Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
184-109
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 6,950 feet 4,975 feet true vertical 6,447 feet N/A feet Effective Depth measured 4,975 feet 3735, 4988 feet true vertical 4,588 feet 3499, 4600 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)5-1/2" 17# / L-80 3,735' MD 4,449' TVD ZXP Pkr, BWD Pkr;3,735' MD/3,499' TVD 4,988' MD/4,600' TVD Packers and SSSV (type, measured and true vertical depth)SSSV 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: 4,750psi 3,090psi 6,870psi 2,532'2,461' Burst 1,530psi Collapse 520psi 1,540psi Production Liner 6,950' 1,200' Casing Structural 6,440' 5-1/2" 6,950' 4,952'4,580' Conductor Surface Intermediate 20" 13-3/8"2,532' measured TVD 7,740psi 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 184-109 50-133-20371-00-00 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 Sterling 6 Gas Storage Kenai Beluga Unit (KBU) 23X-06 Plugs Junk measured Length 126' 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 126' 321 Size 126' 0 2864132 0 1410 150 Chad Helgeson, Operations Engineer 324-099 Sr Pet Eng: 6,280psi Sr Pet Geo:Sr Res Eng: WINJ WAG 3601 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 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 Samantha Coldiron at 8:45 am, Apr 15, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.04.12 17:16:13 - 08'00' Noel Nocas (4361) RBDMS JSB 041824 Page 1/1 Well Name: KEU KBU 23X-06 Report Printed: 4/12/2024www.peloton.com Alaska Weekly Report - Operations Jobs Actual Start Date:3/29/2024 End Date: Report Number 1 Report Start Date 3/29/2024 Report End Date 3/30/2024 Last 24hr Summary MIRU HES E-line. Re perforate Sterling gas pool 6 sands. From 4906'-4886', 4886'-4866', 4866'-4846'. 150.4 PSI consistent prior and post perforations with well shut in. Last gun # 4 4829'-4846' miss fire. Post perforations rate increased from 4.74 mmcf, to 5.35 mmcf. RDMO HES E-line unit. Field: Kenai Gas Field Sundry #: 324-099 State: Alaska Rig/Service:Permit to Drill (PTD) #:184-109Permit to Drill (PTD) #:184-109 Wellbore API/UWI:50-133-20371-00-00 Lease: State: Country:USA Angle/Perfs: KOP (TVD): 65.7' 30.7' Well Name & Number:Kenai Beluga Unit 23x-6 Angle @ KOP & Depth:30 deg. A-028142 County or Parish:Kenai Peninsula Borough Alaska 04/03/24 RKB (above GL):04/18/07 Revised by:D Ambruz Last Revision Date: Date Completed:Ground Level (above MSL): Casing Patch @ 4200' - 4303' Owen Oil Tool, ID = 7.75" Isolating B-3 perfs (4214' - 4275') Inactive Perfs: Sterling Pool 5.1 isolated perfs: 4214' - 4275' (Casing Patch) Sterling squeeze perfs: 3784' - 3786' 4278' - 4280' (1/31/85) Beluga squeeze perfs: 5110' - 5112' (2/3/85) U-1: 5112' - 5130' (3/27/07) U-2: 5153' - 5165' (3/27/07) 5201' - 5204' (2/17/85) 5215' - 5221' (2/17/85) 5280' - 5301' (2/14/85) U-5: 5282' - 5303' (1/3/01) U-7: 5398' - 5430' (3/27/07) U-9: 5520' - 5545' (3/27/07) 6696' - 6706' (2/9/85) Beluga perfs covered with junk: L-3: 6788' - 6810' ( 6/01) PBTD MD: 4,975' TVD: 4,588' Active Perfs: Sterling Pool 6, 4,829' - 4,906' MD (3/13/02) 4-5/8" TCP guns, 5 spf (Reperforated) 4,829' - 4,906' MD (5/12/07) 3-3/8" 6 spf (Reperforated) 4,846' - 4,906' MD (3/29/24)Top of Stub @ ~ 4,970' Baker 2-7/8" Cast Iron Cement Retainer @ 4,975' FlexLock Hanger & ZXP Liner Top Packer @ 3,735' External Casing Packer @ 4,784' 6.625" OD 4.892" ID 4.676" Drift Locator sub @ 4,985' Halliburton BWD Packer @ 4,988' TD MD: 6,950' TVD: 6,447' Drive Pipe 20" H-40 94 ppf Top Bottom MD 0' 126' TVD 0' 126' Surface Casing 13-3/8" K-55 61 ppf BTC Top Bottom MD 0' 2,532' TVD 0' 2,461' Cmt w/ 1,900 sacks Production Casing 9-5/8" N-80 47 ppf BTC Top Bottom MD 0' 6,950' TVD 0' 6,440' Cmt w/ 3000 sacks Permit #:184-109 API #:50-133-20371-00-00 Property Des:A - 028142 KB:30.7' AGL (96.4' KB Elevation) Spud Date:3/8/2002 Rig Released:4/18/2007 Lat: Long: Liner 5-1/2" L-80 17 ppf BTC Top Bottom MD 3,752' 4,952' TVD 3,514' 4,580' Tubing 5-1/2" L-80 17 ppf Modified Butress Top Bottom MD 0' 3,735' TVD 0' 3,499' KBU 23x-6 Pad 14-6 291' FSL, 1,208' FWL Sec. 6, T4N, R11W, S.M. Tag w/ Caliper @ 4945' (6/22/23) SCHEMATIC 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): 6,950'N/A Casing Collapse Structural 520psi Conductor Surface 1,540psi Intermediate Production 4,750psi Liner 6,280psi 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: 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 ZXP Pkr, BWD Pkr; SSSV 3,735' MD/3,499' TVD, 4,988' MD/4,600' TVD; N/A, N/A 6,440'4,975'4,588' Kenai Sterling 6 Gas 13-3/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Beluga Unit (KBU) 23X-06CO 510C Sterling 6 Gas Storage 6,440'9-5/8" ~168psi 6,950' 4.975' Length February 27, 2024 4,952'1,200' 5-1/2" 4,580' 126'20" 6,950' Perforation Depth MD (ft): 5-1/2" See Attached Schematic 1,530psi 3,090psi2,532' Size 2,532' MD Hilcorp Alaska, LLC Proposed Pools: 126'126' 17# / L-80 TVD Burst 3,735' 6,870psi 2,461' 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 184-109 50-133-20371-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Chad Helgeson, Operations Engineer AOGCC USE ONLY 7,740psi 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 12:35 pm, Feb 20, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.02.19 16:33:29 - 09'00' Noel Nocas (4361) 324-099 ADL0390821 SFD SFD 2/20/22024 10-404 BJM 2/27/24 DSR-2/21/24 Re-Perforate 6,447' SFD *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.27 16:29:58 -09'00'02/27/24 RBDMS JSB 022824 Well Prognosis Well: KBU 23X-06 Date: 2-12-24 Well Name: KBU 23X-06 API Number: 50-133-20371-00 Current Status: Storage Prod/Inj Permit to Drill Number: 184-109 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 BHP in 4 years) Max. Predicted Surface Pressure: ~ 168 psi (Current Pool 6 SI pressure) Brief Well Summary KBU 23X-06 was originally drilled in 1984 and completed with a dual string in the Beluga and Sterling Pool 5.1. It was worked over and converted to a Sterling Pool 6 storage well in 2007, where the Beluga was plugged back and the Sterling Pool 5.1 had a casing patch isolating those perfs. A 5-1/2” liner and tie-back were run in the well completing in Sterling Pool 6 sand, where the well is an active producer in the winter and injector in the summer. 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 5-1/2” completion x EL tagged bottom @ 4945’ (6/22/23) x MIT-IA to 1500 psi completed 4/6/23 Pool Top in KBU 23X-06 based on KU 21-6 reference well in CO 510C - Sterling Gas Pool 6 Top: 4,825’ MD; 4,452’ 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 ±4,829’ ±4,906’ ±4,455’ ±4,525’ ±77’ 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. o reperforate the Pool 6 sands. Well Prognosis Well: KBU 23X-06 Date: 2-12-24 d. These sands are in the Sterling Gas Pool 6 per CO 510C. 4. RDMO e-line 5. Turn well over to production Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Lease: State: Country:USA Angle/Perfs: KOP (TVD): 65.7' 30.7' Kenai Peninsula Borough Alaska 06/01/11 RKB (above GL):03/15/02 Revised by:Mike Sulley Last Revision Date: Date Completed:Ground Level (above MSL): Well Name & Number:Kenai Beluga Unit 23x-6 Angle @ KOP & Depth:30 deg. A-028142 County or Parish: Casing Patch @ 4200' - 4303' Owen Oil Tool, ID = 7.75" Isolating B-3 perfs (4214' - 4275') Inactive Perfs: Sterling Pool 5.1 isolated perfs: 4214' - 4275' (Casing Patch) Sterling squeeze perfs: 3784' - 3786' 4278' - 4280' (1/31/85) Beluga squeeze perfs: 5110' - 5112' (2/3/85) U-1: 5112' - 5130' (3/27/07) U-2: 5153' - 5165' (3/27/07) 5201' - 5204' (2/17/85) 5215' - 5221' (2/17/85) 5280' - 5301' (2/14/85) U-5: 5282' - 5303' (1/3/01) U-7: 5398' - 5430' (3/27/07) U-9: 5520' - 5545' (3/27/07) 6696' - 6706' (2/9/85) Beluga perfs covered with junk: L-3: 6788' - 6810' ( 6/01) PBTD MD: 4,975' TVD: 4,607' Active Perfs: Sterling Pool 6, 4,829' - 4,906' MD (3/13/02) 4-5/8" TCP guns, 5 spf (Reperforated) 4,829' - 4,906' MD (5/12/07) 3-3/8" 6 spf Top of Stub @ ~ 4,970' Baker 2-7/8" Cast Iron Cement Retainer @ 4,975' FlexLock Hanger & ZXP Liner Top Packer @ 3,735' External Casing Packer @ 4,784' 6.625" OD 4.892" ID 4.676" Drift Locator sub @ 4,985' Halliburton BWD Packer @ 4,988' TD MD: 6,950' TVD: 6,440' Drive Pipe 20" H-40 94 ppf Top Bottom MD 0' 126' TVD 0' 126' Surface Casing 13-3/8" K-55 61 ppf BTC Top Bottom MD 0' 2,532' TVD 0' 2,461' Cmt w/ 1,900 sacks Production Casing 9-5/8" N-80 47 ppf BTC Top Bottom MD 0' 6,950' TVD 0' 6,440' Cmt w/ 3000 sacks Permit #:184-109 API #: 50-133-20371-00-00 Property Des: A - 028142 KB: 30.7' AGL (96.4' KB Elevation) Spud Date:3/8/2002 Rig Released: 3/15/2002 Lat: Long: Liner 5-1/2" L-80 17 ppf BTC Top Bottom MD 3,752' 4,952' TVD 3,514' 4,580' Tubing 5-1/2" L-80 17 ppf Modified Butress Top Bottom MD 0' 3,735' TVD 0' 3,499' KBU 23x-6 Pad 14-6 291' FSL, 1,208' FWL Sec. 6, T4N, R11W, S.M. Tag 2" DD bailer 4955' on 5/31/11 Tag 2.5" DD bailer 4945' on 1/26/10 Lease: State: Country:USA Angle/Perfs: KOP (TVD): 65.7' 30.7' Kenai Peninsula Borough Alaska 02/12/24 RKB (above GL):04/18/07 Revised by:Chad Helgeson Last Revision Date: Date Completed:Ground Level (above MSL): Well Name & Number:Kenai Beluga Unit 23x-6 Angle @ KOP & Depth:30 deg. A-028142 County or Parish: Casing Patch @ 4200' - 4303' Owen Oil Tool, ID = 7.75" Isolating B-3 perfs (4214' - 4275') Inactive Perfs: Sterling Pool 5.1 isolated perfs: 4214' - 4275' (Casing Patch) Sterling squeeze perfs: 3784' - 3786' 4278' - 4280' (1/31/85) Beluga squeeze perfs: 5110' - 5112' (2/3/85) U-1: 5112' - 5130' (3/27/07) U-2: 5153' - 5165' (3/27/07) 5201' - 5204' (2/17/85) 5215' - 5221' (2/17/85) 5280' - 5301' (2/14/85) U-5: 5282' - 5303' (1/3/01) U-7: 5398' - 5430' (3/27/07) U-9: 5520' - 5545' (3/27/07) 6696' - 6706' (2/9/85) Beluga perfs covered with junk: L-3: 6788' - 6810' ( 6/01) PBTD MD: 4,975' TVD: 4,607' Active Perfs: Sterling Pool 6, 4,829' - 4,906' MD (3/13/02) 4-5/8" TCP guns, 5 spf (Reperforated) 4,829' - 4,906' MD (5/12/07)3-3/8" 6 spf Reperforate 4,829' - 4,906' MD (PROPOSED) Top of Stub @ ~ 4,970' Baker 2-7/8" Cast Iron Cement Retainer @ 4,975' FlexLock Hanger & ZXP Liner Top Packer @ 3,735' External Casing Packer @ 4,784' 6.625" OD 4.892" ID 4.676" Drift Locator sub @ 4,985' Halliburton BWD Packer @ 4,988' TD MD: 6,950' TVD: 6,440' Drive Pipe 20" H-40 94 ppf Top Bottom MD 0' 126' TVD 0' 126' Surface Casing 13-3/8" K-55 61 ppf BTC Top Bottom MD 0' 2,532' TVD 0' 2,461' Cmt w/ 1,900 sacks Production Casing 9-5/8" N-80 47 ppf BTC Top Bottom MD 0' 6,950' TVD 0' 6,440' Cmt w/ 3000 sacks Permit #:184-109 API #:50-133-20371-00-00 Property Des:A - 028142 KB:30.7' AGL (96.4' KB Elevation) Spud Date:3/8/2002 Rig Released:4/18/2007 Lat: Long: Liner 5-1/2" L-80 17 ppf BTC Top Bottom MD 3,752' 4,952' TVD 3,514' 4,580' Tubing 5-1/2" L-80 17 ppf Modified Butress Top Bottom MD 0' 3,735' TVD 0' 3,499' KBU 23x-6 Pad 14-6 291' FSL, 1,208' FWL Sec. 6, T4N, R11W, S.M. Tag w/ Caliper @ 4945' (6/22/23) PROPOSED 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 KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON EPX KBU 23X-6 50133203710000 184109 6/22/2023 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 23X-06 KENAI BELUGA UNIT 23X-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/11/2023 23X-06 50-133-20371-00-00 184-109-0 G SPT 3499 1841090 1500 349 349 349 350 12 14 14 14 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 BELUGA UNIT 23X-06 Inspection Date: Tubing OA Packer Depth 4 1685 1656 1646IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230412101843 BBL Pumped:1.8 BBL Returned:1.8 Thursday, May 11, 2023 Page 1 of 1 Hikor� AWk�. LIA: i Kenai Gas Field NBU 23X06 133/8x95/SxSY. BHTA, Otis, 71/16 3M FE x 9.5" Otis quick union top Valve, Swab, Gray model C, 7 1/16 3M FE, HWO Coiled tubing head, VG -CTM, 5" nominal bore, 7 1/16 3M x 71/163M No Coil tubing installed Valve, Master, Gray model C, 71/163M FE, HWO Hanger bushing/isolation sleeve, 5" Type H BPV profile Tubing head, VGSF, 115M x 11 SM, w/ 1- 2 1/16 SM SSO, 1- 71/16 3M EFO Void test good after packing off to 5000psi, initial test showed leak on bottom side,i had to use plastic injection packing in order to make hold 1/29/2020 Casing spool, VGSF, 13 5/8" 3M x 115M, W/ 2- 2 1/16 SM SSO Starting head, CIW-WF, 13 5/8" 3M x 13 3/8" SOW, w/2-21/16 SM EFO , 2 1/16 SM Wing section w/ Pneumatic SSV Adapter, Vetco XP -1, 115M stdd bottom x 7 1/16 3M FE top Valve, Wing, Gray model C, 7 1/16 3M FF. HWO tubing set on sips W/ packing unit Valve, Wing, SSV, WKM, 7 1/16 3M FE, w/ Baker MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, April 29, 2019 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 23X-06 KENAI BELUGA UNIT 23X-06 Src: Inspector Reviewed By: P.I. Supry J{' Comm Well Name KENAI BELUGA UNIT 23X-06 API Well Number 50-133-20371-00-00 Inspector Name: Guy Cook Insp Num: milGDC190423171809 Permit Number: 184-109-0 Inspection Date: 4/15/2019 Rel Insp Num: Pretest Initial I5 Min 30 Min 45 Min 60 Min 300 300 - 300 - 300 I00 1734 1695 I681- 1'- 113 13 Monday, April 29, 2019 Page I of I Packer Depth Well 23X-06 Typelnj G �fVD 3499 - Tubing PTD s41o90 Type Test sPT Test psi soo IA BBL Pumped: T 1.5 � BBL Returned: 15 OA Interval -- — 4vRTST p/F 1° Notes: Testing performed with a triplex pump and calibrated gauges, ✓ Pretest Initial I5 Min 30 Min 45 Min 60 Min 300 300 - 300 - 300 I00 1734 1695 I681- 1'- 113 13 Monday, April 29, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,May 04,2015 TO: JP.!. Raperg (1/ 5(0/1 P.I.Supervisor I 1 I SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 23X-06 FROM: Jeff Jones KENAI BELUGA UNIT 23X-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv_ ? -- NON-CONFIDENTIAL Comm Well Name KENAI BELUGA UNIT 23X-06API Well Number 50-133-20371-00-00 Inspector Name: Jeff Jones Permit Number: 184-109-0 Inspection Date: 4/21/2015 Insp Num: miUJ150501080810 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 23X-06 'IType Inj N TVD 3499 Tubing' 90 80 - 80. 80 PTD I 1841090 TYP e Test, SPT Test P si 1500 • IA 80 1700 1650 1625 ----------- Interval4YRTST IPS i P OA o 0 0 0 / Notes: < 1 BBL methanol pumped 1 welll inspected,no exceptions noted ,/ SCANNED MAY 2 2 2015 Monday,May 04,2015 Page 1 of 1 . • • AOGCC Docket 10 -12 MIT Test Anniversary Dates Marathon Oil Company Request Dated May 26, 2010 ',4t ''11' t tt•l' Background Marathon requested changing the anniversary dates of eight Kenai Peninsula injection wells to allow the mechanical integrity test (MIT) required by regulation/order to be performed during summer months. Marathon proposed the wells be adjusted to show a September 1 anniversary date. Action Marathon's email request dated May 26, 2010 followed several telephone discussions between Kevin Skiba (Marathon; 907 - 283 -1371) and Jim Regg (AOGCC; 907 - 793 - 1236). Subsequent to the email request, telephone discussions were held on June 1, 2010, February 7, 2011 and February 8, 2011. Mr. Skiba was told that the following during discussions: - MIT due date can be changed by simply scheduling the test during the summer months; - Tests must be completed in advance of the next due date; - Make sure to give AOGCC Inspectors the required advance notice to allow for opportunity to witness; AOGCC witness is required to adjust the anniversary date; - Industry Guidance Bulletin 10 -002 provides details about testing injectors for mechanical integrity. Marathon was told the proposed September 1 anniversary date would not work for all wells since some MITs would be performed later than the currently required anniversary date. Resulting from the guidance provided to Marathon, the anniversary date for each of the eight injection wells has been changed based on successful, witnessed MITs as shown below: Well PTD MIT Completed Next MIT Due Beaver Creek Unit 2 1670260 5/4/2011 5/4/2015 Kenai Beluga Unit 23x -6 1841090 5/25/2011 5/25/2015 Kenai Unit 11 -17 1811760 5/3/2011 5/3/2013 Kenai Unit 12 -17 2080890 5/3/2011 5/3/2013 Kenai Unit 24 -07RD 2050990 5/3/2011 5/3/2015 Kenai Unit 31 -7X 2001480 5/25/2011 5/25/2015 Kenai Unit WD -1 1811070 5/3/2011 5/3/2015 Sterling Unit 43 -09 1630110 5/4/2011 5/4/2015 With MITs completed on these wells during May 2011, Docket 10 -12 can be closed. 4i 4k#1 .1?e-e; . James B. Regg ( 1 October 6, 2011 • • Colombie, Jody J (DOA) From: Regg, James B (DOA) Sent: Wednesday, May 26, 2010 11:25 AM To: Colombie, Jody J (DOA) Subject: FW: MIT tests anniversary date setup Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Skiba, Kevin J. [mailto:kskiba @marathonoil.com] Sent: Wednesday, May 26, 2010 11:10 AM To: Regg, James B (DOA) Subject: MIT tests anniversary date setup Jim, Below is a list of Marathon Alaska's injection well MIT dates. Well Last test Frequency Next test BC -2 1/15/08 4 -year 1/15/12 KBU 23x -6 6/4/07 4 -year 6/4/11 KU 11 -17 5/12/10 1 -year 5/12/11 KU12 -17 8/27/09 2 -year 8/27/11 KU 24 -7RD 2/12/10 2 -year 2/12/12 KU 31 -7x 8/8/07 4 -year 8/8/11 SU 43 -9 5/13/09 2 -year 5/13/11 WD -1 5/12/10 4 -years 5/12/14 As per our telephone conversation, we would like to set up an anniversary date for the MIT tests on these wells. As stated, the anniversary date would allow us to complete the MIT tests in the summer months without having the forward movement affect on the test dates. With that said, we are interested in a September 1 date as the anniversary date. Please let me know if you need any additional information concerning this request. Thanks again, Kevin Skiba Regulatory Compliance Representative Marathon Alaska Production LLC 1 Office (907) 283 -1371 • • Cell (907) 394 -1880 Fax (907) 283 -1350 2 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 08, 2011 TO: Jim Regg k P.I. Supervisor \� el b(1, SUBJECT: Mechanical Integrity Tests (l MARATHON OIL CO 23X -06 FROM: Matt Herrera KENAI BELUGA UNIT 23X -06 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: KENAI BELUGA UNIT 23X -06 API Well Number: 50- 133 - 20371 -00 -00 Inspector Name: Matt Herrera Insp Num: mitMFH110608062119 Permit Number: 184 -109 -0 Inspection Date: 5/25/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 23X -06 Type Inj. G 'T TVD 3499 ' IA 0 1600 1580 1570 - P.T.DI 1841090 TypeTest SPT Test psi 1500 - i - OA 20 22 22 22 Interval 4YRTST _ P/F P _ Tubing 390 390 390 390 Notes: G us SkOt 12, %rTet Ber ptta4AC6 * f , JUN 1 3 2,011 Wednesday, June 08, 2011 Page 1 of 1 . . 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 3 1- 7X (' I/l ?fi\~~q~ SCANNED JUL 2 7 2007 . . ¿ M.) Marathon MARATHON Oil Company Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 RECEIVED July 13, 2007 JUL 1 7 Z007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 Oil ,"9. Gas Cons, COOlmission Anchorage Reference: 10-404 Sundry Report for permit 184-109 Field: Kenai Gas Field Well: KBU 23x-6 &;ANNED JUL 113 2007 Dear Mr. Maunder: Enclosed please find a 10-404 Sundry Report for Kenai Gas Field well KBU 23x-6 and associated attachments. This well was previously completed as a dual producer. The dual tubing strings were removed to 4,988' MD. The Beluga perforations were isolated with cement. A 5-1/2" liner was run and cemented across the Sterling Pool 6 perforations at 4,829' - 4,906' KB to approximately 3,735'KB. A 5-1/2" tubing tie-back string was run from the 5-1/2" liner top packer to surface. The Sterling Pool 6 interval was reperforated through the 5-1/2" liner to allow for Pool 6 gas production and gas injection. Please contact if you have any questions or need additional information. I can be reached at (907) 283-1371 or klskiba@marathonoil.com. Sincerely, ~ J' 0~ Kevin J. Skiba Production Technician Enclosures: 10-404 Sundry Report Well Schematic Operations Summary cc: Houston Well File Kenai Well File KJS KDW ~ . STATE OF ALASKA . -?/9t:J? ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED JUL 1 7 2007 qiaska Oil & Gas Cons. Cammission 1. Operations Abandon U RepairWell U Plug Perforations ~ Stimulate U Other U AnchOrage Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool D WaiverD Time Extension D Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Oil Company Development 0 Exploratory D 184-109 r 3. Address: Stratigraphic D ServiceD 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20371 r 7. KB Elevation (ft): 9. Well Name and Number: 0' KBU 23x-6 / 8. Property Designation: 10. Field/Pool(s): A - 028142 / Kenai Gas Field I Beluaa Pool . 11. Present Well Condition Summary: Total Depth measured 6,950' . feet Plugs (measured) Cast Iron CementD Retainer @4,975' true vertical 6,440' feet Junk (measured) NA Effective Depth measured 4,988' feet true vertical 4,609' feet Casing Length Size MD TVD Burst Collapse Structural 126' 20" 126' 126' 1,530 psi 520 psi Conductor Surface 2,532' 13-3/8" 2,532' 2,454' 3,090 psi 1,540 psi Intermediate Production 6,950' 9-5/8" 6,950' 6,447' 6,870 psi 4,750 psi Liner 1,200' 5-1/2" 4,952' 4,580' 7,740 psi 6,280 psi Perforation depth: Measured depth: 4,829' - 4,906' True Vertical depth: 4,455' - 4,526' Tubing: (size, grade, and measured depth) 5-1/2" 17 ppf L-80 3,735' Packers and SSSV (type and measured depth) Baker ZXP Liner Top Packer 3,735' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Cement Squeezed Intervals 5,112' - 5,545' Treatment descriptions including volumes used and final pressure: RBDMS BFL JUL 1 8 2D07 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA 2,700 77 psi Subsequent to operation: NA 3,950 65 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory D Development D Service 0 Daily Report of Well Operations X 16. Well Status after work: OilD Gas 0 WAG D GINJ 0 WINJ D WDSPL D 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 -087 Contact Kevin Skiba (907) 283-1371 Printed Name Ken D. Walsh Title Senior Production Engineer Signature r'~ .... h, '.' t¡ º~ Phone 0(907) 283-1311 Date -¡íI3/(Y1 ~"""~;,,ik)'-' "",,~.,,;:, ,"j\."j .0_ . ""» ,",~ Form 10-404 Revised 04/2006 0 RIG I N A L k'q h."'- ¿ -?1?¡6Ybmit Original Only Tubing 5-112" L-BO 917ppf Modified Sutress Im:! Bottom MD 0' 3,735' TVD 0' 3,499' Sterling Pool 6, 4,829' - 4,906' MD (3/13/02) 4-5/8" TCP guns, 5 spf (Reperforated) 4,829' - 4,906' MD (5/12/07) 3-3/8" 6 spf 5110' - 5112' (2/3/85) U-1: 5112'·5130' (3/27/07) U-2: 5153'·5165' (3/27/07) 5201' - 5204' (2/17/85) 5215' - 5221' (2/17/85) 5280' - 5301' (2/14/85) U-5: 5282' - 5303' (1/3101) U-7: 5398' 5430' (3/27107) U-9: 5520' - 5545' (3/27/07) 6696' - 6706' (2/9185) Drive Pipe 20" H-40 94 ppf Im:! Bottom MD 0' 126' TVD 0' 126' Surface Casing 13-318" !{-55 Im:! MD 0' TVD 0' 6B1ppf BTC ~ 2,532' 2,461' Cmt wi 1,900 saCKS Production Casin!! 9-5/8" N-80 Im:! MD 0' TVD 0' 407ppf BTC Bottom 6,950' 6,440' emt wi 3000 sacks 5-112" L-80 Im:! MD 3,752' TVD 3,514' 17 ppf BTC ~ 4,952' 4,580' Locator sub @ 4,985' Halliburton BWD Packer @ 4,988' USA . . Page 1 of 5 Marathon Oil Company Operations Summary Report Legal Well Name: KENAI BELUGA UNIT 23X-6 Common Well Name: KENAI BELUGA UNIT 23X-6 Event Name: CONVERSION Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date Ff(>m-T(> Hours Gode<IJ~Je >Phase 4/8/2007 12:00 - 06:00 18.00 RURD_ RIG_ MIRU 4/9/2007 06:00 - 13:30 7.50 RURD - RIG_ MIRU , 13:30 - 18:00 4.50 REPAIR RIG_ MIRU 18:00 - 06:00 12.00 RURD_ RIG_ MIRU 4/10/2007 06:00 - 09:00 3.00 RURD_ RIG_ MIRU 09:00 - 12:00 3.00 RURD_ RIG_ MIRU 12:00 - 18:00 i RURD_!RIG_ I RURDJRIG_ I i I ! I RURD I RIG MIRU -: - I I REPAIR I RIG_ RIGMOD 6.00 MIRU 18:00 - 00:00 6.00 MIRU 00:00 - 06:00 6.00 4/11/2007 06:00 - 12:00 6.00 12:00 - 18:00 6.00 I I REPAIR i RIG RIGMOD I - . i I Start: 4/1/2007 Rig Release: 3/15/2002 Rig Number: 1 Spud Date: 3/8/2002 End: Group: Description of Operations Move In GD-1 Set gen,boiler and water tank ( remove generator i and prep for shipping to NC. set sub and mud boat. Scope up sub I set carrier.and cuttings tank. RlU camp units and electrical and water lines. Set shop and parts house. Run service lines Electrical,steam air and water lines. Pull pits together,Set up camp,change house. Set hand rails on pump, pit rooms.Start rig ,gen.,test run back up gen. Level carrier and turnbuckle down. ( Note: all permit loads moved from NS-3 to KBU23X6 ) Cont R/U GD-1. Crane fuel tank, stairways to rig floor ,House for board. Set Gray iron. Change out oil coolers ( htd.) Crane And Attempt to set dog house. Suspend crane operations due to high winds 24m ph gusts to 30mph At 1330hrs. Continue to replace Hydraulic oil coolers. R/U pits Remove Mirror PJSM; untie lines and cables from derrick and landings and carrier install derrick house. Crane work set fuel tank ,set stairs and landings,set up grey iron Welder repair ladder on fuel tank. Repair handrails on stairs, weld eyes on landing. Lowered windwalls, set in cuttings tank. PJSM;Rig up with crane,front windwalls on sub base Rig up trip tank,bumper hose to mud pumps,mud pump lines between pumps and pits.Put up servo lines,air,steam,put up lights,while putting cooling tower. PJSM;Raise mast,set cooling tower in place,roof,and winterize Rig up walkway cable between pump and gen. set,Pull wireing and plug in,pumps,pits,carrier,change out #2 pump pop off. Stage top drive to change out gooseneck PJSM;Crane up dog house and choke house,stairs,back landing windwalls,and panic line. R/U service lines. PJSM;Prep and scope up derrick, secure guide lines. Fix tugger control handle. Wire in cooling towers. Fix gaitronics in pits. Pull wires for choke and dog house to carrier. PJSM;Check and bolt windwalls,install cylinder tarps on telescope jack over floor,flop floor plate,finish hooking up gaitronics to camp install bows on carrier and cover,trouble shoot and repair camp gen. charging problem,install brake to rig floor,work on top drive actuater modifications and brackets,PJSM; Install beaver slide. PJSM;lnstall torque tube ,install stairs from BOP connex to rig floor complete drill console, plug in install killline,and choke line chute inventory pump parts,fuel equip.,water return,and air around rig, replace boiler fuellines,solenoid,and coil,start warming boiler, steam disc. install geronimo line, install torque "1" bar.Work on shaker beds PJSM;Adjust turn buckles on torque tube.Pick up top drive. Rig up service loop. Install brackets in pits.Adjust new mud saver valve, and actuater on top drive. Install service 100p.Purge air line C/O cylinder on top drive compensator. Install and calibrate probes on pvt system. R/U run hyd hoses on man riders. C/O savor sub on top drive. Mount guards and brackets for goose neck on top drive. Repair hydralic hoses on rig floor controls. continue to R/U man riders. Printed: 7/12/2007 5:15:49 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 4/11/2007 . . Page 2 of 5 Marathon Oil Company Operations Summary Report KENAI BELUGA UNIT 23X-6 KENAI BELUGA UNIT 23X-6 CONVERSION GLACIER DRILLING GLACIER DRILLING Code. J~~p Phase ICoâe 4.00 REPAIR I RIG RIGMOD I - I i i i 18:00 - 22:00 Start: 4/1/2007 Rig Release: 3/15/2002 Rig Number: 1 Spud Date: 3/8/2002 End: Group: Description of Operations PJSM;lnstall bales,Reroute 37 pin from top drive.repair hyd. leak in drillers panel. Finish work on shakers,put 175 mesh screens on shaker and 210 mesh on #2 shaker.Preheat two vacum trucks of water and load out.Reroute air line to. Fill pits with 300 bbls. build 6% KCL brine. Work on heater core from cellar,change oil in top drive gear box.lnstall elavators.Change out red tugger cable. PJSM; Cut and slip drilling line PJSM; Rig up attempt to pump down Short String press to 500 psi. Pump 192 bbls.Down back side. Two bbls. minute. (Accept Rig At 0000 Hrs.) Nipple down tree. Nipple up BOP. PJSM; Remove single gate from stack. Set Spool 11"X 13 5/8". N/U bop stack. choke & kill lines. Install riser flow, and trip tank lines..R/U accumlator lines. C/O pipe rams to 2 3/8". Pull BPV and set TWC in 2 3/8" and 2 7/8" sides of tubing hanger. M/U test joint to test 2 3/8" side of hanger. PJSM: Test bope 250/2500psi. Test annular to 1500psi. Upper & Lower topdrive valves failed test. Drawdown test accululator 2:56min to recharge. AOGCC rep Lou Grimaldi wittnessed test. PJSM review procedures for changing out upper /Iower topdrive valves. Changeout upperllower topdrive valves. Permanently remove the hydraulic upper valve actuator. Replace hoses for the actuator for new "mud saver" valve. Retest valves to 250psi/2500psi. Open annulus - no pressure. Pull TWC from both tbg hangers. Observe well. 2-7/8" side went on vacuum. 2-3/8" full. Install BPV in 2-7/8" hanger close annulus. MU 3-1/2" EUE 8rd landing jt to 2-3/8" tbg. hanger (11 rds) wI side-entry sub and TIW valve. PJSM review plan forward and RU procedures and hazards for e-line eq. RU Expro equipment. PU 1-9/16" tbg puncher w/ 6 shots (.41" holes) over 2' interval. RIH. Tag at 4742' corrected. PU to put shot interval in middle of tbg joint f/4687'-4689'. Fire punch and tbg went on vacuum. Let well stabilize then POH. CBU Pump 8.7ppg 6% KCL brine down 2-3/8" tbg 200gpm I 1480psi. Took 65bbls to see returns. Returns 75% Start RU of Weatherford tools. i I 22:00 - 00:00 2.00 CUT ¡WIRE RIGMOD 00:00 - 03:30 3.50 CIRC CFLD XMBO -I I 03:30 - 06:00 2.50 NUND ¡TREE XMBO 4/12/2007 06:00 - 14:30 8.50 NUND IBOPE XMBO 4/13/2007 14:30 -15:30 15:30 - 16:30 16:30 - 21 :30 21 :30 - 21 :40 21 :40 - 00:45 00:45 - 01 :15 01:15 - 01:30 01 :30 - 01:45 01 :45 - 02:15 02:15 - 04:05 04:05 - 06:00 06:00 - 07:00 07:00 - 07:15 07:15 - 14:00 14:00 - 15:00 1.00 TEST _ BOPE 1.00 TEST I BOPE 5.00 TEST = I BOPE 0.17 SAFETYI DRIL 3.08 REPAIR I RIG_ i i I 0.50 PULL i EQIP -I 1 0.25 PULD_ EQIP 0.25 SAFETYiMTG_ 0.50 RURD : ELEC 1.83 RUNPU ELEC I 1.92 CIRC_ !MUD i - I i I 1.00 RURD I CSG 0.25 SAFETY I MTG_ 6.75 RUNPUUTBG I - i i I 1.00 REPAIR i EQIP ! 1.00 NUND i BOPE 1.00 RUNPULjTBG_ I 1.50 TEST ; BOPE -I XMBO XMBO XMBO XMBO XMBO XMBO CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL RU weatheford tubing tongs and elevators PJSM: hold safety meeting tubing handling and tong operations Pull 2 3/8" hanger mandrel and UD landing joint .poh with 2 3/8" hyd 511 tubing F-4838' and UD Total of 155jts UD. Hole took approx 50bbls/hr to fill. Drill holesin last three Jts for trapped pressure. Found Rags blocking lower perfs. Complete installation of electrical feeds to rental generator. Repair flow line. Remove 2 3/8" rams and install 2 7/8" rams. Install 2 3/8 tubing hanger mandrel and set TWC in 2 3/8 and 2718 side ofTbg. hanger. M/U test joint and test 2 7/8" rams 250/ 2000psi Printed: 7/12/2007 5:15:49 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . Page 3 of 5 Marathon Oil Company Operations Summary Report KENAI BELUGA UNIT 23X-6 KENAI BELUGA UNIT 23X-6 CONVERSION GLACIER DRILLING GLACIER DRILLING Start: 4/1/2007 Rig Release: 3/15/2002 Rig Number: 1 Spud Date: 3/8/2002 End: Group: 19:30 - 19:45 119:45 - 20:10 120:10 - 22:15 122:15 - 00:15 00:15 - 06:00 4/14/2007 I i 06:00 - 07:00 07:00 - 07:30 07:30 - 08:30 108:30 - 09:30 09:30 - 10:30 10:30 - 12:30 12:30 - 13:45 113:45 - 20:10 20:10-21:00 21 :00 - 00:00 4/15/2007 00:00 - 03:30 03:30 - 04:00 04:00 - 05:45 05:45 - 06:00 06:00 - 06:20 06:20 - 07:30 07:30 - 09:00 09:00 - 10:00 10:00 - 10:30 10:30 - 11 :00 11 :00 - 13:45 13:45 - 14:30 14:30 - 16:00 1.00 RUNPU TBG_ 0.251 SAFETY I DRIL 0.42 RURD I ELEC 2.08 RUNPUY ELEC CMPPUL CMPPUL CMPPUL , i I 2.00 CIRC_I CFLD i CMPPUL 5.75 PULD_ TBG_ CMPPUL 1.00 RUNPU TBG_ CMPPUL 0.50 RURD_ CSG_ 1.00 TEST BOPE 1.00 REPAIR RIG_ 1.00 RURD_ RIG_ 2.00 TEST _ BOPE CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL 1.25 TRIP _ DP _ CMPPUL 6.42 PULD_ DP _ CMPPUL 0.83 CIRC_ CFLD , \ ! CMPPUL I CMPPUL I I 3.00 CIRC_ CFLD i 3.50 TRIP _ I DP _ Ii CMPPUL 0.50 TRIP _ I BHA_ i CMPPUL 1.75 RURD_ICSG_ iPR1CSG 0.25 SAFETY MTG IPR1CSG 0.33 SAFETY DRIL PR1CSG 1.17 RUN_ CSG_ IpR1CSG I 1.50 RUN_ CSG_ IPR1CSG 1.00 RURD_ CSG_ ¡PR1CSG 0.50 RUN jCSG IPR1CSG 0.50 RURD¡CSG - !PR1CSG 2.75 TRIP -=-! DP ~ I PR1CSG 0.75 CIRC_ jCFLD IPR1CSG I 1.50 SETRELlPKR_ jPR1CSG I Pull TWC and 23/8" mandrel. RlU 3 1/2" landing joint safety valve and lubricator. MU to 2 7/8" side of tubing hanger 11 turns. PJSM review plan forward and hazards for RU of e-line equipment and PU jet cutting tools. RU e-line equipment. PU on 2-7/8" tbg to 50k set slips and secure. RIH with 2.25" Expro Specialty jet cutter and tag at 4963' corrected. Position cutter at 4961' I which is 7' below top of 1 st full tbg jt above packer and shot. Good surface indication shot fired. No indication on pipe jump. POH with tools and RD lubricator. PU on tbg and see separation at 65k. Pump 77 bbls 6% KCL brine then had returns. SD pump. Observe well - static. LD TIW, landing jt, "parent bore" tbg hanger, and 2 jts tbg. Pump 41 bbls of CaC03 SafeCarb10 mixed at 100ppb followd by 25 bbls KCL brine. LD 2-7/8" 6.5# eue tbg. Hole taking about 2bbls hr over calculated displacement. Continue pulling LD 2-7/8" tbg and blast jts. total 152 jts, 5 blast jts and assorted pups.. Blast jt # 4 had large wash out! Tubing cut joint was Clean. Fluid loss to hole 2bbls per hr. RID Weatherford tubing tongs and tools C/O pipe rams f-2 7/8" to 2 -7/8 X 5 "varables. Work on man riders Spool Line and RlU RlU rig floor&drillpipe handling tools M/U testjt. set test plug. Test 5" Pipe rams 250/2000. Test Dart and floor safety valve. Pull test plug, set wear bushing RID test joint. M/U 7 5/8 mill,boot basket bit sub and x-over. P/U & Drift 5" drillpipe and RIH. Fluid loss to hole 0.5 bbl per hr.Tagged at 4908'. PU to 4900'. Circulate with increasing rates f/ 2.5bpm to 5.8bpm 100% returns. Wash down quickly to 2-7/8" tbg stub tagging at 4965' DP measurement. Circulate bottoms-up seeing sand and CaC03. (approx 10 bbls of sand/CaC03) Pump hi-vis sweep around until hole clean. Total bbls lost to hole while circulating <10bbls. TOH and slm. 10' discrepancy. Will need to strap while RIH w/ liner. LD BHA Change out to long bales on topdrive. RU Weatherford tongs, elevators. PJSM review plan forward and hazards to run 5-1/2" liner. PJSM: review plan forward and hazards to run 5-1/2" liner. M/U Shoe jt Ck floats plu insert seal sub ,ecp packer, and es cementer rih Run 28jts 51/2" 17# L-80 BTC liner. C/O bails R/U 5" drillpipe Tools P/U M/U Baker 7x 9 5/8 Flexlock Hyd Hanger RID Csg tools RlU 5" dp handling tools RIH 5 1/2 "liner W/ 5" drillpipe Tag 2-7/8" tubing stub at 4953'. space out with 5' drillpipe pup placing shoe at 4952'. Circ at 4952' 4bbl min Hold PJSM hazards of cementing and high pressure. Drop 1 3/4" rubber coated steel ball. M/U cement head wait 25min. for Printed: 7/12/2007 5:15:49 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . Marathon Oil Company Operations Summary Report KENAI BELUGA UNIT 23X-6 KENAI BELUGA UNIT 23X-6 CONVERSION GLACIER DRILLING GLACIER DRILLING .§~þ Phase ¢q~e 4/15/2007 14:30 - 16:00 16:00 - 17:00 17:00 - 18:00 18:00 - 20:00 20:00 - 20:30 20:30 - 21 :00 21 :00 - 00:00 00:00 - 01 :30 01:30 - 04:10 4/16/2007 04:10 - 04:50 04:50 - 06:00 06:00 - 07:00 07:00 - 07:30 07:30 - 10:30 10:30 - 13:15 13:15 - 19:40 19:40 - 21 :20 21 :20 - 21 :35 1.50 SETREL PKR_ PR1CSG 1.00 PUMP _ CMT_ PR1CSG 1.00 CIRC_ CFLD PR1CSG 2.00 TRIP _ DP_ 0.50 SERVIC RIG_ 0.50 SERVIC RIG_ 3.00 WAlTON CMT_ 1.50 WAITON CMT_ 2.67 TRIP _ DP_ 0.67 CIRC_ CFLD 1.17 TRIP _ DP_ 1.00 TRIP _ DP_ 0.50 PULD_ PKR_ 3.00 TRIP _ DP 2.75 SETREL PKR_ PR1CSG PR1CSG PR1CSG PR1CSG PR1CSG PR1CSG PR1CSG PR1CSG PR1CSG PR1CSG PR1CSG PR1CSG 6.42 PULD_ DP _ PR1CSG 1.67 PULD_ BHA_ PR1CSG 0.25 SAFETY MTG_ PR1CSG Page 4 pf 5 Start: 4/1/2007 Rig Release: 3/15/2002 Rig Number: 1 Spud Date: 3/8/2002 End: Group: ball to seat in packer. Pressure up to 500psi hold for 5min increase to 750/5min, 900/3min 1150/3min 1350/3min Bleed down to 750/3min 500/3min. total of 2 bbls pumped with 1 3/4 bbls returned. 