 CURRENT STATUS IMOCWI JNRI DAILY WELL COST CUM WELL COST Bleed nitroaen from well 100.00 (% 87.50 (% 61 430.00 235,070.00 24 HR FORECAST I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST Lay down drillpice . n/d stack' nlu tree: release ria None 9/9/2001 9/2/2001 FIELD NAME I STATEIPROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Kenai Alaska Kenai 7.625 (in) @ 5,650.0 (ft) (in) @ (ft) OP COMMENTS: R/u Schlumberger; log;pick up 3 1/2" drill collars, 27/8" drill pipe , 4" drillpipe and RI.H. to 4000' IHang off with Howco storm packer; nipple down and install new tbg. spool 1 rig up B-J, : " ,OPERATIONS SUMMARY' F~OM TO ' HRS DEPTH FM DEPTH'TO SUB PHASE, , DESCRIPTION 06:00 08:30 2.50 5,650 5,650 CSGPR Logging, other 08:30 12:00 3.50 5,650 5,650 CSGPR Pick up 3 1/2" collars, 2 7/8" drill pipe, 4" drillpipe and RI.H to 4000' (30000 #) 12:00 13:00 1.00 5,650 5,650 CSGPR Pick up Howco storm packer; set at 58' 13:00 22:30 9.50 5,650 5,650 CSGPR nipple down stack; change-out tubing spool; nlu stack 22:30 00:30 2.00 5,650 5,650 CSGPR test B.O.P.s 00:30 01:00 0.50 5,650 5,650 CSGPR Lay down storm packer 01:00 03:30 2.50 5,650 5,650 CSGPR Tripping 03:30 04:30 1.00 5,650 5,650 CSGPR Rig up to reverse fluid with nitrogen 04:30 06:00 1.50 5,650 5,650 CSGPR Reverse out 169 bbls. water I max. pressure 2000 psil bleed to atmosphere thru gas buster ',DENSITY(ppg),1 8.34 ,PP' IECDI I MUD DATAl DÄILYCOST I 625.00 ; cuM COST 12,936.00 I : ,FV: PVIYP ,GELS "Wui-l;rHP ,' FClT.SOL' OILIWAT %~and/MBT ' PhlpM" , ' Pf/Mf : CI" ": Ca,' , H2S LIME' '::,'ES,' 26 1 I 6.01 I 1 1 1 1 " " PERSONNEL DATA " " " , " " .. .. COMPANY : SERVICE' ,'NO., HOURS' " COMPANY , SERVICE NO~ : HOÜRS : ' " , Glacier Drilling 17 216.00 Marathon 2 36.00 B-J 3 36.00 Halliburton 1 12.00 Printed: 9/9/2001 10:17:16AM yO ( ( MARATHON Oil Company Pad #? KU21-6X slot #KU21-6 Kenai Gas Field Kenai peninsula, Alaska SURVEY LIS TIN G by Baker Hughes INTEQ Your ref: PGMS <778 - 5650> Our ref: svy6612 License: Date printed: 11-Jan-2002 Date created: 18-0ct-2001 Last revised: 11-Jan-2002 Field is centred on n60 27 33.151,w151 16 7.223 Structure is centred on 272621.520,2367320.000,999.00000,N Slot location is n60 28 31.144,w151 16 18.601 Slot Grid coordinates are N 2367873.600, E 270536.460 Slot local coordinates are 513.62 N 2095.36 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North f MARATHON Oil Company Pad #?,KU21-6X Kenai Gas Field,Kenai Peninsula, Alaska Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth 0.00 96.00 150.00 196.00 251.00 312.00 374.00 435.00 497 . 00 561.00 623.00 654.00 746.00 778.20 840.75 903.30 965.85 1028.40 1090.95 1153.50 1216.05 1278.60 1341.15 1403.70 1466.25 1528.80 1591.35 1653.90 1716.45 1779.00 1841.55 1904.10 1966.65 2029.20 2091.75 2154.30 2216.85 2279.40 2341.95 2404.50 2467.05 2529.60 2592.15 2654.70 2717.25 2779.80 2842.35 2904.90 2967.45 3030.00 9.00 10.00 11.00 11.55 13.23 15.25 17.91 20.88 24.28 27.77 31.68 34.62 35.17 35.17 35.26 35.41 35.52 35.63 35.64 35.60 35.63 35.63 35.66 35.76 35.98 36.22 36.40 36.65 36.89 37.19 37.40 37.77 37.34 36.56 35.76 34.99 34.22 33.49 32.79 32.21 0.00 0.25 0.25 0.25 1.25 0.00 330.00 46.00 24.00 96.00 4.00 4.25 5.00 6.25 7.50 100.00 97.00 112.00 112.00 112.00 107.00 111.00 106.00 111.28 111.86 112.46 112 . 91 114.05 114.24 114.61 113.02 111.22 110. 61 109.84 109.41 108.75 108.68 109.09 108.44 108.80 109.77 112.28 112.20 113.14 114.07 114 . 92 115.89 116.13 117.31 116.28 117.58 118.49 117.66 118.15 118 . 95 118.38 11 7 . 65 117.31 117.76 118.18 0.00 96.00 150.00 196.00 250.99 311 . 92 373.76 434.57 496.27 559.81 621.16 651.74 742.20 773.78 834.87 895.49 955.44 1014 . 43 1072 . 18 1128.38 1182.69 1235.05 1286.36 1337.49 1388.59 1439.62 1490.56 1541. 44 1592.28 1643.12 1693.97 1744.82 1795.65 1846.44 1897.12 1947.66 1998.07 2048.33 2098.44 2148.37 2198.13 2247.70 2297.29 2347.27 2397.77 2448.78 2500.26 2552.20 2604.58 2657.33 { ~, SURVEY LISTING Page 1 Your ref: PGMS <778 - 5650> Last revised: 11-Jan-2002 R E C TAN G U LA R Dogleg Vert COO R DIN ATE S Deg/100ft Sect O.OON 0.18N 0.37N 0.53N 0.57N 0.13N 0.52S 1. 79S 4.07S 6.94S 9.878 11 . 558 16.838 18.848 23.788 29.598 36.488 44.778 54.598 65.958 78.448 91.30S 104.078 116.538 128.648 140.478 152.118 163.898 175.618 187.24S 199.278 212.348 226.148 240.218 254.898 270.178 286.068 302.398 ' 319.228 336.208 353.378 371. 308 389.258 406.848 424.488 441.858 458.548 474.628 490.428 506.188 O.OOE 0.10W 0.08W 0.03E 0.68E 3.44E 7.85E 12.56E 18.19E 25.29E 33.68E 38.51E 54.41E 60.37E 72 . 85E 87.09E 103.56E 122.60E 144.51E 169.49E 197.87E 229.56E 262.98E 296.79E 330.76E 364.95E 399.33E 433.76E 468.26E 502.78E 537.16E 571.17E 604.91E 638.60E 672.18E 705.72E 739.17E 772.63E 806.07E 839.71E 873.49E 907.17E 940.81E 974.03E 1006.45E 1038.23E 1069.58E 1100.50E 1130.82E 1160.50E 0.00 0.26 0.57 0.21 2.18 0.00 -0.16 -0.21 -0.16 0.43 G RID COO R D S Easting Northing 270536.46 270536.36 270536.39 270536.50 270537.15 270539.90 270544.30 270548.98 270554.57 270561.61 270569.95 270574.75 270590.54 270596.45 270608.83 270622.97 270639.30 270658.18 270679.89 270704.65 270732.78 270764.22 270797.39 270830.95 270864.69 270898.64 270932.79 270966.98 271001.26 271035.55 271069.69 271103.44 271136.91 271170.32 271203.61 271236.85 271269.99 271303.13 271336.24 271369.54 271403.00 271436.32 271469.61 271502.49 271534.56 271566.00 271597.03 271627.63 271657.64 271687.02 2367873.60 2367873.78 2367873.97 2367874.13 2367874.16 2367873.67 2367872.93 2367871.57 2367869.18 2367866.18 2367863.09 2367861. 32 2367855.73 2367853.60 2367848.43 2367842.35 2367835.15 2367826.50 2367816.25 2367804.43 2367791. 39 2367777 . 93 2367764.52 2367751.42 2367738.66 2367726.18 2367713.88 2367701. 45 2367689.07 2367676.78 2367664.09 2367650.37 2367635.93 2367621. 22 2367605.91 2367589.99 2367573.46 2367556.50 2367539.03 2367521. 40 2367503.59 2367485.02 2367466.44 2367448.21 2367429.96 2367411.98 2367394.70 2367378.03 2367361.65 2367345.32 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #KU21-6 and TVD from Glacier #1 (80.00 Ft above mean sea level). Bottom hole distance is 2648.66 on azimuth 111.93 degrees from wellhead. Vertical section is from wellhead on azimuth 111.10 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 4.52 0.53 2.32 2.02 1. 95 3.16 7.51 12.36 18.43 26.09 2.68 3.86 1.47 3.63 2.69 34.98 40.09 56.82 63.10 76.52 3.24 4.26 4.79 5.44 5.59 91.91 109.75 130.50 154.48 181.87 6.38 4.96 1.04 0.71 0.42 212.84 247.03 282.82 318.84 354.90 0.66 0.19 0.42 0.61 0.34 391.05 427.31 463.67 500.09 536.48 0.90 2.34 0.09 0.89 0.94 572.89 609.32 645.76 682.26 718.87 0.89 0.96 0.46 1.19 1.10 755.66 792.60 829.69 866.95 904.44 1.30 1.07 1.06 1.33 1.48 942.14 980.01 1017.86 1055.19 1091.79 1.34 1.40 1.21 1.19 0.99 1127.68 1162.95 1197.58 1231.55 1264.92 It (" MARATHON Oil Company SURVEY LISTING Page 2 Pad #?,KU21-6X Your ref: PGMS <77 8 - 5650> Kenai Gas Field,Kenai Peninsula, Alaska Last revised: ll-Jan-2002 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect Easting Northing 3092.55 31.94 118.56 2710.33 521.97S 1189.73E 0.54 1297.87 271 715.93 2367328.98 3155.10 31.73 118.51 2763.48 537.73S 1218.72E 0.34 1330.59 271744.61 2367312.67 3217.65 31.52 118.16 2816.74 553.30S 1247.58E 0.45 1363.12 271773.18 2367296.55 3280.20 31. 20 118.70 2870.15 568.79S 1276.21E 0.68 1395.41 271801.50 2367280.51 3342.75 31.07 118.52 2923.69 584.28S 1304.60E 0.26 1427.47 271829.59 2367264.49 3405.30 31.01 119.52 2977.28 599.92S 1332.81E 0.83 1459.42 271857.49 2367248.30 3467.85 32.47 118.56 3030.48 615.89S 1361.58E 2.47 1492.01 271885.94 2367231.79 3530.40 33.59 118.34 3082.92 632.13S 1391.55E 1. 80 1525.82 271915.60 2367214.98 3592.95 34.15 110.58 3134.88 646.52S 1423.23E 6.97 1560.56 271947.00 2367199.98 3655.50 34.50 104.73 3186.55 657.20S 1456.81E 5.30 1595.73 271980.37 2367188.67 3718.05 32.90 99.36 3238.60 664.47S 1490. 71E 5.40 1629.98 272014.12 2367180.75 3780.60 33.23 98.93 3291. 02 669.90S 1524.41E 0.65 1663.36 272047.71 2367174.68 3843.15 33.55 98.70 3343.24 675.17S 1558.42E 0.55 1697.00 272081.61 2367168.76 3905.70 33.57 97.73 3395.37 680.11S 1592.65E 0.86 1730.70 272115.73 2367163.16 3968.25 32.43 100.38 3447.83 685.46S 1626.28E 2.94 1764.01 272149.26 2367157.17 4030.80 32.22 101.94 3500.68 691.93S 1659.10E 1.38 1796.95 272181.94 2367150.07 4093.35 31.72 103.40 3553.75 699.19S 1691.41E 1.47 1829.71 272214.11 2367142.20 4155.90 31.54 106.80 3607.01 707.73S 1723.07E 2.86 1862.32 272245.60 2367133.05 4218.45 31.36 109.70 3660.37 717.95S 1754.05E 2.44 1894.91 272276.38 2367122.25 4281.00 31.40 110.09 3713.78 729.03S 1784.68E 0.33 1927.47 272306.79 2367110.58 4343.55 31.64 108.41 3767.10 739.81S 1815.55E 1.46 1960.15 272337.44 2367099.21 4406.10 31.73 108.02 3820.32 750.08S 1846.76E 0.36 1992.97 272368.45 2367088.35 4468.65 31. 45 104.97 3873.61 759.38S 1878.16E 2.59 2025.62 272399.67 2367078.44 4531.20 31. 59 104.87 3926.93 767.80S 1909. 76E 0.24 2058.13 272431.10 2367069.42 4593.75 31. 70 104.98 3980.18 776.26S 1941. 47E 0.20 2090.75 272462.64 2367060.36 4656.30 31. 89 106.87 4033.35 785.30S 1973.16E 1.62 2123.57 272494.15 2367050.72 4718.85 32.01 107.48 4086.42 795.07S 2004.78E 0.55 2156.59 272525.58 2367040.34 4781. 40 32.11 109.60 4139.43 805.63S 2036.26E 1. 81 2189.76 272556.84 2367029.18 4843.95 31. 59 110. 82 4192.56 817.03S 2067.23E 1.32 2222.76 272587.59 2367017.19 4906.50 31.64 112.82 4245.83 829.22S 2097.67E 1. 68 2255.54 272617.79 2367004.43 4969.05 32.36 112 . 41 4298.88 841.96S 2128.27E 1.20 2288.68 272648.14 2366991.10 5031.60 32.10 112.93 4351.79 854.82S 2159.05E 0.61 2322.02 272678.67 2366977.66 5094.15 31.44 114.08 4404.97 867.95S 2189.25E 1.43 2354.93 272708.61 2366963.95 5156.70 32.27 112 . 92 4458.10 881.11S 2219.52E 1.65 2387.91 272738.62 2366950.22 5219.25 32.22 112.81 4511 . 00 894.07S 2250.27E 0.12 2421. 27 272769.12 2366936.66 5281.80 31.97 113.51 4563.99 907.14S 2280.83E 0.72 2454.48 272799.42 2366923.01 5344.35 31.89 114 . 60 4617.08 920.63S 2311.04E 0.93 2487.51 272829.36 2366908.95 5406.90 31. 73 115.69 4670.23 934.64S 2340.88E 0.95 2520.40 272858.93 2366894.37 5469.45 31. 90 115.70 4723.39 948.93S 2370.60E 0.27 2553.27 272888.37 2366879.51 5532.00 31.97 114.84 4776.47 963.06S 2400.52E 0.74 2586.27 272918.01 2366864.82 5567.20 31.82 114 . 92 4806.35 970.88S 2417.39E 0.44 2604.83 272934.73 2366856.67 5650.00 31.82 114 . 