1/4 bbl in I tlexlock hanger. Confirmed I ECP packer set. Bleed pressure down to O. Pressure up to 2950psi I pressure dropped to 250psi with 0 returns. Confirmed ES cementer opened. Circ 10 min. Pump 5 bbls H20 ahead to fill lines. Test lines to 4500psi. Mix and pump 145 sks 13.5ppg cement w/ additives = 47.2 bbls. Shutdown. Launch DP wiper plug followed by 64bbls KCL brine at 4-5 bpm slow to 2bpm pick-up liner wiper plug at 65.4 bbls. Continue pumping 4-5 bpm. Slow down to 2bpm at 87.5bbls Plug down. Increase pressure to 1150psi and closed ES cementer. Pressure up to 1650psi and held f/5 min. Bleed pressure off- no flow back. CIP at 1630 hrs. RD cementhead. MU 1 stand DP. Setdown on line hanger. Rotate 5 turns to right then 7 more turns right. Pressure up to 500psi with rig pumps. Unsting from seal assembly. Pressure dropped to 250 psi inc rate to 7bpm. Circulate out excess cement. Estimate 2 bbls cement to surface. Continue circ 2x bottoms up. TOH with DP and Baker Liner Hanger setting tool. MU Baker PBR polishing mill. RIH to 132'. Service rig. WOC PJSM. Load 5-1/2" csg to pipe racks, drift and tally. Clean mud pits. Build 250bbls new 8.7ppg 6% KCL brine. WOC. PJSM new crews. review plan forward. Finish tally on 5-1/2" csg. TIH slowly with Baker PBR polishing mill. Tagged bottom of PBR at 3769.18' Pull out of PBR. Pump 1 bpm rotate 30 rpm's trq 3.2k work back to bottom PBR. Pull back out. CBU Continue TOH w/ 5" DP and PBR polish mill. M/U Baker Liner top Packer rih RIH w/ Liner Top packer on / 5" drillpipe to 3735' PJSM: R/U lines to BJ. Sting into PBR with pump running 50psi increase at 3744' Confirmed entry into BPR . Pressure test Linertop to 1500psi /10min .Drop 1 1/2 brass ball wait 20m in. Switch to BJ and pressure up to 1750 and set zxp packer. inc psi to 2500 to set pack off. Bleed off psi, and put 15 rh turns in drill pipe P/U to 100k, 10 k over up wt. then 11 Ok, 120k, 135k, 150k. Unable to release from packer. Work pipe down and put 4 more RH turns in drill string Torque increased to 17k. No Success. Pressure up on backside to 1500psi and attempt to set down on packer, P/U with no success. Pressure up to 3150 psi blow ballseat. Packer released. Set down 20k then p/u to 90k confirm packer released EXP PBR top at 3744.17 PJSM; POH LID drillpipe F-3745'. Clear derrick and LDDP. PU 10 jts 5" HWDP and Howco SSV/RTTS. RIH and set top SSV at 56'KB. LD setting tool. PJSM: review plan forward to ND BOP"s identify hazards and Printed: 7/12/2007 5:15:49 PM . . Page 50f5 Marathon Oil Company Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KENAI BELUGA UNIT 23X-6 KENAI BELUGA UNIT 23X-6 CONVERSION GLACIER DRILLING GLACIER DRILLING c?8dbe Phase 0.25 SAFETYl MTG_ 2.92 NUND BOPE 3.50 NUND WLHD 4/16/2007 21 :20 - 21 :35 21 :35 - 00:30 00:30 - 04:00 PR1CSG PR1CSG PR1CSG 04:00 - 06:00 2.00 NUND BOPE PR1CSG 4/17/2007 06:00 - 07:00 1.00 TEST_ BOPE PR1CSG I 1.00 SETRELi PKR_ PR1CSG 107:00 - 08:00 08:00 - 11 :00 3.00 RURD_i RIG_ PR1TIE 11 :00 - 15:30 4.'" RUNPuiTBG- PR1TIE 15:30 - 16:30 1.00 RUNPU TBG_ PR1TIE I 16:30 -17:30 1.00 CIRC_ I CFLD PR1TIE 1 17:30 - 19:00 1.50 TEST CSG_ PR1TIE '19:00 - 19:15 0.25 SAFETY MTG - PR1TIE 19:15 - 00:00 4.75 NUND BOPE PR1T1E 00:00 - 03:00 3.00 NUND WLHD PR1TIE 03:00 - 06:00 3.00 RURD_10THR RDMO 4/18/2007 06:00 - 22:00 16.00 RURD I RIG - RDMO -¡ I I 22:00 - 06:00 8.00 RURD_ RIG - RDMO I Start: 4/1/2007 Rig Release: 3/15/2002 Rig Number: 1 Spud Date: 3/8/2002 End: Group: Description of Operations procedures. ND BOP's. Test secondary pack-off seals on 9-5/8" - failed. ND 11"-5M dual tbg spool and 13-5/8"-3M x 11 "-5M inter csg spool. Inspect 9-5/8" csg stub. Stub is 4" re-cut to 2-3/4". ID slips as Type CA. Install new 13-5/8"-3M x 11 "-5M csg spool and test to 2200psi for 15 min. Install test plug. NU 11"-5M x 13-5/8"-5M DSA and 13-5/8"-5M 24" spacer spool. NU BOP stack, choke/kill lines. Test breaks on BOP stack to 250/2000 10min ( Good) pull test plug UD test jt. Pull howco SSV/ RTTS & UD . UO 10jts hwdp RID all 5" drillpipe handling tools. Tongs and spinners. C/O i Bails and elevators. RlU Weatherford tubing tongs and elevators P/U BOT Seal assy M/U and run 5.5" L-80 17# btc tubing. Total of 98jts to 3751.77' Note: Lay down bent jt Tag up at 3744' and sting into PBR 16' set down on locator test seal assy to 1500psi . P/U to 3720' Circ and displace back annulus and 5.5 tubing W/ 280bb18.7kcl w/ conqor A303 Test annulus 250/1500 30min Test tubing 250/1500 30min (good) PJSM review plan forward and safety issues for NO BOPE, setting slips. ND BOP stack and lift. Install 5-1/2" x 11' slips set w/ 74k weight. Make rough cut on 5-1/2" tbg and LD. Continue to ND stack and move out of cellar. Cleanout mud pits and cuttings tank. Note: Seal Assy l' stick up from Locator. Make final cut on 5-1/2" and dress. Install pack-off bushing. NU rebuilt 11"-5M x 11"-5M tbg head. Test seal area 5000psi f/10 min - good. PJSM.. Flush lines and pits RID and UD top drive. Continue RD Torque tube, pits, and Service lines. Blow down boiler RID beaver slide & cat walk. Remove cover from carrier. RID back windwalls from rig floor. RID board. Scope down mast. Remove berm. PJSM Crane safety. Crane down dog and choke house. Remove stair ways. RID down gray iron. PU location. Clean-up rig. Make small repairs. Organize equipment for trucking. Rig released at 0600 hr 4-18-2007 Move to KBU 12-5 Printed: 7/12/2007 5:15:49 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . Marathon Oil Company Page 1 of 1 Operations Summary Report KENAI BELUGA UNIT 23X-6 KENAI BELUGA UNIT 23X-6 CONVERSION GLACIER DRILLING GLACIER DRILLING 5/9/2007 5/10/2007 5/11/2007 5/12/2007 5/13/2007 07:00 - 08:30 08:30 - 15:45 15:45 - 17:00 17:00 - 20:30 07:00 - 08:00 08:00 - 12:15 12:15 -12:25 12:25 - 14:00 14:00 - 21:15 21:15 - 22:00 - 23:00 10:00 - 11 :00 11 :00 - 13:30 13:30 - 13:45 13:45 - 15:00 15:00 -18:00 18:00 - 19:30 19:30-21:00 09:00 - 10:00 10:00 - 14:00 07:00 - 07:45 07:45 - 10:15 10:15 - 12:00 12:00 - 12:20 12:20 - 14:15 14:15 -15:15 15:15-17:00 , 1.50 SAFETY i MTG_ 7.25 RURD_ COIL 1.251 TEST _ BOPE 3.50 I RURD_ COIL 1.00 SAFETY MTG_ 4.25 RURD COIL , 0.17 TEST 1 BOPE 1.581 RUNPU COIL 7.25' DRILL_ CMT_ I 0.75 RUNPULJ COIL 1.00 RURD_iCOIL 1.00 SAFETY MTG_ 2.50 RURD_ COIL 0.25 TEST _ BOPE 1.25 RUNPUU COIL 3.00 DRILL_ I CMT_ , 1.50 RUNPU~COIL 1.50 RURD_ COIL 1.00 SAFETY MTG_ 4.00 RURD COIL 0.751 SAFETY MTG_ 2.50 RURD_ ELEC 1.75 LOG_ CSG_ 0.33 SAFETyIMTG_ 1.92 PERF _iCSG_ I 1.00 PERF -ICSG- 1.75 RURD_I ELEC I Phase i CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT CLNOUT Start: Rig Release: Rig Number: Spud Date: 3/8/2002 End: Group: 5/8/2007 3/15/2002 1 Description of Operations On location. sign in, issue permit, hold safety meeting. RU injector. PU stinger for cement retainer and stab on well. Perform full BOP test 200 / 3000 psi. Secure location and leave for night. On location. sign in, issue permit, hold safety meeting. RU lubricator and tools. Fill CT. PU 2-7/8" mud motor and 4.75" 6 bladed cement mill. Perform shell test 200 / 3000 psi. RIHCT. Tag cement at 4750 (corrected). Drill cement to 4777 and stall on ES cementer. Drill ES cementer and drill through casing packer and ball and seat. Continue drilling to 4825'. Very slow progress. Pull out of hole. Secure location and leave for night. On location. sign in, issue permit, hold safety meeting. RU lubricator and tools. Fill CT. PU 2-7/8" mud motor and 4.75" 4 '[ bladed cement mill. Perform shell test 200 / 3000 psi. iRIHCT. ITag cement at 4839 (corrected). Drill cement to 4940'. Well clear below 4915'. Pull out of hole. Drop circulating ball and purge CT while POH, OOH. Secure location and leave for night. On location. sign in, issue permit, hold safety meeting. RD and release CTU On location. sign in, issue permit, hold safety meeting. Spot and RU eline truck. Run GR / CCL correlation log from 9448' to 3700' and tie into open hole logs. Hold perforating satety meeting PU and RIH 3-3/8" 6 spf, 60 deg phased 41' gun and shoot 4865' - 4906'. POH PU and RIH 3-3/8" 6 spf, 60 deg phased 36' gun and shoot 4829' - 4965'. POH RD and release expro. Printed: 7/12/2007 5:16:43 PM MEMORANDUM . TO: ~~S~:;~isor ~'Î f((;¡fD7 State of Alaska Alaska Oil and Gas Conservation commie DATE: Wednesday, June 20, 2007 SUBJECT: Mechanical Integrity Tests MARATHON OIL CO 23X-06 KENAI BELUGA UNIT 23X-06 Src: Inspector \0<\ ~/ \~ FROM: Jeff Jones Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv "íß/Z- Comm Well Name: KENAI BELUGA UNIT 23X-06 API Well Number: SO-I33-20371-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ070608092442 Permit Number: 184-109-0 Inspection Date: 6/4/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 23X-06 IType Inj. N TVD I 3753 IA I 0 i 1600 1580 1575 I I P.T.D 1841090 ITypeTest SPT Test psi I 1500 OA I 0 0 0 0 Interval INITAL P/F P v" Tubing I 120 130 130 130 Notes: 1 BBL water punped. This well was recently converted to a gas storage injector. s~ J\J\\\ 2 7 20D7 . . Wednesday, June 20, 2007 Page 1 of I Re: KBD 23X-6: Request to Change Rig BOP Test Pressure . . Ken, This confirms our discussion earlier this morning. Testing to 2000 psi is appropriate for the work conditions. A copy of this message should be available at the rig. Call or message with any questions. Tom Maunder, PE AOGCC SCANNED APR 1 7 2007 Walsh, Ken wrote, On 4/12/20079:51 AM: Tom, As we discussed this morning, Marathon is requesting that the AOGCC accept a change to the drilling rig BOP test pressure for the KBU 23X-6 workover. In my procedure that accompanied the Form 10-403 request #307-087, I mistakenly specified that the drilling rig BOP equipment should be tested to 250/4500 psi. This test pressure then was stipulated in the approval of the Form 10-403. Marathon is requesting that the test pressure be amended to 250/2000 psi. This pressure test will be below the 3000 psi WP wellhead flange connection and well above the estimated reservoir pressure of 130 psig for the Sterling Pool 6 interval open in the well. Marathon will plan to maintain the 250/4500 psi test pressure for the coiled tubing BOP equipment to be used during this workover. Please send an email confirmation with your consent to the proposed change. Thanks, Ken Ken D. Walsh Senior Production Engineer Marathon Oil Company-Alaska Asset Team 907-283-1311 (office) 907 -394-3060 (cell) 1 of 1 4/13/20072:46 PM . . SARAH PALIN, GOVERNOR AI,ASHA OIL AND GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ken Walsh Senior Production Engineer Marathon Oil Company PO Box 1949 Kenai Alaska 99611-1949 ~\Dq \C6~ Re: Kenai Gas Field, Sterling/Beluga Gas Pool, KBU 23X-6 Sundry Number: 307-087 SCANNED MAR 1 6 2007 Dear Mr. Walsh: 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, DATED this I!j-day of March, 2007 Encl. or.s Abandon 0 Alter casing0 Change approved program 0 2. Operator Name: Marathon Oil COmDanv 1. Type of Request: )/'" 2.tv1 STATEOFALASgQ- "I4-.4>Î~? :~~:¡Vr:::D ALASKA OIL AND GAS CONSERVATION COMMI"N ~ I,,> .. 9 2007 APPLICATION FOR SUNDRY APPROVALS Alaska ail&: Gas Co C . 3 j(/\r r,....., Anch'---~s ommlSs;on -,..../ - I 20 AAC 25.280 ",ran" Suspend 0 ( Operational shutdown 0 Perforate 0 Waiver 0 - OtherD Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 .4/ A 4. Current Well Class: 5. Permit to Drill Number: ~J1'J Development 0 Exploratory 0 /84-109/ "1'" Stratigraphic 0 Service 0 6. API Number: 3. Address: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20371 / 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: 8. Well Name and Number: A- 028142 No 0 KBU 23X-6/ 10. KB Elevation (ft): 11. Field/Pool(s): ¡ 0' Kenai Gas Field I Sterling and Beluga Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 6,848' 6,346' Plugs (measured): Cement 6848' Csg Patch 4200-4303' Junk (measured): Remnants of drilled Otis Pkr @ 6781' 12. Total Depth MD (ft): 6,950' Total Depth TVD (ft): 6,440' Casing Structu ral Conductor Surface Intermediate Production Liner Length 126' Size 20" MD TVD 126' 126' 2,532' 2,454' 6,950' 6,447' Tubing Size: Tubing Grade: Burst Collapse 1 ,530 psi 520 psi 3,090 psi 1 ,540 psi 6,870 psi 4,750 psi 2,532' 13-3/8" 6,950' 9-5/8" 13. Attachments: Description Summary of Proposal Detailed Operations Program 0 BOP Sketch 15. Estimated Date for o o 2-7/8" 6.4 ppf 3/8" 4.7 ppf Packers and SSSV MD (ft): 4988' 14. Well Class after proposed work: t.f?"""'" 1\7 / Exploratory 0 Development ~ Service 'EiI' 16. Well ~tatus after proposed work: ... Oil 0 Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ 0 2- L-80 Tubing MD (ft): L- 5100' 4838' Perforation Depth MD (ft): 4829-4906' Sterling Pool 6 5112-6810' Beluga (gross) Packers and SSSV Type: Halliburton BWD Perforation Depth TVD (ft): 4455-4525' Sterling Pool 6 4713-6311' Beluga (gross) 80 Commencing Operations: 17. Verbal Approval: Commission Representative: 3/13/2007 Abandoned o o .lGwv\ Date:·~ , ~-()"\ ~"Þ. p t ~,~«:-~"V~:l 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Ken D. Walsh Title Senior Production Engineer Signature /J J/ ¡1, D ~ _. //... Phone Date f/ I( '--r-- 1\0<..'<' p. t.J (907) 283-1311 3/8/2007 COMMISSION USE ONLY WDSPL Kevin Skiba (907) 283-1371 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: (3¡) 1 - 0 8 7 Plug Integrity 0 BOP Test "R Mechanical Integrity Test ~ Location Clearance 0 Other: ~'\\«\'\~ \SCJ~\-1t.s\ ~()OO~\ Q'\5\(-'(h\~\)~ \-<c~\~ l\ÇOO~~ ~~C'L~~":~ \C ~\\:) '\ N-.~~~ ~~\_~\~~ \>~c::.,~ \~~~<:...\\:C~. :~~~~F~ R~";,~ ~~ ,Øf/J¡MISSIONER :::~~~: Bf~:A;~::_d r t-orm 1 U-4U;J Hevlsea l- J f' ,...., 1 Ì\ 1\ j t)UDmlt In uup"cate . . ~M.) Marathon MARATHON Oil Company Alaska Asset Team Northern Business Unit P.O. Box 1949 Kenai, AK 99611-1949 Telephone 907/283-1311 Fax 907/283-1350 March 8, 2007 RECEIVED MAR 0 9 2007 Alaska Oil & Gas Cons. COfJ1mIølon Anchorage Tom Maunder AOGCC 333 West ¡th Ave Suite 100 Anchorage, AK 99501 Reference: Form 10-403 Sundry Request Field: Kenai Gas Field Well: KBU 23X-6 Dear Mr. Maunder: Attached and submitted for your review and approval is the Form 10-403 to workover this dual Beluga and Sterling Pool 6 producing gas well. The intent of the workover is to isolate the watered out Beluga perforations with cement, pull the dual tubing strings, and run a 5-1/2" liner and tubing tie-back string within the 9-5/8" current production casing. Marathon's goal is to be able to produce gas from the Sterling Pool 6 interval in this well when necessary and to be able to inject gas into the same interval for gas storage when surplus is available. Also attached for your review and record is the proposed workover procedure and the wellbore schematics of the current condition of the well and the proposed final configuration. Marathon would like to begin work to isolate the Beluga perforations on March 13, 2007, and continue work to prepare the wellbore prior to moving in the drilling rig around March 26, 2007. If you would like any other information, please contact me at 283-1311 or kdwalsh @ marathonoil.com. Sincerely, I~h.w~ Ken D. Walsh Senior Production Engineer Enclosures: 10-403 Sundry Well Schematics (2) Workover Procedure cc: AOGCC Houston Well File Kenai Well File KDW API: 50-133-20371 AOGCC: 84-109 RT-THF: 19.80' 291'FSL,1208'FVVL Sec. 6, T4N. R11VV, S.M. Tree Cxn (SS & LS): 3-1/2" EUE 8rd 5-bolt crescent flange Lonq Strinq: 2-7/8", 6.4 ppf, L-80, IBT-M tubing to 5100'. Steel blast joint: 4821' - 4910' Sidepocket mandrel (SF02) @ 4941' Loaded with 1.5" circulation valve X-Nipple (ID = 2.313") @ 4984' with PX prong and blanking plug installed. Fill tagged with slickline at 4892' KB. Locator sub @ 4985' Seal assembly: 4" OD x 8.5' Halliburton BVVD Packer @ 4988' X-Nipple (10 = 2.313") @ 5034' X-Nipple (ID = 2.313") @ 5066' VVireline Re-entry Guide @ 5100' inactive Perfs: Isolated (Casinq Patch): Pool 5.1, 4214' - 4275' Squeeze perfs: 3784' - 3786' (2/1/85) , 4278' - 4280' (1/31/85) 5110' - 5112' (2/3/85) 5201' - 5204' (2/17/85) 5215' - 5221' (2/17/85) 5280' - 5301' (2/14/85) 6696' - 6706' (2/9/85) VVell Name & Number: County or Parish: Angle/P;;¡rfs 30 deg. Date Completed: Prepared By: KBU 23x-6 J 1 Drive Pipe: 20", 94 ppf, H-40 driven to 126' Surface Casinq: 13-3/8", 61ppf, K-55, BTC to 2532' Cmt w/1900 sks Casinq Patch: 4200' - 4303' Owen Oil Tool, 10 = 7.75" Isolating B-3 perfs (4214' - 4275') Short Strinq: 2-3/8", 4.7 ppf, L-80, Hydril 511 tubing to 4838' XN-Nipple (ID = 1.875", no-go = 1.791") @ 4836' Bull Nose Re-entry Guide @ 4838' Active Perfs: Shortstrinq: Pool 6, 4829' - 4906'MD (4455' - 4525'TVD) 4-5/8" TCP guns, 5 spf, 3/13/02 Lonqstrinq (Beluga) (4711'-6311' TVD) U-1: 5112' - 5130' (6 spf, 4/17/02) U-2: 5153' - 5165' (6 spf, 4/17/02) U-5: 5282' - 5303' (1/3/01) U-7: 5398' - 5430' (6 spf, 4/17/02) U-9: 5520' - 5545' (2/12/85) L-3: 6788' - 6810' (covered w/ junk) Junk: Remnant of Otis VVD-1 packer @ 6781' on top of fill (6/01) Production Casinq: 9-5/8", 47 ppf, N-80, BTC to 6950' Cmt w/ 3000 sks KBU 23x-6 Kenai State/Provo Gary Eller Last Revision Date: Kenai Gas Field, Pad 14-6 Country: KOP TVD 18-Apr-02 API: 50-133-20371 AOGCC: 84- 109 RT-THF: 19.80' 291' FSL, 1208' FVVL Sec. 6, T4N, RiiVV, S.M. Tree Cxn (SS & LS): 3-1/2" EUE 8rd 5-bol! crescent flange 2-7/8", 6.4 ppf, L-80, IBT- Locator sub @ 4985' Seal assembly: 4" 00 x 8.5' Halliburton BVVO Packer @ 4988' X-Nippie (10 = 2.313") @ 5034' X-Nipple (10 2.313") @ 5066' Inactive Perfs: Pool 5.1, 4214' 4275' erfs: 3784' - 3786' (2/1/85) 4278' - 4280' (1/31/85) 5110' - 5112' (2/3/85) 5201' - 5204' (2/17/85) 5215' - 5221' (2/17/85) 5280' - 5301' (2/14/85) 6696' - 6706' (2/9/85) State/Provo Ken VValsh l 20",94 13-3/8",61 ppf, K-55, Active Perfs: Pool 6, 4829' - 4906'MO (4455'- 4c5/8" TCP guns, 5 spf, 3/13/02 Abandoned Beluga Perforations: (4711'-6311' TVD) U-1: 5112' - 5130' (6 spf, 4/17/02) U-2: 5153' - 5165' (6 spf, 4/17/02) U-5: 5282' - 5303' (1/3/01) U-7: 5398' - 5430' (6 spf, 4/17/02) U-9: 5520' - 5545' (2/12/85) L-3: 6788' - 6810' (covered w/ junk) Junk: Remnant of Otis VVD-1 packer @ 6781' on top of fill (6/01) 9-5/8",47 ppf, N-80, BTC to 6950' Cmt w/ 3000 sks Kenai Gas Field, Pad 14-6 Country: KOP TVD Last Revision Date: B-Mar-07 . . (lð~ Marathon Oil Company Alaska Asset Team KBU 23X-6 Workover Procedure Kenai Gas Field, Pad 14-6 WBS # RW.07.14789.CAP Objective: Abandon Beluga completion. Pull dual completion, add Pool 6 perforations,' and recomplete as an injector/producer in Pool 6. The new completion will allow for both gas storage injection and Pool 6 swing production as necessary. Specific well considerations include a 7.75" ill Owen Casing Patch set in the 9-5/8" casing at 4200- 4303' MD and holes in the steel blast joints run on the LS across the Pool 6 perfs at 4829- 4906' KB. See attached wellbore diagram to confirm minimum I.D.'s (1.791" in SS and 2.313" in LS). Pre-Rh~ Procedure: 1. Submit all Sundry Notices and obtain Reeulatory Aeency Approvals for work. 2. Work Permit and P.JSM - Contact Kenai Gas Field Office for work permit, hold PJSM's, review appropriate JSA's, and discuss safety and environmental concerns at least daily. Discuss shutting well in with KGF operator. 3. Tae fill in LS with slickline. MIRV Pollard Wireline to tag fill in the LS side. Fill out Safe Work Permit and hold PJSM. Spot equipment. MV and RIH with 2" OD drive down bailer to tag and recover a sample of fill from the LS. Attempt to bail fill from the LS above the plug and prong. 4. Temporarily isolate Pool 6 Perfs with X-link Polymer Plue. Shut in well per KGF operator instructions. Fill out Safe Work Permit and hold PJSM. Lay liner material. Spot fluid supply, flowback, and 50/50 methanol water tanks. Deliver manlift, two light plants, and MOC trailer. Fill supply tank with 6% KCL water. MIRV BJ Service pumping equipment to mix and pump a 20 bbl "Clean Plug" cross-linked polymer pill down the shortstring tubing to temporarily isolate the perforations from workover fluid and debris. Make pump line connections to the top of the tree on the SS side. Pressure test pump equipment and lines to 2000 psi. Open SS tree valves and pump 20 bbls of 100# Clean Plug pill and displace Clean Plug out the end of the 2-3/8" tubing with 18.7 bbls of 6% .KCL water. After allowing plug to gain full viscosity, attempt to bleed off gas pressure from SS tubing and annulus to verify that the Clean Plug is in place and holding. Fill tubing by 9-5/8" annulus with clean 6% KCL water by circulating down the SS tubing and up the LS túbing or 2-1116" annular valve. 5. Perform CT work to clean out fill in LS above PX plue - MIRV BJ CoilTech CTV with 1-3/4" OD coiled tubing and related equipment. Review and discuss specifics of BJ CoilTech procedure to clean out on top of plug. RV CT crescent-shaped flange . . connection, 3-1/16" 10M x 4-1116 5M DSA, Flow Cross, 4-1116" 5M x 4-1/16" 10M DSA, and 4-1116" Dual-Combi CT BOP. MU 1-3/4" dimple-on connector, double flapper check valve (DFCV), and 1-3/4" Vortex wash nozzle. RU flowback iron. PU injector head and lubricator. Test CT BOP and lubricator to 200/4500 psi with methanol water. Displace methanol water back to storage tank with 6% KCL water. RIH and wash to top of PX prong at 4984' KB with 6% KCL water. POOH with wash tool. LD lubricator and BHA. Standback CT injector head. 6. Pull PX pron!! and blankin!! plu!! from profile nipple in LS. MIRU Pollard Wireline.· MU crossover, pump-in tee, and wireline valve to top of BJ CoilTech BOP. MU 2.0" JDC Pulling tool on 1-112" slickline tool string. Install and test lubricator to 20012000 psig with methanol water. Bleed pressure off lubricator to tank. RIH to latch PX prong set in blanking plug at 4984' MD. POOH and LD prong. RIH with 2-1/2" GS Spear on slickline tool string. Latch, release, and POOH with PX blanking plug set in 2.313" ill X Profile nipple at 4984' MD. PU and RIH with 2.25" gauge ring to tag fill below the WLEG in theLS. RDMO Pollard Wireline. Note: If unable to pull prong or blanking plu~, make arrangements to pull them with coiled tubing. 7. Punch LS tubin!! below the Halliburton BWD Packer. MIRU Expro Wireline. Review explosive checklist. MU crossover, pump-in tee, and wireline valve to top of BJ CoilTech BOP. Go to radio silence. Arm 2' of 1-9/16" OD (1-11/16" OD swell) tubing punch loaded 0 deg phasing, and 4 SPF. MU magnetic de centralizer, tubing punch, PX-l firing head, and CCL on wireline. MU wireline lubricator, take to wellhead, and pressure test to 20012000 psig with methanol water. Bleed methanol water back to tank to release pressure. RIH with tubing punch and log CCL pass from just above WLEG to above the top of the blast joints at 4821' MD. RIH and punch the LS tubing about 5' below the bottom of the Halliburton BWD Packer. POOH and LD punch assembly. 8. Set Cast Iron Cement Retainer above BWD Packer in LS. MU Baker Oil Tools cast iron cement retainer (sized to be set in 2-7/8", 6.4 ppf tubing), Baker #5 setting tool, and CCL on Expro wireline. Pull into lubricator, take lubricator to wellhead on LS side, and pressure test to 20012000 psig with methanol water. Bleed methanol water back to tank. RIH in LS with cement retainer and set at about 4975' MD (just above the profile nipple located at 4984' MD). Make sure that the wireline is flagged with paint at the setting depth. PUH and then RIH to tag and verify cement retainer set properly. POOH with setting tool and CCL. RDMO Expro Wireline. 9. RIH with CT to stin!! into Cement Retainer and Cement Squeeze Belu!!a Perfs. Review and discuss specifics of CoilTech Procedure: Run 3 ~ P&A Production Casing Perforations. MU cement retainer stinger assembly to dimple-on connector on 1-3/4" OD CT. Add CT lubricator as needed to cover cement retainer stinger BHA. Take lubricator to wellhead and pressure test to 200/4500 psig with methanol water. Displace methanol water to storage tank with 6% KCL water. RIH pumping 6% KCL water at minimum rate to top of cement retainer CBU. Break circulation to ensure hole KBU 23X-6 Workover 3/9/2007 Conversion from Dual Beluga/Sterling Pool 6 to Sterling Pool 6 StoragelProducer Page 2 . . is full. Stab stinger into cement retainer. Establish and record injectivity with 6% KCL water per BJ CoilTech procedure. Batch mix 13.7 ppg cement volume based on slickline tag depth in Step #6 and hole volume to cement retainer. Pump 2 bbls fresh water lead, calculated cement volume, and 2 bbls fresh water tail. Displace cement and fresh water with 26.3 bbls of 6% KCL water to abandon six Beluga interval perforations ranging from 6810' to 5112'. Sting out of cement ~etainer when tail of cement is within 500' of the end of the CT. Circulate bottoms up three times with 6% KCL water until returns are free of cement. Stop pumping and POOH with CT and cement stinger. Freeze protect and purge the CT by blowing dry with nitrogen. RDMO CT unit and equipment. 10. Cut Lonestrine and circulate kill fluid. Set tubine-end plue in LS. MIRV Expro Wireline to jet cut longstring tubing just above cement retainer at ±4975' MD (locator sub at 4985'). Fill out explosive checklist. MV wireline lubricator. Go to radio silence. Arm the 2.25" OD Spectra Cutter and pull into the lubricator. Take lubricator to wellhead and pressure test to 200/2000 psig with methanol water. Bleed methanol water back to tank to release pressure. RIH and correlated depth to wireline flag recorded in Step #9. Jet cut LS as close to the top of the cast iron cement retainer set at ±4975' MD. POOH and LD jet cutter. RV to pump down LS and circulate 6% KCL water down LS to surface out casing valve. PV 2-7/8" Owen cast iron bridge plug, setting tool, and CCL on wireline. RDMO Expro Wireline. 11. Set blankine plue in Shortstrine. MIRV Pollard Wireline. MV and test lubricator to 200/1500 psig with methanol water. Bleed back pressure to tame RIH with slickline in shortstring and set a blanking plug and prong in SS "XN" profile nipple (1.875" ID and 1.791" No-Go) at 4836' MD. 12. Set BPVs in dual tubine haneer and 7" side outlet. MIRV Vetco to set a back pressure valve in both long and short strings. Set a BPV in the 7" side outlet valves and remove the valves prior to MIRV the Glacier Drilling Rig #1. Mark SS and LS sides on wellhead before removing Wellhead Spools and Christmas Tree. Rig W orkover procedure 13. MIRV Glacier Drilline Rie #1. a. Check well for pressure. b. Nipple down tree and release to Vetco for inspection and repair. c. Inspect and verify hanger threads for landing joint MV. NU 11" 5M BOPE equipped with variable bore rams for 2-7/8" and 2-3/8" tubing. Test BOPE to 250/4500. d. Pull BPV in SS. e. Make up landing joint to short string tubing hanger. KED 23X-6 Workover 3/912007 Conversion from Dual Beluga/Sterling Pool 6 to Sterling Pool 6 Storage/Producer Page 3 . . 14. Pull and LD 2-3/8" SS - Rig up Weatherford Tubing Services 2-3/8" tubing tongs and equipment. Use 2-3/8" Hydril 511 lift nubbins and elevators to pick up tubing. Pull and lay down 2-3/8" SS. Inspect tubing for NORM while POOH. Send tubing into Tuboscope for inspection. 15. Pull and LD 2-7/8" LS - Pull BPV in LS hanger. MU landing joint in LS hanger and pull LS. Lay down same. Inspect tubing for NORM while POOH. Send tubing into Tuboscope for inspection. 16. PU and RIH with 7-5/8" bit on drill pipe to clean out fill below the Pool 6 Perfs to the top of the severed 2-7/8" tubing stub. Circulate well clean with 6% KCL water. Have product available to mix and spot another 20 bbl pill of the Clean Plug cross-linked polymer across the Pool 6 perforation. POOH with bit and drill pipe. 17. Run 5-1/2".17#. L-80 mod-Buttress liner Establish a good count of blank: casing on rig, and drill pipe and collars standing in derrick. Since liner will not be run to bottom, placement is dependent on tally alone. RU casing running equipment. Verify calibration of tongs. Ensure that a drill pipe crossover to the liner is on the rig floor. Remember to slow down while running External Casing Packer and ES Cementer through the Owen Casing Patch set 4200-4303' MD. Run the liner in the following order: a. 1 joints of blank 5-1/2" 17# Modified Buttress casing, wi float shoe made up Baker- Locked, b. 2-3 joints of blank: 5-1/2" 17# Modified Buttress casing to cover the interval from 4810' to 4975' (or the maximum depth allowed by the Tubing Stub above the Casing Packerl Locator Stub at ±4975'), c. Baker Insert Ball Seat Sub made up and Baker-Locked, d. Pup joint: Crossover 5-1/2", 10' long. Baker-Locked pin threads. e. 7.000 IN OD, 10.00 FT SEAL STANDARD ELASTOMER Baker External Casine Packer (ECP) 5-1/2" 17# Butt Box x Box (4.892" ID, 4.767"Drift) pinned for 1,250 psi opening pressure and set at ± 4815' MD (14' above top Pool 6 perf), f. Pup Joint crossover: 5-1/2" Butt pin x 5 1/2" 8Rd box. 6 feet g. Halliburton ES Cementer: 5-1/2" 8Rd box x pin, L-80, 3,300-psi opening pressure. (Part Number 100013915 14.787" ID after drill out!) h. X-over: 5 1/2", 17# 8rd box x 5-1/2" Buttress pin 1. Pup joint: 5-1/2" Buttress, 6' long, J. 5-1/2" 17 # Modified Buttress liner to place Liner Hanger at ± 3 770' MD, k. Crossover 7" Buttress x 5-1/2" Buttress, I. 190-60 x 10ft. Seal Bore Extension, m. Baker 7" x 9-5/8" Flexlock Hydraulic-Set Hane:er Assembly set at ±3770' MD (pinned for ±1056 psi (three pins @ 356psi - brass shear pins), n. Baker Setting Sleeve with 6-ft tieback sleeve and C2 running profile, o. Baker C2 running tools and Lift Nipple with Junk Bonnet. KBU 23X-6 Workover 3/912007 Conversion from Dual Beluga/Sterling Pool 6 to Sterling Pool 6 StorageIProducer Page 4 . . p. Sufficient joints of 4" HWDP and 4", 14 nominal ppf Drill Pipe to reach to the drilling floor and to provide required weight to push liner in the hole. Liner running notes: a. Use Best-O-Life thread compound. b. The 10' Baker ECP needs to be set above the Pool 6 Perforations from 4829' to 4906'. c. The liner assembly contains an ECP. Do not reciprocate the liner while circulating or displacing. d. Record liner pick-up and slack-off weights. e. Count liner joints and drill pipe not run to be sure of proper liner placement. 17. Establish circulation with 6% KCL water without exceedine: 700 psi pump pressure. Record P/U and S/O weights. Circulate 6% KCL water until good bottoms up are obtained. 18. Install Baker Oil Tools Cementine: head and RU BJ Services cement line. Space out drill pipe to place cementing head at a safe and workable distance above the work floor. MIRU BI Services Cementing equipment. MU and pressure test pump lines to 19. Set Baker Liner Hane:er per Baker onsite Representative. Break drill pipe and drop 1- 3/4" OD Phenolic ball. Pump ball to seat in Ball Seat Sub with 6% KCL water. Increase pressure to set Flexlock Liner Hanger at ±1,058psi. Slack off 20,000 lbs. to ensure liner is set. 20. Increasine: pressure to open and inflate ECP at ±1250psi. Fluids inflate ECP as follows: Pressure up to 500 psi. Make sure that suction and return is lined up on same displacement tank of pumping unit. Measure and record height of fluid in displacement tank. Hold pressure for 5 minutes and record any pressure increase due to temperature. Rapidly increase pressure in 200-psi increments, measuring and recording fluid height at each increment. (Pressure drops are difficult to detect while the pump is running therefore short fast pump increments is best.) When the pressure differential at the packer exceeds 1250 psi, the ECP will shear open and inflate and the pressure will drop. Let the pressure stabilize then increase pressure to 750 psi to verify that the ICV has closed and the packer is completely inflated. Bleed pressure back to 300 psi and measure the displacement tank. The volume of fluid that is missing is the inflation volume to use to calculate the hole size in which the ECP was inflated. 21. Continue increasine: pressure to +3.300 psi to open Halliburton ES cementer. 22. Cement liner. Mix and pump 5 bbls water spacer and 55 bbls of 13.7 ppg Class G cement slurry (to cover 8.681" ill x 5.5" OD from 3770' -4975' MD plus 2 bbls excess). Wash lines to pit prior to pumping displacement. Drop pump-down plug and displace cement with 5 bbls fresh water followed by 6% KCL water. This plug will pick up the liner wiper plug C±2,200 psi increase). Continue pumping until wiper plug latches into Halliburton ES cementer. KBU 23X-6 Workover 3/9/2007 Conversion from Dual Beluga/Sterling Pool 6 to Sterling Pool 6 StoragelProducer Page 5 . . 23. Increase pressure to close ES cementer. Example: Final displacement pressure Expected closing pressure (5.5 in., 17lb tool) Additional pressure to be sure tool is closed Pressure required to close cementer- 800 psi + 1,080 psi + 250 psi 2,130 psi 24. Release liner runnine tool by turning applying use right-hand rotation. (6 turns at the tool). Pick up and determine that Liner Running Tool has released. For the purpose of keeping cement out of production PBR, apply 500 psi down the drill string. PIU slowly. 25. Circulate any excess cement out of the well above the liner toP. Once the pack off is out, immediately engage the pumps (6 bpm) to circulate the cement above the liner top (approximately 50 bbls) up hole. Slow pumps to 2 bpm, and continue to circulate excess cement out of the well. 26. POOH with settine tool and stand back about 3770' of drill pipe. WOC for a minimum of 24 hours. 27. Run Tieback Polish and Dress mill to cleanout tie-back assembly prior to running Seal assembly tieback completion. RIH with assembly and clean Liner Tie Back Sleeve. POOH and Rack Drill Pipe. 28. RIH with a ZXP Liner Top Packer and Tie Back Stem Seal assembly with Liner Top Packer Hydraulic Pusher/Setting Tool. RIH and land Tie Back Seals in Tie Back Sleeve. Pressure Back Side to 500 psi to verify seals are landed. 29. Set ZXP Liner Top Packer by bleeding off pressure and dropping a 1-7/16" Kirksite setting ball (Allow time for ball to get on seat per Baker on-site Rep). Pressure drill pipe to 3,500 and set ZXP Liner Top Packer. Bleed off pressure and pull up 5,000 lbs to verify ZXP is set. Bring drill pipe to neutral position and pressure to 4,000 psi to shear ball seat. 30. Release C-2 Runnine Tool with Right Hand Rotation (6 turns at the tool) and POOH. 31. Set RTTS packer in 9-5/8" casine and Chanee out Tubine Head. RIH with Halliburton 9-5/8" RTTS packer çm 4" drill pipe. Set RTTS packer at about 300' KB or per Halliburton On-site Representative recommendation. POOH with Drill Pipe. RU Vetco to change out wellhead spools. Break connection and PU Drilling BOP Stack. Remove Dual Tubing and Interll1ediate Casing Spools. Install and test a new Tubing Spool capable of hanging and packing off around 5-1/2", 17 ppf tie-back tubing. Set Drilling BOP Stack back down on 5-1/2" tubing spool. NU BOP Stack to new tubing spool. Install test plug in BPV prep. Pressure test the BOP Stack connection to the new tubing spool to 250/4500 psig. Remove test plug. KBU 23X-6 Workover 3/9/2007 Conversion from Dual Beluga/Sterling Pool 6 to Sterling Pool 6 Storage/Producer Page 6 . . 32. RIH with drill pipe to release and POOH with RTTS packer. 33. RIH with Seal Assemblv and 5-1/2" tie-back tubine. PV Baker 190-60 x 10 ft. Seal Assembly with 4.875" ID x 6.00" OD and RIH on approximately 3750' of 5-1/2", 17ppf, L-80 Modified Buttress completion string. Land Seals in Seal Bore and Pressure Test to 1,500 psi. 34. Hane off 5-1/2" tubine. ND BOP. Reinstall and test dual tubine spool with 7" side outlets. Bleed off pressure and space out for final landing depth and tension. Break and ND Drilling BOP stack. Set slips around 5-1I2"tie-back tubing and make final cut. Reinstall and pressure test dual tubing spool with 7" side outlets. Set BPV in 5-1/2" tubing head. Secure wellhead. 35. ND BOP / NV tree - Nipple down BOP and Nipple up new 11" 5M x 7-1116" 3M XP-l Adaptor and a single 7-1116" master valve. 36. RDMO Glacier Rie # 1. Post Rig Procedure: 37. Install and test CT Concentric Strine Tubine Heads. and 7-1116" 3M Christmas tree. Deliver diesel-fueled manlift and ASRC loader to location. Pull 5-112" BPV and install 2- way check. Install 2-3/8" CT tubing head (with 2-1116" gate and actuator valves), 1-3/4" CT tubing head (with 2-1116" gate and actuator valves), dual 7-1116" 3M master gate valves, and Otis tree cap adapter. Pressure test Christmas Tree to 3000 psig with methanol water. Pull 2-way check. 38. RV FOR CT Work: Deliver liner, and dunnage to location. ASRC to lay liner and berm under MOC choke skid, fluid supply tank, and flowback tank. Liner also to be placed around wellhead and vicinity to be occupied by wireline and coil tubing equipment. Deliver MaC flow back tank and gas buster to location. Deliver MOC 2", 5K flowback choke skid and flowback chicks an to location. Deliver 500 bbl Rain-for Rent Tank to location and fill with 6% KCL water. Set gas buster on flow back tank and bind down with chains and boomers. 39. MIRV B.J Coiled Tubine EQuipment. MIRV BI CoilTech 1-3/4" CT unit, fluid pumper, nitrogen unit, and filter pod trailer. Hold PISM. ND 7-1/16" Otis connection from top of swab valve. Install BI flow cross to top of 7-1116" 3M top master valve. Have ASRC crane pick up BI coil tubing BOP and then flange up 7-1116" CT BOP to flow cross. Place coil tubing in injector head. Make up lubricator to injector head. Make up pump line to CT swivel. MV flow back chicksan from CT flow tee to choke manifold and gas buster. Pick up injector head and lubricator with crane. Install 2" OD bullnose jetting nozzle on end of coil tubing and make proper pull test. Make up CT injector head and KBU 23X-6 Workover 3/912007 Conversion from Dual Beluga/Sterling Pool 6 to Sterling Pool 6 StoragelProducer Page 7 . . lubricator to BOP's. Pressure test CT BOP pipe and blind rams with methanol water to 250 low/4500 high psi. Pressure test flowback iron to 250 low/4500 high psi. Displace methanol water to tank with nitrogen. 40. Drill out Cement. DV tool. and Ball Seat Sub with CT and KCL water. MV Baker 4.75" OD mill, 2-7/8" motor, MHA, and CT connector to 1-314" CT. Make proper pull and pressure tests. RIH and drill out any residual cement, the Halliburton ES Cementer (DV Tool), and the Baker Ball Seat Sub. Push debris down to top of 5-1/2" Float Shoe. Circulate bottoms up until returns are clean. POOH and LD milling assembly. Stand back CT injector head and lubricator. 41. Run CBL: MIRV Expro with packoffto run cement bond log. Connect pump-in tee to top of BJ CoilTech BOP equipment. Connect flow back chicksan to handle 6% KCL water displaced from hole with tools and wireline. Hold PJSM. PV and RIH with SCMT/GR/CCL on wireline. Correlate MD to openhole logs run. Log SCMT from PBTD to 200' above 5-1/2" liner top at about 3750' KB. RD Expro wireline. 42. RU for CT JET: RV MOC flowback iron to allow reverse circulation of fluids through the coil tubing to the flowback tank. Pick up injector head and lubricator with crane. Install 2" OD bullnose jetting nozzle on end of coil tubing and make proper pull test. Make up CT injector head and lubricator to BOP's. Pressure test CT BOP pipe and blind rams with methanol water to 250 low/4500 high psi. Pressure test flowback iron to 250 low/4000 high psi. Displace methanol water to tank with nitrogen. 43. Jet Well dry with CT and Nitro2en: Open well and RIH with coil tubing to PBTD unloading KCL water from wellbore by pumping nitrogen down CT by 5-1/2"casing annulus, up CT, and into flowback tank with nitrogen. Note: Important to take initial and final flowback and fluid supply tank straps before and after running in with coil tubing. POOH with coil tubing bleeding off all nitrogen in well to the flowback tank. RDMO BJ Services coil tubing and nitrogen units. 44. Add 1 Reperf Pool 6 intervals - MIRV Expro Wireline to perforate 5-112" casing across from existing Pool 6 perforations in 9-5/8" casing at 4829-4906' MD. Hold PJSM and review explosive safety check list. Observe radio silence. Run shooting GR/CCL to log strip and ensure all casing collars are identified on first run. PV and RIH with GR/CCL and 3.375" HSD guns loaded 6 SPF 60 degree-phased with SDP-3125-311NT3 charges and PX-l firing head. API target perfonnance is 0.36" entrance hole and 40.25" penetration. Max gun swell in air is 3.625" OD. Correlate depth to Expro CBUGR/CCL log. Perforate 4829-4906' MD. POOH and RDMO Expro Wireline. 45. Flow test well to sales. If well production or injection is less than expected/desirable, consider acidizing perfs with 7-1/2% HCL to reduce perforating damage and break any residual Clean Plug cross-linked polymer restrictions in the near wellbore. KBU 23X-6 Workover 3/912007 Conversion from Dual Beluga/Sterling Pool 6 to Sterling Pool 6 Storage/Producer Page 8 . . 46. If necessary to keep the well unloaded while it is in a production cycle. run 2-3/8" x 1.75" conèentric CT string - Run 2-3/8" x 1.75" CT concentric string to depth at bottom of Pool 6 perf interval as determined by reservoir and geology. CONTACTS: Ken Walsh: 907-283-1311 (w) 907-394-3060 (c) Jennifer Enos 713-296-3319 (w) 713- 408-3583 (c) Lyndon Ibele: 907-565-3042 (w) 907-748-2819 (c) Clyde Scott: Moksh Dani: 713-296-2336 (w) 713-296-3140 (w) Welby Sweet: 713-296-3111 (w) KGF Operators: 907-283-1305 JRT 1/4/2007 KDW revised 3/6/2007 KBU 23X-6 Workover 3/9/2007 Conversion from Dual Beluga/Sterling Pool 6 to Sterling Pool 6 StoragelProducer Page 9 Date: To: From: Subject: . . /) March 13,2007 '. ;//?j/~/ File !' /1. II Jane Williamson " / Kenai Beluga Unit 23X-6 Abandon Beluga, Recomplete to Sterling 6. Marathon has requested approval to workover KBU23X-6 from a dual Beluga and Sterling Pool 6 well to a Sterling 6 producer/storage injector. Production from the Beluga and from the Sterling 6 are separately shown below. The Beluga was produced in the well from 1985-1999 at a rate of around 2 MMSCFD. It was S1 early 2000. Our production data suggests that the Beluga was tested for a total of 70 days ITom 8-2006 through 12-2006 at around 600 mscfd. I don't see evidence of water. I don't have January production, however. Sterling 6 has been producing since 2001. It appears that it has a capacity of up to 8000 mscfd. . ~)~'VJ i( {' - '...tJ~ ~ /7 c '" ,) ¡:'lS, ~)¿,k~v Annual reports before 2001 showed pressures of a low of 466 psi for thet pool (not sure of the well) - but noted a datum of 4900'ss. However, report of2004, 2005 and 2006 show pressures that are much higher- around 2000-2300 psi. at a datum of 6600' ss. There has been quite a bit of drilling in the Beluga in recent years so at first glance plugging back Beluga shouldn't be a problem. It is hard to say, however, whether this well's Beluga is in communication with those in the remainder of the field. With the low rate in the Beluga interval and the number of wells in the remainder of the Beluga pool, I don't see a waste issue. 23X.o6 UP TYONEK ~I 100 50 Gas Rate Gas 10 5 0.5 0.1 93 94 95 96 97 98 99 87 88 89 90 91 CÄTE 011 Prod 01 02 03 04 05 06 10 5 0.5 0.1 1999 2000 23X.oS 01 02 03 OI\TE GAS Gas Rate (CD) ( M\II:::f/d ) Press (M) - Gas \MIls 04 05 06 07 Re: KBD 23X-6 (184-109) . . Ken, I have looked further at the sundry. Placing the new liner in the well will isolate all the old perforations. That should essentially give you a new wellbore. I wondered about some sort of bond log once the wellbore was cleaned out, but one was run when the well was drilled (prior to squeezing) and the production history of the well does not show much water production. As intervals were switched, the rate and pressure changes also indicate isolation. We won't be able to get a signed copy of the 403 out for a couple of days, but it should be issued prior to beginning the rig work. By copy of this message, you have "verbal" approval to proceed with the pre-rig work. Good luck, call or message with any questions. Tom Maunder, PE AOGCC Walsh, Ken wrote, On 3/12120076:10 AM: Tom, No problem or offense taken at all with your questions. I am always looking for better ways to "geterdone". Thanks, Ken Ken D. Walsh Senior Production Engineer Marathon Oil Company-Alaska Asset Team 907-283-1311 (office) 907-394-3060 (cell) -----Original Message----- From: Thomas E Maunder Ito:torn maunderCq"adrnin.staLe.ak. Sent: Saturday, March 10, 2007 8:05 AM To: Walsh, Ken Subject: Re: RE: KBU 23X-6 (184-109) Hi Ken, No I don't really don't see any "gotchas". The operation is in your control. You have the detailed information. All I can do is examine what you have submitted and pose questions. I hope you don't mind my posing such questions. Best regards, Tom Maunder Original Message ----- From: "Walsh, Ken" <kdwalsh@marathonoil.com> Date: Friday, 9, 2007 4:26 pm Subject: RE: KBU 23X-6 (184-109) To: Thomas Maunder <tom maunder@admin.f:3tate.ak.us> 10f2 3/13/20077:54 AM Re: KBU 23X-6 (184-109) . . Tom, Answers embedded within your questions below. Ken Ken D. Walsh Senior Production Engineer Marathon Oil Company-Alaska Asset Team 907-283-1311 (office) 907-394-3060 (cell) -----Original Message----- From: Thomas Maunder ,to: Sent: Friday, March 09, 2007 4:10 PM To: Walsh, Ken Subject: KBD 23X-6 (184-109) .sc.ate.ak.us Ken, I am reviewing the procedure for KBD 23X-6. You indicated that you are planning to get the pre-rig work underway as soon as you can. I have a couple of questions for that section. Pre-Rig 1. What is the fill depth in the LS? Is access to the deep perfs restricted? Question answered step 6. 2. After setting the polymer pill the possibility of taking returns via the long string is mentioned. Are the strings in communication? We believe that there is at least one hole in the blast joints across from the Pool 6 interval. 3. Will circulating via the long string as planned in step 10 mess up the polymer pill? It could but we will have at least enough product for two more pills available. I may also look at just making sure that the hole is full from the annulus. Are you seeing a major "gotcha" that I may be missing here? Thanks in advance for your reply. Tom Maunder, PE AOGCC 20f2 3/13/20077:54 AM . _"," '1' . 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 '(;'Äi' N;N~;;:;!i' ;""j. . ~\, L." y. .". -~_. 'J: r) 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. API No. APD No. 21-6RD 5011331009001 201097 43-6RD 5011331009101 201231 34-31 5011331009700 159013 33-32L 5011331009800 165007 44-30L 5011332013900 178055 DU5-L 5011332031900 168071 14X-6AN SO 11332034200 181092 34-32L 5011332034800 181154 14-32L 5011332035100 182015 13-6L 5011332035600 182085 23X-6SAN 5011332037100 ·18-4104 IXlf-lo'1 33-7S 5011332038000 185181 31- 7X 5011332049500 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 Fil s Brian Havelock, ADNR, Anch rage Greg Noble, BLM, Anchorage ( ( MEMO TO EACH WELL FILE LISTED BELOW Date January 7, 2004 Two previously undefined intervals, the D 1 sand of the Tyonek Formation and the Beluga Formation in the Kenai Unit of the Kenai Gas Field, have been combined into a single defined pool the Kenai, Beluga/Tyonek Gas Pool, field & pool code number 448571. This change was effective in January 2004. Production from these two intervals had previously been reported to production codes 448569 Kenai, Beluga Undefined Gas and 448570 Kenai, Tyonek Gas. These codes have been deleted from some of the wells listed below. The wells listed below have had their production records modified reflecting this change. 184-109 KBU 23X-06 200-023 KTU 32-07 181-153 KBU 31-07 168-049 KDU 2 195-055 KBU 31-07RD 184-108 KTU 13-05 174-050 KU 14-06RD 199-024 KBU 33-06 178-055 KDU 5 195-054 KTU 43-06XRD 177-029 KBU 13-08 203-066 KBU 43-07X 185-181 KBU 33-07 199-073 KTU 24-06H 202-043 KTU 32-07H 195-054 KBU 43-06XRD 179-029 KBU 41-07 169-012 KDU 4 184-108 KTU 13-05 179-030 KBU 43-06X 199-024 KBU 33-06 199-025 KBU 42-07 200-188 KBU 24-06 202-025 KBU 41-07X 200-1 79 KBU 44-06 ~~tA~NElfJ, JJ~N 2 «) 2004 Alaska iness Unit Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 June 13, 2002 Mr. Steve McMains AOGCC 333 West 7th Ave. Suite 100 Anchorage, AK 99501 Subject: KBU 23x-6 Workover Dear Mr. McMains: As per our telephone conversation today, I am providing you with the daily operations reports for the June 2001 workover of well KBU 23x-6 (permit #84-109) in the Kenai Gas Field. This is the workover that converted well KBU 23x-6 from a single producer in the Beluga Pool to a dual producer in the Beluga and Sterling Pool 6 pools. As described in the operations reports, although the workover was performed in June 2001, the Pool 6 was not perforated until October 2001. Therefore the Sterling Pool 6 in well KBU 23x-6 did not produce to sales until November or December 2001. The 2002 workover, of which you already have daily operations reports, was performed in order to repair tubing damage that occurred when the Pool 6 was perforated in October 2001. As you indicated in our conversation, these records should complete the required documentation of the sundry operations performed in well KBU 23x-6 in 2001 and 2002. Please call if you have any questions. I can be reached at 564-6315. Sincerely, ~ Production Engineer bjv C: CEF w/o attachments RECEIVED .,.llJi'q 1 4 2002 Alaska. 0ii &,~f .... ~, ::. (',u,~;~ ~,u~,.'-'i'~"'. Anch0rar~e Environmentally aware for the long run. g:~crnn\drfg~gflwells~ku l 1-SsV~OGCCO4a,xls 1. Operations perf STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Perforate Other Operation Shutdown Stimulate Plugging Pull Tubing Alter Casing Repair Well X 2. Name of Operator 5. Type of Well: MARATHON OIL COMPANY Development x 3. Address Exploratory P. O. Box 196168, Anchorage, AK 99519-6168 Stratigraphic 4. Location of Well at Surface Service 291' N & 1208' E of SW Corner Sect. 6, T4N, RIW, S.M. At top of Productive Interval 1468' N & 1491' E of SW Corner Sect. 6, T4N, R11W, S.M. At Effective Depth At Total Depth [Workover to repair tubing communication 2421' N & 1704' E of SW Corner Sect. 6, T4N, R11W, S.M. 6. Datum Elevation (DF or KB) Pad 66' MSL 7. Unit or Property Name Kenai Beluga Unit 8. Well Number KBU 23x-6 9. Permit Number ~L) I -/~_~ 84-109 (Sundry: 302-081 ) 10. APl Number 50-133-20371 11. Field/Pool Kenai Gas Field/Beluga/Sterling Pool 12. Present Well Condition Summary Total Depth: measured true vertical 6950 feet Plugs (measured) 6447 feet Effective Depth: measured true vertical 6841 feet Junk (measured) 6341 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length Size Cemented 126' 20" Driven 2532' 13-3/8" 1870 sx 6950' 9-5/8" measured 5112'-6810' MD Long String Measured Depth True Vertical Depth 126' 126' 2532' 2454' 695O' 6447' 4829'-4906' MD Short String true vertical 4711-6311' TVD Long String 4455' - 4525' TVD Short String Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 2-3/8", 4.6ppf, L-80, 4771' 2-7/8", 6.4 ppf, L-80, 5100' Short String Long String Halliburton Permaseries packer at 4988' 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) N/A Treatment Description Including Volumes Used and Final Pressure N/A Anch0r~e 14. Representative Daily Avera.qe Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation 0 0 0 150 (Note: Prior/subsequent volumes are for the specific intervals treated, not the well as a whole.) Subsequent to Operation 0 500 0 150 150 15. Attachments Copies of Lo! Daily Report ~7. I h%{ Signed Form 10-404 Rev. 06/15/88%'''''~ 16. Status of Well Classification as: s and Surveys run fWell Operations ~ Oil Gas x Suspended foregoing is l~and correct to the best of my knowledge. · "-~'~ '" \ (~N~,,~,.,~ (, \ N~ J.Gary Eller Title Production Engineer ORIGINAL Service Date 05/01/02 Submit in Duplicate KBU 23x-6 j I IDrive Pipe:20", 94 ppf, H-40 driven t¢ APl: 50-133-20371 I126' I! I I AOGCC: 84-109 RT-THF: 19.80' ISurface Casinq: 13-3/8% 61 ppf, K-55, BTCI · l, Ito 2532' I 291' FSL, 1208' FWL I Cmt w/1900 sks Sec. 6, T4N, R1 lW, S.M. Tree Cxn (SS & LS): 3-1/2" EUE 8rd 5-bolt orescent flange Casinq Patch: 4200' - 4303' Owen Oil Tool, ID = 7.75" Isolating B-3 perfs (4214' - 4275') Lon.q String: 2-7/8", 6.4 ppf, L-80, IBT-M tubing to 5100'. Short String: 2-3/8', 4.7 ppf, L-80, Hydril 511 tubing to 4838' Steel blast joint: 4821' - 4910' ~ ~ XN-Nipple (ID = 1.875", no-go = 1.791 ") @ Sidepocket mandrel (SFO2) @ 4~941' ~ ~ 4836' Loaded with 1.5" circulation valve Bull Nose Re-entry Guide @ 4838' X-Nipple (ID = 2.313") @ 4984, Locator sub @ 4985' Seal assembly: 4" OD x 8.5' -lalliburton BWD Packer @ 4988' X-Nipple (ID = 2.313") @ 5034' X-Nipple (ID = 2.313") @ 5066' Active Perfs: Shortstrinq: Pool 6, 4829' - 4906' Wireline Re-entry Guide @ 5100' 4-5/8" TCP guns, 5 spf, 3/13/02 Lonqstrinq (Beluga) U-I' 5112' - 5130' (6 spf, 4/17/02) U-2: 5153' - 5165' (6 spf, 4/17/02) U-5: 5282' - 5303' (1/3/01) U-9: 5520' - 5545' (2/12/85) L-3: 6788' - 6810' (covered w/junk) Inactive Perfs: Isolated (Casing Patch): Pool 5.1, 4214' - 4275' . .................... ¢¢:3J~,~ ............. ~.~,~C3 I Junk: Remnant of Otis WD-1 packer @ 6781' on Squeeze per[s: ~~::r 3784,. 3786, (2/1/85) ........... i_?-i-..-?. ~ ......... ~f fill (6/01) I 4278' 4280' (1/31/85) ~:-~'~'~' - ~..~ ..~ 5110' - 5112' (2/3/85) ~:~.-.-.~:~..~- 5201'- 5204' (2/17/85) 5215'- 5221' (2/17/85) I Production Casinq: 9-5/8", 47 ppf, N-80, 5280'- 5301' (2/14/85) IBTC to 6950' 6696' - 6706' (2/9/85) I PBTD: 6848'lTD: 6950' ICmt w/3000 sks Well Name & Number: KBU 23x-6J J Lease J Kenai Gas Field, Pad 14'6 County or Parish: Kenai J State/Prov. Alaska Country: Angle/Perfs J30 deg. Angle @ KOP and Depth KOP TVD Date Completed: 03/15/02J RKB: J Prepared By: Gary Eller J Last Revision Date: 18-Apr-02 J MARATHON OIL COMPANY , DALLY WELL OPERATIONS REPO, DATE: 3/5/2002 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: 5066' RKB FIELD: TUBING: Dump sand on Plug Complete Kenai Gas Field 2 7/8" 400 PSI CASING: TREE CONDITION: WIRE TEST: WELL #: 23X-6L 22 WBS # WO0206464. EXP Hrs. 9 TOOL STRING: WIRELINE CREW: RSO #: 455-864 SUMMARY OF OPERATIONS F. Pollard/Smith PROD: DRILL: Ticket #: P-124 Leave Shop w/Unit & Mast Truck Arrive in Field, discuss job w/Wayne Arrive on location Safety meeting R/U, P. T. Lub & WLV RIH w/] 3/4" DD Bailer to 5060' RKB, shows Prong marks on bottom of Bailer RIH w/1 3/4" Dump Bailer w/1 gal. of sand to 5060' RKB, POOH, did not dump RIH w/same to 5060' RKB, POOH, dumped 3 qts. of sand RIH w/same w/1 gal. of sand to 5058' RKB, POOH, all sand dumped RIH w/same to 5058' RKB, POOH, dumped 1 gal. of sand R/D, move to KBU 41-7 Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. 9 of 12 hr min $1,377.00 $1,377.00 Pollard Wireline Inc. I 3/4" DD Bailer $150.00 $1,527.00 Pollard Wireline Inc. 1 3/4" Dump Bailer $150.00 $1,677.00 Pollard Wireline Inc. Pollard Wireline Inc. DAILY COST: $1,677.00 CUM: REPORTED BY: Wayne Cissell MARATHON OIL COMPAN~ DALLY WELL OPERATIONS RI. ,::IT PAGE 1 OF 1 DATE: 3/7/2002 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field WELL #: KBU 23x-6 TUBING: 2 7/8" CASING: 3/5/2002 TREE CONDITION: Good dump sand BENCHES OPEN: Sterling Kill well for work over WlRELINE CREW: Hrs. SUMMARY OF OPERATIONS BJ arrived on location, Previously mixed up 300 bbls of 3% KCL RU 2" chicksan from well to pump and down back side of well. WHP - 290 psig. PT pump in iron to 1000 psig. Pump 260 bbls water down back side while bleeding down the tubing. To flow back iron to tank. Blow down trap gas on back side of the well to open top tank. Well bled down to 0 psig. RD BJ services. Vetco Gray arrived we set back pressure valves in the 2 7/8", 2 3/8" and 2 - way check in the 6" tree hanger. Note: Marked the long and short side of hanger and tree with a metal stencil. Short marked with a "S" and Long with a "L". All flow line Vendor Equipment Daily Cost Cumulative Cost BJ Services pump unit $3,700.00 Vetco Gray $600.00 DAILY COST: $4,200.00 CUM: $4,200.00 REPORTED BY: Wayne Cissell KENAI BELUGA UNIT 23X-6 OH 96.38 3/8/2002 SUPERVISOR RIG NAME & NO. I RIG PHONE AUTH MD AFE NO. [AFE COST R.C. Lawson GLACIER DRILLING It V/O.02.06464. EXI~ 400,000 CURRENT STATUS MOC Wi NRI DAILY WELL COST CUM WELL COST .R/D rig. 100.00 (%)~ 92.20 (%) 8,725.00 8,725.00 24 HR FORECAST J ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST R/D rig.I NONE 3/6/2002 FIELD NAME I STATE/PROV'1 COUNTY/OTHER LAST CASING'INEXT CASING LEAKOFF PPG KenaiI AlaskaIKenai Borough 9.625 (in) @ 6,950 (ft)I (in) @ 0 (ft) OP COMMENTS: R/D rig. 18:00 00:00 6.00 AF MIRU Rig accepted from KBU41-7X @ 18:00hrs 03/07/02. R/D circ. lines. Drain mud pumps. R/D top drive and torque tube. R/D elec. lines, fuel lines, and water lines. Pull rotary table motor. 00:00 06:00 6.00 ~AF MIRU R/D floor. PJD pits. R/D monkey board. Blow down steam lines. Telescope - - derrick down. Pull cylinder covers and winterization tarps. Marathon 1 12.00 Inlet Drilling 18 216.00 M-I Drilling Fluids 1 12.00 Printed: 3/14/2002 10:18:24 PM KENAI BELUGA UNIT 23X-6 OH 65.70 1 2 3/9/2002 SUPERVISOR RIG NAME & NO. ]RIG PHONE AUTH MD AFE NO. IAFE COST R.C. Lawson GLACIER DRILLING 1I ~/O.02.06464.EX~ 400,000 CURRENT STATUS MOC WI NRI DAILY WELL COST CUM WELL COST R/U rig. 100.00 (%) 92.20 (%) 17,425.00 26,150.00 24 HR FORECAST ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST R/D rig. Begin workover. None 3/6/2002 Kenai Alaska Kenai Borough 9.625 (in) @ 6,950 (ft) (in) @ 0 (ft) !OP COMMENTS: R/U rig. :iiEROMi=' !~:i:=1:O~iiii~ii :i~~i ii?:iiiiiii~;!i;?! ii:i::!ii!!DESCRiPTION.; ~::ii:i'?!i:~ !~: ::; :' : :: :::!:~:,~':i!ii::=.:~ ii'., i i~:ilil ~:i?: ii i ! -~:~:~.:::~:~:. ~ ~:-~:~ ~ ~:~-~:~-.~ .~;~ ~ : ~ ~-: ~ ~-~ ~ ~ ~:~ ~ ~:.:~: ............. :. ~: ~ ~ ;~::~:.~ ~.~ .... ::.::~ :; ~ .:. ...... , ; , ..... , ;: ~, ,- ~ .~:;. , ....~.: ~;~.. :~ ~:.: :. ...... 06:00 12:00 6.00 AF MIRU R/D pits and pump room. 12:00 00:00 12.00 AF MIRU Lay over derrick. Remove doghouse. R/D carrier, mud boat, and sub base. Move generator, boiler, water tank, pitts, mudd boat, and sub base off of rig matts to new location. Load trailers. L/D liner and lay rig matts. Spott sub base, mud boat, pitts, generator house, boiler, water tank, slop tank. Raiser sub, move pitts together. Plug in electric lines. PJU lights. Spot trip tank. R/U outriggers. 00:00 06:00 6.00 AF MIRU Raise derrick and set fuel tank. R/U choke house, drillers dog house and derrick dog house. R/U rear landing and windwalls. Raise windwalls on rigfloor. R/U beaver slide and catwalk. PJU service lines. Marathon I 24.00 Vecco I 12.00 M-I Drilling Fluids I 24.00 APC 6 40.00 Inlet Drilling 18 432.00 Weaver 3 72.00 Printed: 3/14/2002 10:1E~:26 PM KENAI BELUGA UNIT 23X-6 OH 2 3 J 3/10/2002 SUPERVISOR RIG NAME & NO. J RIG PHONE AUTH MD AFE NO. JAFE COST R.C. Lawson GLACIER DRILLING 1J VIO.02.06464.EXp 400,000 I CURRENT STATUS J MOC WI J NRI DAILY WELL COST i CUM WELL COST Mix KCL.J 100.00 (%)J 92.20 (%) 25,483.00 51,633.00 24 HR FORECAST ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST Circulate well. N/D tree. N/U BOP. Test BOP. Pull 2 3/8" None 3/6/2002 FIELD NAME J STATEJPROV'J COUNTY/OTHER LAST CASING NEXT CASING LEAKOFF PPG KenaiJ AlaskaJKena Borough 9.625 (in) @ 6,950 (ft) (in) @ 0 (fi) OP COMMENTS: R/U rig. 06:00 12:00 6.00 AF MIRU Install steam traps, carier mufflers, handrails. R/U mud line. Set#2 water tank. R/U guide wires. Fire up boiler. Pull and R/U electric lines. R/U gas buster. 12:00 00:00 12.00 AF MIRU Scope up derrick. Tighten guide wires. Adjust sub. Install dresser sleeves in pitts. Cont. R/U steam, air, water and electric lines. R/U brake linkage, drillers console, beaver slide, rotary table motor, choke chute and hose~ kill line, mud manifold. Spot tool basket, berm rig. R/U slop tank, carrier tarps, sub tarps, rig floor spill protection. R/U and calibrate gas alarm. R/U top drive torque tube. 00:00 06:00 6.00 AF MIRU R/U derrick board. Organize rig floor and tools. Install top drive toque tube turn buckles, derrick cylinder socks, Geronimo line, drillers control cover plate, cellar winterization. R/U top drive and service lines. R/U long bales. Mix 3% KOL. Service top drive. Marathon I 24.00 Vecco I 8.00 M-I Drilling Fluids 1 24.00 APC 4 24.00 Inlet Drilling 18 432.00 Weaver I 12.00 Printed: 3/14/2002 10:18:28 PM SUPERVISOR ~IG NAME & NO. RIG PHONE AUTH MD AFL NO. ~AFE COST R.C. Lawson GLACIER DRILLING I ~iO.02.06464.EX~ 400,000 CURRENT STATUS MOC WI ~ NRI DAILY WELL COST CUM WELL COST C/O rams to 2 3/8". 100.00 (%~ 92.20 (%) 22,316.00 73,949.00 24 HR FORECAST ACCIDENTS 24HR LAST SAFE~ MTG. BOP PSI TEST Test BOPE. Pull 2 3/8" tubing. C/O rams and test. Pull 2 7/8 None NEXT 3/6/2002 ~ELD NAME STAT~PROV COUN~IOTHER ~STCASING CASING LEAKOFF PPG Kenai~ Alaska Kenai Borough 9.625 (in) ~ 6,950 (fi) (in) ~ 0 (fi) OP COMMENTS: Complet ~U rig. Pumps LCM pills and fill well. N/D tree. N/U BOP. 06:00 09:30 3.50 AF MIRU ~U Koomey lines, panic line, rig ~on'gs, trip tank gauge, ~'U~'Cylin~'er socks. ~U kill and choke lines. 09:30 11:00 1.50 AF OTHER 'Check annulus presure 0psi. LS pressure 30psi. SS 0psi. ~U lubricator and pull BPV from LS and SS. 11:00 12:00 1.00 AF OTHER ~U kill line to LS and choke line to annulus. Testlinesto250/1000psi. 12:00 12:30 0.50 ~ - AF OTHER Pump58bbls down LS. Well on vacuum. 12:30 13:30 1.00 AF OTHER Mix HEC LCM pill. 13:30 14:00 0.50 AF OTHER Pump30bbls HEC LCM pill down LS. 14:00 14:30 0.50 AF OTHER Monitor LS. LS static. 14:30 16:00 1.50 AF OTHER ~U kill line to SS and circulate 280bbls to get returns out annulus valve. Well on vacuum. 16:00 17:30 1.50 AF OTHER Build 300bbls of 3% KCL in pits. 17:30 18:00 0.50 AF OTHER Pump down SS and cimulate out annulus(losses 17BPH). 18:00 18:30 0.50 AF OTHER Mix HEC LCM pill. 18:30 19:30 1.00 AF OTHER Spot 20bbls HEC LCM pill to bosom of ~ 3/8" tubing(circulated while spoffing). 19:30 20:00 0.50 AF OTHER ~D on SS and ~U on LS. Fill w/4bbls. 20:00 20:30 0.50 AF OTHER Install ~C in LS and SS(well on slight vacuum). 20:30 21:30 1.00 AF XMBO Sting into tubing bonnet and veri~ no pressure be~een tree and tubing ~head. N/D tree. Inspect hanger threads. 21:30 00:00 2.50 AF XMBO N/U 11"5mX 135/8"5M adapter spool. N/D single gate from BOP stack. Position BOP into sub structure. 00:00 05:00 5.00 AF XMBO N/U 13 5/8" 5M S,Rd,A BOP 05:00 05:30 0.50 AF XMBO Set mouse hole. 05:30 06:00 0.50 AF XMBO C/O rams in BOP to 2 3/8". Marathon 1 24.00 Inlet Drilling 18 432.00 M-I Drilling Fluids I 24.00 Vetco I 6.00 Printed: 3/14/2002 10:18:29 PM KENAI BFLUGA UNIT 23X-6 OH 96.38 4 5 3/12/2002 SUPERV~SOa ~G NAME & NO. ~G P.ONE AUTH MD A~E NO. IAF~ COST R.C. Lawson GLACIER DRILLING 1 ~/O.02.06464.EXI~ 400,000 CURRENT STATUS MOC WI [NRI DAILY WELL COST CUM WELL COST Prepare to C/O pipe rams. 100.00 (%)J 92.20 (%) 21,428.00 95,377.00 24 HR FORECAST IACClDENTS 24HR LAST SAFETY MTG. BOP PSI TEST Pull 2 7/8 tubing. Make TCP run. I None 3/11/2002 3/11/2002 FIELD NAME STATE/PROV I COUNTY/OTHER LASTCASING I NEXT CASING LEAKOFF PPG Kenai AlaskaIKenai Borough 9.625 (n) @ 6,950 (ft)I (in) @ 0 (ft) OP COMMENTS: Test BOPE. Pull 2 3/8"tubing. 06:00 08:00 2.00 =AF XMBO M/U 2 3/8" test joint to test fixture. Run in stack. R/U to test. Finish excavate cellar for mouse hole. 08:00 12:00 4.00 AF XMBO Test 2 3/8" pipe rams, Annular,check valve, inside and outside kill valves, valves 1-12 on choke manifold to 250/3000psi 10min. 12:00 16:00 4.00 AF XMBO Attempt test blind rams and HCR. Test failed. C/O plug valve on mud manifold. Retest 250/3000psi 10min. Attempt test choke line manual valve. Test failed. Service manual valve and retest 250/3000psi 10min. Test IBOP, TIW, and lower TD valve to 250/3000psi 10min. Attempt test upper TD valve. Test failed. 16:00 18:00 2.00 TA XMBO C/O upper and lower TD valves(upper and lower TD valves one package w/this TD). 18:00 19:00 1.00 AF XMBO Test upper and lower TD valves to 250/3000psi 10min. 19:00 19:30 0.50 AF XMBO Perform Koomey test. 19:30 21:00 1.50 TA XMBO Attempt to pull TWC's. Hanger covered with trash. Pump out stack and jet hanger clean. Pull TWC's and set BPV in long string. 21:00 21:30 0.50 AF OTHER Screw into short string w/3 1/2" landing joint. Pull hanger to floor. B/O landing joint. R/U circulating iron. 21:30 23:00 1.50 AF OTHER CBU w/3% KCL(took 35bbls to fill the hole) 4BPM w/750psi(well staic while circulating). Safety meeting prior to POOH. 23:00 23:30 0.50 AF OTHER PJD circulating iron. B/O hanger assy. POOH w/2 3/8" 4.TPPF L-80 HydriI 511 tubing. 23:30 05:30 6.00 AF OTHER Safety meeting w/crew coming on tower. POOH L/D 2 3/8" tubing(total 151JNTS)(well took 4bbls while POOH). 05:30 06:00 0.50 AF OTHER Organize and clean rig floor. Prepare to C/O pipe rams to 2 7/8". Marathon 1 24.00 Vetco 1 6.00 M-I Drilling Fluids I 24.00 Weatherford Completion 2 36,00 Inlet Drilling 18 432.00 Prinled: 3/14/2002 10:18:31 PM KENAI BELUG^ U~IT 23X-6 OH 65.70 5 6 3/13/2002 SUPERWSO~ R~G NAME & NO. I ~a PUONE Atrm MD AFE NO. IAF£ COST R.C. Lawson GLACIER DRILLING II ~/O.02.06464.EX1~ 400,000 CURRENT STATUS I MOC WI- / NRI DAILY WELL COST CUM WELL COST Run 4 5/8" TCP guns on 2 7/8" TBG.I 100.00 (%)~ 92.20 (%1 17,875.00 113,252.00 24 HR FORECAST ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST Perforate. Make cleanout trip. Run TBG. None 3/13/2002 3/11/2002 FIELD NAME I STATE/PROV I COUNTY/OTHER LASTCASING NEXT CASING LEAKOFF PPG KenaiI AlaskaIKenai Borough 9.625 (in) @ 6,950 (ft) (n) @ 0 (ft) OP COMMENTS: C/O pipe rams and test. POOH w/2 7/8" TBG. L/D perforated TBG and fired TCP guns. RIH w/TCP guns. 06:00 08:30 2.50 AF XMBO C/O pipe rams F/2 3/8" to 2 7/8". M/U 2 7/8" test joint w/test fixture. Pull BPV from LS and set TWC. Set seal sub w/TWC in SS side of hanger. Attempt to test rams. Test failed. 08:30 10:30 2.00 TA !XMBO Open doors to inspect rams. Turn rams over and attempt test. Test failed. C/O 2 7/8" rams. 10:30 11:00 0.50 AF XMBO Test 2 7/8" rams 250/3000psi 10min. 11:00 12:00 1.00 AF XMBO Pull TWC F/LS. Pull seal sub F/SS side of hanger. M/U 3.5" landing joint to TBG hanger. Pull hanger to floor. B/O hanger and L/D. 12:00 13:00 1.00 AF OTHER POOH w/2 7/8" TBG to 4700'. R/U cim. iron. 13:00 15:00 2.00 AF OTHER CBU(took 11BBLS to fill well, well static while CBU). 15:00 19:00 4.00 AF OTHER POOH and rack back 2 7/8" 6.5PPF L-80 8rd EUE TBG(no losses to the hole). 19:00 23:30 4.50 AF OTHER R/U dual slips and L/D 3 5/8" Halliburton TCP guns that are attached to tubing w/Y-block. L/D perferated joints of 2 7/8" TBG(F/Y-block down first joint OK. Top 22' of JNT#2 OK. Bottom 9.5' perforated. Top 18.5' of Joint#3 OK. Next 8.5' perforated). 23:30 00:00 0.50 ~,F OTHER Run wear bushing. 00:00 01:00 1.00 AF OTHER PJSM prior to TCP job. P/U 77' of 4 5/8" Halliburton TCP guns. C/O elevators. 01:00 06:00 5.00 AF OTHER Run 2 7/8" TBG. Marathon 1 24.00 Vetco I 6.00 M-I Drilling Fluids I 24.00 Weatherford Completion 2 36.00 Inlet Drilling 18 432.00 Halliburton TCP 2 28.00 Prinled: 3/14/2002 10:18:32 PM KENAI BELUGA UNIT 23X-6 OH 65.70 6 7 3/14/2002 SUPERVISOR RIG NAME & NO. I RIG PHONE AUTH MD AFL NO. IAFE COST R.C. Lawson GLACIER DRILLING 1I VIO.02.06464.EXp 400,000 i CURRENT STATUS J MOC WI J NRI DAILY WELL COST CUM WELL COST RIH w/2 7/8" long sting TBG.I 100.00 (%)~ 92.20 (%) '68,861.00 182,113.00 24 HR FORECAST ACCIDENTS 24HR LAST SAFE'PC MTG. BOP PS! TEST Run long string. Run short sting. N/D BOP. N/U tree. None 3/14/2002 3/11/2002 FIELD NAME I STATE/PROV COUNTY/OTHER'ILAST CASING NEXT CASING LEAKOFF PPG KenaiI Alaska Kena Boroughl 9.625 (in) @ 6,950 (ft) (in) @ 0 (ft) OP COMMENTS: RIH w/TCP guns. Perforate. POOH L/D guns. RIH w/2 3/8" stinger. Circulate seal bore clean. POOH. Pull Wear bushing. M/U and run 2 7/8" production assy and 2 7/8" long string TBG. 06:00 06:30 0.50 AF OTHER Cont. fllH w/2 7/8" TBG. 06:30 07:00 0.50 AF OTHER Space outto perforate. 07:00 08:30 1.50 AF OTHER R/U safety valve and circulation line. 08:30 09:00 0.50 AF OTHER Spot 49bbls LCM pill in annulus. 09:00 09:30 0.50 AF OTHER RJD circ. line. Drop bar to fire Halliburton 4 5/8" guns(guns fired in 2min). Lost 6 bbls fluid to the hole(perforated 4829' to 4906' 5SPF 60 DEG phase 39gm Millennium charges). 09:30 13:00 3.50 AF OTHER PJD safety valve and POOH. 13:00 13:30 0.50 AF OTHER L/D guns(100% fired). 13:30 14:30 1.00 AF OTHER Service rig. 14:30 19:00 4.50 AF OTHER RIH w/2 3/8" stinger. 19:00 20:30 1.50 AF OTHER Break circulation and RIH to bottom of packer seals @ 4999(positive indication of pressure increase when tagging bottom of seals). Pump 40bbl hi-vis sweep and circulate out. 20:30 00:30 4.00 AF OTHER POOH w/2 3/8" stinger. 00:30 01:00 0.50 AF OTHER Pull Wear Bushing. 01:00 03:00 2.00 AF OTHER Clean and organize rig floor. Prepare Long String TBG accessories. 03:00 05:00 2.00 AF OTHER M/U and RIH w/Long String production assy. 05:00 06:00 1.00 ~,F OTHER Run 2 7/8" 6.5PPF L-80 EUE 8rd TBG. R and K 1 12.00 Inlet Drilling 18 432.00 Marathon I 24.00 Weatherford Completion 2 36.00 M-I Drilling Fluids I 24.00 Halliburton TCP 2 28.00 Printed: 3/14/2002 10:18:34 PM KENAI BELUGA UNIT 23X-6 OH 96.38 7 3/15/2002 SUPERVISOR RIG NAME & NO.'IRIG PHONE AUTH MD AFE NO. IAFE COST R.C. Lawson GLACIER DRILLING 1I ~VO.02.06464. EXp 400,000 CURRENT STATUS I MOC WI ! NRI DAILY WELL COST CUM WELL COST Prepare to N/U tree. J 100.00 (%] 92.20 (%) 48,459.00 230,572.00 24 HR FORECAST ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST N/U tree. Test tree. R/D rig. Move dg. None 3/14/2002 3/11/2002 FIELD NAME' ' , STATE/PROV I COUNTY/OTHER I LAST CASING NEXT CASING LEAKOFF PPG KenaiI IAlaska Kenai Borough l 9.625 (in) @ 6,950 (ft) (in) ~ 0 (ft) OP COMMENTS: Run 2 7/8" TBG. Displace well to clean 3%brine. Land LS. C/O rams to 2 3/8" and test. Run 2 3/8" SS TBG. Set TVVC and N/D BOP. 06:00 09:30 3.50 AF RCMP Cont. RIH wi2 7/8" LS(total 155JNTS). 09:30 10:30 1.00 AF RCMP Sting into packer @ 4988'. Test seals to 500psi. Sting-out of packer and L/D top joint. 10:30 12:00 1.50 AF RCMP PJU circ. line and displace well to clean 3%KCL brine. Drift 2 3/8" TBG on the rack. 12:00 13:30 1.50 AF RCMP Space out w/4' 2 718" pup below first full JNTofTBG. M/UVetcoTBG hanger and 3 1/2" landing joint. Land hanger and tset tubing seals to 750psi. B/O 3 112' landing joint and L/D. 13:30 16:30 3.00 AF RCMP Set TWC in LS. Set SS hangerw/TVVC. C/O to 2 3/8" pipe rams. M/U 2 3/8" test joint to test fixture and test 2 3/8" rams to 250/3000psi 5min. L/D test joint and pull 2 3/8" hanger and set BPV in 2 7~8" LS. . 16:30 17:00 0.50 AF RCMP Organize rig floor. M/U safety valve and X/O for 2 3/8" 511 hydrill TBG. 17:00 00:30 7.50 AF RCMP Run 2 3~8" 4.7PPF Hydril 511 TBG(totaI153JNTS). ,. 00:30 01:30 1.00 AF RCMP N/U vetco TBG hanger and land out(end of SS TBG @ 4835') 01:30 02:30 1.00 AF OTHER Load outWeatherford and rig floor rotary tools. 02:30 06:00 3.50 AF XMBO C/O pipe rams to variable rams. N/D kill and choke lines. N/D flow line. N/D BOP. Marathon I 24.00 iWeatherford Completion 2 36.00 M-I Drilling Fluids 1 24.00 R and K 2 18.00 Inlet Ddlling 18 432.00 Vetco 1 18.00 LAST BOP TEST: 3/11/2002 LAST CASING TEST: NEXT BOP TEST: ' 9'6~5 I I 6,950 o I o ..... I " ' I ' ' ' , Printed: 3115/2002 9:27:51 A,M KENAI BELUGA UNIT 23X-6 OH 96.38 65.70 8 9 3/16/2002 SUPERVISOR RIG NAME & NO. RIG PHONE AUTH MD AFL NO. AFL COST R.C. Lawson GLACIER DRILLING 1 WO.02.06464.EXP 400,000 CURRENT STATUS MOC WI (%) NRI DAILY WELL COST CUM WELL COST Rig released to KTU 32-7H @ 12:00hrs 03/15/02. 