92 4876.71 989.28S 2456.98E 0.00 2648.39 272973.96 2366837.53 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #KU21-6 and TVD from Glacier #1 (80.00 Ft above mean sea level). Bottom hole distance is 2648.66 on azimuth 111.93 degrees from wellhead. Vertical section is from wellhead on azimuth 111.10 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ( MARATHON Oil Company Pad #?,KU21-6X Kenai Gas Field,Kenai Peninsula, Alaska Me TVD Rectangular Coords. Comments in wellpath -------- ------------- Comment " .1 ( SURVEY LISTING Page 3 Your ref: PGMS <778 - 5650> Last revised: 11-Jan-2002 5650.00 2456.98E ----------------------------------------------------------------------------------------------------------- 4876.71 989.28S Projection to TD Target name Geographic Location Targets associated with this wellpath Rectangular Coordinates - --- ----- - ----- -- - -- ----------------------- T.V.D. Revised ----------------------------------------------------------------------------------------------------------- KU21-6X StrlngC2 Tgt 0 4665.00 1003.61S 2302.55E 1S-Jun-2001 :t \ ~u!ÆuŒ mJ~ &\~&\~[K{&\ \ \, AlAS IiA. 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 w. "fTH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 P .K. Berga Drilling Superintendent Marathon Oil Company P.O. Box 196168 Anchorage AK 99519-6168 Re: Kenai Unit KU 21X-6 Marathon Oil Company Pennit No: 201-097 Sur Loc: 515' FSL, 2089' FEL, Sec. 31. T5N, R11W, S.M. Btmhole Loc. 587'FNL, 1964' FWL, Sec. 6, T4N, R11W, S.M. Dear Mr. Berga: Enclosed is the approved application for pennit to redrill the above referenced well. The pennit to redrill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF THE COMMISSION DATED this 2c¡.'t"day of May, 2001 jj clEnclosures cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ( '- 11\ ') Marathon MARATHON Oil Company Tom Maunder AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 May 16, 2001 Dear Mr. Noble: ~ Alaska Region Domestic Production P.o. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 RECEIVED MAY 17 2001 Alaska Oii & Gas Cons. Commission Anchorage Attached is the Permit to Drill for Well Number KU 21X-6, the accompanying Drilling Program summary, schematics and procedure. Please note that this well has been renamed because it is a sidetrack well. The previous well name was KU 21-6. If you would like any other information, please contact me at 564-6319 or pkberQ.§.@marathonoil.com. Sincerely, {b~ Peter K. Berga Operation Superintendent Enclosure bjv ORIGINAL g:\cmn\drlg\sterling\su44-1 O\AOGCCPTD,XL~ { STATE OF ALASKA, ~ 1--1 p). ALAS1" \ OIL AND GAS CONSERVATION COM~I~.310N t;iJ,MD) PERMIT TO DRILL 210 AAC 25.005 1a. Type of Work DrillD Re-Entry[R] 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 515'FSL, 2089'FEL, Sec. 31, T5N, R11W, S.M. At top of Productive Interval 208'FNL, 1248'FWL, Sec. 6, T4N, R11W, S.M. At Total Depth 587'FNL, 1964'FWL, Sec. 6, T4N, R11W, S.M. Re-Drill[R] DeepenD 1 b. Type of well. Exploratory(] Stratigraphic TesD ServiceD Development Ga{8] Single Zone[] 5. Datum Elevation (DF or KB) 10. Field and Pool 64' KB feet Kenai Gas Field/Sterling Development aiD Multiple Zon{8] 6. Property Designation A-028142 7. Unit or Property Name Kenai Unit 11. Type Bond (see 20 AAC 25.025) Blanket Surety Number 5194234 Amount $200,000 8. Well Number KU 21 X-6 9. Approximate Spud Date 6/11/2001 12. Distance to Nearest Property Line(unit boundary 7392 feet 16. To be Completed for Deviated Well: Kickoff Depth 3400 feet Maximum Hole Angle 18. Casing Program Size 13. Distance to Nearest Well 14. Number of Acres in Property 15. Proposed Depth (MD and TVD) 662 feet 6000 5650' MD/4884' TVD feet 17. Anticipated Pressure (see 20 AAC 25,035 (e) (2)) 32 0 Maximum Surface 1798 psig at T ota! Depth (TVD) 4884' Hole Casing Weight Driven 20" 78.6 12 1/4" 103/4" 32.75 9 7/8" 7 5/8" 26.4 6 3/4" 41/2" 11.6 Specifications Grade Coupling K-55 PE H-40 STC J-55 LTC L-80 LTC Setting Depth Top Bottom Quantity of Cement Length MD TVD MD TVD (including stage data) 51' 0' 0' 51' 51' In Place, Driven 1282' 0' 0' 1282' 1239' In Place wI 750 sacks 3400' 0' 0' 3400' 2977' In Place, wi 700 sacks 2400' 3250' 2849' 5650' 4884' 360 sx f, \'1 II V-" -(~ r hi-\ . Kenai Unit well KU 21-6 will be plugged back according to AOGCC regulations to 3400'pOOg(g.'ß~ ~i~18Y'~~~~ctOl~kI¡;2;1(X-6 will be directionally drilled to an estimated total depth of 5650' MD, 4884' TVD from the existing K~c¡ijIßa§eField pad 34. 31.The production interval will be cased with 4.511, cemented in place as a production liner. Marathon's drilling rig will be used to drill and complete this well. The following documents are attached: Drilling Program, Area Maps, Location Map, Structure Map, Surface use plan, Directional Maps, Mud pit drawing and Blowout Prevention Equipment drawings. 20. Attachments Filing Fee[R] Property Pla(8] BOP Sketch[R] Drilling Fluid PrograrrG Time vs Depth PloD Refraction AnalysiG 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Phone: 564-6319 Craig Young 564-6310 Title Drilling Superintendent Commission Use Onl Permit Number API Number Approval Date .20/-0 r.7 50--/3:!-/ðD9D ~Ol ',0 Conditions of Approval Samples Required DYes ~No Mud Log Required DYes I5{INo Hydrogen Sulfide Measures DYes ~ No Directional Survey Required ~Yes D No Required Working Pressure for BOPE D2M ~M D5M D 10M D15M Other: Diverter SketcO Seabed Repo rD Drilling program[8J 20 MC 25.050 RequirementO Signed P. K. Berga Date: 5/14/2001 See Cover Letter For Other Requirements Approved by Form 10-401 Rev, 12-1-85 ORIGINAL SIGNED BY ~..) T'aylor Seamount Commissioner by order of the Commission Date .C) ('; r"'~! , r. ~ ~\ f s " i. I : .." ," ,I."" ': ~.,~./ ' Submit in Triplicate Marathon Oil compan~ Alaska Region { Pl.c.,¡?ared By: Approved By: Date: C E Young 08-23-00 Drilling Program Well: KU 21X-6 AFE: 9206501 Area: Kenai Gas Field Drilling Contractor: Inlet Drilling Company Rig: Glacier Drilling Rig No.1 Geologic Program Depth Target Locations FSL FEL Block MD TVD Tolerance Surface 515' 2089' Sec. 31, T5N, R11W 21'RKB 21'RKB Sterling A8 723' 1729' Coordinates from 4193' 3650' South East Wellhead Sterling All 759' 1803' Coordinates from 4348' 3781' South East Wellhead Sterling B1 780' 1845' Coordinates from 4437' 3856' South East Wellhead Sterling B4 844' 1977' Coordinates from 4713' 4090' South East Wellhead Sterling C1 969' 2232' Coordinates from 5248' 4543' South East Wellhead Sterling C2 1003' 2303' Coordinates from 5396' 4669' 150' Radius South East Wellhead Bottom Hole 1102' 2445' Coordinates from 5650' 4884' South East Wellhead RKB Elevation: 21' Total Depth: TVD 4884' MD 5650' Avg. Angle 31. 75 Course 112 Abnormal Pressures: 250 psi to 1000 psi in Sterling Sands Subnormal Pressures: Coring and DST's: Mud Logging: Contractor: Epoch Start Depth: Below KOP Services: Basic with GCA, shale density, temperature in and out, sample collection. 10' samples to TD Logging Program: Contractor To be determined LWD Wireline Logs Surface NA production NA GR/CNL/LDT/AIT/DSI/NGT/MSFL/RFT/SWC/CMR KU 21X-6 Drilling Program Page 1 of 7 ( ( Drilling Program Summary Production: The existing wellbore will be plugged back to 3400' MD as per the AOGCC regulations. Set CIBP 3' above casing collar at 3400' MD. Test plug and casing to 3000 psi. TIH with bottom trip whipstock and MWD. Set whipstock for 45 degrees left of highside for casing exit. Cut window and ensure all mills are worked thru window. CBU. Test shoe to leakoff (15.5 PPG anticipated). Drill a 6 3/4" hole to 5650' MD/ 4884' TVD per the attached directional program. ~un logs as per program. Make a wiper trip and pull wear bushing. Run 4 ~" production liner and cement per the attached program. RDMO drilling rig. Casing Program API Values Casing Casing Hole Size Set Set To Weight Casing Conn Size Burst Collapse Tension (in) From (MD) (pp f) Grade Type (in) (psi) (psi) (K lbs) (MD) 7 5/8" 0' 3400' 26.4 J-55 LTC 9 7/8" 4140 2890 346 4 ~/I 3250' 5650' 11. 6 L-80 BTC 6 3/4/1 5350 4960 277 *7/1, 29# drifted to 6.125/1 Casing Design Fracture Formation Casing Casing Setting Gradient Pressure Design Factors Size weight Casing Depth at Shoe at Shoe MASP (in) (ppf) Grade (TVD) (ppg) (ppg) (psi) Burst Collapse Tension 7 5/8/1 26 J-55 2977' 15.5 9.0 1258 1. 59 2.06 1. 66 4 %/1 12.6 L-80 4884' 9.0 1798 3.00 2.71 1. 67 KU 21X-6 Drilling Program Page 2 of 7 f ~I. Directional Program Directional Co: Baker Hughes Inteq 3350 Direction: 112 Gyro Co: To be determined Dog Leg: 12.0 To: 31.6 deg @ 2977' TVD Drop Rate: 3.0 To: 31.6 deg @ 3145' TVD KOP: Turn Depth: 3400' MD/ 2977' TVD Gyro Survey Required: at TD Magnetic Multishots Required: Use MWD surveys below drive pipe General Calculation of Maximum Anticipated Surface Pressures The Maximum Anticipated Surface Pressure (MASP) for the intermediate casing is based on the highest exposed pore pressure less a column of 30% mud on top of 70% gas. The MASP for the production casing is based on pore pressure less the hydrostatic pressure of gas. 7 5/8" Intermediate Casing @ 2977' TVD MASP = ((PP * .052 * TVDtd) MASP = (9.0 * 0.052 * 4884) - MASP = 1258 psi (%mud * 0.052 * MWtd * TVDtd) - (%gas * GG * TVDtd)) (0.3 * 0.052 * 9.0 * 4884) - (0.7 * 0.1 * 4884)) 4~" Production Liner @ 4884' TVD MASP = PP * 0.052 * TVDf MASP = 9.0 * 0.052 * 4884' MASP = 1798 psi (GG * TVDf) - (0.1 * 4884') ---- - Cementing Program Contractor: BJ Services Production Casing Size: 4 3/2" Setting Depth: 5650' MD/ 4884' TVD Annular Volume to 3250' with 6 3/4" gauge hole: 331 ft3 Tail Slurry: Top of Cement: Specifications: Density: 15.8 ppg, Yield: 3250'MD/ 2849' TVD Class G + additives Mixed w/ fresh water 1.15 ft3/sx, Sx: 360 sx, cf: 414 ft3 Compress Strgth: 500 psi in 6 hrs, 3600 psi in 24 hrs Total Volume: 414 ft3, 25% Open Hole Excess, WOC Time: 6 hrs KU 21X-6 Drilling Program Page 3 of 7 ( ( Diverter and BOP Program t"'It) ~\~t<.