100.00 92.20 (%) 15,448.00 246,020.00 24 HR FORECAST ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/14/2002 3/11/2002 FIELD NAME STATE/PROV COUNTY/OTHER LAST CASING NEXT CASING LEAKOFF PPG Kenai Alaska Kenai Borough 9.625 (in) @ 6,950.0 (ft) (n) @ (ft) OP COMMENTS: N/U tree and test. Begin R/D rig while empty and clean pits. 06:00 12:00 6.00 XMBO N/U tree. Test 2000psi/10min SS and LS. Pull TWC's and install BPV's. Fill tree w/methanol. R/D monkey board, pull mud pump valves, R/D Geronimo line. Clean pits. Rig released to KTU 32-7H @ 12:00hrs 03/15/2002. Marathon 1 24.00 R and K 2 12.00 M-I Drilling Fluids 1 24.00 Vetco 1 6.00 Inlet Drilling 18 108.00 Printed: 3/19/2002 7:58:4-2A, M MARATHON OIL COMPANY DALLY WELL OPERATIONS REPO, DATE: 3/26/2002 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field TUBING: 2 7/8" CASING: TREE CONDITION: Bail sand WIRE TEST: Continuing WBS # WELL #: KBU 23X-61 2 7/8" 8rd 21 CC20284500 TOOL STRING: WIRELINE CREW: RSO #: 455-864 SUMMARY OF OPERATIONS RS, K J, 10' Stem, K J, O J, SJ Vowell/Tomlinson/Belden Hrs. 12 PROD: X DRILL: Ticket #: P-140 Travel to location Held safety meeting R/U, test Lub, test - OK Ran 2" DD Bailer, tagged up at 4989' RKB, beat through, went to 5034' RKB, beat down, POOH, had small recovery of sand, scale and metal Ran 2" Pump Bailer, 9 trips, bailed sand, scale and metal from 5034' to 5045' RKB, recovered large particals of metal and other trash, total recovery 2 gal of trash & 7 gal of slushy water R/D Travel to Shop Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. 12 hr min $2,080.00 $2,080.00 Pollard Wireline Inc. 2" DD Bailer $100.00 $2,180.00 Pollard Wireline Inc. 2" Pump Bailer $100.00 $2,280.00 Pollard Wireline Inc. 1 Flapper Bottom $127.00 $2,407.00 Pollard Wireline Inc. DALLY COST: $2,407.00 CUM: REPORTED BY: Cannot read signature MARATHON OIL COMPANY DALLY WELL OPERATIONS REPO', DATE: 3/27/2002 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field TUBING: 2 7/8" CASING: 3/26/2002 TREE CONDITION: Bail sand & fish for GLV WIRE TEST: Continuing WBS # WELL #: KBU 23X-61 2 7/8" 8rd 21 CC20284500 TOOL STRING: WIRELINE CREW: RSO #: 455-864 SUMMARY OF OPERATIONS RS, K J, 10' Stem, K J, O J, SJ Vowell/Tomlinson/Belden Hrs, 12 PROD: X DRILL: Ticket #: P-141 Travel to location Held safety meeting Cut and test wire, made new Rope Socket R/U Ran 2" Pump Bailer, 8 trips, recovering sand, scale & metal from 5044' RKB to 5055' RKB Ran 1 5/8" JDC P/T to 5053' RKB, could not latch Valve, POOH Ran 2" Bailer, 2 trips, recovering small amounts of sand Had marks on Bailer bottom of Gas Lift Valve Ran 1 5/8" JDC to 5053' RKB, could not latch GLV, POOH Ran 2" Bailer, bailed at 5053', had small recovery R/D for night Travel to Shop Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. 12 hr min $2,080.00 $2,080.00 Pollard Wireline Inc. 2" Pump Bailer $100.00 $2,180.00 Pollard Wireline Inc. 1 5/8" JDC Pulling Tool $75.00 $2,255.00 Pollard Wireline Inc. Fuel $50.66 $2,305.66 Pollard Wireline Inc. DAILY COST: $2,305.66 CUM: REPORTED BY: Cannot read signature MARATHON OIL COMPANY DALLY WELL OPERATIONS REPOI DATE: 3/28/2002 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: Kenai Gas Field WELL #: KBU 23X-61 TUBING: 2 7/8" CASING: 3/27/2002 TREE CONDITION: 2 7/8" 8rd WIRE TEST: 21 Bail sand, pull PX Plug Complete OTHER: WBS # CC20284500 RS, K J, 10' Stem, K J, O J, SJ Hrs. 12 TOOL STRING: WIRELINE CREW: RSO #: 455-864 SUMMARY OF OPERATIONS Vowell/Tomlinson/Belden PROD: X DRILL: Ticket #: P-143 Travel to Field Held safety meeting R/U, P. T. Lub -OK Ran 2" Pump Bailer, 2 trips, recovering small amount of sand from 5053' RKB Ran 2.25" LIB to 5053' RKB, had impression of PX Prong Ran 2" JDC to 5053'RKB, latched Prong, beat up w/Oil Jar hitting 1500 # licks for 1 hour, came free, POOH w/Prong Ran 2" Bailer and belled from 5054' to 5057' RKB, made 5 trips, recovered mud, sand and meta Ran 2 1/2" GS P/T to 5057' RKB, latched and pulled 2 1/2" PX Plug R/D, moved equipment to Bull Rail Travel to Shop Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. 12 hr min $2,080.00 $2,080.00 Pollard Wireline Inc. 2" Pump Bailer $100.00 $2,180.00 Pollard Wireline Inc. 2 1/2" GS Pulling Tool $75.00 $2,255.00 Pollard Wireline Inc. 2" JDC $75.00 $2,330.00 Pollard Wireline Inc. Fuel $63.30 $2,393.30 DALLY COST: $2,393.30 CUM: REPORTED BY: Wayne Cissell MARATHON OIL COMPAN~ DALLY WELL OPERATIONS RL FIT PAGE I OF 1 DATE: 4/1/2002 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field WELL #: KBU 23X-61 TUBING: 2 7/8" CASING: 3/5/2002 TREE CONDITION: Good BENCHES OPEN: Sterling jet well in following workover WlRELINE CREW: Hrs. SUMMARY OF OPERATIONS BJ arrived on location, RU PT flow lines to 3000 psig, RIH w/1 3/4" coil, with a 2" no771e, CT at 2051' returns to flow back tank (FB) WHP = 26 psig, PIP = 1040 psig, PIR on N2 @ 600 SCF. Work CT down well Ct @ 3238 KB. WHP= 59 psig, PIP = 1319 lbs. PIR= 750 SCFM. good returns to tank. 40 bbls back from well when CT @ 4147'. Pick up weight @ 13300 lbs, WHP = 107 psig, total N2 pumped = 31512 SCF, CT @ 5670 KB, Rate @ 550 SCFM CT @ 6472 KB, PIP = 1881 psig, PIR = 500 SCFM, Total N2 pumped = 92778 SCF. CT sat down at 6640 KB, WHP = 978 psig, PU to 6600 KB RIH with CT to 6733 KB, WHP=m 870 psig, Vac truck pulled 1 load off of the flow back tank. open up choke to FB tank. Increased N2 rate to 1000 SCFM, WHP= 555 psig, total N2 pumped = 117, 300 SCF water flow back tank dropped off to a trickle, when CT @ 6000 KB, Increased rate to 1200 SCFM, work CT up hole when CT at 5585 KB dropped N2 rate back to 750 SCFM, WHP= 357 psig, PIP = 1755 psig, N2 pumped = 161,775 SCF. PU CT to 4902 KB, Shut down N2, small returns of water to tank, well does not appear to be picking up pressure to the FB tank. Decide to POOH with CT. POOH with N2 at 750 psig, CT @ 4390 KB, total N2 pumped 179, 405 SCF, WHP = 650 psig. When CT @ 1047 KB, WHP = 118 psig, no returns to tank, PIP 85 psig, iWHP= 70 psig, let well flow to FB tank for 10 minutes, metered gas to tank. Rig aside CT incase we decide to Rig back up on well tomorrow. Placed well to production to meter any gas to system. At 2000 hour the well was flowing 640 MCF to production. WHP- 116 psig. Total water flowed back 110 bbls Vendor Equipment Daily Cost Cumulative Cost BJ Services coil & nitrogen $37,000.00 DAILY COST: CUM: $41,000.00 REPORTED BY: Wayne Cissell MARATHON OIL COMPANY DALLY WELL OPERATIONS RE[ r PAGE 1 OF 1 DATE: 4/17/2002 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field WELL #: TUBING: 2 7/8" CASING: 4/1/2002 TREE CONDITION: RIH with coil to 6733', jet well in BENCHES OPEN: Perf Beluga U1, U2, & U7 Sands WlRELINE CREW: KBU 23X-61 Good Beluga Hrs, SUMMARY OF OPERATIONS MIRU Schlumberger on KBU 23x-61. Shut in well at wing valve (had been flowing about 600 MCFD). Held prejob safety meeting. Pressure test lubricator. RIH with GR/CCL log. Located fluid level at 4260'. Log 4900' - 6000', correlate to RST log of 2/28/01. POOH. PU 32' of 2-1/8", 6 spf, 0 degree phase Enerjet strip guns with 14.4 gm Powerjet charges. Tie in with CCL. SlTP = 300 psi. Perforate the U7 Sand from 5398' - 5430'. No apparent change in surface pressure. POOH. PU 12' of 2-1/8", 6 spf, 0 degree phase Enerjet strip guns with 14.4 gm Powerjet charges. Tie in with CCL. SITP = 400 psi. Perforate the U7 Sand from 5153' - 5165'. No apparent change in surface pressure. POOH. PU 15' of 2-1/8", 6 spf, 0 degree phase Enerjet strip guns with 14.4 gm Powerjet charges. Tie in with CCL. SITP = 500 psi. Re-perforate the U7 Sand from 5115' - 5130'. No apparent change in surface pressure. POOH. RDMO Schlumberger. Note: Opened well to production. Well went to 130 psig with no flow to separator. Shut in well to bull head gas down tubing to displace H20. Vendor Equipment Daily Cost Cumulative Cost Schlumberger electric line $0.00 Veco crane $0.00 Misc. $1,000.00 $1,000.00 DAILY COST: $1,000.00 CUM: REPORTED BY: Gary Eller / Wayne Cissell -. MARATHON OIL COMPANY ,,'/~-' DAILY WELL OPERATIONS RE PAGE 1 OF 1 DATE: 10/23/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field WELL #: 23X-6L TUBING: 2 7/8" CASING: 9 5/8" 10/14/2001 TREE CONDITION: Good Gas Valve C/O, C/O Orifice BENCHES OPEN: Complete WIRELINE CREW: Whitaker/Watson Twist test wire - 23 turns Hrs. 14 SUMMARY OF OPERATIONS Arrive @ MOC, meet w/Foreman, discuss job Check equipment, hold safety meeting Move equipment to 14-6 Pad & spot up Remove snow around Tree to make accessable R/U, pressure test to well bore RIH w/2 7/8" OM-1 KOT & 1 1/2" JDC to 4834', sat down, worked tool, couldn't pass, POOU OOH, discussed w/Foreman RIH w/2.25" LIB to 4834', sat down, POOH, no discerning marks on bottom RIH w/1.85" GR to 4950', POOH, no problems RIH w/2.30" GR to 4834', beat down 30 times, worked free, POOH RIH w/2.0" LIB to 4950', POOH, sides of LIB many marks RIH w/2.25" LIB to 4834', beat down 5 times, POOH w/many marks on sides of LIB RIH w/2.15" GR to 4960', POOH, no problems RIH w/2.25" Swedge to 4834', work through to 4844', worked through to 4864', work through, pull up and down from 4830' to 4900', several times, POOH RIH w/2 7/8" OM-1 KOT & 1 1/2" JDC to 4924', latch and pull 1 1/2" Orifice Valve, POOH RIH w/2 7/8" OM-1 & 1 1/2" Dummy to 4924', set Dummy, POOH R/D, clean up, move equipment to MOC Depart MOC Tool Cost: 1.85" Gauge Ring $50.00 2.0" LIB . $50.00 2.25" LIB $50.00 2.25" Swedge $50.00 2.15" Gauge Ring $50.00 1 1/2" JDC $75.00 2 7/8" OM-1 KOT $300.00 Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. Tools $625.00 $625.00 Pollard Wireline Inc. Unit & Crew 12 hr min $1,830.00 $2,455.00 Pollard Wireline Inc. 2 add hrs $250.00 $2,705.00 DAILY COST: $2,705.00 CUM: $2,705.00 REPORTED BY: S. Bookey MARATHON OIL COMPAN~i DATE: FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: Unknown DALLY WELL OPERATIONS R T changed dummy valve to orifice PAGE 1 OF 1 FIELD: Kenai Gas Field WELL #: ~';,.'.., 23X-6L TUBING: 2 7/8" CASING: 9 5/8" 10/15/2001 TREE CONDITION: Good BENCHES OPEN: pump N2 on back side WIRELINE CREW: wireline unit installed double check in mandrel Hrs. SUMMARY OF OPERATIONS Contacted Anchorage engineering determined that the gun on the back side would not fire unless we pressured up the 2 7/8" tubing to 4100 psi, BJ N2 still hooked up the long string. Cool down unit and pressure up the tubing brought the tubing up to 900 psig. Back side pressure climbed to 250 psig while bringing up the tubing. SD pumping the N2. blow down the back side pressure to 75 psig. Had the BJ N2 pump pressure back up to 500 psig, Back side pressure rose to 150 psig, SD N2. blew down the back side to 50 psig, RD BJ services Vendor Equipment Daily Cost Cumulative Cost BJ Services N2 pump unit $6,518.00 $6,518.00 DAILY COST: $6,518.00 CUM: $29,400.00 REPORTED BY: Wayne Cissell MARATHON OIL COMPANY1 DALLY WELL OPERATIONS R .T PAGE I OF 1 DATE: 10/17/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field WELL #: Unknown TUBING: 2 7/8" CASING: 10/15/2001 TREE CONDITION: changed dummy valve to orifice BENCHES OPEN: pump N2 on back side WlRELINE CREW: KBU 23X-61 9 5/8" Good wireline unit installed double check in mandrel Hrs. SUMMARY OF OPERATIONS RU BJ N2 unit to back side of well. MU chicksan to long string through gas buster. PT lines to 3000 psig. Break out leaking 90 deg. Ell, PT lines held, ready to pump N2. Start down hole with N2. Instructed to maintain less than 600 psig on PIP. N2 at 600 scfpm. Returns to open top tank. 21 bbls back to tank. Increase rate to 1050 psig, after 114 bbls back to tank. Increase rate to 1350 psig, after 170 bbls back to tank. maintain rate until returns stopped and N2 blowing down to tank. Shut in N2. Est. total = N2 @ 3150 gal., 293000 scf., 314 bbls water flown back to the open top tank. Blown the back side pressure to 75 psig on the back side of the well. Start pressuring up on the long string to fire guns. PU to 2900 psig. Wait 5 minutes, no indication that the guns fired. PU to 3100 psig, no indication that the guns fired. PU to 3400 psig. No change on the back side pressure. Shut down N2 pump and wait till am to try and see if well builds pressure over night on the back side of the well. Before rigging down the N2 truck. Note:discuss with Engineering in Anchorage in morning on why no indication that the guns fired when pressured up on the 2 7/8" tubing. Vendor Equipment Daily Cost Cumulative Cost BJ Services N2 pump unit $22,704.00 $22,704.00 DAILY COST: $22,704.00 CUM: $22,704.00 REPORTED BY: Wayne Cissell MARATHON OIL COMPANY DALLY WELL OPERATIONS R ,T PAGE 1 OF 1 DATE: 10/15/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: Unknown FIELD: Kenai Gas Field WELL #: 23X-6L TUBING: 2 7/8" CASING: 9 5/8" TREE CONDITION: Good C/O Gas Lift Valve BENCHES OPEN: Complete WIRELINE CREW: Whitaker/Lewis Wire test - 24 turns Hrs. 3 SUMMARY OF OPERATIONS Arrive @ MOC, meet w/Foreman, discuss job TGSM R/U, test Lub & WLV to Well Bore Pressure, test - good RIH w/2 7/8" OM-1 & 1 1/2" Orifice Valve to 4924', set Valve, POOH OOH Meet w/Foreman R/D, move equipment to KU 21-6RD Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. 2 7/8" OM-1 $150.00 $150.00 Pollard Wireline Inc. 3 of 12 hr min $457.50 $607.50 DAILY COST: $607.50 CUM: $607.50 REPORTED BY: Wayne Cissell MARATHON OIL COMPANY DALLY WELL OPERATIONS R .T PAGE I OF 1 DATE: 10/13/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field WELL #: 23X-6L TUBING: 2 7/8" CASING: 9 5/8" TREE CONDITION: Good C/O GL Valve BENCHES OPEN: In progress WIRELINE CREW: Whitaker/Lewis Wire twist test - 24 turns Hrs. 7 SUMMARY OF OPERATIONS R/U RIH w/2 7/8" OM-l, sat down @3', Ice Plug Pour 1 1/2 gal of Methanol in Tree RIH w/1.90" GR, hand spang for 15 min, let set, hand spang for 15 min, let set, work tool, fell through run down to 700', POOH RIH w/2 7/8" OM-l, locate Mandrel @ 4920', pull Valve, POOH, no Valve Redress KOT RIH w/same to 4920', locate, sit down, POOH, JDC sheared, redress tools RIH w/same to 4920', latch and pull Dummy Valve, POOH w/Valve RIH w/2 7/8" OM-1 & I 1/2" Orifice Valve to 4924', locate but can't sit down, POOH OOH w/Valve Call Wayne, no lights to work by R/D, secure well for nite Depart MOC Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. 1 1/2" JDC $75.00 $75.00 Pollard Wireline Inc. 2 7/8" OM-1 KOT $300.00 $375.00 Pollard Wireline Inc. 1.90" Gauge Ring $50.00 $425.00 Pollard Wireline Inc. 7 of 12 hr min $1,067.50 $1,492.50 Pollard Wireline Inc. 3 add hrs $375.00 $1,867.50 DAILY COST: $1,867.50 CUM: $1,867.50 REPORTED BY: Wayne Cissell Marathon RPT#: 15 DATE: 06/22/01 LOCATION DAY~.'. 14 SPUD DAYS: Oil Company ' *-. 9207101 GL: KE. MOC WI: WELL: KBU 23X-6 RIG: Glacier Drilling Rig 1 FTG: 0 DEPTH: (MD) 5,900 (TVD) 4,966 ~SG SIZE: 9.625 CSG MD: 6,800. CSG TVD: 6,301. SHOE TEST: - MAX. SI 0 LINER TOP: PRESENT OP:RIG RELEASED FROM KBU 23X-6 @ O0:OOHRS 6/22/01. CONT. RUNNING 2 3/8" SHORT STRING. LAND HANGER. SET 2-WA Y CHECK IN SS. CLEAR DERRICK AND EXECUTIVE RIG FLOOR. CHANGE OUT TOP RAMS ON BOP TO 2 7/8". N/D BOP. N/U X-MAS TREE. REMOVE BPV IN LS SUMMARY AND REPLACE W/2-WA Y CHECK. TEST TREE VOID TO 5000PSI. TEST LS AND SS ON TREE TO 250/5000PSI. (MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE 8.5 1261 I I I I I I .I. I [ /32 J I I PPB PPB PPB (OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES (bblift! BKGD CONN TRIP MAX daily cum ( BIT# SIZE TYPE OFF FIG HRS FTIHR RPM WOB I O D L B GOT R CPF COMMENTS ( BIT # SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP~ / / / / / I I BHA: Length: DRILL PIPE DESCRIPTION ' MAX PULL: ( JARS MW~ MOTOR TORQUE WEIGHT (1-000) - I 1 I I f 1 IBHA: PU Rot -So Eft' (MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. N/S E/W DOG LEG { OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 7:00 %00 CONT. RUN 2 3/8" 4.6PPF L-80 HYDRIL 511 TBG SHORT STRING(TOTAL 151 JOINT RUN). 7:00 8:00 1.00 M/U 2 3/8" TBG HANGER ASSY. LAND HANGER. PULL BPV FROM 6" ANNULUS VALVE AND VlSUALLY VERIFY HANGER LANDED. REPLACE BPV IN 6" ANNULUS VALVE. SET 2-WAY CHECK IN 2 3/8" SHORT STRING. 8:00 9:30 1.50 ED 4 JOINTS 2 7/8" TBG FROM DERRICI~ R/D WEA THERFORD TUBING RUNNING EQUIPMENT. CLEAR RIG FLOOR. 9:30 12:00 2.50 CHANGE OUT TOP RAMS IN BOP TO 2 7/8" RAMS. 12:00 14:30 2.50 N/D BOP. 14:30 15:30 1.00 N/U X-MAS TREE. REMOVE BPV FROM LONG STRING AND REPLACE WITH 2-WA Y CHECK. 15:30 18:00 2.50 TEST TREE VOID TO 5000PSI. TEST LONG STRING AND SHORT STING ON X-MAS TREE TO 250/5000PSL PULL 2-WAY CHECK IN LS AND SS AND REPLACE W/BPV. 18:00 0:00 6.00 CLEAN MUD PITS. RIG RELEASED TO FALLS CREEK #I @ O0:OOHRS 06/22/01. AFE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 05/27/01 DALLY: 625 CUM: 17,691 DAILY: 185,505 CUM: 690,512 NO ACC/DENTS REPORTED TODAY DRILLING SUPERVISOR: R.C. LAWSON '- Marathon R~# '. 14 DATE: 06/21/01 LOCATION DAYS: 13 SPUD DAYS: -.. Oil Company · .~ 9207101 GL: KB: MOC WI: WELL: KBU 23X-6 RIG: Glacier Drilling Rig I FTG: 0 DEPTH: (MD) 5,900 (TVD) 4,966 ~SG SIZE: 9.625 CSG MD:--6,800. CSG TVD: 6,30~--- - SHOE TES~: MAX. SI 0 LINER TOP: PRESENT OP:RIH W/2 3/8" TBG SHORT STRING(RUN 130 OF ~51 JNTS). CONT. RIH WI2 7/8" Y-BLOCK COMPLETION LONG STRING. TUBING CONNECTIONS ABOVE THE Y-BLOCK EXECUTIVE HANGING ON THE SQUARE SHOULDER OF THE TOP OF THE CSG PATCH. POOH AND CHANGE 22 JOINTS SUMMARY ABOVE Y-BLOCK TO SPECIAL CLEARANCE CONNECTIONS. RIH AND STING INTO PACKER @ 4988'. SPACE OUT AND LAND TBG HANGER AND TEST TBG SEALS TO 500PSL RIH W~ 2 3/8" S. STRING. (MW VIS PV YP GELS WL T 7.5 30 "T FC CEC SAND SLO BENT SALT DRILLED BARITE ( 8;1~. 126II1 / I [ [ / II 132 I I / PPB ~PB 'PPB WTR, pH Pm Pf Mf 'CL CA LIME MUD LOSSES tbbl/ftt BKGD CON~I TRIP- ( BITe SIZE ~PE OFF FTG HRS FTIHR RPM WOB IO D L B G OT R CPF COMMENTS ( BIT ~ SERIAL~ PRESS. GPM JETS TFA ANNU~R VELOCI~ BIT HP~ BHA: Length: DRILL PIPE DESCRIPTION: ' ' M~ PULL: ( JARS MW~ MOTOR TORQUE WEIGHT (~000) ' I 1 I 1 I 1 iBHA: Pa- Rot S°- -Eft (MB. DEPTH ANGLE DIRECTION ~D VERT. SEC. N/S ~ , DOG LEG ) I{ OPE~TIONS I" SEQUENCE START END HOURS DESCRIPTION 6:00 7:00 ~.00 CONT. RIH WI2 7/8" Y-BLOCK COMPLETION ASSY. 7:00 7:30 0.50 CONNECTION ON 2 7/8" TBG ABOVE Y-BLOCK HANGING ON SQUARE SHOULDER OF CSG PATCH. 7:30 9:00 1.50 CHANGE ELEVATOR BAILS TO SHORT BALLS. 9:00 ~:00 4.00 POOH TO Y-BLOC~ ASSY R4C~NG eACK 2 7/~" reG. 13:00 14:30 1.50 P/U 22 JOINTS 2 7//8" TBG W/SPECIAL CLEARANCE CONNECTIONS RUNNING IN HOLE. 14:30 17:00 2.50 CONT. RIH WI2 7/8" ~BG FROM DERRIC~ 17:00 ~8:30 ~.50 ROTATE MULE sHOE 1/2 TURN TO GET INTO CSG PATCH. CONT. RIH W~-BLOCK ASSY AND STING INTO PACER ~ 498~ ~:30 20:00 1.50 PJSM. SPACE OUT AND ~ND 2 7/8" TBG HANGER~OTAL 158 JOINTS 2 7/8" TBG) . DRAIN STACK AND VISUAL Y VERIFY TBG HANGER HAS LANDED. 20:00 20:30 0.50 ~U TEST LINE AND TEST TBG SEALS TO 500PSI DOWN TBG. ~D TEST LINE. BIO AND ~D ~NDING JOINT. SET BPV IN HANGER. 20:30 21:3~ 1.00 CHANGE OUT TOP PIPE RAMS FROM 2 7/8" TO 2 3/8". 21:30 6:00 8.50 PJSM. M/U 2 3/8" ~RELINE ENTRY GUIDE AND X-N NIppLE. RIH WI 2 ~/8" 4. GPPF L-80 HYDRIL 511 TBG(RUN ~30 OF ~51 JOINTS). ~FE: DH TSTICSG COMP TOT ~ST PIT DRILL DATE: 05/27/0~ ~MUD COSTS ACTUAL ~{~:~:.~:. ~ ~ WELL COSTS ACTUAL ~ST BOP TEST DATE: 06/01/01 DAILY: 625 CUM: 17,066 DAILY: 24,846 CUM: 505,006 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: R.C. '~WSON ........ . Marathon ~..1:# - 13 DATE: 06/20/01 LOCATION DA,,_.,_.,YS- 12 SPUD DAYS: Oil Company 9207101 GL: KB: MOC WI: WELL: KBU 23X-6 RIG: Glacier Drilling Rig 1 FTG: 0 DEPTH: (MD) 5,900 (TVD) 4,966 CSG SIZE: 9.625 CSG MD: 6,800. CSG TVD: 6,301. SHOE TEST: MAX. SI 0 LINER TOP: PRESENT OP:RIH W/Y-BLOCK COMPLETION ASSY ON 2 7/8" TBG. RIH W/Y-BLOCK COMP. ASSY. COULD NOT PASS 4297: POOH W/COMP. ASSY. RUN 7.6" GAUGE RING JUNK EXECUTIVE BASKET ON EL TO 4350: RIH W/Y-BLOCK COMP. ASSY. SUMMARY ~MW VIS PV YP GELS WL T 7.5 30 "T FC CEC SAND SLD BENT SALT DRILLED BARITE 8.5 1261 I I I I J I .I. J I 132 I I / PPB PPB PPB ~ WTR pH Pm Pf Mf CL CA LIME MUD LOSSES lbbl/ft~ BKGD CONN TRIP MAX ~ BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOB IO D L B GOT R CPF COMMENTS ( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT / / / BHA ' Length: DRILL PIPE DESCRIPTION: MAX PULL: ( JARS MW6 MOTOR TORQUE WEIGHT (1~)00) - ~ MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. N/S E/W DOG LEG ~ OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 13:00 7.00 CONT. RIH W/COMPLETION ASSY ON 2 7/8" 6. SPPF L-80 TBG. TO 4297'(BOTTOM OF GUNS 2' BELOW TOP OF PATCH @ 4202~. ATTEMPT TO WORK Y-BLOCK COMP ASSY PAST 4297' WITHOUT SUCCESS. 13:00 17:30 4.50 PJSM ON PULLING COMPLETION. POOH W/COMPLETION ASSY RACK BACK 2 7/8" TBG. 17:30 19:00 1.50 PJSM ON LAYING DOWN TCP GUNS. L/D GUNS AND Y-BLOCK ASSY. INSPECTION OF COMPLETION ASSY INDICATED THAT ASSY WAS HANGING UP DUE TO SQUARE SHOULDER TO SQUARE SHOULDER CONTACT WITH THE CSG PATCH. 19:00 19:30 0.50 BEVEL SQUARE SHOULDERS ON Y-BLOCK WITH GRINDER. 19:30 21:00 1.50 PJSM FOR RUNNING ELECTRIC LINE. R/U SCHLUMBERGER. 21:00 22:30 1.50 RIH W/7.6" GUAGE RING W/JUNK BASKET TO 4350'(HAD TO MAKE SEVERAL RUNS TO GET GAUGE RING TO ENTER CSG PATCH). POOH W/GAUGE RING/JUNK BASKET. R/D SCHLUMBERGER. 22:30 23:30 1.00 P/U Y-BLOCK COMPLETION ASSY(CHANGE BOX CONNECTIONS OF 2 7/8" TBG BELOW Y-BLOCK AND ADJACENT TO THE TCP GUNS TO REDUCED CLEARANCE BEVELED CONNECTIONS). 23:30 1:00 1.50 PJSM FOR RUNNING TCP GUNS. P/U 3 3/6" 60DEG PHASE 6SPF TCP GUNS. ~,FE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 05/27/01 ~i~?i.~?..~:.:i~ LAST BOP TEST DATE: 06/01/01 ~:~ii:~::.'il MUD COSTS ACTUAL !~i ii;.~i!~i~ I WELL COSTS ACTUAL DAILY: 625 CUM: 16,441 DAILY: 27,425 CUM: 480,160 NO ACCIDENTS REPORTED TODAY DRILLING S'UPERVISOI~': R.C. LAWSON " - Well: KBU 23X-6 ~,-~--,.~ Date: 20-Jun-01 Operations Cont (d) SEQUENTIAL OPERATIONS (REPORT TIGHT SPOTS, LOC. TORQUING UP PROBLEMS, ETC.: 112 HOUR MINIMUM START END HOURS DESCRIPTION 1:00 6:00 5.00 RIH W/COMPLETION ASSY ON 2 7/8" TBG. -- ., . Marathon .~.T#'~,_ 12 DATE: 06/19/01 LOCATION DAYg- 11 SPUD DAYS: Oil Company ~ ~ 9207101 GL: KB: MDC WI: WELL: KBU 23X-6 RIG: Glacier Drilling Rig I FTG: DEPTH: (MD) 5,900 (TVD) 4,966 ~SG S~ZE: 9.625 CSG Mb: 6,800. CSG TVD: 6,301. SHOE TEST: - MAX. SI 0 LINER TOP: PRESENT DP:. RUNNING 2 7/8" TUBING W~ "Y" BLOCK PERFORA TING GUNS R.I.H. W / CSG. PATCH -- SET AND SHEAR OUT@ 3200 PSI / LA Y DOWN CSG. TOOLS, AND ALL DRILL EXECUTIVE PiPE / INSTALL 2 7/8" RAMS, TEST DOOR SEALS, RIG UP, HOLD PRE-JOB SAFETY MEETING RUN SUMMARY TBG. AND "Y" BLOCK PERFORATING GUNS (MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE 8.5 126~ I1 i I II i j [ /32 J I I PPB PPB PPB! (OIL WTR pH ,Pm Pf Mf 'CL CA LI,ME MUD LOSSES tbbllft) BKGD CONN TRIP MAX ! BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOB IO D L B G CT R CPF COMMENTS ,( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP~ ! BHA: Len§th ' DRILL PiPE DESCRIPTION: MAX PULL: - ( JARS MWD MOTOR TORQUE WEIGHT (1~)00) ................ .............................. ,. ................................................. _ ................ ......................................................... ....... : ................. ( MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. N/S E/W DOG LEG ' ( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 8:30 2.50 R. LH. WITH CASING PATCH TO 4315 8:30 1 ~ :00 2.50 RIG UP E- LINE / DETERMINE SETTING DEPTH FOR CSG. PA TCH /RIG DOWN 11:00 12:30 1.50 SET 103' CSG. PATCH/TOP @ 4200/BTM. @ 4303' 12:30 18:00 5.50 P.O.H. LAYING DOwN DRILL PIPE 18:00 21:00 3.00 R.I.H. PIPE IN DERRICK / LAY DOWN SAME 21:00 23:00 2.00 PULL WEAR RING / SET TEST PLUG AND INSTALL 2 7/8" RAMS I TEST B.O,P.S 23:00 2:00 3.00 PICK UP LONG BALES / RIG UP CASERS / HOLD SAFETY MEETING ! 2:00 6:00 4.00 PICK UP LOCA TOR SEAL ASSr/WOULD NOT DRIFT/PICK UP PERF. GUNS AND R.I.H. / . RUN REBORED SEAL ASS'Y , GLM , TUBING, AND MAKE UP 'Y' BLOCK CONNECTION / . AFE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 05/27/01 ~iii MUD cosTs ACTUAL ii WELL COSTS ACTUAL i!i*i;i:::;i:ii;!;iii:. LAST BOP TEST DATE: 06/01/01 DAILY: 2,163 CUM: 15,816 DAILY: 93,605 CUM: 452,735 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR-~ J.C. LORENZEN " Marathon ~R~-~T# ' 11 DATE: 06/18/01 LOCATION DAYS' 10 SPUD DAYS: Oil Company .~ 9207101 GL: KB: MOC WI: WELL: KBU 23X-6 RIG: Glacier Drilling Rig 1 FTG: DEPTH: (MD) 5,900 ('rVD) 4,966 CSG S~E: 9.625 CSG M~)~' 6-,800. CSG TVD: 6,301. ~HOE TEST~ MAX. SI 0 LINER TOP: PRESENT OP:R.I.H. WI CASII~G PATCH INSTALL TBG. SPOOL/NIPPLE UP AND TEST B.O.P. S / PULL STORM PACKER/RIG UP AND RUN (2) EXECUTIVE GUAGE RINGS ;WlRELINE SET PACKER ~ 4988'/PICK - UP-- MAKE UP CASING PA TCH AND R.I.H. ON SUMMARY DRILLPIPE (MW VIS PV YP GELS WL T 7.5 30 "T FC CEC SAND ELD BENT SALT DRILLED BARITE 8.s 12611I I ) I I I I I 132 I I / PPB PPB_ PPB ~OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES {bbllft) BKGD 'coNN TRIP MAX 1 I 7.5 1 1 I 15'000I 1 idaily cum 1 J. 1 [ ( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY , BIT HP) BHA: I_ength: DRILL PIPE DESCRIPTION: MAX PULL · ( .JARS ~W~ MOTOR TORQUE WEIGHT Ca000} f 1 I _ 1 I [ BHA'. Pu -Rot so ' Eft ~MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS E/W DOG LEG ( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 9:30 3.50 ;NIPPLE UP TUBING SPOOL AND B.O.P." S 9:30 10:30 1.00 TEST TO 1000 PSI/SET WEAR RING 10:30 12:30 2.00 PICK UP STORM PACKER TOOLS AND T.'I.W. VAL VE / R.I.H. TO 85'AND RETRIEVE STORM PACKER 12:30 ~'5:30 3.00 P.O.H. LAYING DOWN BHA 15:30 18:30 3.00 RIG UP SCHLUMBERGER / 1 ST. RUN GUAGE RING TO 5000'/ BROUGHT RUBBER AND .09; WIRE 1ST. RUN /2ND RUN TO 5500' O.K. 18:30 23:30 5.00 PICK UP 3 JTS. 2 7/8" TAILPIPE WI MULESHOE; (2) "X" NIPPLES AND MAKE uP TO WIRE- LINE RUN PACKER/RUN AND SET @ 4988'/ W/L ENTRY @ 5100 23:30 0:30 ~.00 RIG UP TO RUN CASING PATCH/PRE-JOB SAFETY MEETING 0:30 4:00 3.50 MAKE UP CASING PATCH 4:00 6:00 ZOO R. LH. SLOW ON DRILLPIPE / ~,FE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 05/27/01 i!' ~!i~!I-MUD COSTS ACTUAL ~i ~;i;~i~i::il WELL COSTS ACTUAL I.:~i!! ?ii:ii.:. LAST BOP TEST DATE: 06/01/0~ DAILY: 625 CUM: 13,653 DAILY: 47,560 CUM: 359,130 NO ACC/DENTS REPORTED TODAY DRILLING SUPERVISOR'-: J. C. -LORENZEN - Marathon RP~T#: 10 DATE: 06/17/01 LOCATION DAY~' 9 SPUD DAYS: Oil Company ! 9207101 GL: KB: MOC WI: WELL: KBU 23X-6 RIG: Glacier Drilling Rig I FTG: DEPTH: (MD) 5,900 (TVD) 4,966 CSG SIZE: 9.625 CSG MD: 6,800. CSG 'I'VD: 6,301'~ ~HOE TES:I': MAX. SI 0 LINER TOP: PRESENT OP: NIPPLE UP ADDITIONAL TUBING SPOOL R. LH. W/CSG. SCRAPER, STRING MILL, REAM THRU PERFS @ PROPOSED CASING PATCH / P.O.H. AND EXECUTIVE SET STORM PACKER @ 85'/TEST TO 1000 PS! / NIPPLE DOWN STACK / INSTALL ADDITIONAL TUBING SUMMARY SPOOL (MW VIS PV YP GELS WL T 7.5 30 "T FC CEC SAND SLD BENT SALT DRILLED BARITE 8.5 1261 I I / I I I I ,I I 132 .J [ I PPB PPB PPB i~OIL WTR pH Pm Pf Mf CE CA LIME MUD LOSSES tbbl/ft) BKGD CONN TRIP MAX ] I 7.5 1 1 I15'000 I Idaily cum ( BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB I0 D L B GOT R CPF COMMENTS ( BIT# SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP~ BHA: Length: DRILL PIPE DESCRIPTION: MAX PULL · ( JARS MWD MOTOR TORQUE WEIGHT (1~)00) [ 1 I I I 1 IBHA: pU Rot So -Eft (MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. N/S E/W DOG LEG ~ OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 7:30 1.50 PUMP HIGH rISC. SWEEP 7:30 12:30 5.00 P.o.H' 12:30 13:30 1.00 LA Y DOWN PACKER MILL AND CLEAN JUNK BASKETS/MAKE UP BIT, CSG. SCRAPER AND STRING MILL (B.H.A. # 5) 13:30 16:00 2.50 R.I.H. TO 4153, 16:00 16:30 0.50 CHANGE OUT WASHPIPE / SERVICE RIG 16:30 18:30 ZOO R.I.H. - REAMING THRU 4153' TO 4340' AND 6665' TO 6695' (TIGHT @ 66957 / WASH - REAM TO 6781' 18:30 19:30 1.00 PUMP HIGH VISC. SWEEP 19:30 23:00 3.50 P.O.H. 23:00 0:00 1.00 PICK UP STORM PACKER / SET @ 85'/ TEST TO IOOO PSI / O.K. 0:00 6:00 6.00 NIPPLE DOWN B. O.P. S / PULL WEAR RING , REMOVE BELL NIPPLE AND MOUSE HOLE REMOVE SPACER SPOOL, D.S.A. , INSTALL ADDITIONAL TUBING SPOOL · FE: DH TSTICSG COMP TOT LAST PIT DRILL :DATE: 05/27/01~' i~'~::~'~:~:~';':~:'~':'~-~*~:~*~*~<;'~':~s;;~:~<~;~a*:s~;:~ ACTUAL li~:!;~;~i:~i;~i;!; LAST BOP TEST DATE: 06/01/01 MUD COSTS ACTUAL WELL COSTS DAILY: 1,450 CUM: 13,028 DAILY: 29,763 CUM: 311,570 NO ACCIDENTS REPORTED TODAY DRILLING S~PERVISO~: J.C. LORENZEN Marathon RPT#; 9 DATE: 06/16/01 LOCATION DAYS- 8 SPUD DAYS: Oil Company ' ~-'" ~ i 9207101 GL: KB: MOC WI: WELL: KBU 23X-6 RIG: Glacier Drilling Rig 1 FTG: DEPTH: (MD) 5,900 (TVD) 4,966 -- - _ CSG SIZE: 9.625 CSG MD: 6,800. CSG TVD: 6,301. SHOE TEST: MAX. SI 0 LINER TOP: PRESENT OP: WASH/REAM/ PUSH PACKER TO BOTTOM P.O.H. /LAY DOWN 6' CUT-OFF, SEAL NIPPLE, (2) JTS. TAILPIPE, AND WILl ENTRY GUIDE//PICK UP PACKER EXECUTIVE MILL, MILL PACKER LOOSE, WASH, REAM, PUSH PACKER DOWNHOLE PROBABLE PBTD @6781' SUMMARY (MW VIS PV YP GELS WL T 7.5 30 HT FC CRC SAND SLD BENT SALT DRILLED BARITE 8.5 126111 I I I I .i. J [ /32 I [ I PPB_ PPB PPB ~O!.L WTR pH Pm Pf Mf CL CA LIME MUD LOSSES (bbllftt BKGD CONE TRIP MAX ( BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOB I O D L B O OT R CPF COMMENTS ( BIT # SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT / / / / / / BHA · Length: DRILL PIPE DESCRIPTION: MAX PULL: - ( JARS MWD MOTOR TORQUE WEIGHT (1000) I 1 [ 1 I I IBHA:- PU- Rot -So- -Eft ( MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. ElS E/W DOG LEG ( , OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 10:30 4.50 P.O.H. 10:30 1 ~:00 0.50 LA Y DOWN 6' CUTOFF; SEAL NIPPLE; (2) JTS. TAILPIPE AND W/L ENTRY GUIDE 1~:00 ~2:00 %00 MAKE UP PACKER MILL; B.H.A. #4 12:00 15:00 3.00 R. LH. 15:00 22:00 7.00 MILL ON PACKER ~)4989' 22:00 6:00 8.00 WASH / REAM / PUSHING PACKER TO BOTTOM //ENCOUNTER MODERATE GAS THRU PERFORATED INTERVALS / (PACKER - JUNK @6781 ~ AFL: DH TSTICSG COMP TOT LAST PiT DRILL DATE: 05/27/01 i::~:::~ ~ ~ ~: ~."~;< ~ ~ -':~:~:~ ~:~::. ~;'~;~:.~.-'~'~%;i ~.~-~i ~- .:~:;-Z:.i:~ ~;!' ~- :'i; ~ MUD COSTS ACTUAL WELL COSTS ACTUAL ~!:!i::!'!:i?'iiii LAST BOP TEST DATE: 06/01/01 DAILY: 1,5~I CUM: 11,578 DAILY: 34,306 CUM: 281,807 NO ACCIDENTS REPORTED TODAY i DRILLING SUPERVISOR: J.C. LORENZEN Marathon ~#. 8 DATE: 06/15/01 LOCATION DAYS: 7 SPUD DAYS: Oil Company ~ ., 9207101 GL: KB: MOC WI: . . WELL: KBU 23X-6 RIG: Glacier Drilling Rig 1 FTG: DEPTH: (MD) 5,900 (TVD) 4,966 CSG SIZE: 9.625 CSG MD: 6,800. CSG TVD: 6,301. sHoE TES~' - MAX. SI 0 LINER TOP: PRESENT OP: P.O.H. W/FISH ? · MAKE UP BIT AND ATTEMPT TO R.I.H. / BIT WOULD NOT PASS TEST PLUG BORE/RETREIVE OUTER SLEEVE EXECUTIVE WITH STRING MILL / R.I.H. W/BIT~ WASH AND REAM TO TOP OF FISH / C.B.U. / PICK UP SPEAR AND R. IoH. / SUMMARY SPEAR INTO FISH / CIRCULA TING MODERATE GAS FROM WELL (..MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLO BENT SALT DRILLED BARITE 8.5 126] [ I I I, I l I I I 132 J [ .I. PPB PPB PPB {OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES,lbbllft) BKGD CONN TRIP MAX, { BIT# SIZE TYPE OFF FTG ,RS FTIHR RPM WOB IO D LB GOT R CPF COMMENTS ~ BIT # SERIAL # PRESS. GPM JETS TFA .~.NNULAR VELOCITY BiT HP / ! I I I I BHA · Length: DRILL PIPI~ DESCRIPTION · MAX PULL: C JARS MWi~ MOTOR TORQUE WEIGHT (1-000) - i } I 1 I I 'IBHA:' Pu- Rot So' E~ff' ~ MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. N/S E/W DOG LEG , , ~ OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 7:00 1.00 PICK UP BIT AND BIT SUB 7:00 12:00 5.00 ATTEMPT TO R. LH. / NO GO / RETRIEVE OUTER SPACER FROM 7' TEST PLUG LEFT IN WELLHEAD 12:00 16:30 4.50 R. LH. TO 4190'/ PiCK UP 16 JTS. DRILLPIPE TO 4656' 16:30 18:00' 1.50 WASH AND REAM TO TOP OF FISH @ 4982' 18:00 19:00 1.00 CIRC. HIGH VlSC. SWEEP 19:00 22:30 3.50 P.O.H. 22:30 1:30 3.00 MAKE UP SREAR / R. LH. 1:30 2:00 0.50 SPEAR INTO FISH / PULL FREE W/ 50,000 # OVERPULL 2:00 5:00 3.00 CIRCULATE MODERATE GAS FROM HOLE 5:00 6:00 1.00 P.O.H. , , , , AFE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 05/27/01 .__ MUD COSTS ACTUAL WELL COSTS ACTUAL i;;~r~ii,~i ;:;;.t LAST BOP TEST DATE: 06/01/01 DAILY: 1,504 CUM: 10,067 DAILY: 51,226 CUM: 247,501 NO ACCIDENTS REPORTED TODAY DRILLING sUPERVISOr: J.C.-LORENZEN - ' Marathon RPT#: 7 DATE: 06/14/01 LOCATION DAYS: 6 SPUD DAYS: Oil Company 9207101 GL: KB: ~" MOC WI: __ WELL: KBU 23X-6 RIG: ~lacier Drilling Rig 1 FTG: DEP I'H: (MD) 5,900 (TVD) 4,966 CSG SIZE: 9.625 CSG MD: 6,800. CSG TVD: 6,30~ '~HOE TEST~' - MAX. SI 0 !LINER TOP: 'PRESENT OP: P.O.H./ LAYING DOWN FISH ~:~a-~-.~.~::...:~.:~,:t~..-'.~;~~!~.~:~;::, ~:c::~:~.~:;~.:~,.~.~:~::~:.~..'~:::~q~:~T ~-~.?~;.~¢:~-.~.~W~ ~, ,,,, .... , , ,- , ,, ,,,, ', '."H ' PICK UP B.H.A. AND SPEAR / R.I.H. PICKING UP ORILLPIPE / SPEAR INTO CUT AND PICK'UP3O' r EXECUTIVE CIRC GAS FROM UNDERPACKER /C.B.U./ P.O.H./LAYEDDOWNCUT-OFF; 5 B~STJTS.// 23 SUUUARY JTS. TBG. ,AND 24' CUT- OFF JT. (MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE I i I I I t I x32 I I PPB PPB PPa ~ ~R pH Pm Pf Mf ~L CA LIME MUD LOSSES (bbll,~ ,KGD CONE TRIP M~ ( BIT~ SIZE ~PE OFF FTG HRS FT/HR RPM WOB I O D L B GOT R CPF ~OMMENTS ( BIT~ SERIAL ~ PRESS. GPM JETS TFA ANNU~R VELOCI~ BIT HP BH~: konflth: ( ~. nfi~H ~OCE n~RfiCT~O~ ~D V~RT. SEC. ~tS fi~ ~00 C~O ( OPE~TIONS IN SEQUENCE ) START END HOURS DESCRIPTION 6:00 9:30 3.50 PICK UP AND R. LH. W/ SPEAR AND B.H.A. 9:30 1~:30 2.00 LOAD DRILLPIPE ONTO RACKS / COUNT AND STRAP 11:30 16:00 4.50 R. LH. PIC~NG UP DRILLPIPE ?6:00 17:30 1.50 SLIP AND CUT DRILL LINE / SERVICE RIG 17:30 19:00 1.50 C.B.U. 19:00 22:00 3.00 CIRC. INTO CUT/PICK UP FISH 30'/CIRC. CONSIDERABLE GAS OUT OF HOLE / OBSERVE ~LL 22:00 22:30 O. 50 P.O.H. W/ FISH 22:30 23:00 0.50 REPAIR TOP DRIVE 23:00 3:00 4.00 P.O.H. SLOW W/ FISH / ~ Y DOWN JARS, SPEAR, AND CUT- OFF 3:00 6:00 3.00 ~LAYDOWN23JTS. + 24'CUT-OFF(6'CUTJT.,S~LNIPPLE,AND2JTS. TAILPIPE REMAIN) ~',::/~ ............. ~:;~:~;~,~ ................ ~:~:, ~ ..... ,, ~ ..................... :~::~.~:~::~:?:~..~ :::~:: :~<: ~:: ~.~. ~.:-:...: ~ ~ . : .: , · . :: . ~ . ~ ~ · FL: DH TST/CSG COMP TOT ~ST PIT DRILL DATE; ~~}~ MUD COSTS ACTUAL ~:~~ :,~::-~}~}~ WELL COSTS ACTUAL [}~i:~'~}~: ~ST BOP TEST DATE: 06/01/01 DAILY: 625 CUM: 8,563 DAILY: 40,4~3 CUM: 196,275 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: J.C. '[ORENZEN Marathon RPT#: 6 DATE: 06/13/01 LOCATION DAYS: 5 SPUD DAYS: Oil Company I 9207101 GL: KB MDC WI: WELL: KBU 23X-6 RIG: Glacier Ddlling Rig I FTG: DEPTH: (MD) 5,900 (TVD) 4,966 CSG SIZE: 9.625 CSG MD: 6,600. CSG TVD: 6,301. SHOE TEST: MAX. SI 0 LINER TOP: PRESENT DP: LAYED DOWN SHORT STRING AND LONG STRING WITH PACKER/CHECK EVERY JT. FOR N.O.R.M. / EXECUTIVE CHANGE RAMS / TEST B.O.P. S / PICK UP SPEAR AND B.H.A. / PICKING UP DRILL PIPE SUMMARY (~MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE 8.2 126111 I I I I I I I 132 ] I I PPB PPB ,PPB ~"~IL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES Ibbl/ft 1 I 7.5 (~ BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOB I O D L B G OT R CPF COMMENTS ( BIT # SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP BHA: Length: DRILL PIPE DESCRIPTION: MAX PULL: ( JARS MWI~ MOTOR TORQUE WEIGHT (1-000) - ~ MEA. DEPTH ANGLE DIRECTION 3'VD VERT. SEC. NIB E/W DOG LEG ~ OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 7:30 1.50 CIRC. DOWN LONG STRING 7:30 15:30 8.00 P.O.H, LAYING DOWN SHORT STRING (LAY DOWN 139 JTS. + 17 PUP JTS. 3 1/2" TBG. CHECK EVERY JT. FOR N.O.R.M. 15:30 17:30 ZOO CIRC. BTMS. UP DOWN LONG STRING 17:30 1:30 8.00 P.O.H. LAYING DOWN LONG STRING AND PACKER / CHECK EACH JT. FOR N.O.R.M.. 1:30 2:30 1.00 RIG DOWN TUBING TONGS / CLEAR FLOOR 2:30 6:00 3.50 CHANGE UPPER AND LOWER PIPE RAMS TO 4" / TEST B.O.P. S .... ~FE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 05/27/01 ~i~iii!