~, Ç(\Öl'\~~ I s\d~rocL The diverter system will consist of a 21 %", 2000 psi annular preventor and a 16" O.D. nonbifurcated vent line. The vent line will be full opening and integrated with the annular in the fail safe design as stipulated in 20AAC 25.035. The vent line will be a minimum of 75' from any source of ignition. The blowout preventer stack will consist of a 13 5/8", 5000 psi annular, a 13 5/8", 5000 psi double ram preventor with blind rams on bottom and pipe rams on top, a 13 5/8", 5000 psi drilling spool (mud cross) with 3 1/8", 5000 psi flanged outlets, and a 13 5/8", 5000 psi single ram preventer with pipe rams. The choke manifold will be rated 3 1/8", 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a mud gas seperator. Casing Casing Test Size MASP Test BOPS Low/High Casing (in) (psi) (psi) Size & Rating (psi) 1258 1500 ( 1) 13-5/8" 5M Annular 250/3000 Intermediate 7 5/8" (9.2 (1) 13-5/8" 5M Blind ram 250/3000 ppg (2) 13-5/8" 5M Pipe ram 250/3000 mud) 2500 ( 1) 13-5/8" 5M Annular 250/3000 Production 4 'h" 1798 (10.0 ( 1) 13-5/8" 5M Blind ram 250/3000 ppg (2) 13-5/8" 5M Pipe ram 250/3000 mud) v ~ Casing Test Pressure Calculations Casing test pressures are based on the lesser of (1) MASP, or (2) 70% of rated burst pressure of the casing adjusted for the mud weight used during the test less a 8.3 PPG back-up unless otherwise noted. 7 5/8" Intermediate Casing at CTPMASP = 1258 psi CTPBurst = 4140 * 0.7 - Test to 1500 psi 2977' TVD ((9.0-8.3) * 0.052 * 2977) = 2790 psi 4~" production Casing at 4884' TVD CTPMASP = 1798 psi Test to 2500 psi CTPBurst = 5350 * 0.7 - ((9.0-8.3) * 0.052 * 4884) = 3567 psi KU 21X-6 Drilling Program Page 4 of 7 i ¡~: Mud Program Contractor: MI Drilling Fluids Interval (TVD) Mud Weight From To (ppg) Water Loss Mud Type 2977' 4884' 8.7 - 9.0 <8 Flo Pro/KCl Wellhead Program Manufacturer Cameron Model DCB Tubing Head DCB 11" 3M X 7 1/16" 3M w/ 2 5M SSO Tubing Hanger DCB 7 1/16" X 2 7/8" X 2 7/8" Split Hanger Detailed Drilling Procedure Formation Leakoff Test LOT Q\o.t'~ 0...\ v3,~\J..:J Surface and Intermediate casing shoes will be tested to Leak-off. Prior to drilling out of casing strings, test BOPs and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests (LOT) are to be conducted as described below: 1. Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out. 2. Pull drill string into the casing shoe and close ram preventer, and line up to the choke manifold with a closed choke. 3. Begin slowly pumping fluid down the drill string at 1/2 bpm drillpipe pressures at 1/2 bbl intervals. A running plot of kept by the drilling foreman while the test is in progress. 4. Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. 5. Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. while recording casing and pressure versus volume should be Bit Program The following guidelines are recommended for use on this well. Interval Bit Size IADC WOB RPM (MD) (in) Bit Model Code (k lbs) 3400' - 5650' 6 3/4" XR15TDGPS 447X 15/35 200 KU 21X-6 Drilling Program Page 5 of 7 il. Drill String Item Ppf Makeup Torque Max Pull - Premium 31/2" HWDP, 3 1/2" IF 24.4 12000-13200 248,400 Ibs. ft.-lbs. 4", 8-135, HT 38 15.53 13,500-19,800 403,500 Ibs. ft.-lbs. 5 1/2" HWDP, 41/2" IF 49.3/53.6 29,000 543,000 Ibs. ft.-lbs. Hydraulics Program Rig mud pumps available are shown below. Install 5 " liners in all mud pumps. Liner ID Stroke Max Press Gal/Stroke Max Rate Make Model (in) (in) (97% eff) (spm) Oilwell A 600 PT 4 ¥2" 8" 3207 1.6005 135 Oilwell A 600 PT 5.0 8" 2597 1. 9788 135 Oilwell A 600 PT 5 ¥2" 8" 2147 2.3959 135 Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. Pump Standpipe Nozzle Depth Hole Size Rate Pressure AV ECD Size (MD) (in) (gpm) (psi) (fpm) ( ppg) (32"s) Remarks 5650' 6 3/4" 265 2200 - 219 9.5 12,12,14 Motor Drilling 2400 Note: 5" liners are recommended. KU 21X-6 Drilling Program Page 6 of 7 ,I II Planning Report ( Company: Field: Site: Well: Wellpath: Field: Marathon Oil Company Kenai Gas Field Pad 34-31 KU 21-6 Original Kenai Gas Field Kenai, Alaska usa Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Date: 5/9/2001 Time: 09:48:15 Page: Co-ordinate(NE) Reference: Well: KU 21-6, Grid North Vertical (TVD) Reference: Old RKB 84.0 Section (VS) Reference: Well (0.00N,O.00E,114.27Azi) Plan: Plan #1 1 Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre Wmm_95 Site: Pad 34-31 Centered on 21-6 wellhead Section 31, R11W, T5N Site Position: From: Map Position Uncertainty: Ground Level: Northing: Easting: 2367873.60 ft 270536.46 ft 0.00 ft 0.00 ft Latitude: 60 28 31 .144 N Longitude: 151 16 18.601 W North Reference: Grid Grid Convergence: -1 .11 deg Slot Name: Well: KU 21-6 Well Position: +N/-S +E/- W Position Uncertainty: 0.00 ft Northing: 0.00 ft Easting : 0.00 ft 2367873.60 ft 270536.46 ft Latitude: Longitude: 60 28 31.144 N 151 16 18.601 W Wellpath: Original Current Datum: Magnetic Data: Field Strength: Vertical Section: Old RKB 5/3/2001 57433 nT Depth From (TVD) ft 0.00 +N/-S ft 0.00 Height 84.00 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +EI-W ft 0.00 Surface 0.00 ft Mean Sea Level 33.01 deg 84.15 deg Direction deg 114.27 Plan: Plan #1 Principal: Yes Plan Section Information MP "Inel Azim TVD +N/-S +EI-W 'ft .. deg deg ft ft ft 3350.00 31.09 116.29 2934.49 -538.85 1322.58 3400.00 31.60 104.78 2977.23 -547.92 1346.84 3597.79 32.10 116.00 3145.39 -584.21 1444.26 5650.00 32.10 116.00 4883.91 -1062.23 2424.36 Date Composed: Version: Tied-to: 5/4/2001 1 From: Definitive Path DLS" Build Turn " deg/100ft deg/1 OOft" deg/1 OOft 0.00 0.00 0.00 12.00 1.03 -23.01 3.00 0.25 5.67 0.00 0.00 0.00 TFO" deg 0.00 270.00 90.00 0.00 Target Section 1: Start DLS 12.00 TFO 270.00 MD Inel "Azim TVD +N/-S +E/-W "VS DLS, Build TUrn TFO ft' deg ,deg ft ft ft ft deg/1 OOft. deg/1 OOft 'degl1 OOft deg 3350.00 31.09 116.29 2934.49 -538.85 1322.58 1427.17 0.00 0.00 0.00 0.00 3375.00 31.22 110.49 2955.89 -543.98 1334.43 1440.09 12.00 0.52 -23.18 -90.00 3400.00 31.60 104.78 2977.23 -547.92 1346.84 1453.02 12.00 1.55 -22.84 -85.04 Section 2: Start DLS 3.00 TFO 90.00 MD Inel AZim TVD +N/-S +E/- W VS DLS Build Turn, TFO ft deg deg ft' ft ft ft deg/100ft' deg/1 OOft deg/1 OOft deg 3500.00 31.73 110.49 3062.36 -563.81 1396.81 1505.11 3.00 0.13 5.71 90.00 3597.79 32.10 116.00 3145.39 -584.21 1444.26 1556.75 3.00 0.38 5.63 85.14 Section 3: Start Hold MD Inel Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/1 OOft degl1 OOft deg 3600.00 32.10 116.00 3147.26 -584.72 1445.32 1557.92 0.00 0.00 0.00 0.00 3700.00 32.10 116.00 3231.98 -608.02 1493.08 1611.03 0.00 0.00 0.00 0.00 3800.00 32.10 116.00 3316.69 -631.31 1540.84 1664.14 0.00 0.00 0.00 0.00 3900.00 32.10 116.00 3401.41 -654.60 1588.59 1717.26 0.00 0.00 0.00 0.00 4000.00 32.10 116.00 3486.12 -677.90 1636.35 1770.37 0.00 0.00 0.00 0.00 ,~ \ Planning Report Company: Marathon Oil Company Field: Kenai Gas Field Site: Pad 34-31 Well: KU 21-6 Wellpath: Original Section 3: Start Hold Date: 5/9/2001 Time: 09:48:15 Page: Co-ordinate(NE) Reference: Well: KU 21-6, Grid North Vertical (TVD) Reference: Old AKB 84.0 Section (VS) Reference: Well (0.00N,0.00E,114.27 Azi) Plan: Plan #1 2 MD Inel Azim TVD +N/-S +EJ-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg 4100.00 32.10 116.00 3570.84 -701.19 1684.11 1823.48 0.00 0.00 0.00 0.00 4200.00 32.10 116.00 3655.55 -724.48 1731.87 1876.59 0.00 0.00 0.00 0.00 4300.00 32.10 116.00 3740.27 -747.77 1779.63 1929.70 0.00 0.00 0.00 0.00 4400.00 32.10 116.00 3824.98 -771 .07 1827.38 1982.81 0.00 0.00 0.00 0.00 4500.00 32.10 116.00 3909.70 -794.36 1875.14 2035.93 0.00 0.00 0.00 0.00 4600.00 32.10 116.00 3994.41 -817.65 1922.90 2089.04 0.00 0.00 0.00 0.00 4700.00 32.10 116.00 4079.12 -840.95 1970.66 2142.15 0.00 0.00 0.00 0.00 4800.00 32.10 116.00 4163.84 -864.24 2018.42 2195.26 0.00 0.00 0.00 0.00 4900.00 32.10 116.00 4248.55 -887.53 2066.18 2248.37 0.00 0.00 0.00 0.00 5000.00 32.10 116.00 4333.27 -910.83 2113.93 2301.48 0.00 0.00 0.00 0.00 5100.00 32.10 116.00 4417.98 -934.12 2161.69 2354.60 0.00 0.00 0.00 0.00 5200.00 32.10 116.00 4502.70 -957.41 2209.45 2407.71 0.00 0.00 0.00 0.00 5300.00 32.10 116.00 4587.41 -980.71 2257.21 2460.82 0.00 0.00 0.00 0.00 5400.00 32.10 116.00 4672.13 -1004.00 2304.97 2513.93 0.00 0.00 0.00 0.00 5500.00 32.10 116.00 4756.84 -1027.29 2352.72 2567.04 0.00 0.00 0.00 0.00 5600.00 32.10 116.00 4841.56 -1050.59 2400.48 2620.15 0.00 0.00 0.00 0.00 5650.00 32.10 116.00 4883.91 -1062.23 2424.36 2646.71 0.00 0.00 0.00 0.00 Survey MD Inel Azim TVD +N/.S +EI-W VS DLS Build Turn TóoVComrnent ft deg deg.. ft ft ft ft deg/1 00ftdeg/1 OOft deg/1 OOft 3350.00 31.09 116.29 2934.49 -538.85 1322.58 1427.17 0.00 0.00 0.00 MWD/GYRO 3375.00 31.22 110.49 2955.89 -543.98 1334.43 1440.09 12.00 0.52 -23.18 MWD/GYRO 3400.00 31.60 104.78 2977.23 -547.92 1346.84 1453.02 12.00 1.55 -22.84 MWD/GYAO 3500.00 31.73 110.49 3062.36 -563.81 1396.81 1505.11 3.00 0.13 5.71 MWD/GYRO 3597.79 32.10 116.00 3145.39 -584.21 1444.26 1556.75 3.00 0.38 5.63 MWD/GYRO 3600.00 32.10 116.00 3147.26 -584.72 1445.32 1557.92 0.00 0.00 0.00 MWD/GYRO 3700.00 32.10 116.00 3231.98 -608.02 1493.08 1611.03 0.00 0.00 0.00 MWD/GYRO 3800.00 32.10 116.00 3316.69 -631.31 1540.84 1664.14 0.00 0.00 0.00 MWD/GYRO 3900.00 32.10 116.00 3401.41 -654.60 1588.59 1717.26 0.00 0.00 0.00 MWD/GYRO 4000.00 32.10 116.00 3486.12 -677.90 1636.35 1770.37 0.00 0.00 0.00 MWD/GYAO 4100.00 32.10 116.00 3570.84 -701.19 1684.11 1823.48 0.00 0.00 0.00 MWD/GYRO 4200.00 32.10 116.00 3655.55 - 724.48 1731.87 1876.59 0.00 0.00 0.00 MWD/GYRO 4300.00 32.10 116.00 3740.27 -747.77 1779.63 1929.70 0.00 0.00 0.00 MWD/GYRO 4400.00 32.10 116.00 3824.98 -771.07 1827.38 1982.81 0.00 0.00 0.00 MWD/GYRO 4500.00 32.10 116.00 3909.70 -794.36 1875.14 2035.93 0.00 0.00 0.00 MWD/GYRO 4600.00 32.10 116.00 3994.41 -817.65 1922.90 2089.04 0.00 0.00 0.00 MWD/GYRO 4700.00 32.10 116.00 4079.12 -840.95 1970.66 2142.15 0.00 0.00 0.00 MWD/GYRO 4800.00 32.10 116.00 4163.84 -864.24 2018.42 2195.26 0.00 0.00 0.00 MWD/GYRO 4900.00 32.10 116.00 4248.55 -887.53 2066.18 2248.37 0.00 0.00 0.00 MWD/GYRO 5000.00 32.10 116.00 4333.27 -910.83 2113.93 2301.48 0.00 0.00 0.00 MWD/GYRO 5100.00 32.10 116.00 4417.98 -934.12 2161.69 2354.60 0.00 0.00 0.00 MWD/GYRO 5200.00 32.10 116.00 4502.70 -957.41 2209.45 2407.71 0.00 0.00 0.00 MWD/GYAO 5300.00 32.10 116.00 4587.41 -980.71 2257.21 2460.82 0.00 0.00 0.00 MWD/GYRO 5400.00 32.10 116.00 4672.13 -1004.00 2304.97 2513.93 0.00 0.00 0.00 MWD/GYRO 5500.00 32.10 116.00 4756.84 -1027.29 2352.72 2567.04 0.00 0.00 0.00 MWD/GYRO 5600.00 32.10 116.00 4841.56 -1050.59 2400.48 2620.15 0.00 0.00 0.00 MWD/GYRO 5650.00 32.10 116.00 4883.91 -1062.23 2424.36 2646.71 0.00 0.00 0.00 MWD/GYRO ( ( MARATHON OIL COMPANY KU 21X-6 ,....., .5 ~ o. o. 0 ~i ........ .-.. + --- "Ë 0 ~ .-.. I --- ~ 0 00 -1000 -2000 1000 10: 0 i I I 20 0 I I W est( - )Æast( +) [1 OOOft/in ] oS I $:1., I <II) ! Q, I I "a . 0 ! - J::I: I ~I (11) >- <11) 2 ~I ,,' ( ( MARATHON OIL COMPANY KU 21X-6 ,---, .S ~ 0 0, 0, N ........ -2000 2000 4000 6000 0 0 2000 Vertical Section at 114.27° [2000ft/in] 4000 ,I 'l 'I I, SURFACE USE PLAN FOR KENAI UNIT KU 21 X-6 Surface Location: SW 1/4 of SE 1/4, Sec. 31, T5N, R11W, S.M. 1. Existing Roads Existing roads that will be used for access to Kenai Unit KU 21-6 are shown on the attached map. Kenai, Alaska, is the nearest town to the site and is also shown on the map. 2. Access Roads to be Constructed or Reconstructed No new roads will be required to access KU 21-6. 3. Location of Existing Wells Well KU 21-6 will be sidetracked from an existing well on pad 34-31. A pad drawing is attached that shows existing wells and the location for KU 21-6. 4. Location of Existing and/or Proposed Facilities The location of existing production facilities in the Kenai Unit are shown on the attached pad drawing. These facilities may be upgraded to handle the additional gas production. 5. Location of Water Supply The location of the water well is shown on the pad drawing. Water will be used to make and maintain the drilling mud. 6. Construction Materials No road or pad modifications or improvements are planned. 7. Method of Handling Waste Disposal a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be hauled to Pad 41-18 of the Kenai Gas Field for disposal into Well KU 24-7, a Class II disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). N :\DRLG\KGF\W ELLS\KU21-6L \SU RFUSE.doc Surface Use Plan Kenai Unit KU 21-6 Page 2 if \ b) Garbage All household and approved industrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be hauled to Pad 34-31 of the Kenai Gas Field and injected in Well WD #1, an approved disposal well (AOGCC Permit #7-194). d) Chemicals Unused chemicals will be returned to the vendor who provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. 8. Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the existing water well on the pad. Town & Country will collect and transport sanitary wastes to their ADC approved disposal facility. No additional structures will be necessary. 9. Plans for Reclamation of the Surface Kenai Unit KU 21-6 will be drilled from an existing pad. Reclamation of the pad will occur after abandonment of KU 21-6 and the other existing wells on the pad. Approval of the plan of reclamation will be obtained from CIRI Native Corporation prior to any reclamation work beginning. 10. Surface Ownership The surface owner of the land in the Kenai Unit is the CIRI Native Corporation. Surface Use Plan Kenai Unit KU 21-6 Page 3 ~. < 11. Operator's Representative and Certification I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions that currently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and that the work associated with operations proposed herein will be performed by Marathon Oil Company and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U.S.C. 1001 for the filing of a false statement. Date: s--/" - 0 / Name & Title: . ~/(~ 7)r.: / /;,; f- Marathon Oil ompany I P. O. Box 196168 Anchorage, Alaska 99519-6168 (907) 561-5311 s-~/~~ ~ ,,¡" , (. Marathon Oil Well KU 21 X-6 Choke Manifold t 1311 5M Valves 2 9/1611 10M Swaco Hydraulically Operated Choke t 3 1/811 5M Manually Adjustable Choke ¡Flow Nipple I 13 5/811 5M Annular Preventer 13 5/811 5M Double Ram Preventer 3 11811 5M Manually Operated Valves \1 Marathon Oil Well KU 21 X-6 BOP Stack - I Flow Line I I . I ~ "'. / ./ " I I I '" ./ ./ '- I I Pipe Ram I I IBlind Ram I I '" ./ " '- I I I I '" ..... I Kill I ¡Choke II .... ~:'" .... I I " " '" I Pipe Ram I I '" ./ " '- I I I I .... " \ / -----.. 3 1/811 5M Hydraulically Operated Valve ~~ [J@ij][J@ij] 1135/811 5M Cross I 13 5/811 5M Single Ram Preventer ,¡ [I@[][[I@J]] t 3 1/811 5M Manually Operated Valve ~ i t[ File: Stressck1 .-.-...----------------- - -. - -.-.-----------------..--- -- -,,_. -------- WELL SCHEMATIC (DEPTH - MD), " .--- -- ---------,,------------Q~~fv1~Y_Q~,__?9_QJ.J:Age:_.) ,... RKB 1282 ft ~ 3250 ft - 3400 ft .. 5650 ft Side Track KU 21X-6 ... 10 3/411 Surface Casing ,... TaL .. 7 5/811 Intermediate Casing ~ 4 1/211 Production Liner ... StressCheck 2000.0 + KDU-7 X I 0 MILE MARATHON OIL COMPANY ALASKA REGION COOK INLET, ALASKA NET W.t : 100% 2001 " - ~;, ;J ?; :>,:~ ,.,;~ ,>;.: ~;þ :.~~ > y ;~); ~.~ }-(~ ',;';: I,' .,j, h .~~~: ii :,~i ::~~, ^, " ,;, '~:,. ~~;; . ;'~t ":"j , , ;/1 ~~,:~, '):~',,¡ :\. .:\\;::~ '^~,,: ,~~ "':~\b., " ',' .. .. , . KU 21-6 Proposed Abandonment ~.., ' ø~ ¡\ <~I'~~~ !þ;'~ '~'; $~ ;;; ;::...; ~:,j, ,~ .;. : .~ f.~~ ,.~':, \)/:; Cast I ran Bridge Plug @ 3450' Sterling Pool 4: 4417' -4465' 4527' -4554' 250psi ( ~: :~ ~~: ~:' :~: Hole in blast jt of Long String @ 4638' (confirmed :::~~;:i(~:B:)}::::::::={~{: ' Sterling Pool 5.1: 550psi 4580' -4650' ~,: ~ ,$'. t :'~ .. >:" " , , -, . :~' I Cement Plug I Squeezed Perfs Sterling Pool 5.1: 1050psi 4700' -4835' Sterling Pool 5,2: 1440psi 4884'-4918' ~,:" :;: } " , ~, ::): .............. ........... " . ".'.'.'.'.'.'.' Sterling Pool 6: 5255' -5320' 350psi Cement Plug .}: :i~ W " , )~: , ," ~jj " ,=:; ':', ,~: .~~ (, f: :.:~ l ,~; ~, :' ~;¿ .~~ ," l ;0-' ,~ '~ " .... ~~ ~: " ~ ,-;.; , " ~: .. :':,: :,;.- ..~ ,y ..~ .. " ;0-' ,~ .. f ) ~~ (: ~" .. ... " ,~ ,K '¡,:' :..:: ;': ... " ,¡.; '~-:: ,~ ', y' ':~ ~ ¿~) " \ .. .