~ii~!i MUD COSTS ACTUAL WELL COSTS ACTUAL l~!';;~!i.lii':.i;i:..;iiii LAST BOP TEST DATE: 06/01/01 DAILY: 927 CUM: 7,938 DAILY: 20,927 CUM: 155,862 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: J.C. LORENZEN Marathon RPT#: 5 DATE: 06/12/01 LOCATION DAYS: 4 SPUD DAYS: Oil Company ,r~'''~ ~-~ i 9207101 GL: KE MOC WI: WELL: KBU 23X-6 RIG: Glacier Drilling Rig 1 FTG: DEPTH: (MD) 5,900 (TVD) 4,966 CSG sIzE: 9.625 CSG M~)~ ~800. CSG TVD: 6,301. SHOE TEST: MAX. SI 0 LINER TOP: PRESENT OP: NIPPLE UP B.O.P. S / FIX HCR LEAK / CHANGE RAMS TO SHEAR- BLINDS ON BTM. / BLINDS; THEN DUAL 3 EXECUTIVE 1/2"; ANNULAR / RIG UP TO PULL TUBING; RIG UP TONGS / PULLED 2 JTS+; 5 PUP JTS. S/S / THEN SUMMARY PULL PACKER LOOSE AND PULL 2 JT. PLUS 3 PUP JOINTS LONG STRING / CIRC. DOWN US ~ 2 BPM TO BOTTOMS UP/PREPARE TO P.O.H. LAYING DOWN S/S ~MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE 8.51261 I I / I I I I I { 132 I I I PPB mP8 PPB COIL W'rR pH Pm Pf Mf CL CA LIME MUD LOSSES tbbllft~ BKGD CONN TRIP MAX 7 5 1 1 I 17,000 ) ldaily cum 1 i BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB I O D LB GOT R CPF COMMENTS ( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT BHA · Lenflth: DRILL PICE DESCRIPTION: MAX PULL: , - ( JARS MWD MOTOR TORQU£ WEIGHT H 000~ I I { 1 I I'IBHA" Pu Rot -So' ' E" ...................................................................................... .......... ~. ...... ~ ......................... 1. ......... ~ > ~ , ~ ~. OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 9:00 3.00 NIPPLE UP B.O.P. S 9:00 10:00 1.00 INSTALL BACK PRESSURE VALVES IN S/S AND US 10:00 22:00 12.00 INSTALL 3 1/2" DUAL RAMS; BLIND SHEAR RAMS ,INSPECT RAM CAVITY, AND REPLACE DOOR SEALS / TEST B.O.P. S / FIX LEAKS ON STANDPIPE BLEED, 4" SHUT-IN VALVE, AN . #1 MUD PUMP / TEST O.K. 22:00 23:00 1.00 RIG UP DUAL 3 1/2 "SLIPS AND ELEVATORS 23:00 1:00 ZOO PULL BACKPRESSURE VALVES/PICK UP LANDING JT. /RIG UP TUBING TOOLS 1:00 5:00 4.00 PULL SHORT STRING LOOSE/LAY DOWN (2) JTS. AND (5) PUP JTS. // PULL PACKER LOOSE; LAY DOWN (2) JTS. AND (3) PUP JTS /. BOTH HANGERS LAID DOWN 5:00 6:00 1.00 CIRC. VOLUME OF HOLE ~,FE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 05/27/0~ ii1 MUD COSTS ACTUAL ~i~= ~ ~i~!~i~i WELL COSTS AC;UAL i~i~ii~i~ii~~, LAST BOP TEST DATE: 06X01X01 DAILY: 751 CUM: 7,011 DAILY: 32,939 CUM: 134,935 NO ACCIDENTS REPORTED TODAY DRILLING S~IPERVISO~: J.C. 'LORENZEN - Marathon RPT#: 4 DATE: 06/11/01 LOCATION DAY.~: 3 SPUD DAYS: Oil Company ~?'"' ~ i ~ 920710~ GL: KE MOC WI: WELL: KBU 23X-6 RIG: Glacier Drilling Rig 1 FTG: DEPTH: (MD) 5,900 ('FvD) 4,966 CSG SIZE: 9.625 CSG MD-;. 6,800. CSG TVD: 6,301. SHOE TES'F: " MAX. SI 0 LINER TOP: PRESENT OP: LUBRICATE AND BLEED GAS FROM WELL / JET CUT SHORT STRING ~4146'/ JET CUT LONG STRING EXECUTIVE 5001 ' AND 4~67'/ CONTINUE BLEEDING GAS AND CIRCULATING LONG STRING, SHORT STRING AND SUMMARY ANNULUS/SET B.P.V. / NIPPLE DOWN TREE / NIPPLING UP B.O.P. S {MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE 6.51261 II / I / ! i I I i32 I I i PPB pPa PPB (~OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES lbbl/ftl .i~(~O CONN TRIP MAX 1 I 116,5001 daily cum ( BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB I O D LB G OT R CPF COMMENTS ( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT BHA: Lenflth: DRILL PIPE DESCRIPTION: MAX PULL: ( JARS MWD MOTOR TORQUE WEIGHT ¢~-000~ - · I 1 I I I II BHA" Pu 'Rot SO- Eft' ............................................................................................... . ............ . ...... ~ .......... ! ...... ~ { MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. N/S E/W DOG LEG ( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 9:00 3.00 CONTINUE LUBRICATE AND BLEED TO 0 PSI / MONITOR WELL 9:00 12:00 3.00 RIG DOWN FROM I_/S - RIG UP TO CUT TBD. ON S/S 12:00 14:00 2.00 BLEED GAS FROM SIS _ FILL WITH BRINE 14:00 16:00 ZOO RIH W/ JET CUTTER / CUT SHORT STRING @4146'/RIG DOWN OFF S/S 16:00 19:30 3.50 MOVE LUBRICATOR TO LONG STRING/RIH/JET CUT TBG. @5001' AND 4167' ~9:30 1:30 6.00 BLEED GAS S/S AND US / CIRC. US RETURN S/S TILL CLEAN; THEN CIRC. S/S, RETURN FROM ANNULUS TILL CLEAN/MONITOR WELL 1:30 2:00 0.50 SET B. P.V. IN SHORT STRING AND LONG STRING 2:00 6:00 4.00 NIPPLE DOWN TREE/NIPPLE UP B.O.P.S ~.FE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 05/27/01 ~i!!:iii ~:1 MUD COSTS ACTUAL ~i!!:!i!!i. ii!.!ii~!~iii~;i?:-~i~?:1 WELL COSTS ACTUAL ..... BOP DATE: ................................................................................... I!?,?-? ~::i'; LAST TEST 06/01/01 DAILY: 3,063 CUM: 6,260 DAILY: 31,393 CUM: 101,996 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOA-: J.C. LORENZEN Marathon RPT#: 3 DATE: 06/10/01 LOCATION DAYS: 2 SPUD DAYS: Oil Company '~"-'"; 9207101 GL: K£ MOC WI: WELL: KBU 23X-6 ' RIG: Glacier Drilling Rig 1 FTG: DEPTH: (MD) 5,900 (TVD) 4,966 .. CSG SIZE: 9.625 CSG MD: 6,800. CSG TVD: 6,301. SHOE TEST: MAX. SI 0 LINER TOP: PRESENT OP: SCOPE DERRICK UP / FINISH TIE IN ALL ELECTRICAL, WATER, AND MUD LINES/MOVE AND SET CAMP, EXECUTIVE HOOK UP SEWER, WATER, AND ELECTRIC / FILL PITS, MIX 500 BBLS. 3% KCL / ACCEPT RIG @1800 HRS SUMMARY LONG STRING HAS 440 PSI; SHORT STRING HAS 230 PSI / LUBRICATE L/S TO 0 PSI W~ 20BBLS. PUMP 25 BBL. LCM TO S/S/ DISPL. W/ 35 BBLS BRINE ~MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE · 8.5 1=71 I I I I 1 I I I I /32 I I I Ppa PPB PPB COIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES Ibbllftl BKGD CONN TRIP MAX 1 I 7.5 i 1 1'6,5001 1[daily cum I J ~ BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB I O D L B G OT R CPF COMMENTS ( BIT# SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP~ BHA: Length: DRILL PIPE DESCRIPTION - M~ PULL: ~ JARS MW~ MOTOR TORQUE WEIGHT (1~00) - I 1 I 1 I 1 IBHA: -Pu 'Rot So -Eft ~ ~EA. DEPTH ANGLE DIRECTION ~D VERT. SEC. NIS ~ DOG LEG ~( OPE~TIONS IN SEQUENCE ) START END HOURS DESCRIPTION 6:00 18:00 12.00 TELESCOPE DERRICK/HOOK UP STEAM, AIR, AND WA TLR LINES / HANG TORQUE TUBE SET CAMP, HOOK UP TO WA TLR WELL ~8:00 0:00 6.00 HOOK UP CHOKE, ~LL AND FILL UP LINES/RIG UP TO PUMP DOWN LONG STRING, FILL FILL ANNULUS / TEST ANNULUS TO IO00PSI // ACCEPT RIG ~1800 HRS. 0:00 2:30 2.50 LUBRICATE AND BLEED LONG STRING / STARTING ~0 PSI / ENDING 0 PSI 2:30 4:30 ZOO RIG UP TO PUMP DOWN SHORT STRING / MIX AND PUMP 25 BBLS. LCM / DISP~CE ~TH 11 BBLS. BRINE//PRESSURE TO 2400 PSI / STOP DISPLACEMENT /APPROX 18 BBL~ LCM REMAIN IN S/S 4:30 6:00 1.50 BLEED GAS FROM US ~FE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 05/27/01 ~:~:..~ MUD COSTS ACTUAL,..~:~?~.-~..~.~.~.~.~-.:~:~:~.~.~-~=:~~:~ ~~;~. ~-~.'~ WELL COSTS ACTUAL~; %?~;~-;;~ LAST BOP TEST DATE: 06/0~/0~ DAILY: 2,572 CUM: 3,~97 DAILY: 24,720 CUM: 70,603 NO ACCIDENTS REPORTED TODAY ~ DRILLING SUPERVISOR: J.C. LORENZEN Marathon RPT#: 2 DATE: 06/09/01 LOCATION DAYS: I SPUD DAYS: Oil Company ~-'~", , 9207101 GL: KB MOC WI: WELL: KBU 23X-6 RIG: Glacier Drilling Rig 1 'FTG: DEPTH: (MD) 5,900 (TVD) 4,966 CSG SIZE: 9.625 CSG MD~ 6,800. CSG TVD: 6,301. SHOE TEST: MAX. SI 0 LINER TOP: PRESENT OP: MOVE ALL COMPLEXES TO KBU 23X~6 /SET SUB-BASE AND ALL MODULES / HOOK UP ELECTRICAL AND EXECUTIVE WATER / RAISE DERRICK SUMMARY ~MW VIS P¥ YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE COIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES (bbllft) BKGD CONN TRIP MAX ( BIT~ SIZE ~PE OFF FTG HRS FTIHR RPM WOB I O D L B G OT R CPF COMMENTS ( BIT~ SERIAL~ PRESS. GPM JETS TFA ANNU~RVELOCI~ BIT BH~ · konflth: ~:=~ 'd'~.'~'~PTH ANGLE DIRECTION ~D VERT. SEC. NIS ~ DOG LEG ~ OPE~TIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 6:00 24.00 ~ MOVE MUD PITS, PUMP ROOM ,CARRIER, MUDBOAT AND SUB OFF 2~5 ~RANSPORT ALL COMPONENTS TO 23X-6 / MOVE AND SET RIG MA TS AND SET ALL COMPONENTS A T SIT~ HOOK UP ELECTRICAL AND RAISE DERRICK- READY TO SCOPE THIS A. M. ~FE: DH TSTICSG COMP TOT ~ST PIT DRILL DATE: 05/27/01 DAILY: 0 CUM: 625 DAILY: 31,413 CUM: 45,883 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: J.C. LORENZEN Marathon RPT#: I DATE: 06/08/01 LOCATION DAYR: SPUD DAYS: Oil Company ~-~ .... 9207101 GL: K[ MDC WI: WELL: KBU 23X-6 RiG: Glacier Drilling Rig 1 FTG: DEPTH: (MD) 5,900 (TVD) 4,966 CSG SIZE:-- CSG MD: CSG TVD: ~HOE TEST~ - MAX. SI 0 LINER TOP: PRESENT DP: RIG DOWN GLACIER #1 FROM K U 24-5 PREPARE RIG FOR MOVE TO KBU 23X-6 EXECUTIVE SUMMARY (MW wsPvYP GELS WL T 7.5 30 HT FC CEC SAND ELD BE.T SALT DRILLED BARITE ~ I I I I / I I I ,I. I I X32 I I / PPB PPB PPB oCoC~ WTR pH Pm Pf Mf CL CA UME MUD LOSSES (bbl/.) BKGD 'CoNN'" TRIP MAX ~ C BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOB I O D L B G OT R CPF COMMENTS ~ I I I I I I ( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP~ ! ~HA: I_ongth · DRILL PIPE DESCRIPTION · MAX PULL: ( JARS MWi~ MOTOR TORQUE WEIGHT (1~)00) '· I 1 ! 1 I ! IBHA: Pu Rot So Eft- ~MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. N/S E/W DOG LEG ~ ;( OPERATIONS IN SEQUENCE ; START END HOURS DESCRIPTION 6:00 18:00 12.00 RELEASE FROM KU 24-5 @ 1800 18:00 6:00 12.00 CLEAR RIG FLOOR/LA Y DOWN TOP DRIVE/REMOVE BEAVER SLIDE/PULL ELECTRIC LINE AND HOSES/COMPLEXES ARE READY TO BREAK APART THIS A.M. ~,FE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 05/27/01 ~iii:~!!:i:~!:i!~iiiiiill MUD COSTS ACTUAL i~!~:;!i~ii!~i:!i!i~ ill WELL COSTS ACTUAL I':iii:i:~:ili~::!::;~.:::;. LAST BOP TEST DATE: 06/0'1/01 DAILY: 625 CUM: 625 DAILY: 14,470 CUM: 14,470 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR': J.C. LORENZEN MARATHON OIL COMPAN'i DALLY WELL OPERATIONS R PAGE 1 OF 1 DATE: 5/16/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: Tag XN @ 4173' KB FIELD: Kenai Gas Field WELL #: 23x-6S TUBING: 3 1/2" CASING: 9 5/8" TREE CONDITION: Old BENCHES OPEN: Complete WlRELINE CREW: WhitakedBaker Hrs. 4 SUMMARY OF OPERATIONS R/U, pressure test Lub & BOP's, travel to fuel W/L Unit RIH w/2.70" GR to 4173' KB, tag, no-go, POOH, no problem, Tubing clear R/D Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. 2 of 12 hr min $250.00 $250.00 Pollard Wireline Inc. 2 add hrs $200.00 $450.00 Pollard Wireline Inc. 2.70" GR $50.00 $500.00 DALLY COST: $500.00 CUM: $500.00 REPORTED BY: Ray Schmansky MARATHON OIL COMPANY DATE: 5/11/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: DALLY WELL OPERATIONS R .T PAGE 1 OF 1 FIELD: Kenai Gas Field WELL #: 23x-6 TUBING: 3 1/2 CASING: 9 5/8" TREE CONDITION: Old - operab;e Set Plug & Prong BENCHES OPEN: Complete WIRELINE CREW: Whitaker/Baker Hrs. 7 SUMMARY OF OPERATIONS Arrive @ MOC Office, meet w/Foreman, discuss job, hold safety meeting, check equipment, travel to 23x-6 R/U, trouble getting Tree cap off, operator used come along to remove, pressure test Lub & BOP's - test good, twist test wire - 23 turns RIH w/3" X-line RFF and 2.81" Plug to 5026', could not shear off, POOH, tool (X-lock & Plug) covered with Gray ssticky substance, clean tool, check pins RIH w/same to 5026', set Plug, POOH RIH w/2 1/2" SB w/Prong to 5022', set Prong, POOH R/D, move to 31-7x Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. 7 of 12 hr min $875.00 $875.00 Pollard Wireline Inc. X-line RFF $200.00 $1,075.00 Pollard Wireline Inc. 2 1/2" SB $100.00 $1,175.00 Pollard Wireline Inc. Plug $150.00 $1,325.00 DAILY COST: $1,325.00 CUM' $1,325.00 REPORTED BY: Wayne Cissell MARATHON OIL COMPANY DATE: 4/4/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: N/A DALLY WELL OPERATIONS R. )[. FIELD: TUBING: 4/3/2001 Verify Sleeve shut Complete Kenai Gas Field 3 1/2" CASING: TREE CONDITION: BENCHES OPEN: WIRELINE CREW: Hrs. PAGE 1 OF 1 WELL #: 23x-6s 13 3/8" Good D. Pollard/Lo~iston 3 SUMMARY OF OPERATIONS Arrived and meet w/Supervisor Started R/U RIH w/2.75" Swedge to 500', POOH RIH w/3 1/2" Shifting Tool to 4095', verified Sleeve shut, POOH R/D, moved to next well Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline InA. 3 of 12 hr min $375.00 $375.00 Pollard Wireline Inc. 2.75" Swedge $50.00 $425.00 Pollard Wireline Inc. 3 1/2" Shifting Tool $150.00 $575.00 DALLY COST: $575.00 CUM: $575.00 REPORTED BY: Wayne Cissell MARATHON OIL COMPANY DALLY WELL OPERATIONS RL DATE: 4/3/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: N/A FIELD: TUBING: N/A Verify Sleeve shut In progress Kenai Gas Field 3 1/2" CASING: TREE CONDITION: BENCHES OPEN: WIRELINE CREW: Hrs. PAGE 1 OF 1 WELL #: 23xo6s 13 3/8" Good D. Pollard/Logston 5 SUMMARY OF OPERATIONS R/U on 23x-6s RIH w/3 1/2" Shifting Tool, set down in Tree, POOH w/tools RIH w/same, set down in Tree, POOH w/tools RIH w/2.65" GR to 500', POOH RIH w/3 1/2" Shifting Tool ( Dogs taped up) set down in Tree, POOH R/D for the night Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. 5 of 12 hr min $625.00 $625.00 Pollard Wireline Inc. 2.65" GR $50.00 $675.00 Pollard Wireline Inc. 3 1/2" Shifting Tool $150.00 $825.00 ,, DAILY COST: $825.00 CUM: $825.00 REPORTED BY: Wayne Cissell Marathon OilCompany Alaska Business Unit P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 9071561-5311 Fax 907~564-6489 March 4, 2002 Tom Maunder AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Attached is the Application for Sundry Approvals for Well Number KBU 23x-6, and the accompanying schematics and procedure. If you would like any other information, please contact me at 564-6315 or jgeller@marathonoil.com. Si~ncerely, Pro ;a~ctiEol~e; ;gineer Enclosure bjv RECEIVED Alaska 0il & Gas Cons. Commission ,Anchorage ORIGINAL 1. Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon Suspend Operation Shutdown n:'~drlg\kgf~,43.6xro%AOGCCO4.xls Re-enter Suspended Well Alter Casing Repair Well X Plugging Time Extensior Change Approved Program Pull Tubing~ Variance Perforate Stimulat6 Other Name of Operator MARATHON el L COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 291'N& 1208' E of SW Corner Sect (-o '~'~'~"~'~,~ At top of Productive Interval 1468' N& 1491' E of SWCorner ~_ 5. Type of Well: Development x Exploratory Stratigraphic Service ,, At Effective Depth IWorkover to repair tubing communication At Total Depth - 2421' N & 1704' E of SW Corner (z, '~ ~ 6. Datum Elevation (DF or KB) Pad 66' MSL I 7. Unit or Property Name Kenai Beluga Unit 8. Well Number KBU 23x-6 9. Permit Num,~ 84-109 10. APl Number ¢ 50-133-20371 11. Field/Pool Kenai Gas Field/Beluga/Sterling Pool 12. Present Well Condition Summary Total Depth: measured true vertical V 6950 feet Plugs (measured) 6447 feet ~' Effective Depth: measured true vertical 6841 feet Junk (measured) 6341 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length Size Cemented 126' 20" Driven 2532' 13-3/8" 1870 sx 6950' 9-5/8" measured 5112'-6810' MD Long String true vertical 4711-6311' TVD Long String Tubing (size, grade, and measured depth) 2-3/8", 4.6ppf, L-80, 4771' 2-7/8', 6.4 ppf, L-80, 5100' Packers and SSSV (type and measured depth) Measured Depth True Vedical Depth 126' 126' 2532' 2454' 6950' 6447' 4829'-4906' MD shortstring~;~EOEiVE~ 4455' - 4525' TVD Short String Short String Long Stdng Halliburton Permaseries packer at 4988' Alaska 0il & Gas Cons. C0mmissic Anchorage 1,3. Attachments Description Summary of Proposal X Detailed Operations Program X BOP Sketch X 14. Estimated Date for Commencing Operation 115. Status of Well Classification as: 3/7/2002 16. If Proposal was Verbally Approved Oil__ Gas X Suspended Name of Approver Date Approved Service 17. I hereby cert%e foregoJng~e and~__~~ correct to the best of my knowledge. Signed '"",~ '~ ~,k ~"~ Gary Filer Title Produ ction Engineer Date 3/2/2002 '~. "' FOR COMMISSION USEONLY Cond~bons" of Approval: No'tify-C4~mission so representative may witness "~(~(~ e,~,¥ ..... \'~")'~· .~_. IApproval No. Plug Integrity__ BOP Test.~ Location Clearance.__ I ~ Mechanical Integrity Test Subsequent Form Required 10- 0riginal $1*Oned By _~//-/.~) "'~ Approved by Order of the Commission 0&~C'-0eC~,~li Commissioner Date Form 10-403 Rev. 06/15/88 Submit/in Triplicate ORiGIi AL Well KBU 23x-6 Kenai Gas Field WBS Workover Procedure to Repair Tubing Objective: Repair tubing communication that is preventing the long string Beluga completion from producing. Procedure: Mark on the tubing head with permanent marker the location of the short and long strings so they can be readily identified when the tree is removed. Also, make alignment marks so that the tree can be reinstalled in exactly the same position as it is now. ND flowlines sufficiently to move in rig substructure. . MIRU slickline on KBU 23X-61 (longstring). Pressure test lubricator to 1500 psi. RIH with a dump bailer full of 20/40 sand. Dump 10' of sand on top of the PX plug in the X-nipple (ID = 2.313") at 5066'. POOH, RDMO slickline. 3. MIRU pump truck. Load casing and tubing strings with fresh water. Do not exceed 2000 psi on 9%" casing. RDMO pump truck. , Call out Vetco wellhead rep. Set 3~" BPVs in both tubing strings and bleed off surface pressure. Set a 6" BPV in the large tubing head outlet. Blind off the 7- 1/16" side outlet of the tubing head. o MIRU drilling rig. Prior to ND ~/" ~/s , 5M tree, confirm that no trapped pressure exists below BPVs. ND tree. Inspect lift threads on tubing hangers. NU BOPs. (~a,,t~. w~n ,,,, h~ able t,~ ,,~,,,,~ .... ~h~ o;,,~,~ ~'~*~~'~"~o duc tv-height-of-the tubing he~_d.) Upper pipe rams should be equipped with 2%", 5M rams and lower pipe rams should be equipped with 5M variable-bore rams capable of sealing on 2~" to __" pipe. Pull BPVs, set 2-way checks. Test BOPE to 250/3000 psi. Pull 2-way checks. . Load hole with 3% KC1 water and establish circulation down the 2~" long string tubing. Apply LCM as needed. Preferred LCM material is HEC polymer pills, second choice is XCD polymer. The last choice of LCM material is sized calcium carbonate. , RU elevators, spiders, dog collar, and integral tongs for pulling the 2%", 4.6 ppf, L-80, Hydril 511 (flush joint) shortstring tubing. Pull short string tubing (expected PU weight = 35,000 lbs plus blocks). Be particularly careful until the end of tubing clears the casing patch (4200' - 4303'). Install thread protectors on each joint, and lay down all 2%" tubing taking extra care not to damage the threads. 8. Close the blind rams. Replace the 2%", 5M rams in the upper pipe rams with 2~", 5M rams. Open blinds, install test plug, and test BOPE as needed. Pull test 9. RU elevators, slips, and tongs for pulling the 2~", 6.4 ppf, L-80, EUE 8rd longstring tubing. Release seal assembly from Halliburton packer at 4988' by a straight pull on the tubing (expected PU weight = 42,000 lbs plus blocks plus seal friction). Stand back 2~" tubing, protecting each pin-end with a thread protector. Be particularly careful until the end of tubing clears the casing patch (4200' - 4303'). LD y-block, 3%" gun assembly, and bad joints of tubing. Send in seal assembly to be redressed. Gas lift mandrel and X-nipple will be rerun later. 10. MIRU Schlumberger. Conduct prejot~ sat'etymeetmg. RIH with 4%", _ spf guns. Tie in with CCL, reperforate the C-1 Sand (Pool 6) 4829' -4906' DIE with the hole loaded with 3% KC1. POOH, RDMO Schlumberger 11. PU one joint of 2%" tubing to use as a stinger. TIH with 2%" tubing and stinger assembly. Sting 2%" stinger into 4.000" seal bore. Reverse out any gun debris from seal bore. TOH standing back 2%" tubing. LD 2%" stinger. 12. PU and TIH with the 2%" completion string consisting of: · Seal assembly · Locator · X-nipple (2.313" ID) · Gas lift mandrel loaded with a l~&" dummy valve · 88' of 3.5" OD steel blast joint, spaced out across the C-1 peris at 4829' - 4906' DIL · 2~" tubing to surface · tubing hanger All 2%" tubing below the casing patch should have beveled, special clearance couplings. Sting seal assembly into seal bore. Pressure up on 2%" tubing to verify seals are in place. Sting out, install space out pups and tubing hanger, and land 2%" tubing. 13. Close the blind rams. Replace the 2%", 5M rams in the upper pipe rams with 2%", 5M rams. Open blinds, install test plug, and test BOPE as needed. Pull test plug. RU elevators, spiders, dog collar, and integral tongs for running 2%" flush joint tubing. 14. PU and Tilt with the 2%" completion string consisting of: · Mule shoe · XN-nipple (2.313" ID with a 1.791" no-go) · 2%" Hydfil 511 tubing to surface · tubing hanger The end of the 2%" tubing will be positioned near 4829' DIL, the top of the C-1 'perfs. Install space out pups and tubing hanger, and land 2%" tubing. 15. Install BPVs in both tubing hangers. ND BOPE, NU tree. Pull BPVs, install 2- way check in tubing hangers. Test tree to 2000 psi using methanol. Pull 2-way check, reinstall BPVs. RDMO drilling rig. 16. Remove 7-1/16", 3M blind flange. Pull 6" BPV in tubing head side outlet. NU 7- 1/16" 3M valve and remainder of tree valves. NU flowlines. 17. MIRU nitrogen pump onto the 9%" casing and flowback tank onto the 2%" shortstring tree top. Pressure test lines to 3000 psi. Reverse out completion fluid using nitrogen. Do not exceed 2000 psi casing pressure. Total estimated recovery = __ bbl. Unload Pool 6 completion to flowback tank until well has adequately cleaned up. Produce shortstring Pool 6 completion to sales. 18. MIRU coil tubing onto the longstring Beluga Sand completion. Test BOPE to 250/3000 psi. Hold prejob safety meeting. MU assembly to latch the prong of the PX plug at 5066'. Must be able to circulate through the latching assembly to wash off the sand on top on the prong. Assembly may need to include a mandrel bypass tool. RI/-I. Wash sand off of the top of the prong and circulate to surface. Latch the PX prong and unsting from the PX plug body. Jet in well with nitrogen. POOH, LD prong. 19. RIH with coil tubing, latch PX plug body at 5066'. POOH. 20. If necessary, RIH once again with coil to jet well to production. Total estimated recovery = __ bbl. Unload Beluga Sand completion to flowback tank until well has adequately cleaned up. Produce longstring Beluga Sand completion to sales. JGE - March 1, 2002 PROPOSED KBU 23X-6 lB-3 Peds 4214-4275' ISOLATED BY PATCH) IC-1 Perfs 4829-4906' 677' (23 joints) of 2 7/8 EUE 6.4 ppf L-80 tubing with special clearance couplings between Y blockand bottom of casing patch 20" 94 ppf H-40 driven to 126' 2-3/8" 4.7 ppf L-80 Hydri1511 tbg for the annulus @ 4771'. Non-upset Need nubbing to pull tubing. ppf L-80 EUE 8rd tbg 13-3/8" 61 ppf K-55 BTC @ 2538' Owen Csg patch w/7.75" ID isolating the B-3 Perfs @ 4200'- 4303' 'XN' Nipple w/1.791 ID NOGO Steel blast joint adjacent to perfs, 4829' - 4906 mandrel for 1-1/2" valves @ 4939' EUE 8rd 'X' nipple w/2.313" ID @ 4983' Hallibudon Perma Sedes Pkr @ 4988' Landed with Iocator sub 4' above packer --. 2-7/8" EUE 8rd 'X' nipple w/2.313' ID @ 5034' 2-7/8" EUE 8rd 'X' nipple w/2.313' ID @ 5066' WL Re-entry guide @ 5100' U-1 Peals 5112-5129' U-5 Perfs 5282-5303' I U-9 Per-Is 5520-5545' t Parts of Otis WD packer at 6781' on top of fill JL-:~--~'e-r~s ~§~:~i0' _ ........ I 9-5/8" 47 ppf N-80 @ 6950' Well Name & Number: J KBU 23X-6 Lease: Kenai Gas Field PerforationsC°Unty or Parish:(MD) State/Prov. (TVD) J Country: J Angle/Peals Angle @ KOP and Deplh J BHP: J BHT: J Completion F u d: Dated Comp eted: Marathon Oil Well KBU 23x-6 Kenai Gas Field Workover BOP Stack I FIow Nipple 13 5/8" 5M Annular Preventer IFIow Line II I Ram Preventer Operated Valves ~) { I Operated Valve I I 113 5/8" 5M Cross I ~ > < ' I IPipe Ram I ~IOperated valve 13 '8" 5M SingleI Ram Preventer I Workover Procedure for KBU :,'3x~, ~,ena, ~as r~u Subject: Workover Procedure for KBU 23x-6, Kenai Gas Field Date: Mon, 4 Mar 2002 12:18:32-0900 From: "Eller, J Gary" <JGEIler@MarathonOii.com> To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak. us> Tom - I sent you a sundry application and procedure for a workover of well KBU 23x-6 in the Kenai Gas Field. That procedure contains an error in step number 5. The procedure I sent you contains the following sentence: (Note: Will not be able to nipple up the single-gate rams due to height of the tubing head.). That sentence is inaccurate; we will be able to nipple up the full set of rams as shown on the BOP schematic that accompanied the sundry application. I have already changed my version of the procedure. Please let me know if you need an updated version. By the way, we're hoping to move omo this well late this week or this weekend. Please let me know if there's any way I can help get the application processed speedily. J. Gary EIler Operations Engineer Alaska Region, Marathon Oil Company 907-564-6315 I of 1 3/4/02 1:51 PM Marathon Oil Company April 24, 2001 Mr. Tom Maunder State of AlaSka Alaska Oil & Gas Conservation Commission 33 West 7th Ave, Suite 100 Anchorage, AK 99501 Reference: Field: Kenai Gas Field Well: KBU 23x-6 Permit No.: 84-109 APl Number: 50-133-20371 Project: Workover Alaska i. ~,on Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 RECEIVED APR ~ ? ZOO1 Alaska Oil & Gas Cons. C, ommission Dear Mr. Maunder: Attached please find FORM 403 - APPLICATION FOR SUNDRY APPROVAL for the KBU 23x-6 well. Please call me if there is any additional data that can be provided. I can be reached at 907-564-6303 (work) or 231-3775 (pager). My e-mail address is rjaffinito@marathonoil.com. Sincer ly, Ralph J. ^ffinito Advanced Production Engineer bjv N :\DRLG\KGF~WELLS\ktu24-6h\aogcclet.doc ORIGIIqAL A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS n:\drlg\kgt~43-6xrd~AOGCC03.xls 1. Type of Request: Abandon Suspend__ Operation Shutdown Alter Casing Repair Well Plugging Change Approved Program Pull Tubing ~ Variance Re-enter Suspended Well Time Extension Stimulate Perforate x Other 2. Name of Operator 5. Type of Well: MARATHON OIL COMPANY Development x 3. Address Exploratory P. O. Box 196168, Anchorage, AK 99519-6168 Stratigraphic 4. Location of Well at Surface Service 291' N & 1208' E of SW Corner Sect At top of Productive Interval 1468' N & 1491' E of SW Corner At Effective Depth IWorkover to Pool 0 Ann. & add Beluga perfs At Total Depth 2421' N & 1704' E of SW Corner 6. Datum Elevation (DF or KB) Pad 66' MSL I 7. Unit or Properly Name Kenai Beluga Unit 8. Well Number 23x-6 9. Permit Number 84-109 10. APl Number 50-133-20371 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical 6950 feet Plugs (measured) 6447 feet 6841 feet Junk (measured) 6341 feet /~PR X ? ZOO1 Oil & Gas C,o~. Commission Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length Size Cemented 126' 20" Driven 2532' 13-3/8" 1870 sx 6950' 9-5/8" measured 5112'-6810' MD Long String Measured Depth True Vertical Depth 126' 126' 2532' 2454' 6950' 6447' 4214-4275' MD Short String true vertical 4711-6311' TVD Long String 3956-4010' TVD Short String Tubing (size, grade, and measured depth) 3-1/2", 9.2 ppf, N-80, 4173" 3-1/2", 9.2 ppf, N-80, 5074' Short String Long String Packers and SSSV (type and measured depth) WD Packer @ 5007'/Dual @ 4155' 13. Attachments Description Summary of Proposal ~ Detailed Operations Program__ BOP Sketch __ 15. Status of Well Classification as: 14. Estimated Date for Commencing Operation 5/14/2001 16. If Proposal was Verbally Approved Name of Approver Date Approved Oil Gas X Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '"~~/~~If' R. Affinito Title Production Engineer ~w' f~' '-¢ ! FOR COMMISSION USE ONLY Date 4/23/2001 Conditions of Approval:Plug IntegrityN°tify CommissiOnBopSO Test~..representative may witneSSLocation "$~Clearance ~ '5'~ ~:~(~ ~ ~,"Ir Approval No. ~..~, Mechanical Integrity Test Subsequent Fg[m Required 10- Approved by Order of the Commission O~~~~~ Commissioner Date ~/~/ Form 10-403 Rev. 06/15/88 Subtnit i~(Tripli~:ate OI~IGINAL BIGNED F_~h~ J. I~. Heusser MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field KBU 23X-6 Deliverability Workover Procedure AFE # 9207101 B. Sclmffnmnn 1L Lanz D. Brimberry C. Young G. Eller D. Titus IL Afflnlto 1) 2) 3) 4) Prepare wellhouse and wellhead for workover operations. · Pressure test annulus to 1000 psig using 3% KCI water. Annulus should be full prior to any well work. RU Slickline on LS. Pressure test lubricator. · Set PXN plug set in 2.75" ID Otis 'X' nipple at 5050' (below permanent packer). Bleed off trapped pressure on tubing strings and annulus. Install BPV's in both the short and long string tubing hangers. Have wellhead vendor prep all necessary wellhead and tree studs for removal. Disconnect flowlines and bleed off pressure. MIRU Glacier Ddlling Rig #1. Haul to location 6800' of 4" 14 Ibm/ft HT-38 DP. Ddfl drill pipe to a 2.3" ID. Nipple down existing dual tree. NU BOP with upper pipe rams equipped with dual 3-1/2" rams and lower pipe rams equipped with single 4" rams. Remove BPV's and install two way checks. Pressure test BOP to 250 / 3000 psig. Pull two way checks. RU dual elevators. 5) Haul to location: 6) · 5,000 of 2-7/8" 6.5 ppf EUE 8 rd tbg and full set of pup joints · 4,800' of 2-3/8" 4.7 BTC 8rd tbg w/SCC All tubing is from Tuboscope. Ddft and talley tubing PU on Short and Long strings and attempt to release Otis Model RDH Dual packer at 4155. Maximum pull on single string of 3-1/2" 9.2 ppf buttress N-80 tubing is 159,090 Ibf (100%). Recommend not pulling more than 110,000 Ibf (70%). a) If Packer releases, then TOH laying down SS, LS, packer, and tailpipe and proceed to bit and scraper run as per Step #15 b) If packer does not release, proceed to Step #7 Operations assuminq tubinQ does not .release. RU APRS 1.375" OD freepoint service on LS. Free point tubing. Assuming LS tubing is free to packer, · RIH on SS and jet cut the tubing at 4150' -just above dual packer. · RIH on LS and jet cut tbg at 4165' -below dual packer. RIH on LS with 2.625" OD chemical cutter and cut LS at 4120' (below the Otis 'XA' Sliding sleeve. Cut must be a minimum of 20' higher than where the SS was cut. RD APRS. 1~ Schofflnann R. Lanz D. Brimberry C. Young G. Eller D. Titus R. AWmito 8) TOH laying down SS and LS 3.5" N-80 tubing. 9) PU the following a) 8-1/8" or 7-5/8" overshot for 9-5/8" 47 ppf casing dressed with a basket grapple for 3-1/2" tubing b) 6.25" OD Bumpersub c) 6.25" OD Hydraulic Jars d) 6.25" OD Ddll collars e) 6.25" OD Accelerator f) 4" HT-38 drill pipe 10) TIH to LS tbg fish. Latch fish and work good hold. Commence tool work to release Dual packer by jarring. a) if packer releases then COH w/packer and proceed to fishing tailpipe as per Step #12. b) If packer is stuck, then proceed to milling packer as per Step #11. 11) Prepare to mill over Baker A-5 dual packer. TIH with the following: a) Baker mill shoe for 9-5/8" 47 ppf casing and Baker A-5 dual packer. b) Bumper sub c) Hydraulic jars d) Ddll collars TIH on 4" DP to packer at approximately 4155'. Commence milling operations using 3% KCl water. Use only 3% KCl water throughout remainder of procedure. If inadequate circulation is being maintained then consider reverse circulating and using LCM and high viscosity sweeps as necessary. Hi-Vis Pill 10 bbls 3% KCI 2-4 vis cups pH-6 (Citric Acid) 1 sack HEC 1-2 vis cups Caustic Soda Wash over packer tdpping for new mill shoe as necessary. Once packer is free, then TOH w/shoe. TIH w/spear and retrieve packer. 12)TIH with the following to retdeve tailpipe fish. a) 8-1/8" or 7-518" overshot for 9-5/8" 47 ppf casing dressed with a control mill basket grapple for 3-1/2" tubing b) 6.25" OD Bumpersub c) 6.25" OD Hydraulic Jars d) 6.25" OD Drill collars e) 6.25" OD Accelerator f) 4" HT-38 drill pipe Latch tubing fish and TOH laying down tubing fish. Utilize washpipe, free points, and chemical cuts as necessary if considerable fill is present. 13) PU and TIH w/metal muncher for tools string as follows: IL Schoffmann 1~ Lanz D. Brtmberry C. Young G. Eller D. Titus I~ Affinito 14) 15) 16) 17) a) Baker mill shoe for 9-5/8" 47 ppf casing and Otis Model 'WD' Production packer. b) Bumper sub c) Hydraulic jars d) Ddll collars Use LCM as necessary along with Hi-Vis sweeps. Push packer to bottom. TOH w/mill shoe making spear run if necessary. Packer can sit on bottom if it does not come out with mill. Make bit and scraper and reamer run in preparation for csg patch. PU the following assembly: · bit for 9-5/8" 47 ppf csg · scraper for 9-5/8" 47 ppf casing · 8.5' OD Spiral reamer · 2 jts ddll stdng · 8.5" OD Spiral reamer TIH through B-3 perfs (4214-4275~) working any tight spots. RIH to 5,050' (RIH to TD if packer was not retrieved in previous step). TOH to above pegs. PU Halliburton Storm Packer, set pkr immediately below surface. Pressure test plug. TOH standing back DP. ND BOP and NU new tbg head w/7-1/16" 3K side outlet. Test. TIH sting into plug wfrlW valve on stdng. Test for trapped gas and release plug and TOH w/tool stdng. RU Schlumberger Logging service RU JB w/8.5 GR run at 100 fpm max speed. PU the following tool stdng: a) 2-7/8" WL Re-entry guide EUE 8rd b) 1 joint 2-7/8' EUE 8rd L-80 tbg c) 2-7/8" EUE 8rd 4' pup joint (pin x pin) d) 2-7/8" L-80 EUE 8rd 'X' nipple with a 2.313" ID (box X box) w/PX plug set in nipple (PX plug set to have an extended prong and larger ports) e) 2-7/8" EUE 8rd 6' pup joint f) 1 joint 2-7/8" EUE 8rd L-80 tbg g) 2-7/8' EUE 8rd 4' pup joint (pin x pin) h) 2-7/8" L-80 EUE 8rd 'X' nipple with a 2.313" ID (box X box) i) 2-7/8" EUE 8rd 6' pup joint j) Cross over to seal bore extension. k) Halliburton Perma-Sedes packer w/4" bore and 8' seal bore extension RIH at 100 fpm maximum speed and set packer on wireline at approximately 4960'. This depth may be vaded depending upon space out of perforating guns from pipe talley. RD Schlumberger WL. Prepare to run 80' Owen casing patch over the Pool 5.1 (B-3) perfs from 4214-4275'. RIH and set patch as per Owen setting procedure to be published at later date. Casing patch will have a 7.75" ID following set. Patch burstJcollapse are 3565 psig / 3765 psig respectively. TOH laying down DP and tools. Change dual pipe rams to 2-7/8" x 2-3/8". Pressure test same to 250/3,000 psig, Change elevators to 2-7/8". Install 15' bales. RU Weatherford power tongs and dual split slips for 2- IL Schofl~um R. Lanz D. Brlmberry C. Young G. Eller D. Titus 1~ Al~flto 7/8" tubing and 3-3/8" perforating guns. Have on location a floor valve for 2-7/8" EUE 8rd tbg. STERLING-POOL 6 (C-1) SAND COMPLETION RESERVOIR INTERVAL PERFS C-1 4,829-4,906' 77' 18) Hold safety meeting and prepare to run tubing conveyed perforating completion. Radio silence is not necessary. PU completion equipment as follows: a) Locator Seal Assembly 4" x 10' w/molded nitrile 90 Durometer seals b) 1 joint 2-7/8" 6.5 ppf EUE 8rd L-80 tubing c) 4' pup joint 2-7/8" EUE 8rd L-80 (pin x pin) d) 2-7/8" side pocket mandrel (SFO2 w/dummy valve installed) e) 6' pup joint 2-7/8" EUE 8rd L-80 (box x pin) f) 2 its 2-7/8" 6.5 ppf EUE 8rd L-80 tubing g) 1 jt 2-7/8" L-80 tubing 6.5 ppf EUE 8rd pin x Hydril 521 pin h) 2-7/8" Hydril 521 Y- block for perforating the Sterling C-1. Perf guns are to be 3-3/8" Low Side 8 SPF guns loaded with Super DP 22 gram RDX charges loaded to perforate the Sterling C-1 (Pool 6) from 4,898-4,906 (77 feet of perforations). Equipped with a Model K tubing pressure firing head and an annular pressure backup firing head both set to fire at 3,084 psig downhole pressure on the tubing and annulus respectively. i) 1 jt 2-7/8" L-80 tubing 6.5 ppf EUE 8rd box x Hydril 521 pin RA tag to be placed in box end - 30' above firing head) j) 2-7/8" 6.5 ppf EUE 8rd L-80 tubing to surface with estimated pups for space out. Note all OD's and ID's along with serial numbers on all components being run downhole. 19) Tag up on packer and land seal assembly. Mark pipe at neutral point, and determine required space out for placing annular guns on depth. Make up necessary space out pups and mandrel hanger (Full set of 2-7/8" EUE 8rd pups are at Tuboscope). Land hanger. Close annular BOP and pressure test annulus to 500 psig to vedfy packer integrity. Monitor tbg pressure dudng test to verify seal assembly is holding. CLOSELY MONITOR TUBING AND ANNULUS PRESSURE. · TUBING MUST NOT BE PRESSURED ABOVE 870 PSIG AS PERFORATING GUNS WILL FIRE. · ANNULUS MUST NOT BE PRESSURED ABOVE 870 PSIG AS PERFORATING GUNS WILL FIRE. 20) Prepare to run 2-3/8" tbg as dead stdng. Change out elevators, spider, and slips to 2-3/8". 21) Pick up and RIH 4,800' of 2-3/8" 4.7 ppf L-80 EUE 8rd tubing w/SCC. Install hanger and flange up tree. Pressure test tree and seals. Install BPV's in both tubing strings and annulus. Release rig and commence ri.q down. 22) Retdeve BPV's. Hook up flowlines, well instrumentation, and building. 23) 24) 25) 26) 27) B. Schofl~amnn 1L Lanz D. Brimberry C. Young G. Eller D. Titus IL Affinito RU Pollard Slickline Unit on 2-7/8" LS to the Beluga completion. RIH and retdeve dummy valve from GL mandrel. RIH and install odfice valve w/dual check valves to unload liquid from the annulus up the tubing. RD Pollard WL unit. RU BJ nitrogen pumping service to annulus. RU chicksan and flowback iron from 2-7/8" long string to open top tank. Commence pumping nitrogen at initial pressure less than 600 psig to unload the annulus and the open ended 2-3/8" tubing. Pressure should climb to a maximum of 2,100 psig. Should recover 332 bbls of 3% KCI water from the both tubing stdngs and the annulus. Blow down pressure from the annulus while keeping the pressure trapped in the 2-7/8" Long string. RD BJ from the annulus. Secure annulus and hook up flowback iron through choke to the open top tank from the 2-3/8" short string. RU BJ nitrogen pumping equipment to the 2-7/8" long string. Pressure up to 2900 psig using nitrogen and fire the annular guns across from the Pool 6 C-1 perfs. Closely monitor annulus to verify that the perforating guns have fired. RD nitrogen pumping equipment. Begin flowing the Pool 8 completion up the 2-3/8" open ended tubing. Well test plan will be published at later date. Following rate stabilization, the well will be flowed up the annulus and the transient testing performed for Pool 6. RU Pollard slickline unit. RIH to 2-7/8" side pocket mandrel (SFO2) and retrieve orifice with dual checks. Re-install dummy valve. TIH and retrieve prong and PX plug in 'X' nipple below permanent packer. RD Pollard WL unit. UPPER BELUGA SAND COMPLETION RESERVOIR INTERVAL PERFS Ul 5115.5130' 15' (REPERF) U2 5153.5165' 13' U7 5398-5430' 32' TOTAL 6O' 28) RU Schlumberger WL service w/0.23" wire, full lubricator (pump in sub and flow tubes), and pressure control equipment. Pressure test to 2,000 psig. Prepare to perforate with 2" HSD guns loaded 6 SPF 60 degree phased with PJ 2006 HMX 6.5 gram charges. Gun system is Schlumbe~er's SAFE system thus radio silence is not necessary. Correlate depth to Gearhart CBL dated 1-30-85 (NOTE: the CBL is approximately o' high to open hole log). Perforate the Beluga intervals noting change in surface pressure and fluid level. RD Schlumberger 29) RU flowback iron, choke, and gas buster to 2-7/8" LS. Unload Beluga completion to tank. Open well to KGF LP facility at discretion of KGF #1 Operator. CONTACTS Ralph Affinito: Denise Titus: 907-564-6303 (w) 907-231-3775 (p) 907-564-6317 (w) 907-268-7252 (p) Wayne Cissell: 907-283-1308 (w) 907-262-3620 (p) B. Schoffmann IL Lanz D. Brimberry C. Young G. Eller D. Titus 1~ Affinito IPROPOSED WELLBORE 20" 94 ppf H-40 driven to 126' 2-3/8" 4.7 ppf L-80 gTC tbg for unloading the annulus. 8rd tbg 13-3/8" 61 ppf K-55 BTC @ 2538' Otis Cs9 patch w/7.75" ID 'Y' block to peri the C-1 from 4829~4906' w/3-3/8" Low Side perf Guns 2~7/8" SFO2 GL mandrel for 1-1/2" valves Halliburton Perma Series Pkr @ 4960' 2~7/8" EUE 8rd 'X' nipple w/2.313" ID 2-7/8" EUE 8rd 'X' nipple w/2.313" ID WL Re-entry guide [U-I Peris 5112~5129' IU-2 Peris 5152-5165' (TO BE ADDED) IU-5 Peds 5282-5303' IU-7 Peals 5398-5430' (TO BE ADDED) 5520~5545' 1~-3 Peris 6788-6810' 9-5/8" 47 ppf N-80 @ 6950' ~ o, P~,~h: t st~o~. / -- ] (TVD)I t Completion Fluid: [Prepared By: ~[ R Aff~nito~ LastR .......... i B-3 Sd. 7 8 Beluoa Zn. ! . V ~ 4 10 '--,..j CASING & ABANDONMENT DETAIL I. Elevation Kelly Bushing at 0.0' II. Cameron Dual Tubing Hanger at 25.41' III..20°, 94~,, H-40 Driven to 126' IV. 13-3/8°, 61~', K-55 Buttress Casing at 2,538° V. E.T.D. at 6,841' VI. 9-5/8', 47+, N-80 Casing at 6,950° TUBING DETAIL LONG STRING: 3-1/2", 9.2~, N-80 TUBING 1. Otis 'XA° Sleeve at 4,116.04' 2. Otis Model 'RDH' Dual Packer at 4,155.04' 3. otis 'XA° Sleeve at 4,180.57' 4. Blast Joints From 4,199.71' to 4,298.63' 5. Otis 'XA' Sleeve at 4,971.90' 6. Otis Straight Slot Locater Sub at 5,006.40' 7. Otis Molded Seal AssemOly From 5,007.76' to 5,O18.11' 8. Otis Model 'WD° Pro(I. Packer at 5,007" 9. Otis 'X' Nioole at 5,050.57' 10. Bottom et Otis Mule Shoe at 5,074.27' SHORT STRING: 3-1/2", 9.2#, N-80 TUBIAIG A. Otis 'XA° Sleeve at 4,085.40' B. Otis Model 'RDH° Dual Packer at 4,154.71' C. Bottom et otis 'XN° Ni0Dle at 4,17:3.16' PERFORATION RECORD DA TE INTERVAL CONDITION 2/23185 6,788'-6,810' 5,520°-5,545' 5,112'-5,129' 4,214°-4.275. Beluga Zn. Pro0uotlon B-3 Sd. Procluction ! WELL KBU 23X-6 WELL SCHEMATIC UNION OIL COMPANY Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7~ Ave Suite 100 Anchorage, AK 99501 June 1, 2001 RE: Annular flow from KBU 23X-6 Permit Number: 84-109 Mr. Tom Maunder, We plan to commence workover operations on the KBU 23x-6 in the Kenai Gas Field approximately June 06m, 2001. This well is intended to have 2-7/8" tubing and a packer to facilitate tubing flow production from the Beluga intervals, and Steding Pool 6 annular production above the packer with open ended 2-3~8" tubing installed as an artificial lift stdng (refer to attached well bore diagram). The approximate SBHP's are Pool 6 - 360 psia and Upper Beluga - 543 psia. Annular flow from the Iow-pressure Sterling Pool 6 reservoir is currently approved in the Kenai Gas Field. A wellhead specifically designed for annular flow will be installed. This tubing head will have dual 7-1/16" 3,000 psig valves on one side and a 2" 3,000 psig blind flange on the opposite side of the tubing head. Annular flow will only be through the 7-1116' outlet. Production will be controlled by a 7-1/16' 3,000 psig surface safety valve. This installation is specifically designed for annular flow due to the large inside diameters exiting the tubing head. The erosional velocity and the wells predicted capability are outlined on the attached document. The odginal dual 3-1/2" 5,000 psig tree will be installed on the tubing head. Anticipated first annular production will be in July 2001. A Form 10-407 Well Completion Report will follow the workover operations. Please feel free to call for any additional information or to discuss any required changes 907-564-6303. Sincerely, Ralph J. Affinito Production Engineer Enclosure MARATHON OIL COMPANY ALASKA REGION KENAt GAS FIELD WELL KBU 23X~6 ANNULAR FLOW EVALUATION 'The KBU 23X-6 was designed to facilitate annular flow from the iow-pressure (tess than 400 psig) Kenai Gas Field Steding resep¢oirs. The tubing head has 7-1/16" 3,000 psi9 working pressure valves in addition to a %I/16" surface safety valve at the weUhead, Based upon Iog evaluation, the Poo~ 6 reservoir's maximum predicted detiverabi!ity via annular flow is 14 MMCFGPD. TOPIC D~SCUSS~ON Erosional Velocity Corrosion Surface Safety Controls The highest potential for erosive flow exists at the BPV profiles in the %!/16" 3K flanged outlet of the tubin9 head. The BPV threads inside this outlet has an iD of 5-13/16" as the smallest restriction, Marathon pians to produce the well below erosive limits. Marathon will conduct periodic UTT inspection of the wellhead and flowlines for siqns of unusual wear. The partial-pressure of CO2 is less than 1.0 psi. If the partial pressures of CO2 is less than 7 psi the 9as is generally considered noncorrosive. There is no H2S gas produced in the Kenai Gas Field. Corrosion o,_____.____ f. the The annulus will be produced via a separate flowfine from the existing tubing completion. Surface safety controls will be similar to that of other Kenai Gas Field completions. Burst/Collapse of Casing e Pressures imposed on the 9-5t8" casing during this procedure will not compromise the integrity of the casing. Worst-case forces will not exceed 25% of the rated casin~ burst. Fwd: KBU 23x-6 ,~-.-~ Subject: Fwd: KBU 23x-6 Date: Wed, 23 May 2001 22:44:02 EDT From: STMaunder@aol.com To: tom_maunder@admin.state.ak.us Subject: RE: KBU 23x-6 Date: Wed, 23 May 2001 09:40:48 -0800 From: "Affinito, Ralph J." <RJAffinito@MarathonOii.com> To: <STMaunder@aol.com> Tom, Attached please find our stack configuration. We will have dual 3-1/2" elevators in the top rams while pulling the tubing. We are also looking for swivel elevators to more easily align our pipe with the rams should we need to close them. Regarding the tree, we will be leaving the existing tubing head and installing a 11" 3K tbg head with a 7-1/16" 3K side outlet for annular flow on top of the existing tbg head. We will re-use the existing dual 3-1/2" tree. As for our rig schedule, we will move the rig from KU 24-5 to KBU 23x-6, then to SU 41-15. I will be sending you a sundry for SU 41-15 this week. After that Tom, we are not sure where the rig will go next. We expect it to be the Falls Creek #1 workover to repair the communication problem. We then are submitting permits for a KU 21-6 sidetrack and a second Niniichik well, but the timing of these has not been resolved internal to MOC at this point. Please let me know when/if you have approved the KBU 23x-6 sundry as we will likely begin work early next week if possible. Thanks, Ralph J. Affinito Marathon Oil Company- Alaska 907-564-6303 --~-Original Message- .... From: STMaunder@aoi.com [maiito:STMaunder~,aol.com] Sent: Thursday, May 03, 2001 6:24 AM To: Affinito, Ralph J. Cc: tom_maunder@admin.state.ak, us Subject: KBU 23x-6 Ralph, ! was reviewing your proposal for this workover/recompletion and had a few questions/requests. 1-Could you please provide a diagram of the stack and wellhead configuration. ;Z--What are the present surface and bottomhole pressures for the SS and I of 2 5/31/01 3:39 PM Fwd: KBU 23x-6 , LS? 3-What has the recent production been for each string? 4-In your procedure you discuss filling the annulus to allow a pressure test of same. Prior to setting the tubing plug, do you plan to kill the tubing strings? 5-When you set your storm packer, you say to pressure test above the plug. I presume you mean the casing from the storm packer to surface. I understand the rig has been idle due to road restrictions. Would you please provide a schedule of the work planned when the rig gets back to work, Thanks Ralph. !'ii look forward to talking with you later today. Tom Maunder Type: Microsoft Excel Worksheet (application/vnd.ms-excel) i Name: BOP.xls t ~BOP.xlsl Encoding: base64 [Description: BOP.xls 2 of 2 5/31/01 3:39 PM Marathon Oil Well KU 21X-6 BOP Stack IFiow Nipple i13 5/8" 5M Annular Preventer 13 5/8" 5M Double Ram Preventer ' 3 1/8" 5M Manually ! Operated Valves '-~ ~"--~ ....... ',~, t,35/s,,'5UCr&ss"l ~ ~ Ram Preventer ! I I IPipe Ram ! IBlind Ram I , ! IPipe Ram ] I3 1/8" 5M Hydraulically IOperated Valve IOperated Valve , , EI I~wcl: KBU Subject: Fwd: KBU 23x-6 Date: Wed, 9 May 2001 22:28:09 EDT From: STMaunder@aol.com To: tom_maunder@admin.state.ak.us Subject: RE: KBU 23x-6 Date: Wed, 9 May 2001 16:39:37 -0800 From: "Affinito, Ralph J." <RJAffinito@MarathonOil.com> To: <STMaunder@aol.com> Tom, I am back in the office today (Wednesday). Sorry for the delay. To answer your questions. 1. I will fax you a diagram of our proposed stack configuration as well as the current tree/wellhead. 2. The current SBHP's for the SS (Sterling B-3 - Pool 5.1) is approximately 525 psig. The current SBHP for the LS (Upper Beluga) is approximately 435 psig. 3. The recent production for both strings is 0 MCFGPD. The B-3 is watered out and the Upper Beluga is loaded up with water. Part of our proposed project will install smaller tubing to help unload the Beluga reservoir. 4. Pressure testing the annulus is something that i would rather do once the rig is on the well to reduce costs. The tubing will be filled with the rig following the pressure test, so i will not kill the zones. 5. Regarding the Storm Packer - yes, we will pressure test the casing above the pkr prior to removing the stack. The current rig schedule is as follows (oilfield dates): May 04-18 KU 24-5 Workover May 20 - June 3 KBU 23X-6 Workover June 06 - June 20 SU 41-15 Workover Gary Eller will be working on the SU 41-15 so I am speculating on the length of the job for that workover. Our plans after these three are not certain. We have a couple of other projects that require attention with the rig. ! will discuss with the rest of our group and we'll send you a schedule in the next week. Please call for any additional information. Thanks, Ralph J. ^ffinito Marathon Oil Company- Alaska 9O7-564-63O3 ..... Original Message ..... From: STMaunder@aol.com [mailto:STMaunder~,aol.com] Sent: Thursday, May 03, 2001 6:24 AM To: Affinito, Ralph J. I of 2 5/31/01 3:41 PM Dec-15-O0 03:1Opm From-UAE^THOH ~...u... +glssG4548g ~ T-Og3 P.OZ/04 F-og$ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation Shutdown Alter Casing _. Repair Well ~ Plugging ---. Change Approved Program __ 2. N~rn~ of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchora~le, AK 9gS1a-6168 4,, Location of Well at 291' N & 1208' E of SW Comer Sect At top of p¢oductive Interval 1468' H & 1491' E of SW Comer At Effeotive Depth lAdd Perforations 242.1' N & 1704' E o~ SW Corner :12, 'Present W~rl-i:.",ondition Summary Pull Tubing __ Variance__ .--- _ . S. Type of Well: IDe.,velo p me n t ...~._x Exploratory Stmtigraphi~"--'- Service ,, Re-enter Suspended Well Time Extension __ Stimulate Pedorate Olher 6. Deism I~l~va~ion (DF or Pad 66' MSL 7, Unit or Property Name Kenai Beluga Unit "8'. Well Number 9, 10, 23x.6L P~-~riit Number 84-109 -APl Number 50-133-20371 · _ Field/Pod Kenal Gas Field/'Belu~a Pool · Total Depth:- measured 6960 feet true verUca! 644? feet plugs (measured) Effeolive Depth: measured 6841 feet true vertical 6341 feet Junk (measured) C~ing Structural Conductor Surface Intermediate Pmduedon liner Perforation Depth; Length 'Size Cemented 126' 20" Ddven 25,3E 18-3/8" 1870sx 6950' g-~8" measured 5112'-6810' Measured Depth True Vertical Depth 126'126' 2532.' 2454' 6950' 6447' RECEIVED tme verticaJ 4'/'11'-6311' Tubing (size, grade, and measured depth) 3-1/2', g.2 ppf, N-80, 5074' Packere and SSSV (type and measured depth) WD Packer @ 5007'/Dual @ 4155' 13. Attachments Description .~mmary of Proposal__ 14. EstimatedO~te for Commenmng Oparalion 12/18/00 P~op~sal wee V~-ally'Approved ..... Name of Apprever Date ApprovEKI DEC 1 5 2000 Alaska OH & Gas Cons. Commission Detailecl Operation~ program ~ BOP Sketch ~ 15. St~tue 0fWell'~31ae~sification as: Oil Gas 7, Suepended ~ Service hereby certify that the foregoing is true and correct to the best of my knowledge, ~i.~ned /~.1/~ ~~_. Deniae Titus 1-ifle ProdkJ (~Joll IErt~ ,rte er ~ ..... FOR cOMMISSldN USE-ONLY ~,75Jldi~ns of Appmv~.l: NoU1~-C0mmission so representative may witness Plug Integrity BOP Test Localion Clearance Me~anic~l In. fy Teat "'"SubseQuent Eorm~equired 1 o.. -7 ~ .~)i-~l LSI I~lAl' $1GNEDBY .... D Taylor Seamount ~pr.oved by O_rd. er el ~e Commission , I o-4o~ Fray, Dute 1N 18100 Commieeione¢ Dale O/ /r~'~/_~ ' :~Ibfnirin' T-r~licate Dec-l~-O0 03:1Opm From-MARATHON OIL +gl~$$4848g T-Og3 P.03/04 Marathon Oil Company Alaska Region KBU 23x-61 Kenai Gas Field, Pad 14-6 Perforate Objective: Add Perforations in the U5 sand Procedure: 1. MIRU Schlumberger electric line. Test BOPs and lubricator to 2500 psig. RIH w/2-1/8" EI Strip gun, 6 spf, 0 deg. phase. Tie in with GR/CCL. Perforate the U5 sand as follows: 5280'-5301' (21') 2. POOH. RDMOelectdc line, 3. Flow well as Per engineer's instruction. 12/15/00, DMT Dec-15-00 , 03:10pm From=MARATHON .., +0155646489 ~._... T-0g3 P.04/04 F-095 II I11 i i ' ' I l ! ! 'lllll lt~ln~a CASING & ABANDONMENT DETAIL I. ElevaTto~ Kelly Busnincj at II. CAmeron Dual Tubincj Hanger at 2E,41' i11. 20', 94~*, H-4C) Driven to 126' IV. 13-318', 61--, K-$5 Buttress Casinq at 2.538' V. E.T.D. at 6,841° VI. 9-$11]', 47~,, N-f30 Casing at 6,950' TUBING DETAIL LONG STRING: 3-I/2', ,9.2,//,, N-80 TUBING Otis 'XA° Sleeve at 4,11;I.04' Otis Model 'RDH' Dual Packer at 4,155,04' $. 6+ T. 8. g. 10. Otis 'XA' Sleeve Blast Joints Frorlt Otis 'XA' Sleeve Otis Straight Slot at 4,1B0.57' 4,199.71' lo 4,298.63' at 4,87'1.90' Locater Sub at 5,008.40° Otis MolCled Seat AssemBly From 5,00T.'78' to.5,010.11' C~tl~ Moclei 'WD' ProS. PacKer at 5,007'. Olis ~X' Nipple a! 5,05CI.57' Bottom of Otis Mule ~rtoe et 5,074.27' SHORT STRING: 3-1/2", 9.2.~, I%1-80 TUBING A. Otf~l 'XA' Sleeve at 4,0-B5.40' B. OltS MB.el *ROll' Oual Peeker at 4,154,71' C, Bottom of Otis 'XN° Nil~ple a! 4,173.16' PERFORATION RECORD DA TE INTERVAL CONDITION 2/23/85 6,788'-6,810' / 5,520'-5,545' ~- Beluqa Zn. PreaUCllon 4,214'-4,275' 8-3 Sd. Production " WELL KE U3X-6 __ -;---- - -~ WELL SCHEMATIC i- i~ r 1']I - ' .... UNION OIL COMPANY $~LI ~ ." ,, OAT~ 414tf/Je - ~-¢.? ,-~ ~_. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Pull tubing __ Alter casing __ 2. Name of Operator Union Oil Co. of Calif. (UNOCAL) 99519-0247 3. Address PCB 190247, Anch, AK., 4. Location of well at surface 291' N & 1208' At top of productive interval 1468' N & 1491' At effective depth Stimulate __ Plugging __ Repair well __ 5. Type of Well' Development X_~ Exploratory __ Stratigraphic __ E of SW Corner Section E of SW Corner Section Attotaldepth 2421' N & 1704' E of SW Corner Section 12. Present well condition sUmmary Total depth: measured true vertical Perforate X ~ Service __ Other __ feet 6. Datum elevation (DF or KB) Pad 66' MSL 7. Unit or Property name Kenai Gas Field 8. Well number KBU 2 3X-6 9. Permit number/approval number 84-109/9-586 10. APl number 50-- 133-20371 Effec.tive depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 6,950' feet 6,447' feet 6,841' feet 6,341' feet Plugs (measured) Junk (measured) ~ngth Size Cemented 126' 13" Driven 2,532' 13-3/8" 1,850 sxs 6,950' 9-5/8" measured Top - 5,112' Bottom - 6,810' truevertical Top - 4,711' Bottom - 6,311' Tubing (size, grade, and measured depth) 3-1/2", 9.6#, N-80 5,074' Packers and SSSV (type and measured depth) Otis "WD" packer @ 13. Stimulation or cement squeeze summary Measured depth 11. Field/Pool Beluga Pool True vertical depth 126' 126' 2,532' 2,454' 6,950' 6,447' RECEIVED OCT 1 .. Alaska Oil & Gas Cons, Comrnissio Anchorage 14. Intervals treated (measured) 5,007'/Dual @ 4,155' 5,112' - 5,129' / 5,520' - 5,545' Treatment description including volumes used and final pressure Reperforated 4 SPF w/2-1/8" W/L guns Tubing Pressure Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 0 ± 2,580' 5 0 ± 350 0 ± 2,980' 5 0 ± 350 Service 16. Status of well classification as: Oil__ Gas X__ Suspended__ Date 10 / 13 / 89 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Roberts Title Environmental Enqineer Form 10-404 Rev 06/15188 SUBMIT IN DUPLICATE ,/~ KENAI GAS FIELD KBU 23X-6 DAILY REPORT 1) 2) 3) 4) 5) 6) 7) RU D.A. wireline perforating guns over KBU 23X-6L. Pressure tested lubricator to 1,000 psi. RIH with 1-11/16" guns loaded, 4 SPF, phased 0°, decentrallized. Located guns across 5,112' - 5,129' / 5,520' - 5,545' / 6,788' - 6,810'. Perforated well at balance. POOH & RD wireline unit. Returned well to production. SBHP: 560 psi Well Contorl Fluid: Water NKS:trf 0669tr-1/2 RECEIVED OCT 1 Alaska Oil & 6as Cons. Comr,',issiori Anchorage STATE OF ALASKA --~ A; .~KA OIL AND GAS CONSERVATION COML ..~ION APPLICATION FOR SUNDRY APPROVALS Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension ~ Stimulate __ Pull tubing __ Variance ~ Perforate ~' Other 1. Type of Request: Abandon ~ Suspend __ Alter casing ~ Repair well Change approved program __ 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 190247, Anch, Ak., 99519-0247 4. Location of well at sudace -291' N & 1208' E of SW Corner Sect. At top of productive interval 1468' N & 1491' E of SW Corner At effective depth 5. Type of Well: Development Exploratory 6. Datum elevation (DF or KB) Pad 66' MSL kT. Unit or_Prope_dy n~lrqe enai ~as ~u.e.LCt 8. Well number KBU 23x-6 9. Permitnumber 84-109 10. APInumber 50-- 133-20371 11. Field/Pool Beluga Pool At total depth 2421' N & 1704' E of SW Corner 6950 ' feet Plugs (measured) 6447 · feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured 6841 true vertical 6341 : Length 126 ' 2532 ' 6950 ' measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Tubing (size, grade, and measured depth) feet Junk (measured) feet Size Cemented Measured depth 20" Dr iven 13-3/8" 1,870 sxs 9-5/8" Top - 5112' Bottom - 6810' Top - 4711' Bottom - 6311' 3-1/2", 9.2#, N-80 5074' WD Paker @ 5007'/Dual @ 4155' True vertical depth 126' 126' 2,532' 2,454' 6,950' 6,447' Packers and SSSV (type and measured depth) Description summary of proposal __ Detailed operations program X' BOP sketch __ 13. Attachments 14. Estimated date for commencing operation July 14, 1989 Date approved 15. Status of well classification as: Oil __ Gas .X__ Suspended __ Service 16. If proposal was verbally approved Name of approver Date 6/7/89 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~:~'~, ~~ Title Environment al Engineer Roe D. Roberts FOR COMMISSION USE ONLY Commissioner I Approval NO. Approved Copy'"' Returned Date "-7 ~ I~.~- ~7 feet Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ORIGINAL SIGNED BY LONNIE C. SMITH Approved by order of the Commissioner 0062~./13 Form 10-403 Rev 06~5/88 SUBMIT IN TRIPLICATE Kenai Gas Field KBU 23x-6L PERFORATING PROCEDURE 1. RU wireline perforating guns over KBU 23x-6L 2. Pressure test lubricator to 1500 psi 3. RIH with 1-11/16" guns loaded, 4 SPF, phased 0°, decentrallized 4. Locate guns across 5112'-5129'/5520'-5545'/6788'-6810'. (Approximately 3 runs may be required since no more than 20' will be shot at a time.) 5. POOH & RD wireline unit 6. Return well to production. SBHP: 560 psi well control fluid: water 0062/14 ALASKA OIL AND ~AS GONSERYATION.~,OMMISSION ! Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA ggs01~3592 TELEPHONE(90/) 27g~1433 Afro.' We ~ish to brtn~ to your attention that the Co~tsston has ye~ ~eceived ~he ~ollo~i~; ;equired items on the subject ~ell Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing .material. erely. Chairman lc:C.024 Union Oil and Gas D~.v~,sion' Western Region Union Oil Company ,.., California P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600 union April 29, 1985 Mr. C.V. Chatterton AK. Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Dear Mr. Chatterton: SUNDRY NOTICE KBU 23X-6 Attached is a Sundry Notice Subsequent showing the correct Total Depth coordinates for KBU 23X-6, Kenai Beluga Unit. If you have any questions, please do not hesitate to contact me at the telephone number listed above. Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST LOC/tj Attachment cc: Partners RECEIVED APR 0 1985 Alaska Oil & Gas Corm. Cornrnissior~ Anchorage '~ "' STATE OF ALASKA ' ' ALASKAIOIL AND GAS CONSERVATION CL~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator UNION 0IL COMPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well 291' N & 1208' E of the SW Cor, Sec 6, 5. Elevation in feet (indicate KB, DF, etc.) Pad F;~' MRI 12. T4N, RllW, SM 7. Permit No. 84-109 8. APl Number 50-133-20371 9. Unit or Lease Name Kenai Beluga Unit 10. Well Number KBU 23X-6 11. Field and Pool I 6. Lease Designation and Serial No. Kenai Gas Field A-028142 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This is to correct the coordinates for Total Depth previously reported to you in error'On the Nell Completion Report on 03-12-85. 2452' N & 1672' E of SW Cor, Sec. 6, T4N, RllW, SM. 14. I hereby c~th~,eg~correct to the best of my knowledge. SignedLawrence 0 Cu~.tinq-'i RECEIVED ,APR o Alaska Oil & Gas Cons. C0mrnlssJ01 The space below for Commission use TiceENVIRONMENTAL SPECIALIST ? Date 0.~-29-85 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Union Oil .and Gas Dj,~__ion' Western Region Union Oil Company o, California P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600 union April 11, 1985 Hr. Michael Minder AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Hinder: Please find attached, information on K8U 23X-6 DST's, requested by you as per our phone conversation dated April 10, 1985. If you have any additional questions regarding this well or any other well in the Kenai Gas Field, please feel free to give me a call. Navin K. Sharma Petroleum Engineer NKS/rrr/lOSlr cc: C. H. Case L. O. Cutting Attachment March 22, 1985 Mr. Robert C. Warthen Union Oil Company of~ California P. O. Box 6247 Anchorage, Alaska 99502-0247 Re: Union Kenai Beluga Unit 23X-6. Dear Bob: Thanks for the timely submittal of the completion report on the subject well. The only problem is, the report we received yesterday was on the federal form, not the Alaska form. The single copy of the federal form you submitteLd' 'iLs accordingly returned herewith. Please submit two copies of the required state Fora 10-407 (Well Completion or Recompletion Report and Log). Sincerely, . ~ William Van Alen Senior Petroleum Geologist be: 8.WVA Enclosure Union Oil and Gas Division: Western Region Union Oil Company, ~, California P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600 union DOCUMENT TRANSMITTAL TO: William Van Alen LOCATION: Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION March 21, 1985 HAND DELIVERED FROM: R.C. Warthen K. D. Kiloh LOCATION' Alaska District y~/~ 2-/~- Transmitting' ., Re: ~'k'BU 23X"6 ~.-;~ - (1 Library magnetic tape of logs and verification list (~.~ ~e (1 DST i report ~One (1) DST 2 report ~ ~ne (1) DST 3 report ~ ~e (1) Sperry Sun multishot gyroscopic survey / ~e (1) 2" and 5" blueline Dual Induction Focu~Log ~One (1) 2" and 5" blueline Microlateroloq ~ne (1) 2" and 5" blueline Compensated D~nsilog ~ne (1) 2" and.5" blueline Compensated Densilog and Compensated Neutron Log ~ne (1) 2" and 5" blueline BHC Acoustilog ~One (1) 5" blueline VDL ~ne (1) 5" blueline Cement Bond Log ~ne (1) 2" and 5" sepia Dual Induction Focused Log ~ne (1) 2" and 5" sepia Microlaterolog ~ne (1) 2" and 5" sepia Compensated Densilog ~ne (1) 2" and 5" sepia Compensated Densilog and Compensated Neutron Log ~ne (1) 2" and 5" sepia BHC Acoustilog ~ne (1) 5" sepia VDL PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: DATED' I STATE OF ALASKA *'~*'. b¢~z~ -:-' ~' - ALASKA u~ AND GAS CONSERVATION GL .MISSION ~ ..... "WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status .of Well Classification of Service Well OIL [] GAS[] SUSPENDED [] ABANDONED [] SERVICE []' 2. Name of Operator 7. Permit Number .... UNION 0TL COMPANY OF CALTFORNIA 84-109 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50_133-20371 , 4. Location of well at surface 9. Unit or Lease Name 291' N & 1208' E of SW Cor, Sec. 6, T4N, RllW, SM Kenai Beluga Unit At Top Rroducing Interval 10. Well Number 1468' N & 1491' E of SW Cor, Sec. 6, T4N, RllW, SM KBU 23X-6 At Total Depth 11. Field and Pool 2421' N & 1704' E of SW Cor, Sec. 6, T4N, RllW. SM .5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kenai Gas Field Pad 66' MSLI A-028142 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 01-10-85 01-27-85 02-28-85 feet MSL 2 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 6950'MD+6447'TVD 6841 'MD+6341 'TVD YES [] NO [] feet MD 22. Type Electric or Other Logs Run CBL/GR/VDL/CCL/FDL/CNL/DIL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED _20. ...... Plain 126, ___ Driven --- 13 3/8" ~1# ~-55 R~d-f_ 7532' ]7 ]/2" 1870 sxs cl ,,G,, ___ ~ 5/8" 47# N-80 R,,tt- '695R, ]2 ]/4" Sxs el "G" ___ 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6788-6810' DIL 6279-6311' TVD 8/HPF SS 3 1/2" 4171' 4155' 5520-5545' DIL 5086-5109' TVD 8/HPF LS '~ 1/?" _5n73, 5ni]9' 5112-5129' DIL 4712-4728' TVD 8/HPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 4214-4275' DT-L · 3914-3699' TVD 8/HPF DERTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED c;FF /~TTAI't. HFD ADDENDIIM 27.' , ':PRODUCTION T'EST Date First Production ' Method'of Operation (Flowing~gas lif~, etc.) 03-05-85 6~s Prodt.~oer Date of Test Hours Tested PRODUCTION FOR O~L-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-O~LRAT~O ~02L08-85 240 DST'S TESTPER~O[) ~ n0-- .i,070 20 bbIs 0.5" ~ ~D:~D~U' p¢ i.*Tu~q' ;~asing Pressure. CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAV ITY-API (cot;)' '~_~-700p:~i-0, 124-HOUR RATE J~ -0-- '4.5 0.8bpd 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Shot 36 Sidewall Cores - Recovered 14 . swc _ RECEIVED -3~3-49 ' ' 3796 ' 4080 ' 4502 ' 5410' 6224 ' ~345' 3810' 4230' 4516' 5522' 6394' i~'1'~,~;~ 2 0 3351 ' 3890 ' 4344 ' 5124 ' 5540 ' 6414 ' 3347' 3~00' 4334' . - 5220' -5910' 6700' ~aska Oil & Ga~ Cons, 3353 ' 4060 ' 4354 ' 5294 ' 5929 ' . 6806 ' Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE - .,~ . .~.~'i GEOLOGIC MARKERS : 'FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Radioactive Marker 3346' 3164' (1). A total of 8 DST's were conducted. SEE ATTACHED ADDENDUM Top Sterling (2). DST's #2,#3 & #7 were completed in the LS. Measured-shut-in pressure 1500 psia & Gas Sands '(A-8) 3782' 3540' 1820 psia bottom hole pressure. (3). DST #8 was completed in the short strin, Top Beluga shut-in pressure 1000 psia & + or - ll70 psia Formation 5113' 4684' bottom hole pressure. · .- (4)- Gas Gravity LS 0.55 (5). Gas Gravity SS 0.557' · 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Lawrence O. Cutting Title ENVIRONMENTAL Date 03-12-85 c;PP¢_ T/~1 TqT INSTRUCTIONS General· This form is designed for submitting a compl.ete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' .Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas' Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". KBU 23X-6 DST INF~R~MATION ON~ PRQD. UCTIVE Z. QNES DST-2 . . (L. Beluga 6788'-6810') RATE TIME TES!ED VQLUME RECOVERED MMCF/D HRS MCF 2/8/85 0.5 0.5 10.4 0.55 0.5 11.5 0.61 0.5 12.7 TOTAL 34.6 MCF Surface flowing pressure was 600 psi during this DST. ~ (U. Beluga 5520'-5545') DATE RATE TIME_TESTED VQLUME R. ECOVERE~ MMCF/D HRS MCF 2/12/85 2.19 0.5 45.6 2.29 0.5 47.7 2.32 0.5 48.3 2.31 O. 5 _48 ._ 1 TOTAL 189.7 Surface flowing pressure was 600 psi during this DST. (U. Beluga 5280'-5301') MMCF/D HRS VOLUME RECOVERED MCF 2/15/85 0.01 3.6 1.5 Surface flowing pressure was 605 psi during this DST. DST-7 ~ _ (U. Beluga 5112'-5129') DATE RA~T_E TIME TES.TED _V~,_U~& 5_E~.y:E~,E_D_ MMCF/D HRS MCF 2/18/85 O. 490 O. 5 10.2 0.479 0.5 10.0 0.475 O. 5 9.9 0.478 O. 5 9.9 0.598 O. 25 6.2 0.599 0.5 12.5 0.599 0.5 12.5 o. o TOTAL 84 Surface flowing pressure was ~ 609 psi during this DST. DST-8 RATE MMCF/D (Pool 5.1 4265'-4275') TIME TESTED VOLUME RECOVERED HRS MCF 2/19/85 4.14 O. 5 86.25 4.13 0.5 86.0 4. O0 O. 5 83.3 4.00 0.5 83.3 4. O0 O. 5 83.3 3.96 0.5 82.5 4.02 0.5 83.7 4.12 i.o TOTAL 760.0 Surface flowing pressure was ~ 694 psi during this DST. LLIBURT SEI~VI~£$ TICKET NO. 85258200 05-MRR-85 KENRI F ORMFI T I ON T E S T I NG SE RV I C E REPORT GAUGE !D NO: 2~% DEPTH: 5250,0 DESCRiPTiON BLANKED OFF: :~i_-~ PRESSURE REPORTED I CALCULATED HOUR OF CLOCK: 12 RE?OR'TED n F i i-JRL HvBS}%'STql ! L' 22'54 T ]I'4E l YPE CALCULATED 7:-~: 0 F GAUGE NO:=Pi-5 DeC'TH:,._, bZbt:=,:3_ BLANKED OFF: NO HOUR OF (2LOCI'(: ]2 ID I DFS£RiPTiON · B I !N! I!'-..:_ Fifi'-7 Fi_O~,/ C I F!N,qL FiR't-:j, 7 FLO~.... n J F,iNfiL ;- '( r) ? Fi !:: i q ! ~- PRESSURE REPORTED j CALCULRTED 4~ ~ 477,7 5 0 0 5 O0 REPORTED 7 ]ldE i TYPE ,r:RL[ULR'IFD ¢ E@UIPMENT & HOLE D~T~ TICKET NUMBER~ 65256200 FORMATION TESTED: NET PAY (ftl~ DATE: 2-2~-85 TEST NO: _2 GROSS TESTED FOOTAGE: 233.0 TYPE DST: WRTER SHUT OFF ALL DEPTHS MEASURED FROM~ R KELLY BUSHING CRSING PERFS. (¢~): HALLIBURTON 6AMP: HOLE OR CASING SIZE (in): 9.825 HENRI ELEVATION Irt]: 0 TOTAL DEPTH (f±)= 5~70o0 JoR. POINOEXTER TESTER: PACKER DEPTH(S) (ft): 5237 FINAL SURFACE CHOKE BOTTOM HOLE CHOKE (~n): 0.750 WITNESS: LARRY Lo GORDRN ?? MUD WEIGHT (lb/gol): 9.09 MUD VISCOSITY (sec)= DRILLING CONTRACTOR: ESTIMflTED HOLE TEMP, (°F): BRINKERHOFF RCTURL HOLE TEMP. (°F): 120 FLUID PROPERTIES FOR SAMPLER BRTR RECOVERED MUD & WATER SOURCE RESISTIVITY CHLORIDES Psig R~ SURFACE: © °F ppm cu,ft, OF GAS: © °F ppm CC OF OIL: ~ °F ppm cc OF WRTER: © °F ppm cc OF MUD: ~ °F ppm © °F ppm TOTAL LIQUID cc= HYDROCARBON PROPERTIES CUSHION BRTR OIL GRAVITY (°flPI): ® __oF TYPE AMOUNT WEIGHT ORS/OIL RRTIO (cu.ft. per bbl): KEL & CRCL2 fFT] ]]00.0 9.09 GAS GRAVITY: RECOVERED. NO RECOVERY REHgRK$: REPORTED TOTgL DEPTH IS ~CTU~LLY PLUGGED B~CK TOTAL DEPTH GAUGE ~ 216 BEHAVING ERRATICALLY, TYPE & SIZE MERSURING DEVICE: AOJUSTR8LE CHOKE ON SURFACE HANZFOLD J %]CKET NO: 85258200 SURFROE 6RS LIOUIB CHOKE PRESSURE RRTE RRTE REMARKS TIME SIZE PSI MCF BPD 1858 j STRRTEB CLOCKS -- 1911 TOOLS MRBE UP 1920 RAN tN HOLE WITH TOOLS 2223 3000 PRESSURE TESTED LINES & SURFACE EOUIPMENT 2254 I SET PREKER 2317 I TOOL OPENED 2318 t STARTED BLEEOING OFF ORS I CUSHION 0030 t LOADED TUBING WITH MUD 0044 I I UNSERTEB PACKER 0045 J SHERRED PUMPOUT SUB 0048 J REVERSE CIREULRTED 0130 I PULLEO OUT OF HOLE WITH TOOLS 0400 TOOLS OUT OF HOLE I I I I ___ I , I I I TICKET NO. 65256200 ODD. LENGTH DEPTH TUBING .......................... CROSSOVER ....................... PUMP OUT REVERSING SUB .......... CROSSOVER ....................... CROSSOVER HYDROSPRING TESTER .............. CROSSOVER ....................... CROSSOVER ....................... RTTS CIRCULATING VALVE .......... CASING PACKER ................... CROSSOVER ....................... BUNDLE CARRIER .................. 3.500 3.000 8.!20 3.000 8.120 3.000 5,000 2.250 4.000 2.250 5.000 0.750 5.000 2.250 5.000 2.250 6. i20 3.000 7.800 3,000 4.750 2.250 5.370 2.250 5220.5 1.1 1.O O.g 0,7 5.0 0.? 1.O 5.9 1.2 8.3 5221.6 5224.1 5230.8 5237.0 5250.0 TOTAL DEPTH 5470.0 EQUIPMENT DATFI LLIBURT SERVICES TICKET NO. 65258300 05-HRR-85 KENR] F ORMR T I ON T E S T I NG SE R V I C E REPORT GAUGE NO 2!5 DEPTH: 86%0.n BLANKED OFF: NO HOUR OF CLOCK: PRESSURF lO DESCRiPTiON ~EPORTED I £ALCULnTED ~ !NiT!aL HYO::<OSTfiTiC 2~}'_c:,'3 2893: ! _,', . _ FTNfi'L FTR-~''-, FLn _ ~ ~_J W c ~ $ O T ]HE TYF'E REPORTED ! CgL£UL-~t[ Lfi ' 8l, C) ID 2!8 DEPTH: 86S0:9 BLfiNKEB OFF: NO HOUR OF CLOCK: _ , _ ''vnPrlqTnT .~ T _,,:'{[TTAt FTRcT Fl OW _ _ i . ',, -~; i _ F i i',.:~L F ~ ~.'-'T · r,O, FL0',,,," PRFSSURE REPORTED ] CALCULATED TIME J T F'L REPORTED I CALCULATED ~ NO: DESCRIPTION EOU I PMENT & HOLE DATA TIGHET NUMBER~ GS~5BSO0 FORMATION TESTED~ NET PAY [ft]~ DATE: ~-23-85 TEST NO: GROSS TESTED FOOTAGE: 74.0 TYPE DST: WATER SHUT OFF ALL DEPTHS MEASURED FROM= R KELLY BUSHING CASING PERFS, [£t)= HALLIBURTON CRMP~ HOLE OR CASING SIZE (tn): 9.625 KENRI ELEVflT!ON {£t): 300 TOTAL DEPTH [fi): 6711o0 J,R, POINDEXTER TESTER: PACKER DEPTH(S) [£t): FINAL SURFACE CHOKE BOTTOM HOLE CHOKE (in)= 0.?50 WITNESS= LARRY L. GORDON ?? MUD WEIGHT lib/gal): 9°09 MUD V~SCOSZTY DRILLING CONTRACTOR: ESTIMATED HOLE TEMP, [°F)= ~0 BRINKERHOFF DRILLING ACTUAL HOLE TEMP. (°F): © ft FLUID PROPERTIES FOR SAMPLER DRTR RECOVERED MUD & WATER SOURCE RESISTIVITY CHLORIDES Pstg RT SURFACE: e °F pp~ cu,ft. OF GAS: © °F ppm cc OF OIL: © °F ppm cc OF WATER: © °F ppm cc OF MUD: © °F ppm © °F ppm TOTAL LIQUID cc: HYDROCARBON PROPERTIES CUSHION DATA OIL GRAVITY [°~PI): ~ oF TYPE AMOUNT WEIGHT GAS/OIL RATIO [cur±. per bbl): KEL & EAEL 2-FT. ]]00.0 9,09 GAS GRAVITY: RECOVERED: NO RECOVERY REMARKS: TYPE & SIZE MEASURING DE¥]CE: ADJUSTABLE CHOKE ON SURFACE MAN]FOLD I TICKET NO: 65258300 ~= ~o~ ~sso~I ~ ~n~ REMARKS I 2-22-85 1808 I STARTED CLOCKS 1821 TOOLS MADE UP 1835 RAN IN HOLE WITH TOOLS 1924 1 MBOE UP SURFACE EQUIPMENT 1948 I 3000 PRESSURE TESTEO SURFACE EQUIPMENT ]958 LOBOEO GAS CUSHION 2007 SET RTTS 2028 TOOL OPENEO 2028 I BLEO OFF GAS CUSHION 2040 I I BUBBLE HOSE OEAO 2204 SHEARED PUMPOUT SUB I 2205 REVERSE CIRCULATED 2245 I PULLED OUT OF HOLE WITH TOOLS I LAYING DOWN TUBING. TICKET NO. 65256300 LENGTH DEPTH TUBING .......................... 3.500 CROSSOVER ....................... 6.120 PUMP OUT REVERSING SUB .......... 6.120 CROSSOVER ....................... 5,000 CROSSOVER ....................... 4.000 HYDROSPRING TESTER .............. 5.000 CROSSOVER ....................... 5,000 CROSSOVER ....................... 5,000 RTTS CIRCULATING VALVE .......... 6.J20 CRStNG PRCKER ................... CROSSOVER ....................... BUNDLE CARRIER .................. 3,000 3,000 3.000 2.250 2.250 0.750 2.250 2,250 3.000 7.800 3.000 4.750 2.250 5,375 2.250 6619.8 1.1 1.0 0.9 0.7 5.0 0.? 1.0 3.9 5.9 1.2 8.6 6620.9 6623.4 6630.0 6637,0 6650.0 TOTAL DEPTH 6711.0 EQUIPMENT DATA LLIBURT SERVICES I]CKET NO. 85256]00 05-MRR-85 KENR] F ORMR T I ON T E $ T I NG SE RV I C E REPORT GAUGE NO: 215 DEPTH: 5175.0 BLANKED OFF: f,!O HOUR OF CLOCK ID DESCRIPTION !N-TilL HYDROSTATIC ][-..]~TT~i F=~ST FI OW FIRST FLOW PRESSURE i TIME REFORiED CBLCUL~iED : REFORTED ] CALCULATED cz 0 94,0 4 7 ~3: C El ' Fi!',~qL ~ ...... ,~YORnSTFI~iC,,~ , .21~i?, .-~.-.~. TYPE GfiUGE NO: 2i5 DEPTH: 5175.0 BLRNKED OFF: NO HOUR OF CLOCK: 24 DESCRIPTION ~i',!~TT~ F_T'-'CT FLNU P, EPO,~TED i 221~ 469 ~ (-;, S ? PRESSURE TME' ...... ','~'~ ......... TYPE CRL£ULRIEEI REPORIED ' £RLCULRTEO 22S~ ~ ;q ~i,,1 , fi.', F 2254: 4 EQUIPMENT & HOLE DATA TICKET NUMBER:85258100 FORMaT!ON TESTED: NET PRY (ft]: DATE: 2-21-85 lEST NO: 1 GROSS 7ESTED FOOTAGE: 74.7 TYPE DST: W~TER SHUT-OFF -ALL DEPTHS MEASURED FROM: R.K~Bo CASING PERFS. (~): HALLIBURTON CAMP: -HOLE OR CASING SIZE (in): g.625 KENRI ~LEVRTION [ft): 0 ~O~RL DEPTH Irt): 5235.0 J.R, POINDEXTER TESTER: 'PACKER DEPTH[S) [Ct): 5~GO FINAL SURFACE CHOKE :BOllOM HOLE CHOKE (~n): 0.750 WIINESS: LARRY L, OROLE ??? MUD WEIGHT [!b/gol): 9°09 MUD VISCOSITY DRILLING CONTRACTOR: ESTIMATED HOLE.~,',,~c~°. [OF}: BRINKERHOFF 54 -ACTUAL HOLE TEMP. [°F]: FLUIB PROPERTIES FOR SAMPLER BATH RECOVERED HUD & WATER SOURCE RESISTIVITY CHLORIDES Psig RI SURFACE: ~ °F ppm cc OF OIL: © __oF ppm cc OF WAT'ER: a __°F ppm cc OF HUD: ~ __°F ppm ~__OFppm TOTAL LIQUID cc: HYBROCRRBON PROPERTIES CUSHION BRTR OIL GRAVITY [°API]: ® oF TYPE AMOUNT WEIGHT GAS/OIL RATIO (cu.rt, per bbl): KCL + CRCL2 {FT] 1100.0 9,09 GAS GRAVITY: ,, RECOVERED: REMgRK5: GAUGE ~215 BEHHViNG ERRHTICRLLY TYPE & SIZE MERSUR TIME CHOKE SIZE NG DEVICE SURFACE PRESSURE PSi ADJUSTABLE CHOKE ON SURFACE MANIFOLD GAS RATE MCF LIQUID RATE APB JTICKET NO: 65256100 REMARKS OPENED SAFETY VALVE 0351 OPENED WELL TO FLARE - NO BUBBLES. 0355 WEAK BUBBLES 0400 BUBBLE HOSE DEAD 052! LOADED TUBING WiTH HUD 0532 UNSEAT PACKER 0535 DROPPED BRA 0541 PRESSURED UP ON ANNULUS 0543 SHEARED IMPACT REVERSINO SUB 0800 PULLED OUT OF HOLE WITH TOOLS 0834 TOOLS OUT OF HOLE I 0349 2-20-85 2230 STARTED MAKING UP TOOLS 2338 STARTED CLOCKS 2-21-85 0001 RUN IN HOLE WITH TOOLS 0315 RIGGED UP SURFACE EQUIPMENT 0318 3000 TESTED LINES AND SURFACE EQUIPMENT. 0344 SET RTTS 034? OPENEO TOOL TICKET NO, 65256100 LENGTH DEPTH 50 5 5 80 5 56 71 5 84 TUBING .......................... CROSSOVER ....................... IMPACT REVERSING SUB ............ CROSSOVER CROSSOVER HYBROSPRING TESTER .............. CROSSOVER RTTS CIRCULATING VALVE .......... 3.500 6.120 6.120 5.000 4.750 5.000 5,000 6,120 CASING PACKER ................... 7,800 CROSSOVER ......... - ........ ; ..... 5.000 BUNDLE CRRRIER .................. 5.375 3.O0O 3.000 3.000 2,250 2.250 0.750 3.000 3.000 3,000 2,250 2.250 5146.8 1.0 1.0 1.0 1,0 5.3 1.0 3.2 5.7 1.0 8.0 5147,8 5150.8 5157.1 5]60.3 5175.0 TOTflL DEPTH 5235.0 EQUI PHENT DATA Directional Services Pressure Services Chemical Transmission Systems :.s Gyroscopic Survey AK-BO-50011 KBU 25X-6 ';as Field Oate: 3anuary 50, ,~ MoGul re 1985 ,yen (7) copies of , ,y on the above well. ._o be of service. INC. UNION OIL OF CALIF. KBU 23X'6 ........ KENAI GAS FIELD ALASKA VERTICAL SECTION CALCULATED ALONG CLOSURE SPERRY-SUN WELL SURVEYING COMPANY PAGE ANCHORAGE ALASKA DATE OF SURVEY dANUARY 30, 1985 ' COMPUTATION DATE BOSS--GYROSCOPIC SURVEY ....... FEBRUARY 1, 1985 dOB NUMBER AK-BO-50011 KELLY BUSHING ELEV. = 27.60 FT. OPERATOR-MCGUIRE ....................... TRUE MEASURED VERTICAL DEPTH DEPTH -'SUB-SEA ........... COURSE COURSE'' VERTICAL INCLINATION DIRECTION DEPTH DEG MIN DEGREES 0 O. lob lOO. 200 ............. 199' 300 299. 400 399. '500 499. 600 599. O0 , -27. O0 72. 99 .............. 172';' 99 272. 98 372. 98 472. 97 572. 60 0 0 N O. 0 E 40 0 39 S 32.50 W 39 ........ 0 34 ............. S"31.50 W 39 0 28 S 51.30 W 38 0 39 S 49.10 W 38 0 31' S 58.30 W 37 0 18 S 40.30 W 700 -'800 900 1000 "-1100 1200 1300 1350 1400 1450 1500 1600 1700 1800 1900 2000 2100 2200 2300 - 2400 25OO 2600 2700 699.97 ..... 799.97 899.97 999.97 '1099.97 1199.97 1299.95 1349.91 1399.85 1449.73 1499.53 1598.68 1696.99 --1794',24 1890.09 1984.27 2076.63 2167.25 2256.31 2344;'43 2432.63 2520.90 2608.45 672.37 772.37 872.37 972.37 "'1072.37 1172.37 1272.35 1322,'31 1372.25 1422.13 1471.93 1571.08 1669.39 I766.64 1862.49 1956.67 2049.03 2139.65 2228.71 ....... 231-6;83 2405.03 2493.3O 2580.85 0 18 '0 16 0 19 0 22 0 7 0 5 1 36 2 28 3 22 4 25 5 46 9 1 12 0 1'4 ..... 54 18 8 21 7 23 55 26 3 28 i S 37.50 W 8'"79, 60 W S46. OW S 49.60 W S '10.80 W S 52.39 E N 3.89 E N 13'80 E N 13.60 E N 11.69 E N12. OE .... N 10.19 E N 14.60 E ........ N -16; 89 E .... N 14.39 E N 14.19 E N15. OE N14. OE N 13.69 E -'28 ..... 24 ......... N'13;50 E 27 48 N 13.30 E 28 15 N 13.19 E 29 31 N 13.50 E DOG'LEG ............................. TOTAL SEVERITY RECTANGULAR DEG/IO0 NORTH/SOUTH 0.00 0.00 0.65 0.48 S .... 0';"08 ...................... 1;38 S 0.21 2.06 S 0.18 2.69 S 0.16 ' 3.30 S 0.24 3.74 S 0.02 4.16 S 0,'21 4.42 S 0.18 4.66 S 0.05 5.07 S O' 29 5.39 S O. 11 5.54 S 1.66 4.18 S 1.87 2.43 S 1.80 0.05 N 2.10 3.37 N 2.72 7.72 N 3.26 20.37 N 3.07 38.16 N 2.96 ...... 60;-'53 N 3.31 87.93 N 2.99 120.49 N 2.81 157.55 N 2.18 198.45 N 1.96 242.58 N ......... 0.40 288,53 N 0.61 334.37 N 0.44 380.11N 1.29 427.11N COORDINATES EAST/WEST 0.00 0.30 '0,87 1.45 2.20 3.01 3.57 3.91 4.31 4.75 5.20 5.47 5.43 .5.27 4.96 4.36 3.62 2.71 0.27 3.74 -10;I0- 17.72 26.01 35.68 46.24 57.12 ........ 68.24' 79.16 89.93 101.09' VERTICAL SECTION 0.00 W -0.53 W ................. ~1',53 '" W -2.32 W -3.09 W -3.86 W -4.41 W -4.90 W" -5.23 W -5.56 W -6.06 W ........ -6,42 W -6.56 W -5.20 W -3.42 W -0.87 ) W 2.53 W .... W 19.86 E 38.09 E '61',30 ..... E 89.69 E 123.26 E ..... 161.53 E 203.74 E 249.17 E ........... 296.44' E 343.54 E 390.53 E~ 438.83 UNION OIL OF CALIF. KBU 23X-6~ KENAI GAS FIELD ALASKA SPERRY-SUN WELL SURVEYING COMPANY~ ANCHORAGE ALASKA COMPUTATION DATE FEBRUARY 1, 1985 VERTICAL SECTION CALCULATED ALONG CLOSURE ., PAGE 2 DATE OF oLRVEY dANUARY 30, 1985 BO~ GYROSCOPIC SURVEY dOB NUMBER AK-BO-50011 KELLY BUSHING ELEV. = 27.60 FT. ' OPERATOR-MCGUIRE MEASURED DEPTH 2800 2694. 2900 2780. 3000 2866; 3100 2952. 3200 3038. ........... 3300 3124. 3400 3210. 3500 3296. ......... 3600 3382. 3700 3468. 3800 3555. ..... 3900 3641. 4000 3728. ......... TRUE ............... SUB-SEA ........ COURSE VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEG 99 2667.39 30 91 2753.31 30 78 .......2839~18 '30 77 2925.17 30 74 3011.14 30 71 .......3097.11 30' 86 3183.26 30 98 3269.38 30 4100 3814. ................. 4200 ....... 3901'; 4300 3988. 4400 4075. ...... 4500- 4162. 4800 4249. 4700 4338. ............ 4800 ........ 4428~ 4900 4519. 5000 4610. 5100 · 4701. 5200 4793. -' 5300 4884. ....... 5400 .......... 4976-; 5500 5067. 5600 5160. 5700' 5252, COURSE ........ DOG-LEG ...................................... TOTAL DIRECTION MIN DEGREES 36 N 13.89 E 55 N 13.89 E 44 ............ N'-"13;89 E 38 N 13.80 E 47 N 13.69 E 38 ...... N'"13,69 E 22 N 1'4. 0 E 43 N 13.60 E SEVERITY RECTANGULAR COORDINATES VERTICAL DEG/iO0 NORTH/SOUTH EAST/WEST SECTION 1.10 '475.79 N 112.95 E 488.91 0.31 525.44 N 125.24 E 540.04 '0-18 575;19 N 137.55 E 591.27 ' 0.10 624.75 N 149.77 E 642.29 0.15 674.37 N 161.92 E 693.36 0.14 724.00 N 174.01E .... 744.42 0.32 773.30 N 186.17 E 795.17 0.40 822.65 N 198.29 E 845.97 94 ....... 3355;'34 ........ 30 93 3441.33 30 12 3527.52 30 55 ....... 36"13~95 .......... 30 · 13 3700.53 29 90 3787.30 29 81 ...... 3874;21 ............. 29 70 3961.10 29 73 4048.13 29 88 4135;28 ..............29 99 4222.39 29 31 4310.71 2~ --4400-.84 ...........24 4491.76 24 4582.86 24 -4674.05 .... 24 4765.40 23 4856.86 23 ~ 23 22 22 22 45 36 46 65- O0 46 05 .......4948;-45 93 5040.33 14 5132.54 52 ..... 5224.91 44 .... N' 13; 69 39 N 13.39 16 N 13.19 7 ......... N i 3; 39 56 N 13.10 39 N 13.10 88 ........... N 12.80 41 N 12.50 18 N 12.39 26-" N 12. 0 23 N 12.30 31 N 11.60 45 ......... N 11.1~ 27 N 11.30 16 N 11.30 10 -- N'lO.8~ 50 N 10.80 51 N 10.39 30' ~ N 10,30 58 N 10.10 33 N 10.10 29 N 10.10 E E E E' E E E E E E E E E E E -E E E E_ E E E 0.06 872. 0.17 921. 0.40 971. 0;18 ........... 1020. 0.23 1068. 0.28 1117. .... 0;15 ........... 11'65. 0.15 1213. 0.39 1261. 0,24 ..... 1309. 0.16 1357. 2.88 1403. ...... 1;78 .... 1446. 0.30 1487. 0.19 1527. '0;19 ..... 1567. 0.34 1607. O.l& 1647. ..... 0;35 ..... 1686~ 0.54 1725. 0.41 1763. " 0.07 1801. 31N 94 N 28 N 23 N 94 N 34 N 56 N 86 N 94 N 87 N 89 N 75 N 17 N 01 N 47 N 73 N 69 N 43 N ~3 N 76 N 85 N 57 N 210.35 E .... 897.05 222.31E 948.09 233.97 E 998.78 245.54 E ...... 1049;-07 .... 257.01E 1097.11 268.28 E 1148.80 279; 37 'E ......... 1198;'27 290.21 E 1247.77 300.82 E 1297.00 311.18 E 1346.05 321.52 E 13~5.16 331.24 E 1442.04 339,80"E .............. 1485;'31-" 347.92 E 1526.95 356.01E 1568.20 363.91- E ............. 1609;-22 371.57 E 1649.90 379.00 E 1690.31 386;22'E .......... 1'730.44 393.20 E 399.99 E 1808.54 406.71E .... 1846.82 '" SPERRY-SUN WELL SURVEYING'COMPANY ........... PAGE ANCHORAGE ALASKA UNION OIL OF CALIF. DATE OF SURVEY JANUARY 30, 1985 KBLI ........ 23X-~6 COMPUTATION-DATE .......................... BOSSGYROSCOPIC--'SURVEY KENAI GAS FIELD FEBRUARY 1, 1985 dOB NUMBER AK-BO-50011 ALASKA KELLY BUSHING ELEV. = 27.60 FT. OPERATOR'MCGUIRE VERTICAL SECTION CALCULATED ALONG CLOSURE MEASURED DEPTH ........ TRUE ............. SLIB~SEA ....... COURSE ........ COURSE ...........DOG-LEG ................... TOTAL ............................................. VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEG MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST SECTION 5800 5345.05 5317.45 22 4 N 9.89 E 0.43 1838.90 N 413.29 E 1884.71 5900 5438.21 5410.61 20 31 N 9.50 E 1.56 1874.70 N 419.41E 1920.99 6000 ...... 5532,-'20 5504,60 19 25 ............. N ..... 9;10 E 1,11 190:9'40 N 424';94'E ........... 1'955,10 6100 5626.82 5599.21 18 19 N 9.19 E 1.09 1940.34 N 430.08 E 1987.40 6200 5722.09 5694.48 17 i N 9.50 E 1.30 1970.30 N 435.01E 2017.73 ..... 6300 '5818.03 5790.43 15 ..... 41 .... N 9,30 E 1 ~ .~ 1998.10 N 439'61'E ...... 2045.87 6400 5914.45 5886.84 15 3 N 10.10 E 0.68 2024.23 N 444.08 E 2072.36 6500 6011.05 5983.45 14 53 N 8.30 ~ 0.49 2049.73 N 448.21E 2098.16 .............. 6600"- 6107,79. ' 6080,18 14 27 'N"8'"O E 0.45 '2074,'82 N 451,80 E '2123.44 6700 6204.60 6177.00 14 33 N 7.80 E 0.10 2099.63 N 455.25 E 2148.42 6800 6301.43 6273.83 14 21 N 8.19 E 0.21 2124.35 N 458.72 E 2173.31 '~'~$'o' ~,~ ' ' ~.~1,~.5 ~ ' ~,~ ~ ' HORIZONTAL DISPLACEMENT = 2173.31 FEET AT NORTH 12 DEG. 11MIN. E~ST AT MD = 6800 ....... THE'-CALCULATION PROCEDURES ARE 'BASED ON THE '-USE'OF"'THREE DIMENSIONAL-RADIUS OF CURVATURE-METHOD; ...... .) UNION OIL OF CALIF. KBU 23X-6 ....... KENAI GAS FIELD ALASKA SPERRY'SUN WELL SURVEYING COMPANY ...... PAGE ANCHORAGE ALASKA DATE OF SURVEY dANUARY 30~ 1985 ................. COMPUTATION DATE FEBRUARY 1, 1985 dOB NUMBER AK-BO-50011 KELLY BLoHING ELEV. 27.60 FT OPERATOR-MCGU I RE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL ...... DEPTH DEPTH ................... DEPTH .... NORTH/SOUTH EAST/WEST ..... DIFFERENCE CORRECTION 0 0.00 -27.60 0.00 0.00 0.00 ................ 1000 ........... 2000 1984.27 1956.67 120.49 N 26.01E 15,73 3000 2866.78 2839.18 575.19 N 137.55 E 133.22 4000'- 3728.'13 3700.53 1068~'94 N- ' 257.01-E ....... 271~87-- 5000 4610.46 4582.86 1527.47 N 356.01E 389.54 6000 5532.20 5504.60 1908.40 N 424.94 E 467.80 6800 6301'.43 .........6273.83 ........... 2124~35"-N ......... 458.72 E ................. 498~57 .... 0';03 .................................................................... 15.70 117.49 138~65 117.67 78.26 30.77 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. .,. UNION OIL OF CALIF. -'KBU '23X~6 KENAI GAS FIELD ALASKA SPERRY~SUN WELL SURVEYING COMPANY PAGE 5 ANCHORAGE ALASKA DATE OF SURVEY JANUARY 30, 1985 COMPUTATION DATE FEBRUARY 1, 1985 dOB NLIMBER'AK-BO-50c)ll KELLY BUSHING ELEV. = 27.60 FT. OPERATOR-MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASURED VERTICAL ''DEPTH .......... DEPTH 0 0.00 .......................... 27 ...................... 27.60 127 127.60 227 227.60 327 327.60 427 427.60 527 527.60 ........ 627 .... 627.60 727 727.60 827 827.60 ....... 927 927.60 1027 1027.60 1127 1127.60 1227 1227.60 1327 1327.60 1427 1427.60 ....... 1528 1527.60 1629 1627.60 1731 1727.60 SUB-SEA VERTICAL "DEPTH" TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST ........ DIFFERENCE ........ CORRECTION -27.60 0.00 0';-00 ........................................ 0;'00 ............. 100.00 0.74 S 1 1 1 1 1 ''1 1 200.00 1.62 S 300.00 2.20 S 400.00 2.89 S 500.00 3.43 S 600-00 ....... 3.86 'S 700.00 4.28 S 800. O0 4.45 S 900.00 ......... 4-78 S 000.00 5.19 S 100.00 5.44 S 200.00 5.56 S 300.00 3.33 S 400.00 1.75 N 500.00 .... 10.75"N~' 60'0.00 25.13 N 1700.00 44.71 N O. O0 O. 00 0;00 ............................... 0,-00 ............... 0:00 0.47 W 0.00 0.00 1.01 W 0.01 1.63 W 0,01 2.44 W 0.02 3.23 W 0.02 3.67 W 0.03 4.00 W 0.03 4.44 W 0.03 4.86 W 0.03 5.34 W 0.03 5.48 W 0.03 5.39 W 0.03 5.17 W 0.07 3.96 W 0.21 2,08 W 0.64'' O. 67 E 1.72 5.51 E 3.75 0.01 O. O0 0.01 O. O0 O, O0 ................................... O. O0 O. O0 O- O0 ................ O. O0 0.00 0.00 .................... O. 03 ) 0.14 O. 43 1.08 2.03 UNION OIL OF CALIF. KBU'23X-6 KENAI GAS FIELD ALASKA SPERRY-SUN WELL SURVEYING COMPANY~ ANCHORAGE ALASKA COMPUTATION DATE FEBRUARY 1, 1985 PAGE DATE OF SURVEY dANUARY 30, 1985 dOB NUMBER AK-BO-50011 KELLY BUSHING ELEV. = OPERATOR-MCGUIRE 27.60 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH ..... DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE' CORRECTION · 1834 1827.60 1800.00 69.41N 12. 7.02 .............. 1939 1927;60 ..... 1900;00 ......... 100;"25"'N ...... 20. · '12,01 2046 2027.60 2000.00 137.28 N 30. 19.07 2155 2127.60 2100'00 179.72 N 41. 28.30 ' ' 2267 2227.60 2200.00 227.74 N 53. 39.88 2380 2327.60 2300.00 279.68 N 66. 53.27 2494 2427.60 2400.00 331.78 N 78. 66.71 ............ 2607 2527.60 .... 2500.00 ........ 383.61N ...... 90. 80.01-- 2722 2627.60 2600.00 437.66 N 103. 94.41 2837 2727.60 2700.00 494.52 N 117. 110.29 2954 2827.60 -- 2800;00 .......... 552;56 N ....... 131. -'126,81'~ 3070 2927.60 2900.00 610.27 N 146. 143.14 3187 3027.60 3000.00 667.93 N 160. 159.43 -3303 .........3127.60 ......... 3100;-00 ................. 725;~7'-N ............174; 3419 3227.60 3200.00 782.82 N 188. 3535 3327.60 3300.00 840.34 N 202. -3427.60 -3400;00 --898;'10 N 216. 3527.60 3500.00 955.64 N 230. 3600.00 1012.35 N 243. .......... 3651 3768 3883 3627.60 71 E 87 E 33 E 56 E 50 E 11E 55 E 75 E " 62 E 59 E 95 E 22 E 34 E 42- E 54 E 57 E 62 E 31 E 67 E 3.27 4.98 7.07 9.22 11.58 13.39 13.44 13.29 14.40 15.88 16.51 16.33 16.29 175;'76 ........................... 1'6.33 191.80 16.04 208.01 16.21 224;35 ................ 16;34 240.54 16.18 256.27 15.73 ........ SPERRY-SUN WELL SURVEYING~COMPANY ............... PAGE 7 ANCHORAGE ALASKA UNION OIL OF CALIF. DATE OF SURVEY dANUARY 30, 1985 KBU ....... 23X~6 COMPUTATION"DATE KENAI GAS FIELD FEBRUARY 1, 1985 dOB NUMBER AK-BO-50011 ALASKA KELLY BUSHING ELEV. = 27.60 FT. OPERATOR-MCGUIRE MEASURED DEPTH ' ........................ 41-1'4 4229 4344 .... 4459 4574 4688 ............ 4799" 4909 5018 5128 5237 5347 .... 5456 5564 5673 ....... 5781 5888 5995 INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR cOORDINATES MD-TVD VERTICAL DEPTH ................... DEPTH NORTH/SOUTH 'EAST/WEST DIFFERENCE ..... CORRECTION 3727.60 3700.00 3827;60 ............ ~800;00 ................. 3927.60 4027.60 4000.00 4127.60'' 4100;00 4227.60 4200.00 4327.60 4300.00 1068.64 N 1'1'24;39'N 1179.88 N 1235.50 N 1290.40 N 1345.57 N 1398.45 N 4427,60 ..... 4527.60 4627.60 4727.60 4827.60 4927,60 5027;60 5127.60 5227.60 5327;-60 5427.60 5527.60 4400'; O0 ............1445.79'N 4500.00 1490.69 N 4600.00 1535.05 N '4700.00 1579.17 N 4800.00 1622.71 N 4900.00 1666.16 N 5000.00 ..... 1708.91 N 5100.00 1750.54 N 5200.00 1791.41N 5300.00 1831.94 N 5400.00 1870.78 N 5500.00 1906.80 N 256.95 E ........... 269.92E 282.62 E 295.00 E ' 307.04 E 318.83 E 330.15 E ..... 339;'72 E 348.66 E 357.52 E 366.11E 374.43 E 382.44 E .... 390;20 E' 397.62 E 404.90 E 412.08 E 418.76 E 424.68 E 271.79 1 ........ 287;01 ........................ 1 302.08 1 317.17 1 331.89 1 346.70 1 360.40 1 371.47 ......... 1 381.45 391.21 400.84 410.23 419.55 - 428,59 .......... 437.16 445.43 453.57 461.07 467.52 5.52 5;22 ................................................... 5.07 5.09 4.71 ........... 4.81 3.70 1.07 .................... 9.98 9.76 9.64 9.39 9.32 9; 04 ............................. 8.57 8.27 8.14 7.5O UNION OIL OF CALIF. .... KBU '23X~6 ..... KENAI GAS FIELD ALASKA SPERRY-SUN WELL SURVEYING COMPANY ................ PAGE ANCHORAGE ALASKA DATE OF SURVEY dANUARY 30, 1985 COMPUTATION DATE FEBRUARY 1, 1985 dOB NUMBER AK-BO-50011 KELLY BUSHINg] ELEV. = 27.60 FT. OPERATOR'MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH ........ NORTH/SOUTH EAST/WEST ...... DIFFERENCE CORRECTION 6100 5627.60 5600.00 1940.59 N 430.12 E 473.23 5.70 ........ 6205 ........ 5727,60 ' '5700"~00 .......... 1971;'97"-N ..... 435,29 E ................... 478,17 4.94 6309 5827.60 5800.00 2000.75 N 440.05 E 482.34 4.18 6413 5927.60 5900.00 2027.71N 444.70 E 486.02 3.68 ..... 6517 6027.60 6000.00 ...... 2054,09 N 448.85 E 489.52 3.50 ..... 6620 6127.60 6100.00 2079.88 N 452.51E 492.86 3.34 6723 6227.60 6200.00 2105.54 N 456.06 E 496.16 3.30 ........... 6800 6301.43 6273.83 2124.35 N 458.72 E 498.57 2.40 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT'MD (FROM RADIUS OF CURVATURE) POINTS .¢ 0.00 5CRLE :- 1 INCH ~0 ~300.00 / ~00.0 KENR! OR5 FIELD KBU 2~X-6 RK-B~-50011 UNlON OIL 0~ CRL!F. · JRNURRY 90, ~985 1300.00 28OO. CO ~90O. O0 5200.00 O50O. O0 ~ 800 2600. O0 VERT ~_ c.,qL PROJECT ! ON N~H -2000.00 __ -1500.00 6800 SCALE-:- 1 INCH ]0 500.00 / 500.0 KENR! ORS FIELD UN~ON O!L 0F CRI IF. KBU 23X-6 J~NURR~ 30, i985 RK-BO-5001i 1.00 t -500.00- L~-500. O0 HOB 'r, Z 0 N-i-,qL PROJECTION UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET A PAGE NO. 1 LEASE A-028142 :.*~' WELL NO. KBU 23x-6 FIELD Kenai Gas Field LOCATION: Section 6~ T4N. RllW. SM +362' N& +112~' E o~ SW Corner Section 6 PERMIT NO. 84-109 SERIAL NO. TD 6950" TVD 6444.86' DEVIATION (BHL) 2149.45N 498.54E COMPANY ENGINEER Wagenhoffer~ Nave' SPUD DATE 1/10/85 COMP. DATE 2/28/85 CONTRACTOR Brinkerhoff RIG NO. #54 TYPE UNIT National 110 UE 1500 HP DRILL PIPE DESCRIPTION '5" ELEVATIONS: GROUND Pad 66' MSL CASING HEAD 29' KB ' /~-~UBING HEAD 27' KB ROTARY~DRI,~E'' BWSHIN6~/~4~bove Around CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 20" 94# Welded H-40 126' Driven 13 3/8" 61# Butt K-55 2532' 1900 sx "G" cmt w/ additives 9 5/8" 47# Butt N-80 6950' 3000 sx "G" cmt w/ additives 3 1/2" SS 9.2# Butt N-80 4173' Otis RDH Dual Pkr - 9 5/8" 4155' 3 1/2" LS 9.2# Butt N-80 5074' Otis WD Perm Pkr - 9 5/8" 5007' PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 1-30-85 5110-5112' 5171' (Ret) Isolation Sqz Sqzd w/ 500 sx "G" cmt, Resqz .w/ 250 s: 1-31-85 4278-4280' 1-31-85 3784-3786' 5171' (Ret) Isolation Sqz 5171' (Ret) Isolation Sqz Sqzd w/ 500 sx "G" cmt Sqzd w/ 500 sx "G" cmt 2-07-85 6696-6706' 6841' FC Prod Perfs 2-08-85 6798-6810' 6841' FC Prod Perfs Sqzd w/ 200 sx cmt Open for Prod 4 HPF Belug~ 2-12-85 5520-5545' 6660' TOC Prod Perfs 2-13-85 5201-5204' 5475' BP 2-13-85 5215-5221' 5475' BP 2-14-85 5280-5291' 5475' BP 2-14-85 5291-5301' 5475' BP 2-15-85 5286-5301' 5475' BP 2-18-85 5112-5129' Prod Perfs~]_ Prod Perfs_~ Prod Perfs~ Prod Perfs ~-- Prod Perfs~r~ 5161' (Ret) Prod Perfs 2-19-85 4214-4275' 5080' BP Prod Perfs 2-23-85 4214-4275' 6841' FC Reperfed for Prod 2-23-85 5112-5129' 6841' FC 2-23-85 5520-5545' 6841' FC 2-23-85 6788-6810' Reperfed for Prod Reperfed for Prod ~841' FC Reperfed for Prod Open for Prod 4 HPF Beluga ~qzd w/ 241 sx "G" cmt Sqzd w/ 216 sx "G" cmt Open for Prod 4 HPF Beluga Open for Prod 4 HPF B-3 Open for Prod 8 HPF Open for Prod 8 HPF Open for Prod 8 HPF Open for Prod 8 HPF" INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS 3-31-85 4214-4275' B-3 Sand 0 .... 8505 MCF/ day Avg March Prod 3-31-85 5112-5129' 3-31-85 5520-5545' 3-31-85 6788-6810'. -Beluga Sands 0 - 4406 MCF/ day Avg March Prod WELL HEAD ASSEMBLY TYPE: Cameron Iron Works CASING HEAD: WF 12" 3M X 13 3/8" SOW w/ 2-2" 5M Flanged Outlets TUBING HEAD: DCB 12" 3M X 10" 5M w/ 2-2" 5M Outlets TUBING HANGER: Dual 8 RD Top X Butt Bottom 3 1/2" TUBING HEAD TOP: 10" 5000# Flanqe MASTER VALVES: 3 1/8" 5M I CHRISTMAS TREE TOP CONN: 3 1/2" EUE UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KBU 23x-6 FIELD Kenai Gas Field DATE ETD KENAI GAS FIELD 23X-6 A DAY 1/04/85 DAILY COST: $ 1,966 CUM COST: $ 1,966 AFE AMT: $3,170,000 B DAY 1/05/85 DAILY COST: $ 1,966 CUM COST: $ 3,932 AFE AMT: $3,170,000 C DAY 1/06/85 DAILY COST: $ 1,966 CUM COST: $ 5,898 AFE AMT: $3,170,000 D DAY 1/07/85 DAILY COST: $ 103,523 CUM COST: $ 109,421 AFE AMT: $3,170,000 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS (UOCO 50.00%) AFE #341104 RELEASE RIG FROM KTU 13-5 PUT WELL ON PERMANENT PRODUCTION. MOVE BSI RIG #54 F/ KTU #13-5 (41-7 PAD) TO KBU 23X-6 (14-6 PAD) ON TURNKEY MOVE. , MOVE BSI RIG #54 F/ KTU #13-5 (41-7 PAD) TO KBU 23X-6 (14-6 PAD) ON TURNKEY MOVE. MOVE 8SI RIG #54 F/ KTU #13-5 (41-7 PAD) TO KBU 23X-6 (14-6 PAD) ON TURNKEY MOVE. RIG UP BSI RIG #54 ON 14-6 PAD. RAISE DERRICK. E DAY 1/08/85 20" ~ 126' DAILY COST: $ 27,764 CUM COST: $ 137,185 AFE AMT: $3,170,000 F DAY 1/09/85 20" ~ 126' DAILY COST: $ 28,923 CUM COST: $ 166,108 AFE AMT: $3,170,000 RIG UP BSI RIG #54 ON 14-6 PAD. ACCEPT RIG ON STANDYBY ~ 1200 HRS, 1/8/85. PU HAMMER & DRIVE 20" TO 126'. MIX MUD & CUT OFF 20". WELD ON 20" SOW FLANGE. SET 20" DIVERTER RU LINES. SET PIPE RACKS. STRAPPED CALIPERED TOOLS FOR BHA #1. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ~028142 WELL NO. KBU 23x-6 FIELD Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1267'/1267' 1 DAY 1/10/85 20" S 126' DAILY COST: $ 43,364 CUM COST: $ 209,472 AFE AMT: $3,170,000 COMP MISC RIG UP. SPUDDED WELL ~ 0230 HRS. TAGGED FILL IN 20" ~ 51'. CO TO SHOE ~ 125'. DRL 17 1/2" HOLE F/ 125-1236'. CIRC HOLE CLEAN & POH W/ BHA #1. MU & RIH W/ BHA #2 (DYNA DRILL). DIRECTIONAL DRILL F/ 1236'- 1267'. 2342'/ 1075' 2 DAYS 1/11/85 20" 8 125' 67 PCF 133 SEC CONT DYNA DRILL RUN #1. DRL 17 1/2" HOLE F/ 1267-2342' DPM. POH. DAILY COST: $ 39,802 CUM COST: $ 249,274 AFE AMT: $3,170,000 2532'/ 190' 3 DAYS 1/12/85 20" ~ 125' 68 PCF 140 SEC POH W/ DYNA DRILL. MU BHA #3 & RIH. REAM THRU DYNA DRILL RUN. DRL 17 1/2" HOLE F/ 2342-2532'. CIRC & COND HOLE. POH IN PREP TO RUN 13 3/8" CSG. RU TO RUN 13 3/8" CSG. DAILY COST: $ 37,687 CUM COST: $ 286,961 AFE AMT: $3,170,000 2532'/ O' 4 DAYS 1/13/85 20" ~ 125' 13 3/8" $ 2538' 68 PCF 55 SEC DAILY COST: $ 280,428 CUM COST: $ 567,389 AFE AMT: $3,170,000 2532' FS 5 DAYS 1/14/85 20" @ 125' 13 3/8" $ 2538' 68 PCF 48 SEC DAILY COST: $ 27,652 CUM COST: $ 595,041 RAN 65 JTS 13 3/8" K-55, 61# BUTT. FS ~ 2532', FC $ 2490'. RIH W/ DP & STAB INTO FC. CIRC & COND MUD. PUMPED 50 BBLS OF 12.5 PH CAUSTIC H20, MIXED & PUMPED 1650 SXS "G" CMT W/ 2% CaC12, .75% CFR-2 & 2 1/2% PREHYDRATED GEL IN MIX WATER. MIXED & PUMPED 250 SXS "G" CMT W/ 2% CaC12, .75% CFR-2 TAIL SLURRY & DISPLACED. CIP $ 1515 HRS. POH W/ DP. WOC. WOC. REMOVED 20" HYDRIL BAG. CUT 13 3/8" CSG. INSTALLED CIW 13 3/8", 3000 PSI SOW SPOOL. NU 13 5/8", 5000 PSI BOPE. TESTING BOPE TO 3000 PSI $ 2400 HRS. AFE AMT: $3,170,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KBU 23x-6 FIELD Kenai Gas Field DATE . ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 2834'/292' 6 DAYS 1/15/85 20" $ 125' 13 3/8" $ 2538' 68 RCF 44 SEC DAILY COST: $ 44,062 CUM COST: $ 639,103 AFE AMT: $3,170,000 COMPLETED BOPE TST. RIH W/ BIT #4 (BHA #4) AND CO TO FC. PRES TST CSG TO 2500 PSI-OK. CO CMT TO 2520' (2' ABOVE SHOE) AND TST CSG TO 2500 PSI-OK. DRILL TO 2542' AND RAN LEAK OFF TST TO 13.0 PPG EMW. POH. RIH W/ BIT #4PR (BHA #5) & DRILL 12 1/4" DIRECTIONAL HOLE TO 2834'. 3999'/ 1165' 7 DAYS 1/16/85 20" ~ 125' 13 3/8" ~ 2538' 70 PCF 49 SEC DAILY COST: $ 36,161 CUM COST: $ 675,264 AFE AMT: $3,170,000 POH FOR BHA CHANGE. RIH & DRL 12 1/4" HOLE F/ 2834-3999'. CIRC, RUN & SURVEY & POH. WELL STARTED SLOWING F/ SWABBING EFFECT. PU KELLY & START PUMPING W/ PARTIAL RETURNS. WORK PIPE FREE FOR i OT, (BIT ~ 2836'). BHA BECAME STUCK & UNABLE TO CIRC. RUN FREE POINT. FREE POINT (STRETCH) $ 2670'-FREE POINT (TORQUE) ~ 2482'. RRER TO RUN STRING SHOT & BACK OFF INSIDE 13 3/8" CSG. 3999'/ O' 8 DAYS 1/17/85 20 "$ 125' 13 3/8" $ 2538' 70 PCF 49 SEC DAILY COST: $ 36,120 CUM COST: $ 711,384 AFE AMT: $3,170,000 3999'/ O' 9 DAYS 1/18/85 20 "$ 125' 13 3/8" $ 2532' 70 PCF 53 SEC RIH W/ STRING SHOT. BACK OUT OF DOT OARS Q 2472' (INSIDE 13 3/8" CSG). POH W/ 5" DP. i RU FISHING ASSY #1 & RIH. SCREW INTO FISH 18 2472'. OAR ON FISH W/O SUCCESS. RU SURF OARS. OAR ON FISH W/O SUCCESS. LD SURF OARS. RUN FREE RT. ESTABLISH STRETCH & TORQUE FREE RT ® 2598'. RUN STRING SHOT & BACK OFF BELOW DOT OARS 8 2505'. ROH W/ 5" DP & OARS. PU 9 5/8" WASH RIPE & RIH. WASH TO 2690' WASHED HARD & STICKY F/ 2650-2690'.. CIRC ~ 2400 HRS. WASH OVER FISH F/ 2690-2790'. POH. RIH & SCREW INTO FISH $ 2505'. CIRC, BUT SUSPECT WASHOUT IN $OINT OF HEAVY WT. DAILY COST: $ 40,680 CUM COST: $ 752,064 AFE AMT: $3,170,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE DATE A-028142 ETD WELL NO. KBU 23X-6 FIELD Kenai Gas Field DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 3999'/ O' 10 DAYS 1/19/85 20 "~ 125' 13 3/8" ® 2532' 70 PCF 53 SEC DAILY COST: $ 45,455 CUM COST: $ 797,519 AFE AMT: $3,170,000 RUN FREE PT. ESTABLISH FISH FREE TO 2772'. RUN STRING SHOT & BACK OFF 8 2690'. POH W/ PARTIAL FISH. RIH & SCREW INTO FISH ~ 2690'. ESTABLISH CIRC & OAR FISH LOOSE. POH W/ FISH. 4095'/ 11 DAYS 1/20/85 20 "$ 125' 13 3/8" ~ 2532' 71 PCF 53 SEC DAILY COST: $ 37,790 CUM COST: $ 835,309 AFE AMT: $3,170,000 4928'/ 883' 12 DAYS 1/21/85 20 "~ 125' 13 3/8" ® 2532' 72 PCF 49 SEC MU & RIH W/ 12 1/4" HOLE OPENER TO 3999'. REAM THRU TIGHT SPOTS ON WAY IN HOLE. CIRC & COND MUD. RAISE MUD WT TO 7i PCF. POH. (SMOOTH TRIP). PU 12 i/4" BIT & RIH. DRL 3999-4095'. DRLD 12 1/4" HOLE F/ 4095-4965'. POH FOR BHA CHANGE. RIH W/ 34' REND. DRL F/ 4650'- 4827'. (ASSY DROPPED 2.4° REP 100'). ROH FOR BHA CHANGE. RIH W/ RACKED ASSY. DRLD F/ 4827-4928'. DAILY COST: $ 48,596 CUM COST: $ 883,905 AFE AMT: $3,170,000 5509'/ 581' 13 DAYS 1/22/85 20" $ 125' 13 3/8" $ 2532' 72 PCF 52 SEC POH. CHANGE OUT MWD. RIH. DRL 12 1/4" HOLE F/ 4928-5509'. CIRC & POH. DAILY COST: $ 37,151 CUM COST: $ 921,056 AFE AMT: $3,170,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KBU 23x-6 FIELD Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6003'/ 494' 14 DAYS 1/23/85 20" ~ 125' 13 3/8" 8 2532' 72 RCF 50 SEC DAILY COST: $ 39,247 CUM COST: $ 960,303 AFE AMT: $3,170,000 6439'/ 436' 15 DAYS 1/24/85 20" ~ 125' 13 3/8" ~ 2532' 72 RCF 50 SEC RAN BORE TEST. RIH W/ 12 1/4" BIT. DRL F/ 5509-5868'. POH FOR BHA CHANGE. RIH W/ NEW BHA. DRL F/ 5868-6003'. DRLD 12 1/4" HOLE F/ 6003-6439'. CIRC & POH. PU NEW BIT & LOCK UP BHA. RIH TO 6400'. REAMED TIGHT HOLE TO 6439. DALLY COST: $ 35,125 CUM COST: $ 995,428 AFE AMT: $3,170,000 6950'/ 511' 16 DAYS 1/25/85 20" $ 125' 13 3/8" $ 2532' 72 PCF 48 SEC DAILY COST: $ 33,141 CUM COST: $1,028,569 AFE AMT: $3,170,000 6950' 17 DAYS 1/26/85 20" ® 125' 13 3/8" $ 2532' 72 PCF 48 SEC DAILY COST: $ 25,874 CUM COST: $1,054,443 AFE AMT: $3,170,000 6950' 18 DAYS 1/27/85 20" ® 125' 13 3/8" ~ 2532' 72 PCF 48 SEC DAILY COST: $ 101,706 CUM COST: $1,156,149 AFE AMT: $3,170,000 DRLD 12 1/4" HOLE F/ 6439-6950'. CIRC & COND HOLE. POH W/ DRLG ASSY. MADE COND TRIP W/O MWD TOOL. HOLE LOOKED GOOD. POH. RU DRESSER ATLAS. RUN DIL/ SONIC/GR/SP. RUN VDL/GR. RAN FDC/CNL. RAN MICRO LATER LOG. RAN & SHOT 36 SWS. 5 MISFIRES, 14 REC, 17 SHOTS LOST IN HOLE. RD DRESSER ATLAS. RIH W/ CO ASSY. CIRC & COND HOLE FOR 9 5/8" CSG. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 DATE WELL NO. KBU 23x-6 FIELD Kpnai gas Field _ ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6950' TD/ 6861' ETD 19 DAYS 1/28/85 20" $ 125' 13 3/8" $ 2532' 72 PCF 48 SEC DAILY COST: $ 298,454 CUM COST: $1,454,603 AFE AMT: $3,170,000 6950' TD/ 6861' ETD 20 DAYS 1/29/85 20" ~ 125' 13 3/8" ~ 2532' 9 5/8" ~ 6950' 72 PCF 40 SEC DAILY COST: $ 201,179 CUM COST: $1,655,782 AFE AMT: $3,170,000 , 6950' TD/ 5171' DIL (CMT RET) 21 DAYS 1/30/85 13 3/8" ~ 2532' 9 5/8" ~ 6950' 70 PCF 40 SEC DAILY COST: $ 41,747 CUM COST: $1,697,529 AFE AMT: $3,170,000 6950' TD/ 3736' DPM (CMT RET) 22 DAYS 1/31/85 13 3/8" ~ 2532' 9 5/8" ~ 6950' 72 PCF 40 SEC DAILY COST: $ 49,657 CUM COST: $1,747,186 AFE AMT: $3,170,000 COND HOLE FOR 9 5/8" CSG. POH. RN 170 OTS OF 9 5/8" 47# N-80 CSG. CIRC & COND HOLE. CMTING 9 5/8" CSG. MIX & PUMP 1000 SXS LEAD SLURRY TO A WT OF 13.2 PPG. MIX & PUMP 2000 SXS TAIL SLURRY TO A SLURRY WT OF 15.6 PPG. LEAD: "G" .75% CFR-2, 5% KCL, 4% HALAD 24 2 1/2% P.H.G. TAIL: "G" .75% CFR-2, 5% KCL, .4% HALAD 24 CONT CMTING 9 5/8" CSG. LANDED CSG ON SLIPS W/ 125M#. CUT EXCESS CSG. NIPPLED UP DCB SPOOL. LANDED & TSTD BOPE STACK. RIH W/ BIT #13 ON DC'S. TAGGED HARD CMT ® 6848'. CIRC. POH. R/U FOR CBL. RUN CBL/GR/VDL/CCL F/ 6861-2200'. RUN MULTI- SHOT GYRO F/ 6861' TO SURF. PREF 4 HPF F/ 5110-5112' DIL. RUN EZ-DRILL CMT RET. SET SAME ~ 5171' DIL. POH W/ WL. RIH W/ 5". DP. STABrlNTO CMT RET ~ 5066' DPM. BROKE DOWN PERFS 5110-12' DIL ~ 800 PSI. MIXED 500 SX OF "G" 1% CFR2, .3% HALLAD 24, & 1% CACL2 TO A SLURRY WEIGHT OF 15.8 #/ GAL. DISPLACE 490 SX CMT BELOW TOOL W/ A FINAL PUMPING RATE OF 1.5 BPM AT 2500 PSI. SQZ SOB HELD 1250 PSI W/ PUMPS OFF AFTER 10 MIN. CIP ~ 0523 HRS. POH W/ DP. PERF F/ 4278-4280' DIL, 4 HPF. SET CMT RET ~ 4240' DIL. RIH W/ 5" DP. STAB INTO CMT RET ~ 4236' DPM. BROKE DOWN PERFS 4278-4280' DIL @ 1450 PSI. MIXED 500 SX OF "G" 1% CFR2, .3% HALLAD 24, & 1% CACL2 TO A SLURRY WEIGHT OF 15.8 #/ GAL. DISPLACE 480 SX CMT W/ A FINAL PUMPING RATE OF 1.5 BPM ® 1400 PSI. SQZ OOB HELD 600 PSI W/ PUMPS OFF AFTER 10 MIN. CIP ~ 1635 HRS. PERF F/ 3784-3786' DIL, 4 HPF. SET CMT RET ~ 3737' DIL. RIH W/ 5" DP. STAB INTO CMT RET ® 3736' DPM. PREP TO SQZ FOR ISOLATION. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 8 LEASE A-028142 WELL NO. KBU 23X-6 FIELD Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6950' TD/ 3736' DPM (CMT RET) 23 DAYS 2/1/85 13 3/8" ~ 2532' - 9 5/8" ~ 6950' 72 PCF 37 SEC DAILY COST: $ 23,477 CUM COST: $1,770,663 AFE AMT: $3,170,000 6950' TD/ 6841' FC 24 DAYS 2/2/85 13 3/8" ~ 2532' 9 5/8" ® 6950' 72 PCF 41 SEC DAILY COST: $ 84,849 CUM COST: $1,855,512 AFE AMT: $3,170,000 6950' TD/ 5060' DIL (CMT RET) 25 DAYS 2/3/85 13 3/8" ~ 2532' 9 5/8" ~ 6950' 72 PCF 41 SEC DAILY COST: $ 39,664 CUM COST: $1,895,176 AFE AMT: $3,170,000 SQZ FOR ISOLATION (3784-3786' DIL) THRU CMT RET ~ 3737' DIL (3736' DPM), BROKE DOWN PERFS ® 1100 PSI. MIXED 500 SXS OF "G", 1% CFR-2, .3% HALLAD-24, 1% CACL2. DIS 475 SXS BELOW CMT RET. SQZ SOB HELD 950 PSI AFTER 10 MIN CIP ~ 0235 HRS. POH. WOC. STAND 3 1/2" TBG IN DERRICK. PU 3 1/2" TBG. SD BK IN DERRICK. RIH & DRL OUT CMT RET ~ 3736' DPM. DRL CMT TO 3791' DPM. RIH TO 3820'. TST SQZ #3 TO .80 PSI/ FT GRAD, OK. RIH & DRL CMT RET ~ 4236' DPM & HARD CMT TO 4291'. TST SQZ #2 TO .80 PSI/ FT GRAD, OK. RIH W/ BIT & DRL CMT RET ~ 5096'. CO STINGERS TO 5125'. TST SQZ #1 TO .80 PSI/ FT W/O SUCCESS. PREP TO RESQZ #1SQZ ~ 5110-5112' DIL. POH. RIH W/ 9 5/8" CSG SCRAPER TO 6841' DPM. CIRC. POH. SET CMT RET ® 5142' DIL ON WL. SET CMT RET ~ 5062' DIL ON WL. PU STINGER ON DP & RIH. RESQZ SQZ #1. PERFS ~ 5110-5112' DIL. BROKE DOWN PERFS ® 1900 PSI PUMPING 2 BPM. MIXED 250 SX "G", 1% CFR-2, .3% HALAD 24, 1% CACL2. DIS 230 SXS BELOW CMT RET W/ FINAL PUMPING RATE OF 1BPM ~ 1550 PSI. SQZ SOB HELD 1250 PSI W/ PUMPS OFF AFTER 10 MIN. CIP ~ 2224 HRS. REV OUT & POH. 6950' TD/ 5062' DIL (CMT RET) 26 DAYS 2/4/85 13 3/8" ~ 2532' 9 5/8" ~ 6950' 72 PCF 39 SEC FIN POH. 'WOC. PU~8 1/2" BIT & RIH. TAG TOP CMT RET ~ 5055'. DRL RET & HARD CMT TO 5062' ~ 2400 HRS. DAILY COST: $ 24,735 CUM COST: $1,919,911 AFE AMT: $3,170,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KBU 23x-6 FIELD Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6950' TD/ 6841' FC 27 DAYS 2/5/85 13 3/8" $ 2532' 9 5/8" ~ 6950' 72 PCF 39 SEC DAILY COST: $ 34,041 CUM COST: $1,953,952 AFE AMT: $3,170,000 6950' TD/ 6841' FC 28 DAYS 2/6/85 13 3/8" ~ 2532' 9 5/8" ~ 6950' 69 PCF 51 SEC DRL FIRM CMT F/ 5062-5105' DPM. RIH TO BP @ 5135' (5142' DIL). CIRC. POH. PU RTTS ON 5" DP & RIH. SET RTTS @ 5045' DPM (5052' DIL). TST SQZ #1, STAGE #2 TO .80 PSI/ FT, OK. RETESTED SQZ'S #2 & #3, OK. POH. RIH W/ 8 1/2" BIT. DRL BP 8 5135'. RIH TO 6841'. CIRC. POH. TST BOPE. PU 9 5/8" CSG SCRAPER & RIH TO 6841'. CIRC & CLEAN PITS. DUMPED & CLEANED MUD PITS. MIXED KCL-CACL2 COMP FLUID. CHGD OVER TO COMP FLUID. DAILY COST: $ 51,810 CUM COST: $2,005,762 AFE AMT: $3,170,000 6950' TD/ 6841' FC 29 DAYS 2/7/85 13 3/8" ~ 2532' 9 5/8" ~ 6950' 69 RCF 48 SEC DAILY COST: $ 35,632 CUM COST: $2,041,394 AFE AMT: $3,170,000 6950' TD/ 6841' FC 30 DAYS 2/8/85 13 3/8" ~ 2532' 9 5/8" ~ 6950' 69 PCF 48 SEC DAILY COST: $ 50,456 CUM COST: $2,091,850 AFE AMT: $3,170,000 POH W/ DP & SCRPR. MU RTTS & BYPASS W/ 30' TBG TAIL. RIH W/ TST TOOLS ON 3 1/2" TBG. RU LUB & TST LINES TO 1500 PSI - OK. TST MANIFOLD TO 3000 PSI - OK. SET RTTS ® 6631' TBG MEAS. OPEN BYPASS & DISP TBG W/ N2, FINAL PRESS = 2313 PSI. CLOSE BYPASS & BLED PRESS TO 1175 PSI. RIH & PERF F/ 6696-6706' DIL ~ 4 SPF, 0° PHASING. FND 47' DISCREPANCY BETWEEN TBG & CBL. COMMENCED DST #1. OPENED WELL TO ATM & SI. NO PRESS BUILDUP. UNSET RTTS & CIRC OUT FORM FLUID. RIH 140' FOR DST #2. RU LUB. TST TO 3000 PSI - OK. DISP TBG/ N2. SET PKR ~ 672~' CBL. BLED PRESS TO 1175 PSI ~'SURF. RIH W/ 12' 2 5/8" GUNS & SET DN ~ 6806' CBL. POH. BLED OFF N2 & FILLED TBG. UNSET PKR & REV CIRC FILL OUT OF HOLE. SET PKR ~ 6728' CBL, DISP W/ N2 & BLED DN TO 1175 PSI. RIH & PERF F/ 6798-6810' DIL ~ 4 SPF 0° PHASING. PERFORMED DST #2. FINAL RATE .61MMCF/D. KILL WELL. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 10 LEASE A-028142 WELL NO. ~BIJ 23W~6 FIELD Ke~ai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS . 6950' TD/ 6722' RET 31 DAYS 2/9/85 13 3/8" ~ 2532' 9 5/8" $ 6950' 69 PCF 5i SEC DAILY COST: $ 51,758 CUM COST: $2,143,608 AFE AMT: $3,170,000 POH W/ TST TOOLS. RU GO WL. RIH & SET HOWCO E-Z DRL RET ~ 6722' DIL. RIH & SET 2ND HOWCO E-Z DRL RET ~ 6677' DIL. RD GO. RIH W/ STINGER ON 5" DP. EST BREAKDOWN THRU RET. MIX & PUMP 200 SX CMT, STAB INTO RET & COULD NOT PUMP THRU RET. REV OUT CMT. POH. RIH W/ 8 1/2" BIT & CO RET $ 6675' DRM. CIRC BTMS UR. 6950' TD/ 6660' TOC 32 DAYS 2/10/85 13 3/8" ~ 2532' 9 5/8" $ 6950' 69 PCF 47 SEC DAILY COST: $ 28,793 CUM COST: $2,172,401 AFE AMT: $3,170,000 6950' TD/ 6660' TOC 33 DAYS 2/11/85 13 3/8" @ 2532' 9 5/8" ~ 6950' 68 PCF 47 SEC DAILY COST: $ 39,500 CUM COST: $2,211,901 AFE AMT: $3,170,000 6950' TD/ 6660' TOC 34 DAYS 2/12/85 13 3/8" ~ 2532' 9 5/8" $ 6950' 72 PCF 37 SEC DAILY COST: $ 44,796 CUM COST: $2,256,697 AFE AMT: $3,170,000 POH. RIH W/ RTTS ON 5" DP. SET PKR ® 6560' (TAIL $ 6573'). SQZ DST #1 PERFS F/ 6696'- 6706' W/ 200 SXS CMT. HELD 2000 PSI ON SQZ FOR 45 MINS AFTER CIP, HELD 1800 PSI FOR 6 HRS. DISR DR W/ N2 & BLED OFF PRESS. SHOT FLUID LEVEL EVERY l0 MIN FOR i HR - NO FLUID RISE (SQZ TST DRY). ROH. RIH W/ TST TOOLS ON 3 1/2" TBG. RIH W/ TST TOOLS ON 3 1/2" TBG. RU LUBRICATOR. RIH W/ 15' 2 1/2" TITIAN PERF GUN. TST TO 3000 PSI - OK. DISR TBG W/ N2 - TBG LEAKED N2 TO ANN. ROH W/ WL. FILLED TBG W/ MUD & SET RKR. PRESS TST TBG & RECD RETURNS FROM ANN CONFIRMING LEAK. ROH W/ TBG. PLUGGED BTM OF TBG & RIH, PRESS TESTING EACH STAND TO FIND LEAK. UNABLE TO LOCATE LEAK. ROH. RIH W/ TST TOOLS ON 3 1/2" TBG. RIH W/ TST TOOLS.ON 3 1/2" TBG. RU LUBRICATOR. ATTEMPT TO TST LUBR - FND WASHOUT. RD & REPAIR LUBR. RU & TST LUBR - OK. DISP TBG W/ N2. BLED PRESS TO 635 PSI. RIH & PERF U. BELUGA SDS F/ 5530-5545' DIL ~ 4 SPF, 0° PHASING. POH. RIH & RERF U. BELUGA SDS F/ 5520-5530' DIL ~ 4 SPF, 0° PHASING. CONDUCTED DST #3. FINAL RATE 2.31 MMCF/D. END TST. KILL WELL. PULL RTTS & CIRC LONG WAY. ROH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 11 LEASE A-028142 WELL NO. KBU 23x-6 FIELD Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6950' TD/ 5475' BP 35 DAYS 2/13/85 13 3/8" $ 2532' 9 5/8" $ 6950' 68 PCF 47 SEC DAILY COST: $ 44,979 CUM COST: $2,301,676 AFE AMT: $3,170,000 6950' TD/ 5475' BP 36 DAYS 2/14/85 13 3/8" $ 2532' 9 5/8" $ 6950' 68 PCF 46 SEC DAILY COST: $ 31,303 CUM COST: $2,332,979 AFE AMT: $3,170,000 6950' TD/ 5475~ BP 37 DAYS 2/15/85 13 3/8" $ 2532' 9 5/8" ~ 6950' 68 PCF 46 SEC DAILY COST: $ 51,255 CUM COST: $2,384,234 AFE AMT: $3,170,000 6950' TO/ 5240' RET 38 DAYS 2/16/85 13 3/8" @ 2532' 9 5/8" ~ 6950' 68 PCF 44 SEC DAILY COST: $ 38,438 CUM COST: $2,422,672 RU GO WL. RIH & SET HOWCO BP ~ 5475' CBL. TST BORE. RIH W/ TST TOOLS ON 3 1/2" IBG. RU LUBR. ISI LINES IO 3000 RSI-OK. DISR TBG W/ N2, SEI RIIS ~ 5134' IBG MEAS, BLED N2 RRESS lO 660 RSI. RIH & RERF F/ 5201-5204' DIL ® 4 SRF 0° RHASING. ROH. RIH & RERF F/ 5215-5221' DIL ~ 4 SRF 0° RHASING. ROH. BLED IO AIM & SI. RRESS BUILI IO 409 RSI. RIH IO RERF F/ 5280-5290' DIL - GUN MISFIRED. ROH. RIH W/ 2 1/2" TITIAN GUN & PERF F/ 5280'- 5291' DIL ~ 4 SPF 0° PHASING. POH. RIH W/ 2 1/2" GUN & RERF F/ 5291-5301' DIL ~ 4 SRF, 0° PHASING. ROH. CONDUCT DST ON THREE OPEN U. BELUGA SANDS. WOULD NOT UNLOAD WATER. DIS TBG W/ N2 & RETEST. WOULD NOT UNLOAD WATER. KILL WELL. PULL RKR & RIH. RESET RKR @ 5225' & DIS TBG W/ N2. CONDUCT DST ON U. BELUGA SANDS F/ 5280-5301' DIL. CONDUCT DST ON U. BELUGA SDS F/ 5280-5301' DIL. REV OUT FLUID IN TBG & CATCH SAMPLES. DISR TBG W/ N2. RIH W/ 15' RERF GUN. DISR N2 INTO FORMATION. RERERF F/ 5286-5301' DIL 8 4 SRF, 0° PHASING. ROH W/ WL. BLED OFF N2 & CONDUCT DST. END TST. KILL WELL. CIRC BTMS UP. POH W/ TST TOOLS. RIH W/ 8 1/2" BIT & 9 5/8" SCRPR & WASHFILL F/ 5419' TO 5470' DPM. MADE 5 STD SHORT TRIP & RIH. TAG FILL @ 5417'. POH. RU GO WL & SET EZ DRL RET ~ 5240' DIL. POH. RD GO. RIH W/ .STINGER ON 5" DP. AFE AMT: $3,170,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 12 LEASE A-028142 WELL NO. KBU 23x-6 FIELD Keoai Gas_Field DATE .: ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6950' TD/ 5161' DIL 39 DAYS 2/17/85 13 3/8" $ 2532' 9 5/8" $ 6950' 68 PCF 42 SEC DAILY COST: $ 28,582 CUM COST: $2,451,254 AFE AMT: $3,170,000 6950' TD/ 5161' DIL 40 DAYS 2/18/85 13 3/8" $ 2532' 9 5/8" ~ 6950' 68 PCF 42 SEC DAILY COST: $ 52,343 CUM COST: $2,503,597 AFE AMT: $3,170,000 6950' TD/ 5080' DIL BP 41 DAYS 2/19/85 13 3/8" ® 2532' 9 5/8" $ 6950' 68 PCF 42 SEC DAILY COST: $ 40,819 CUM COST: $2,544,416 AFE AMT: $3,170,000 6950' TD/ 5240' CMT RET 42 DAYS 2/20/85 13 3/8" ~ 2532' 9 5/8" ~ 6950' 68 PCF 4i SEC DAILY COST: $ 26,735 CUM COST: $2,571,151 SQZ PERFS F/ 5280-5301' DIL THRU RET W/ 216 SX CLASS "G" W/ 1% CFR-2, 1% CACL2 & .3% HALAD 24. ROH. RU GO WL & SET RET ~ 5161' DIL. RD GO. RIH W/ STINGER ON 5" DR & SQZ RERFS F/ 5201-5204' & F/ 5215- 5221' THRU RET $ 5161' W/ 241SX CLASS "G" W/ 1% CFR-2, 1% CACL2 & .3% HALAD 24. ROH. RIH W/ TST TOOLS. RIH W/ TST TOOLS. DIS TBG W/ N2. SET RTTS ~ 5060' DIL. PERF F/ 5112-5129' DIL W. 4 HPF 0° PHASING, W/ 780 PSI SURF PRESS INITIALLY. (25% DRAWDOWN), DST U BELUGA SD ~ A FINAL RATE OF .603 MMSCFD $ 594 PSI SURF PRESS ON TBG. DRY ZONE. REV CIRC & KILL WELL. POH W/ TST TOOLS. RIH & SET BP ~ 5080' DIL. RIH W/ TST TOOLS. DISR TBG W/ N2. SET RTTS ~ 4156' DRM. RERF THE STERLING B-3 SD F/ 4214-4275' DIL W/ 4 HPF, 0° PHASING. INITIAL SURF PRESS OF 750 PSI PRIOR TO PERFORATING (20% DRAWDOWN). OPEN WELL TO FLARE. DST THE B-3 SD ® 4.12 MMSCFD ~ 698 PSI SURF PRESS. B-3 SD WAS DRY. KILL WELL. CIRC. POH AFTER DST #8. TSTD BORE. RIH W/ 8 1/2i" BIT. DRL RTS $ 5081' & 5161' DIL. CO CMT ) 5161-5240' DIL' 'CIRC, POH. MU TOOLS FOR i DRY TESTING SQUEEZED PERFS. AFE AMT: $3,170,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 13 LEASE A-028142 WELL NO. KBU 23x-6 FIELD Kenai Gas Field . DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6950' TO/ 5475' DIL CMT RET 43 DAYS 2/21/85 13 3/8" @ 2532' '~-~ 9 5/8" ~ 6950' 68 PCF 40 SEC DAILY COST: $ 29,590 CUM COST: $2,600,741 AFE AMT: $3,170,000 RIH W/ TST TOOLS· SET PKR (RTTS) ~ 5163' TBG MEAS. DRY TSTD PERFS 5215-5221' & 5201-5204' DIL TO A BHP OF 469 PSI, OK. POH. RIH W/ 8 1/2" BIT. DRL RET ~ 5240'. CO CMT TO TOP OF RET ~ 5475' DIL. CIRC & POH. MU & RIH W/ TST TOOLS. SET PKR (RTTS) ~ 5237' TBG MEAS. DRY TEST PERFS 5280-5301' DIL. 6950' TD/ 6720' DIL CMT RET 44 DAYS 2/22/85 13 3/8" ~ 2532' 9 5/8" ~ 6950' 68 PCF 40 SEC DAILY COST: $ 27,666 CUM COST: $2,628,407 AFE AMT: $3,170,000 6950' TD/6841' ETD 45 DAYS 2/23/85 13 3/8" ~ 2532' 9 5/8" ~ 6950' 68 PCF 40 SEC DAILY COST: $ 55,554 ACC COST: $2,683,961 AFE AMT: $3,170,000 6950' TD/6841' ETD 46 DAYS 2/24/85 13 3/8" ~ 2532' 9 5/8" ~ 6950' 68 PCF 40 SEC DAILY COST: $ 87,496 ACC COST: $2,771,457 AFE AMT: $3,170,000 CMPTD DRY TEST ON PERFS 5280-5301' DIL. INITIAL BHP 492 PSI, FINAL BHP 492 PSI. FILLD TBG. PULLED PKR LOOSE. REV TBG & POOH. MU BIT #20 ON CO ASSY. RIH & DRL RET ~ 5475'. CO CMT 6660' TO RET ~ 6720'. CIRC'D HOLE. POOH. MADE UP TOOLS FOR DRY TEST #3 ON PERFS 6696-6706' OIL. RIH W/ 1100' FLUID CUSHION. SET BTM OF BUNDLE CARRIER ~ 6650'. PKR ~ 6637'. CHARGED TBG W/ 640 PSI FIELD GAS. OPENED HYDROSPRING. BLED OFF GAS CUSHION. WELL DEAD & ON BUBBLE HOSE ® 2040 HRS HELD TEST UNTIL 2140 HRS. FILLED TBG. PULLED PKR LOOSE. REVERSED TBG. POOH LAYING DOWN TEST STRING. COMP POOH & LD 3 1/2" TBG TEST STRING. INITIAL BHP 463 PSI, FINAL BHP 463 PSI. PERFS 6696-6706' OIL DRY TESTED, OK. MU BIT #21 on CO-'assy. RIH & drl ret @ 6720'c Co.cmt f/ 6720' to FC @ 6841'. Perfed for prod to a final shot density of 8 HPF. PRODUCTION PERFS: 6788-6810' 8 HPF 22' OPEN 5520-5545' 8 HPF 25' OPEN 5112-5129' 8 HPF 17' OPEN ~4275-4214' 8 HPF 61' OPEN COMP POOH. RIH W/ BIT & SCRPR TO 6841' · POOH. RAN GR & OB TO 5200' WLM.f RAN 9 5/8" OTIS WD PROD PKR. SET SAME ~ 5000' OIL. RIH W/ SEAL ASSY ON 5" DP. STAB IN & TEST PKR TO 500 PSI, OK. POOH. RU & RUN 3 1/2" DUAL COMP ASSY. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEE1D PAGE NO. 14 LEASE A-028142 WELL NO. KBU 23x-6 FIELD Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6950' TD/ 6841' ETD 47 DAYS 2/25/85 13 3/8" ~ 2532' 9 5/8" ~ 6950' 68 PCF 39 SEC DAILY COST: $ 153,856 ACC COST: $2,925,313 AFE AMT: $3,170,000 COMPL RUNNING DUAL 3 1/2" COMPL STRING. HUNG TBG ON CIW TBG HANGERS IN DCB SPOOL. TSTD PERM PKR TO 500 PSI-OK. ON SS RIH W/ TST PLUG. SET UP IN XN NIPPLE ~ 4171. PRESSURED TO 3000 PSI ON SS/ HOWCO TO SET PKR. BLED OFF PRESSURE. TESTED PKRTO 800 PSI F/ BACKSIDE. HELD PRESSURE OK. BLED OFF ANNULUS. INSTALLED BPV. ND BOPE STACK. 6950' TD/ 6841' ETD 48 DAYS 2/26/85 13 3/8" $ 2532' 9 5/8" ~ 6950' 68 PCF 39 SEC DAILY COST: $ 41,374 ACC COST: $2,966,987 AFE AMT: $3,170,000 6950' TO/ 6841' ETD 49 DAYS 2/27/85 13 3/8" ® 2532' 9 5/8" ~ 6950' DAILY COST: $ 44,101 ACC COST: $3,010,788 AFE AMT: $3,170,000 6950' TD/ 6841' ETD 50 DAYS 2/28/85 13 3/8" ® 2532' 9 5/8" ~ 6950' DAILY COST: $ 25,100 ACC COST: $3,035,888 AFE AMT: $3,170,000 COMPLETED ND STACK. FLANGED UP & TSTD CIW DUAL 3 1/2" BLOCK TREE. RIH W/ SHIFTING TOOL & OPEN XA SLEEVE ~ 4116' IN LS. RIH W/ SHIFTING TOOL & OPEN XA SLEEVE ~ 4085' IN SS. DISPLACE PKR FLUID INTO DUAL 3 1/2" X 9 5/8" ANNULUS. RIH & CLOSE XA ~ 4085' IN SS. OPEN XA IN LS ~ 4972' WLM. CLOSE XA ® 4116' IN LS. PUMP N2 DOWN LS TAKING RETURNS UP SS. BRING WELL ON. RU COIL TBG ON LS IN PREP TO RIH TO 6841' & LIFT FLUID OUT OF 9 5/8" CSG. RIH W/ 1 1/4" COIL TBG DOWN LS TO 6810' DIL. RUMP N2 FOR i HOUR ® 1500 SCF/ MIN. CO FLUID IN 9 5/8" CSG. ROH W/ COIL TBG. RD COIL TBG. INSTALL BRV'S. MOVE COMRL FLUID MUD TO TANKS ~ WD #1. CLEAN PITS. CLEANED PITS. RELEASED RIG TO RIG DN RATE AT 6:30 AM. LAID DN DERRICK. SKIDDED SUB BASE OFF X-MAS TREE. RELEASED CREW CREW AT 2030 HRS. i,,,j Eii;i....! .... F;'. E r;)(3 I::;:;'L'." I::'AGEi }4('-). 16 OD X I D UF:;!qG'T'H .C~,'::)'i"T[]H I :E':Li"i"T::% ,, 9C:.' × 2. '::;.; !:::i 4. ':) 'X 3.0 · :I, ,-".'i-8 X :%, 0 ..-:":::',..:, ,:':1-:1. 25 ,,/t. :1. ':'::' IJ (.:) (::) WELL KBU 23X-6 III IV B-3 Sd. 7 8 CASING & ABANDONMENT DETAIL I. Elevation Kelly Bushing at 0.0° II. Cameron Dual Tubing Hanger at 25.41' III. 20", 94.~, H-40 Driven to 126' IV.' 13-3/8", 61~, K-55 Buttress Casing at 2,538' V. E.T.D. at 6,841' VI. 9-5/8", 47.~,, N-80 Casing at 6,950' TUBING DETAIL LONG STRING: 3-1/2"~ 9.2#, N-80 TUBING 1. Otis 'XA" Sleeve at 4.,116.04' .2. Otis-Model 'RD-H' Dual Packer at 4,155.04' 3. Otis-'XA" Sleeve at 4,180.57' 4. Blast Joints From 4,199.71' to 4,298.63' 5. Otis "XA" Sleeve at 4,971.90" 6. Otis Straight Slot L0cator Sub at 5,006.40' 7. Otis Molded Seal Assembly From 5,007.76' to 5,018.11' 8. Otis 'Model 'WD" Prod. Packer at 5,007' 9. Otis 'X' Nipple at 5,050.57' 10. Bottom of Otis Mule Shoe at 5,074.27' SHORT STRING: 3-1/2"~ 9.2#, N-80 TUBING A. Otis 'XA" Sleeve at 4,085.40' B. 'Otis ModeI'-'RDH" Dual Packer at 4,154.71° C' -Bottom of Otis 'XN" Nipple at 4,173.16' PERFORATION RECORD DA TE INTER VA L CONDITION 2/23/85 6,788'-6,810' -~ 5,520'-5,545'? Beluga Zn. Production 5,112'-5,129' 4,214'-4,275' B-3 Sd. Production Beluga Zn. V VI' REV. DATE WELL KBU 23X-6 WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA ANCHORAGE, ALASKA DRAWN B.._.~..~W.~ CKD. APP'D, SCALE NONE aA'rE 4/4/86 i¢ 26.4' KB 29' 27' ~×-~7 bl O'l' ~ooo~ I~, ~' DAILY DRILLING MILCHEM INCORPORATED/P.O. BOX 22111 /HOUSTON, TEXAS 77027 Contractor Brinkerhoff OPERATOR L~ION OIL COMPANY OF CALIFORNIA MUD .A.I-)DITIONS LEGAL API ¢/50-133-20371 DESCRIPTION SEC 6, T 4N, R l lW, SM r:,,~.~ 2 '" 1985 Well Name Rig No. 54 And No. KBU 23X-6 Field KENAI GAS FIELD COUNTY KENAI STATE ALASKA · Milchem 06-023 Milchem Spud No. Drilling DATE T.D. TOTAL TOTAL Well No. 9973 Warehouse KENAI Date 1-10-85 DaysToT.D. 15 REACHED 1-25-85 DEPTH 6,950' COST $ 142,118.93 ~/~/ ~ "~ ' ' "~ ~ ' ~' ' ~ "' ~ "~-" ' ' ' ' ' ~ ~' ~ '~' ~' ~ ~' ~Y~/,.~ h/~' h~ ~/~7.~' ~r~7 ~' . ~ ~ / ~, /~ , ~ / ., /. s ,/" DATE'..' DEPTH /' P' / ~ / ~,' / ' / ~ / ~ / ~' / ~ ~ ~ i/ ~' / "'Y / ("~ //// //'/ ~' ' %' / ~/~~'' /' ~ /'/ ~/~/~ / ~ /DA /~ /~ /~ /~'/~' /~ / ~ /~ /4 ~ ~/~ /~ /~ /~ / ~. ., _,~-, I-0- ' ~8~ ' i 1' ' ," I i'. s l ~ ~ 5~.~0i5~.~0 ~-10 1235 80 15 2 t i I ' 1 I 2039.50 t 7362.60 ~-~ ~0 ~ ~z ~ I ~ ~ ~ ~6.~0t~055~.~0 ~-~ ~s~ 6o 5 t ! ~ ~ ~7~.s0 t~0~.~0 1-13 2535 2I 1 1 501.00 12534.90 1-14 2535 3 1 1 555.46 13090.36 1-15 2834 55 5 9 2 5 i 5 6 1 1 4364.88 17455.24 1__~16 3999 30 40 5 6 15 i i 7121.75 24576.99 1(~ 3999 t I 2 4 1 1 2072.50 126649.49 1-18 3999 55]. 4 6 12 1 1 6218.00 132867.49 1-19 3999 I I 2 i 1 1230.00 34097.49 1-21 14928 78 !" 3I 2 I 1 1 1' 2538.00 45226.74 1-23 5905 50 100 5 2 7 1 3I 1 1 6007.55156427 19 1-24 6438 50 6 2 6 i 1 1 2890.90 !59318.09 1-25 6950 40 12 5 1 1 5299.80 '64617.89 ~-~6 6~50 6~ 58' 16)~ 5 i ~ ~/~) ~ ~ ~50~.~0 67:~.0~ ~-~7 6~50 ~5 ~7 I I ~ ~ ~70~.65 6~s~.7, D~t~ 2-28-85 ~lchem THRAPP / J. OGLESBEE TSD--OMA- ~/7:[ Technical Represantative District Region ALASF, A PAGE ,,, 1 OF 3 . DALLY rqRILLINR MILCHEM INCORPORATED/P.O. BOX 22111 /HOUSTON. TEXAS 77027 Contractor Brinkerhoff OPERATOR UNION OIL COMPAArY OF CALIFORNIA AD[-)iTIONS LEGAL API ~/50-133-20371 DESCRIPTION SEC 6, T 4N, R llW, SM Well Name Rig No. 54 And No. KBU 23X-6 Field KENAI GAS FIELD COUNTY KENAI STATE ALAS~& Milchem 06-023 Milchem Spud No. Drilling DATE T.D. TOTAL TOTAL Well No. 9973 Warehouse KENAI Date 1-10-85 DaysToT.D. 15 REACHED 1-25-85 DEPTH 6,950' COST $ 142,118.93 ~ /~ ~/~ ~ cos~ 1-28 j 6950! i' i ! I 3 "( i i 6 1 1 I 757.00 t 69580.74 1-29 6950 t I t I 1 1 I 430.00 ,I 70010.74 1-30 6950 30 i ! I 1 1 880.00t 70890.74 'i-31 69501 30 ! t i 1 I 1 880.00 71770.74 2-1 6950' I t I 1 1 430.00 72200.74 2-2 6950 18 1 1 1182.76 73383.50 :-~ 6~50 ........ ~ ~ I ~30.00 7~.50 2 .... ' 6950 168 1 1 2950.00 76763.50 ~;- 6950 90 6 1 1 2030.92 .78794.42 2-6 6950 170 t 1 .... 1 28o i75 .... 50 1 1 25564.oo 1o4358.42 2-7 6950 52 I ,,. 1 91 ,, 57 J 14 1 1 8356.75 t112715.17 :-~6~50 I ,, '"',' i 6 ~ ~ I~:0.00t 2-11 6660' 18 4 10 1 1 2222.80 118067.97 2-12 6660 1 .... i 1 1 617.50 118685.47 2-13 5172 15 10 I I 4 1 ~ 1648.25 120333.72 2-14 5225 i t } i 1 1 430.00 120763.72 2-15 5422 15 i I 5 t . 2 1 1 1298.25 122'~61.97 D~t~ 2-28-85 Mil~em THRAPP / J. OGLESBEE 3 TSD--DMA-- 2/?! Te~ni~l Repre~ntative District Region ALASKA PAGE 2 OF · -, MILCHEM INCORPORATED / P. O. BOX 22111 / HOUSTON, TEXAS 77027 LEGAL A.PI #50-133-20371 Brinkerhoff OPERATOR UNION OIL COMPANY OF CALIFORNIA DESCRIPTION. SEC 6, T 4N, R llW, SM Contractor Well Name Rig No. 54 And No. KBU 23X-6 Field KENAI GAS FIELD COUNTY KENAI Milchem 0(~-023 Milchem Spud No. Drilling DATE T.D. TOTAL Well No. 9973 Warehouse KENAI Date 1-10-85 Days To T.D. 15 REACHED 1-25-85 DEPTH 6,950' STATE ALASKA TOTAL COST $ 142,118.93 .... ,. ,./<- ~-/..-- oO~,/o~ Z oO~/o~ oO/o-- , (1985~ (!t,) /.~ / .~ ,/ ,..~' / ,.~' / ~ ,/~'<Y~'~ ,/ O ,/~ ,/ ~ ,'/' ~ ~ ~. ~ ~ .'/ ~ /~ / ~ ,/~ ,/ ~' 'LYCO~T ICuMulatIvE 2-18 5060 7 5 j J 4 1 1 1251.85 I 125175.4 so6oI 6 6.75'i 2-22 6711 42 35 2 1 1 3175.45~ 136150.6 2~23 6841 1 52 ~ 2 1 1 2644.10 i 138794.7 0.00 I ~-~6 68~; ~ I ~ ~ ~30.00t ~00~.; ~-~7 6~ ~'~,~ ~ ~ ~0.00 ~ ;~05~4.; .~-28 6841 5 (6) 8 (1) 3 1 4 10 6 1 1 1604.21 142118.~ TOT~ UNIT 1180 821 264 .';~'26' 56 39 35 31 5 38 637 2 315 41 8 40 18 112 51 51 / TOT~ $$ 17~700' 00 8210.~0 980.00 12~2 50 937.5( 22,.00~ .35 7560.~,0 252.0{) ~661.5( 20,~0~.00 / Date 2-28-85 Milchem THRAPP / J. OGLESBEE Technical Representative District Region ALASKA ' PAGE 3 OF 3 TSD--DMA- 1/71 MILCHEM INCORPORATED /P.O. BOX 22111 /HOUSTON, TEXAS 77027 BRINKERHOFF Contractor OPERATOR DO HOT DETACH ALONG PERFORATED LINE UNTIL THE DATA IS COMPLETE. DRILLING UNION OIL COMPANY OF CALIFOt~IA MUD RECAP API #50-133-20371 LEGAL DESCRIPTION SEC 6, T4N, RllW, SM Rig No. 54 Well Name And No. KBU 23X-6 Field ~ GAS FIELDS COUNTY Milchem 06-023 Milchem Well No. 9973 Warehouse Spud No. Drilling DATE T.D. 1-25-85 TOTAL 6950 KENAZ Date 1-10-85 Days To T.D 15 REACHED DEPTH STATE ALASKA TOTAL COST $ 142,118.93 CASING PROGRAM BITS TYPE MUD SYSTEM SOLIDS CONTROL EQUIPMENT ADDITIONAL INFORMATION No. Size (in) Depth (ft) Size (in) 9 5/8 DATE TIME" DEPTH (ft) 1-3 17 1/2 4-10 12 1/4 11-21 8 1/2 Type Depth Interval (ft) SPUD 0- 2535 GEL- POLYMER 2535 - 6950 Type Depth Interval (ft) SHAKERS 0 - TD DESANDER 0 - TD DESILTER 0 - TD MUD (~R 0 =TD CENTRIFUGE 2535 - TD GARDNER - DENVER PZ-9 (TYP 2) Pump Specifications D.P. andD.C. 5" -- 19.5# & HWDP, 8"D.C. Other FUNNEL J PLASTIC WT VlSCOSITYJ VISCOSITY (sec/qt) '1 (ppg) 66 140 56 11 56 YIELD POINT (Ib/100ft2) GELS J FILTRATE (lb/100ft2)l pH (mi/30 min) 1 Cake o-0t I , Chloride Calcium Pm Pf/ Mf (ppm) (ppm) i ,, 33 17/25 10.0 15.8 2 .8 .3/.7 250 TR ISand Solids (% by (% by jVol.) Vo.) Oil (% by Vol.) Methy. Water Blue (% by (me/mi Vol.) mud) 3 : 0 97 ' 29 Circ. Volume (bbl) REMARKS 1-9 2200 -0- 970 SPUD MUD READY 1-10 0600 467 67 164 59 19 59 45 29/36 :9.5 14.2 2 .6 .2/.55 250 TR 4 0 96 27 940 DRLG. AHEAD 1-10 2200 1235 67+ 138 59 17 59 30 :19/25 9.5 14.0 2 .6 .2/.5 250. TR 4 0 96 26 940 TRIP FOR DYNA DRILL 1-11 2200 2320 67+ 133 82 11 82 30 20/28 9.5 13.6 2 .5 .2/.4 500 TR 1/3 4 0 96 28 1140 DRLG. - SURVEY 1-12 2200 2533 68+ 140 76 14 75' 35 22/31 '9.0 13.6 2 .3 .1/.2 550 TR 1/3 4.5 0 95.5 27.5 1301 POOH FOR CASING l_L-!3 1200 2535 68+ 55 71 14 100 2300 2535 68 48 62 15 100 1-15 2300 2834 68+ 44 64 14 100 1-16 2300 3999 70 49 90 14 100 24 16/24 9.0 13.8 2 .3 .1/.25 500 TR 1/3 4.5 0 95.5 24 10 4/16 9.5 16.2 2 .3 .2/.6 400 TR 1/4 5.5 0 94.5 24 9 .,~/15 11.5 9.6 29.4 200 2 2.0 .6/.8 400 TR 1/4 7 0 93 23 21 ..7/16. 11.5 7.2 19.4 200 2 .6 .3/.5 400 40 1/4 7 0 93 24 1226 WAITING ON ~ 1150 NIPPLE UP 1083 DRILL AHEAD 1277 STUCK PIPE ON TRIP OU 1-17 2330 3999 70 49 72 15 100 21 4/9 11.5 7.6 14.2 200 2 .8 ~'~4/.8 400 20 1/4 7 0 93 24 22 5/11 11.0 7.4 17.6 200 2 .8 .5/.8 400 20 1.4 7 0 93 24 1301 WASH OVER FISH 1324 WASH OVER FISH ll'tl~--lSi"!,, 2000 3999 70 54 72 16 100 1-19 2330 3999. 69 53 68 14 100 21 5~9 11.0 7.4 18.6 200 2 1.0 '.5/.8 400 20 1/8 6 0 94 24 1246 RETRIA%~ FISH 1-20 2330 4154 71 48 72 '''':''' 14 100 22 4/9 10.0 7.2 19.0 200 2 .4 .2/.5 400 20 1/4 9 0 91 20 1332 REAM TO BO~CI~,.~ 1-21 2330 4928 72 49 70 19 100 29 7/11 9.5 7.2 19.4 200 2 .3 .2/.3 400 20 1/4 9+ 0 91- 18+ 1344 DRILL AHEAD 1-22 2200 5509 72 52 74 19 100 31 7/12 .9.0 6.6 18.2 200 2 .45 .15/.4 400 TR 1/3 9+ 0 91- 21 1457 TRIPPING 26 6/11 9.5 6.6 18.0 200 2 .45 .2/.45 400 TR 1/4 9 0 91 21 1-23 2300 5905 72 50 100 16 100 1666 DRILL AHEAD Milchem Date 2-28-85 Technical Representative TSD--DMR (1)- 1/71 THRAPP / J. OGLESBEE District Region ALASKA PAGE 1 OF 3 , J · . MILCHEM INCORPORATED /P.O. BOX 2211! /HOUSTON, TEXAS 77027 Contractor BRINK~lqHOFF OPERATOR ONTON O/T, COMP~ OF CALIFOt;~IA MUD RECAP LEGAL API #50-133-20371 DESCRIPTION SEC 6, T4N, RllW, SM Well Name Rig No. 54 And No. KBU 23X-6 Field KENAI GAS FIEI_DS COUNTY KENAI STATE ALASKA , , '0 Solids j .... Volume (19 8.~l, (ft) (PPg) APl~'(sec/qt)°F j cp ~ ,J OF , (Ib/10Oft 2) 0/10 p H j! APl JHT-HP J OF (3in~ Pm Pf// Mf ,Chl(ppm)ride CalciUm(ppm) (%vol.)by, (%Vol.)by (;Oobl.~ (%Vol.)by (me/mlmud) % (bbl) RE MAR KS , . , 1-24. 2200 6438 72 50 72 17 100 30 1-25 2100 6950 72+ 48 71' 16 100 26 ~ 26 2100 6950 72+ 48 65 15 100 25 ~---27 2200 6950 72+ 46 65 17 100 24 7/12 9.5 7.0 19.0 200 2 .3 .1/.4 350 TR 1/4 9 0 91 25 7/13 9.0 6.6 17.4 200 2 .3 .15/.35 400 TR 1/4 9+ 0 91- 25 7/13 9.5 6.8 18.0 200 2 .4 .2/.4 400 TR 1/4 9+ '0 91~- 25 6/14 9.0 7.8 18.8 200 2 .3 .1/.3 400 TR 1/4 9 0 91 ~25 1561 WORK STUCK PIPE 1553 SHOR2 TRIP (TD) 1573 I3CC¢~ING 1553 FINISH ~ING CIRC. 1-28 2300 6950 72 44 65 14 100 20 6/12 8.5 8.4 19.6 200 2 .2 .1/.2 400 TR 1/4 9 0 91 25 908 RUN & CEMENT 9 5~.,,, 1-29 2330 6950 72 40 65 15 100 22 4/7 8.5 8.4 19.6 200 2 .2 .1/.2 400 TR 1/4 9 0 91 25 828 NIPPT~ UP CHANC~.BK~ 1-30 2200 6950 72 40 68 15 100 22 4/7 8.5 8.4 19.6 200 2 .2 .1/.2 400 TR 1/4 9 0 91 25 856' RUN CBL PEI~2 & SQ~ 22 856 PERF & SQUF~.ZE @ 1-31 2200 6950 72 40 65 .15 100 2-1 2200 6950 72 37 62 10 100 4 2-2 2200 6950 72 41 65 9 100 8 2-3 2200 6950 72 41 65 9 100 8 4/7 8.5 8.4 19.1 200 2 .2 .1/.2 400 TR 1/4 9 2/6 9.5 11.8 26.0 200 2 .4 .2/.4 400 '160 1/4 9 6/16 12.0 19.8 NC ' 2 2.1 1.5/2.1 400 80 1/4'9 6/16 12.0 19.8 NC 2 2.1 1.5/2.1 400 80 TR 9 0 91 '25 0 91 25 808 PERF & SQUEEZ,E,_~ .__373t 0 91 25 808 DR_TT,T, R & T, 0 91 25 858 ~, SQUF~.ZE 2-4 2330 6950 72 39 65 5/12 12.0 19.6 NC 7 100 6 2 2.2 1.5/2.1 400 40 1/4 9 0 91 25 908 2-5 2200 6950 72 42 62 9 100 9 6/13 12,0 19,8 NC 2 273 1.6/2.2 400 80 TR 9+ 0 91.- 24 908 DRILL OUT BP 2-6 2200 6950 69 51 75 17 100 36 4/5 9.5 NC NC 92000 TR 3 0 97 0 6 888 DISPLACE C.F. 2-7 2200 6950 69 48 72 16 100 32 4/4 9.5 NC NC 92000 TR 3 0 97 0 6 1128 TEST 1ST ZONE 2-8 2200 6950 69 48 68 14 100 29 ~ q 2200 6720 69 51 68 17 100 30 ~=m0 2200 4/4 9.0 NC NC 3/4 10.5 NC NC 92000 TR 3 0 97 0 '6 1116 TEST 1ST ZONE 68000 TR 3 0 97 0 6 1069 ABOR2 SQUF~.~R 6573 67 47 67 15 100 27 2-11 2200 6600 68.5 47 63 15 100 24 2-12 2200 6660 68 45 85 14 100 21 2-13 2230 6660 68+ 47 66 15 100 19. 3/4 10.5 NC NC 3/4 10.5 NC NC 3/3 10.5 NC NC 3/3 10.5 NC - 67000 TR 3 0 97 0 6 1056 SQUR. RZE 65000 TR 3 0 97 0 6 1047 TRIPPING 64000 TR 3 0 97 0 6 1022 TRIPP/NG 66000 TR 3 0 97 0 6 907 DST at 5172 2-14 2300 5225 68 46 72 17 100 20' 3/3 10.5 NC ~ 61000 TR 3 0 97 0 6 960 DST at 5225 2-15 2300 5422 68 46 72 16 100 20 3/3 10.0 NC ~- 62000 TR 3 0 97 0 6 992 DST & KIT,T, WET,T, 2-16 2300 5422 68 44 20 16 100 20 3/3 10.0 NC - 61000 TR 3 0 97 0 6 1016 RATICR PIPE 2-17 2230 5160 68 42 68 15 100 18 3/3 10.5 NC '- 62000 TR 3 0 97 0 6 1007 TRIPPING 2-18 2230 5060 68 43 68 15 100 20 3/3 10.5 NC ~ 62000 TR 3 0 97 0 6 1017 TESTING Milchem Date 2-28-8.5 Technical Representative -TSD -- DMR (2) -- 1/71 THRAPP / J. OGLESBEE District Region ALASKA PAGE 2 ,OF 3 ., MILCHEM INCORPORATED /P. O. BOX 22111 /HOUSTON, TEXAS 77027 Contractor BRINKERHOFF OPERATOR DO NOT DETACH ALONG PERFORATED LINE UNTIL THE DATA IS COMPLETE. RRILLING MUR RECAP UNION OIL COMPANY OF CALIFORNIA API #50-133-20371 LEGAL DESCRIPTION SEC 6, T4N, RllW, SM Rig No. 54 Well Name KBU 23X-6 KEAXIAI GAS FIEI,DS KENAI And No. Field COUNTY STATE ALASKA · . I FUNNEL I ~-AST,C i ~ELS F,LTRATE Alkalinity Solids Methy. I Circ. DATE TIME DEPTH WT VISCOSITY l VISCOSITY KCL (ft) (ppg) (sec/qt) I POINT (lb/100ft2) (mi/30 min) Cake Chloride Calcium Sand Oil Wateri Blue Volume REMARKS I bY i(% Dy ~P; i Vol.) % (bb,) Vol.) mud) (~985) iAP,~ J °F j OF (Ib/10Oft2)I 0/10 pH , I Apl HT-HP OF (~n2r)d Pm Pr/ Mf (Pi)m, (pi)m) '(~oDI.~i(*/° by (% Vol.) (me/mi , ~ ~ ; , , , , i , 2-19 2230 5060 68 41 67 15 100 19 3/3 10.5 62000 -20 223fl 5235 68 41 68 15 100 19 _-21 2200 5420 68 40 70 15 100 12 TR 3 0 97 6 3/3 ]fL.0 62000. TR 3 0 9.7 6 3/3 10.5 6000.0 1/8 3 0 97 .- 6 1022 KILL WEI,T, 1010 TESTING 1030 TESTING 2-22 2300 6711 68 40 72 15 100 9 2-23 2400 6841 68 40 72 14 100 10 2-24 2200 6841 68+ 40 74 13 100 10 2-25 2200 6841 68+ 39 72 13 100 10 3/3 .10.5 61000 3/3 10.5 60000. 1/8 3 0 97 3_/8 3 0 9.7 1132 DRL RET & Dt~f TEST 6 1297 PERFWELL 3/3 10.5 6100.0. 1/8 3 0 97 6 3/3 10.5 61000 TR 3 0 93. 6 1276 SET PKR-LAY DOWN D. [ 1287 RUN DUAL COMPLETION 2-26 2400 6841 PACKER FLUID 805 TEST WET,L 2-28-85 'Date TSD-- DMR (2) -- 1/7! Milchem Technical Representative THRAPP / J. OGLESBEE District Region ALASKA PAGE OF DO NOT DETACH ALONG PERFORATED LINE UNTIL THE DATA iS COMPLETE. MII. CHEM INCORPORATED / P. O. BOX 22111 / HOUSTON, TEXAS 77027 OPERATOR UNION OIL COMPANY OF CALIFORNIA SUPPLEMENTARY LEGAL DESCRIPTION. API #50-133-20371 SEC 6~ T4N, RllW, SM DATA Milchem Well Fla. 06-023-9973 Will Name And No. KBU 23X-6 COUNTYL KENAI STATE ALASKA DATE DEPTH INFORMATION , L I , i ,, 1-9 MUD MIXED READY FOR SPUD. ~. 1-10 1235 SPUD IN AT 0200 HOURS, DRILL AND SURVEY TO 1235' POOH PICK UP DYNA DRILL~ RIH ,. 1-11 2320 DRILL AND SURVEY WITH 9-5/8" DYNA DRILL TO 26° - TARGET 28°+ - MUD IN GOOD SHAPE. DRILL 3 HOURS WITH ONE PUMP BUT NO APPARENT HOLE PROBLEMS. 1-12 2535 POOH, RIH WITH NEW BHA - HOLE TIGHT IN SEVERAL AREAS OF KICK-OFF INTERVAL~ WORK TIGHT SPOTS, DRILL & SURVEY TO 2535', CIRCULATE, POOH FOR WIPER TRIP, RIH, CIRCULATE, POOH FOR CASING. . -!-13 2535 RIG UP AND RUN 13-3/8" CASING, RIH WITH DRILL PIPE, STING IN AND CIRCULATE, RIG UP HALLIBURTON AND CEMENT - WOC. 1-14 2535 NIPPLE DOWN DIVERTER AND NYDRIL, NIppLE UP BOP STACK, TES~'STACK. ,, 1-!5 2834 FINISH BOP TEST, R!H, TAG CEMENT AND CIRCULATE, PRESSURE TEST CASINQ., DRILL F~pAT CALLA{ AND CEMENT TO WITHIN TEN FEET OF SHOE, PRESSURE TEST CASING AGAIN, DRILL OUT SHOE AND TEN FEET OF NEW HOLE, . PERFORM LEAK-OFF TEST. 1-16 3999 DRILL APPROXIMATELY 300' TRIP OUT FOR BHA CHANGE; RIH, DRILL AHEAD TO 3999' POOH - PIPE STUCK ON POOH - ATTEMPT TO CIRCULATE, PACKED OFF, NO RETUR~S2_.FREE POINT,. PIPE STUCK VERTICALLY AT 2736'. __ 1-17 3999 BACK OFF PIPE ABOVE JARS, RIH WITH FISHING ASSEMBLY, JAR ON FISH, NO PROGRESS, RIH AND WASH OVER FISH TO STABILIZER, CBU, POOH. THIS WAS FIRST DAY THAT WE COULD USE CENTRIFUGE. RUNNING AT ALL TIMES TO , HELP REDUCE PV. SET UP PILL PIT TO MIX BLACK MAGIC PILL. ,, .'..1-18 3999 MIX AND STORE BLACK MAGIC PILL. RI~..WITH WASH PIPE AND WASH TO FIRST STABIL.IZER; ~OOHl RIH AND SCREW INTO FISH, ESTABLISH CIRCULATION, CIRCULATE AND CONDITI.ON..MUD, 1-19 3999 BACK OFF FISH ONE COLLAR ABOVE STABILIZER, POOH, RIH WITH FISHING ASSEMBLY, SCREW ONTO FISH, JAR DOWN, .... , ROTATE PIPE & ESTABLISH CIRCULATION, CIRCULATE AND CONDITION MUD, PULL FISH OUT OF HOLE, PICK UP BHA .,.. WITH BULLNOSE AND HOLE-OPENER. ,. . .. , . ,. 1-20 4154 REAM TO BOTTOM WITH HOLE-0PENER~ CIRCULATE AND coNDITION .MU.D~ HOLE STILL TIGHT~ RAISE MUD WEIGHT TO 71PCF, SPOT SOAP ON COLLARS, POOH, CHANGE BHA, RIH, DRILL AHEAD. , L 1-21' '4928 TRIP FOR BHA, CHANGE FOR DIRECTIONAL CHANGE, POOH TO LOCK ASSEMBLY, TRIP IN. MWD TOOL INOPERATIVE. POOH AND CORRECT, RIH, DRILL AHEAD. , . Hllchem TH]~:~P / J OGLESBEE ALASka, Technical Representative ' , District_ . Page 1 of T,SD-SD- I/7 I MII. CHEM INCORPORATED / I). O. BOX 22111 / HOUSTON, TEXAS 77027 OPERATOR ~ION OIL COMPA_NY OF CALIFORNIA SUPPLEMENTARY LEGAL DESCRIPTION API #50-133-20371 SEC 6, T4N, RllW, SM DATA Milchem ?fell No. 06-023-9973 ?fell Name And No. KBU 23X-6 COUNTY KENAI STATE, ALASKA DATE DEP Th INFO R/9, AT ION 1-22 5506 POOH, CHECK ~',TD TOOL, CHANGE OUT ~Bg'D, R!H, CHECK M'~, DRILL AHEAD TO 5506' ~fD FAILED~, CIRCULATE~, ~' , POOH - 1ST FIVE STANDS TIGHT. 1-23 5905 POOH~. FIX MWD~ CHANGE BIT~ RIH~ DRILL AHEAD TO 5840' POOH FOR BHA CHANGE, RIH, DRILL AHEAD _ 1-24 6438 DRILL AND SURVEY TO 6438', POOH, CHANGE BIT, RIH, PIPE STUCK TWO JOINTS OFF BOTTOM~ REST OF TRIP OK. 1-25 6950 WORK PIPE FREE, DRILL TO 6950' TD, CIRCULATE, POOH FOR WIPER TRIP. 1-26 6950 FINISH POOH~.. LAY DOWN MWD AND MONELS~ PICK UP CONVENTIONAL COLLARS~ RIH~ CIRCULATE TWO COMPLETE BOTTOMS UP~ POOH, LOGGING· 1-27 6950 RUN FOUR LOGS AND SIDEWALL CORES, RIG DOWN DRESSER ATLAS, RIH, CLEAN OUT TRASH AND 7' OF F. ILL, CIRCULATE AND CONDITION HOLE. lj2.8 6950.. FINISH CONDITIONING HOLE~ POOH~ RUN 9-5/8" CASING~ CEMENT SAME. . .. 1-29 6950 FINISH CEMENTING 9-5/8" CASING, NIPPLE DOWN BOP'S, NIPPLE UP ON 9-5/8" CASING~ LAY DOWN BHA~ PICK UP 8-1/2" BIT AND 6-1/4" COLLARS~ CUT AND SLIP DRILL LINE, RIH TO FLOAT COLLAR, CIRCULATE.. 1-30 6950 POOH TO LOG, CUN CBL GAUGE RING AND PERF GUN~ PERF AT 5108'-5110' POOH~ RIH WITH EZ DRILL AND SET AT 5069' SQUEEZE, POOH , · 1-31 6950 RIH WITH GEARHART, PERF AT 4280'-4282', SET EZ DRILL AT 4240' , SQUEEZE, REVERSE OUT, POOH, RIH WITH - , , PERF GUN, PERF AT 3787'-3789' SET EZ DRILL AT 3740' , , 2-1 .... 6950 SQUEEZE, REVERSE OUT, .POOH, BREAK DOWN SQUEEZE MANIFOLD, WOC, LAY DOWN 33 JOINTS HWDP, PICK UP 3-1/2" _ TUBING, WOC. 2-2 '' 6950 DRILL RETAINER AND HARD cEMENT AT 37'g1', TEST CASING TO 106~"'PsI, RI~' AND'~RILL CE~E'NT STRINGERS' TO RETAINER AT 4255', DRILL RETAINER AND CEMENT, TEST CASING TO 1190 PSI, RIH TO 4993' , HIT CEMENT, POOH, CHANGE BIT, RIH, DRIL~' CEMENT' TO RETAINER AT 5069'. DRILL RETAINER AND CEMENT, TEST CASING TO 1415 ' PSI, BLED OFF TO 800 PSI, DRILL STRINGERS AND RIH TO 6348' CIRCULATE HOLE CLEAN , · . 2-3 6950 POOH, PICK ,UP SCRAPER, RIH, SLIP DRILL LINE, POOH WITH SCRAPER, PICK UP RTTS AND BY-PASS, RIH, SET pACKER AT 5074' TEST BELOW PACKER - DIDN'T HOLD - POOH WITH RTTS, RIH WITH EZ DRILL, SET AT 5060' -- ' , RIH WITH STINGER, STAB IN RETAINER AT 5055', CEMENT, SQUEEZE, REVERSE OUT. 2-4 6950 POOH WITH STINGER, WOC - MAKE UP BIT, RIH, DRILL RETAINER AT 5055' DRILL JUNK AND HARD CEMENT , · ,, Milchem THRAPP / J OGLESBEE ALASKA 4 Technical Representative. ' District, Page 2 of T~D-SD-I/T' MIL.CHEM INCORPORATED / P. O. BOX 22111 / HOUSTON, TEXAS 77027 OPERATOR UNION OIL COMPANY OF CALIFORNIA SUPPLEMENTARY LEGAL DESCRIPTION API #50-133-20371 SEC 6, T4N, Ri1W, SM DATA Milchem Well No. 06-023-9973 W, II Nome And No. KBU 23X-6 COUNTY KENAI STATE ALASKA DATE DEPTH INFORMATION _ 2-5 6950 DRILL CEMENT 5062' POOH RIH WITH RTTS, TEST SQUEEZE, POOH, PICK UP BIT #16, RIH, DRILL BP 5135' , , , ' .... RUN TO BOTTOM, CIRCULATE, POOH, TEST BOP'S, RIH WITH CASING SCRAPER. 2-6 6950 DUbIP AND CLEAN PITS, BUILD COMPLETION FLUID, PUMP 200 BBL WATER FLUSH, DISPLACE, CIRCULATE AND CONDITIO TO UNIFORMITY. 2-7 6950 CIRCULATE AND BLOW DOWN KELLY POOH~ PICK UP HALLIBURTON TOOL~ RIH WITH TUBING~ MAKE UP WIRELINE ,, LUBRICATOR AND TEST MANIFOLD, TEST FLOW LINE TO 1500 PSI, TEST MANIFOLD LUBRICATOR AND LINES, DISPLACE , TUBING WITH NITROGEN, RUN WIRELINE GUN AND PERFORATE, BLEED OFF NITROGEN, PUT WELL ON TEST, BREAK PACKER, FILL TUBING, GO DOWN FOR NEXT SETTING. 2-8 6~50 SET PACKER, DISPLACE NITROGEN, RUN WIRELINE PERF GUN - GUN STOPPED 40~' O~F BOTTOM, PULL WIRELINE, BLEED , OFF NITROGEN, RUN TUBING TO BOTTOM, REVERSE CIRCULATE - SAND .IN BOTTOM OF WEL. L. SE.T....PACKER, DI..SPL.A. CE NITROGEN, RUN WIRELINE, PERF, BLEED OFF NITROGEN, PUT WELL ON DST, BREAK PACKER, REVERSE AND KILL WELL. 7000+ UNITS GAS. , 2-9 6720 ~ "' POOH, RIG UP GEARHART, RIH WITH BP AND SET AT 6720' POOH RIH WITH EZ DRILL AND SET AT 6675' POOH , , , , RIH WITH HALLIBURTON STINGER, TEST LINES, STING IN, ESTABLISH INJECTION RATE, UNSTING, BUMP CEMENT, SQUEEZE, STING IN - NO INJECTION - REVERSE OUT, POOH, RIH WITH BIT, DRILL ON EZ DRILL. , , 2-10 6573 POOH, RIH WITH RTTS, SET RTTS AT 6573', ESTABLISH..BREAKDOWN RATE, PUMP CEMENT~ SQUEEZE~ HOLD BACK , PRE.SSURE FOR SIX HOURS, BREAK PACKER AND REVERSE OUT~ SET PACKER~ DISPLACE WITH NITROGEN~. ,TAKE FLUID LEVELS EV.E. RY 10 MINS - SQUEEZE SUCCESSFUL - pOOH. 2-11 6660 RIH WITH HALLI..BURTON RTTS, SET RTTS, CHECK PRESSURE, UNSEAT ~ACKER, DISPLACE WIT~ N{'TROGEN, sET PACK~'R~ BUBBLES IN HOLE - BLEED OFF NITROGEN, FILL WITH MUD - PRESSURE UP, PRESSURE FALLING - POOH, RIH LOOKING FOR wAsHouT - NO WASHOUT - POOH. 2-12 6660 RIH WITH HALLIBURTON RTTS, DISPLACE WITH NITROGEN, SET RTTS AT 5490' RUN WIRELINE AND PERF - PUT WELL ' ON TEST, RELEASE PACKER, REVERSE CIRCULATE AND KILL WELL, CIRCULATE 1 FULL BOTTOMS UP, POOH. , , , 2-13 5172 SET RETAINER AT 5424' RIH WITH TEST ASSEMBLY, SET RTTS AT 5172' PERF AND DST ZONE - 2-14 5225 CONTINUE DRILL STEM TEST. " 2-15 5422 FINISH TEST, REVERSE OUT TAKING SAMPLES, RESET RTTS AT 5225', REPERF ZONE, PUT' ON TEST, REVERSE OUT , , AND KILL. CIRCULATE LONG WAY. Milchem Technical Representative, THRAPP / J. OGLESBEE District. , ALASKA Page 3 TSD-$D-I//I of 4 , DO NOT DETACH ALONG PERFORATED LINE UNTIL THE DATA iS COMPLETE. MILCHEM INCORPORATED/P. O. BOX J.~l I1/HOUSTON, TEXAS 7702Y OPERATOR U~ION OIL COMPA_N-~ OF CALIFORNIA SUPPLEMENTARY DATA LEGAL API #50-133-20371 Milchem DESCRIPTION, SEC 6, T4N, RllW, SM Well No. 06-023-9973 W, II Nome A.d No. KBU 23X-6 COUNTY KENAI STATE ALASKA I ,,. Il, I I I I I I I I il i · DATE DEPTH ' INFORMATION i i _ 2-16 5422 SCRAPER RgN, DISCOVER CEMENT SCALE IN PIPE ON TRIP OUT. RATTLE PIPE 35 STANDS IN AND OUT. 2-17 5160 RIH WITH TUBING, SET BRIDGE PLUG AT 5474', SET EZ DRILL AT 5235', SQUEEZE ZONE, REVERSE OUT, POOH, SET EZ DRILL AT 5160' RIH AND SQUEEZED REVERSE OUT, POOH. _ 2-18 5060 RIH WITH TUBING~ DISPLACE TUBING WITH NITROGEN~ SET RTTS AT 5060' PUT WELL ON TEST 2-19 5060 REVERSE AND KILL WELL~ POOH~ SET WIRELINE RETAINER~ RIH~ DISPLACE TUBING WITH NITROGEN~ SET RTTS~ RUN WIRELINE AND PERF, PUT WELL ON TEST, REVERSE ASD KILL WELL. ,. ., 2-20 5235 POOH, Mg_KE UP 8-1/2" BIT, RIH, DRILL cEMENT AND RETAINERS TO 5235', POOH, M_gKE UP RTTS, RIH - DRY TEST. 2-21 5'470 DRY TEST #1. POOH, RIH WITH BIT #19, DRILL CEMENT AND RETAINER TO 5470', CIRCULATE, POOH, RIH WiTH RTTS TOOL ON TUBING. DRY TEST #2. 2-22 6711 DRY TEST #2. REVERSE CIRCULATE, POOH, RIH WITH BIT #20, DRILL CEMENT AND RETAINERS T~ 6711', POOH, RIH WITH RTTS ON TUBING, DRY TEST ZONE, FILL TUBING, REVERSE CIRCULATE, PREPARE TO POOH LAYING DOWN TUBING. 2-23 684i POOH LAYING DOWN TUBING, RIH WITH BIT #21 ON DRILL PIPE, DRILL OUT CEMENT TO 6841', CIRCULATE HOLE, SPOT PERF PILL, POOH, RIG UP GO, BEGIN PERF RUNS. 2-24 6841 FINISH pERFORATING, RIH WITH CASING SCRAPER, CIRCULATE, POOH, SET PERMANENT PACKER, RIH, TEST PACKER, POOH LAYING DOWN DRILL PIPE, RIG UP AND BEGIN RUNNING DUAL STRING COMPLETION TUBING. 2-25 ~.841 FINISH RUNNING. TUBING~ TEST SHORT STRING~ SET ~ACKER~ CHANGE RAMS. 2-26 6841 DISPLACE AI~ULUS WITH PACKER FLUID, 'PUT WELL ON TEST, BEGIN STAGING MUD PRODUCTS BACK TO STOCK POINT. , , ,, , ! . , Idilchem , THRAPP / J. OGLESBEE ALASKA Technical Representative, District ..... Page 4 of T3D-$D-I/?I HUGHES BIT ~ PRINTED IN U.S,A. SHEET OF FILE NUMBER -- JOINTS Z. O.D. J Jz. ~S~K ~CUM WT. VERT PUMP S P M. MUD DULL. COND. FORMATIOh DO NOT USE JET DEPTH FEET HOURS TOOL FTHR DRLG. 1000 R P M DEV. PRESS NO. SIZE MAKE TYPE 32ND IN SERIAL OUT CALL DATEE MI TYPE ~ H~. L~. 1 2 WT. VIS. W.L. T B G OTHER, REMARKS ~,, ,, 't HTC *OB-t. BIT CONDITIO CODE: RP- REPAIRED RR-RERUN ORIGINAL- RF.G!ON OFFICE ,,. PR'"TE~ ,. U.S.A. ~ ~ HUGHES BIT RECORD (j~ TOOL JOINTS & TYPE I. 2. SALI DO NOT USE Mir TYPE SERIAL DEPTH OUT LINER COUNTy OPERATOR SHEET TOTAL DRAWWo[ MUD DULL. COND. FILE NUMBEI FORMATi CALL DA1 REMARK HTC 305-L BIT CONDITION CODE: RP- REPAIRED RR-RERUN ADDENDUM TO COMPLETION REPORT (26)Perf'd .& Sqz'd f/3784-3786' ~ 4/HPF w/475 sxs cl "G" 4278-4280' ~ 4/HPF w/480 sxs cl "G" 5110-5112' ~ 4/HPF w/720 sxs cl "G" 5201-5204' ~ 4/HPFx. 5215-5221' ~ 4/HPF---~w/241 sxs cl "G" 5280-5291' ~ 4/HPF~ 5291-5301' ~ 4/HPF~w/216 sxs cl "G" 5286-5301' ~ 8/HPF' (30) DST'S CONDUCTED DST # 1 2 3 4 ZONE DEPTH Lo Beluga ¢~6-6706'' L, Beluga 6788-68&0' U. Beluga 5520-5545' U. Beluga 5280-5301' 5201-520~' 5215-5221' U. Beluga 5201-520~' 5215-5221' U. Beluga 5280-5301' U. Beluga 5112-5129' B-3 (Pool 5.1) ~21~-~275' COMMENTS Wet - non-productive 0.61MMCFPD - dry gas 2.31MMCFPD - dry gas Wet - non-productive Wet - non-productive Wet - non-productive Trace gas - wet Trace gas - wet 0.01MMCFPD - wet 0.60 MMCFPD - dry gas Tested 4.12 MMCFPD - dry gas. (Only bottom 10' of total pay perforated for DST). RECEIVED IAF: 2 0 1 985 Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, WELL NAME 'AND NI~R and Materials to be received by: Reports Date Required Date Received Remarks Completion Report Well History ~ Samples ,, /Ya-.Pl , ~u~ ~o~ ~~~1 , Registered Survey Plat ~ ~ a --/~ "~~ ~ ~, Inclination Survey ~ .... ~ ~~/- ~ "6~ ~ , ........ Digitized Data ye~, Union Oil and Gas Division' Western Region Union Oil Company o, California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union March 10, 198~ Mr. Chat Chatterton Ak Oil and Gas Conservation Commission 3001Rorcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: MONTHLY REPORTS Attached are Monthly Reports for KBU 23X-6, and G-29 for you information and file. If you have any questions, please feel free to contact me at the telephone number listed above. LOC/tj Attachments Very truly yours, Lawrence 0. Cutting ENVIRONMENTAL SPECIALIST RECEIVED I,.: ~ [ ,- '"~ "; ~-..~; Cons. Commission · -: ' .--, STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CC~, ./IlsSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 84-109 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 5o-133-20371 9. Unit or Lease Name Kenai Beluga Unit 4. Location of Well at surface 291' N & 1208' E of SW Cot, Sec. 6, T4N, RllW, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Pad 66' MSL I A-028142 10. Well No. KBU 23X-6 11. Field and Pool Kenai Gas Field For the Month of ~, ....... 