- ~WD 6\) .. .. ~ .. ~ .. " . ,., . \ .. .;,i)~.ì~':;!í;t ,..' ',",' KENAI GAS FIELD 31 FIGURE .- 1 ,,:,:,i' ?::t..~'~\(': ',f.~ '. . . L I Ii, ; . , ',:,,:, , . , . ,¡ ',' I' ! :,' " , ¡ " r" " , , ~;;;~I ' " ! í ~ !o T ----- ~- .t-.a l-:~I '~. 8 .....a .....tt 1111 '11111'" II ,-~ . .. I I' I I I I I t t ' I ,~ I . ~ I % I ~ ~ I 'rt1 I JC I [i], ..... ""..L .. '- "---... -.. 'ldQÐ9";'~ . 16 M J ;:~I --r- t . . , , , ,., \ ~;~ 9/ lit&! 1 d 009-~ '6 I\!; . , ¡----.., ..... I '-, ,-I .z Þa'III1 DIM , IIU':~ 1 "'-8 t ..... . , -p' 'Ši x 9 ~'SL .;e.,It> , ..tl . S ~,9 cIH G¿. \ "".6-- . -t'... 1811t.1. .. , '.,- '-.8 4 " .t1 ' SX9 elf Sl.J OII ........,. ,a} x ,e ÁrGII ..a-Aol , ,. .0 - .2 MIl .,¡ I . , ~ ,g, . ......-'.... ;!: .. I '" .. ~:SW9~I""" \ .l..OIæOd ,f . \: ',I L " ::,' '" I . , .... ' ; , "~ I . I I , , I t I I ' . , , -:---~~--:--..........., , I I I .....1 , .. . ...... "'..... ""'.n \.... \.... i " i R'O !iI ' :¡ ( , " ...~ " '0202.39 567847.93 + \ 34-31 WASTE H2O 13.9' b ..q: K.U.-14-32 16 ~- WELL 0"""- HOUSE M ELEV. 58.63 20' ~- 0 a> WELL HOUSE W.D. NO.1 H2O INJECTION ;0 14.3' K.D.U.-5 X=270,905.95 Y=2,368,044.23 PIT CONC. PAD WELL "E" X=270,944.5 Y=2,367,957.3 , . TOP 6" PIPE EL.= 60.05, - TOP 2" PIPE EL.= 59.96 { IIcLANE CONSUL TING GROUP SOLDOTNA, ALASKA 99669 (907) 283-4218 DATE OF SURVEY: 11/2/95 No. DATE B' BOOK NO.: gf.3~~'8~~õiO ~ PROJECT NO.: 953156 DRAWING NO.: 95PD3431 SCALE 1"=50' DRAWN BY: PCO 553.3' KU-34-31 10'X10' G WELL HOUSE X..270,494.7 Y=2,367,885.56 - KU-21-6 1 O'X1 0' WELL HOUSE X=270,536.46 Y=2,367,873.6 y.. BLOWDOWN/- 1,.INE '\ - -¡.. 0 586.12' S 87'37'23" W )( ~- BOLLARDS ~ KU-11-6 10'X10' G WELL HOUSE X=270,532.38 Y=2,367,769.1 BALL FIELD FOUL LINE AND OUTFIELD FENCE CONC. S/W '.,... .. . .- '. ,... . . --- ¡.., ..q: ('OJ 7.0' OFFICE 16 3' - ADDN. . ~ 40.5' ~ 7'X9' 0 t WA TER ANTENNA WELL W/ GUY WIRES SHOP ~ + /.., ~ ~~~L LINE /{ . . ~E~/ +.~ ~ / PRIVY 0 ........... 0 6.6'X6' ~ [l ~:T STORAGE HORSESHOE PIT ~........ at'/ \\ ~ ~VE~D 0 TABLES SANDBOX .~. 0 Q @) WELL "A. X=270,944.6 Y==2.367,813.1 , TOP 6. PIPE EL.= 57.41, TOP 2" PIPE EL.= 57.16 ( r:: ('OJ II x -._.-.-.~,- .".".,'" .'."'..'. . ::ò:::r:~RM:~O2 liEV 'INI :.':::¡~?).}?theorder of: '.:,.'. .,- " Marath~~ pi~ C~~pany N\( .H, ), IA(.r AI ASK, \ "':':'::;::':"::ò"".::::';';:' ..'; ,,-,;:-,. .::':- 57. a 15 3 a 1 252 - I / 05 /17/01 ~'Ý1() DY Y~~ r 'MATCH AMOUNT-IN ] ,$ WORD~V~I~~,NUMBERS. ......' ~___..:._-..l01L..QD-'--____'- . , ' '" ,'::': '::..:: ,::':, ':,'_:":..',"..' , ,'" " " ,', , "", , ~~; ~ ~ 8 ~ i~ t ~â~:: , c;:~;;:~~~\,: Anchorage, AR:i99501:,:":.." ,Pay: ,~'..,'::,',,"::',', ,"': "": ,"::"",,:, , VOÐt,r-¡[H iÐDDAY~; ; f"'-~~kA~¡~d.. a~~;;qð~"l~~i.~~~(~t~~~;~~~~: ~~ ': ~~ ~~;~~ ~ ~ ~ ~;~- - ~ - ~ ~ ~ ~- - ~- - - ": ", D~~'I' ~ , NÅ~~~~t:~::~~~~SKA' By r 16 /);;:Zl Company "'::::::::':"::::(:::,:(:'::\:"".., '"':::::'::/':::::<::,...,, ,':",,:.,,:' J-f ,\Ui,':HIIFi; S!GNt,iU'¡, .-1::1 n~r. ~i8..I(:I IIi [IiIJf I='~."~ PH 'P~'" PIr., I rliH '."11 ::I.J.','.'~I~.!!rl].I".!.1..!.'~...!.'~rC'l.:ail III 0 0 . 5 :} 0 III I: . 2 5 2000 5 ? I: 0 .1110 ? 8 5 b ~ III A:F.E. r ACCT. CODE UNIT NO. / C.C. Marathon Oil Company P.o. Box 196168 ANCHORAGE. AlASKA 99519-6168 ~ . NON-REPORTING 100% REPORTABLE INTEREST IF REPORTABLE RENTS INDICATE SERVICES TYPE OF PAYMENT I NON-EMPLOYEE COMP, PRIZES, AWARDS, OR DAMAGES Filing Fee for Permit tÔl Drill o. WelLKU2lX=b¥~~..o~~~,,~,~.~~-..~-~~~~~~~~~~.~~~,~~.~~~~~~~,~o.~,.. WELL PERMIT CHECKLIST COMPANY ~q.r4!AD¡J FIELD & POOL ~ '-!ZS ~ <¡{ INIT CLASS ~ ADMINISTRATION 1. Permit fee attached~ . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. " . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . '. . . . . . 14. Conductor string provided. . . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations. . . . . . . . . . 24. Drilling fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation. . . . . . . . . . 0 . . . . 26. BOPE press rating appropriate; test to ~OO psig. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued w/o hydrogen sulfide measures. . . . . 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . R ..gAlft. 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . ~.~ 34. Contact name/phone for weekly progress reports [exploratory 0 ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UtC/Annuiar COMMISSION: ~þg?Z ~cr~ ¿" - -. WM B~s CQ\ S/., ~ JMIi J1\A H 5124J01 J DATE 7<./ lor ENGINEERING GEOLOGY } APPR DATE I<u WELL NAME.2/)¿ - {; c:\rnsoffice\wordian\diana\checklist (rev. 11/01//00) PROGRAM: exp dev ~ redrll >< serv GEOL AREA ? .2.-C:J UNIT# Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N ~ ~ ~\~Ct~~ o~ Ct 'i-'~~~ f'o.\. v..;)~ \ , N N- N ':1) N fL.' .., ~~ \-, ~ ~, t ~ 't::) ~~CL~ (? ~\+ N ;> ~ N c \o~~~\- ~Ct \ , "\c- o.\c.u ~~~ s.~ ~~'a ~ ~ -\ ~ '\ ~ ~(( \ \ ~~ wellbore seg _ann. disposal para req - S I / ~ 6 ON/OFF SHORE Q~ c 0 Z 0 -t ~ ;U - -t m N N Y)N \-\~~~ ~<>\-~""'o:.~~ Q \,\ <;.<iç ~\ N ?~ - Z -t :I: - en > ;U m > Y N Y N (). \\ ~ \~ "\-ò~ -\c ~ ~'\<;'~~Q<t) \ ~ c... \~~c::. Q ~<è\ \. ~ "'~\Q.. \;] \ ~ t \ ~ n. 0 (J..1'r"'I ~ \'->,., \ ~ Ç>C)~<J.. "f\Q..V"\Y"'\.Q Comments/Instructions:
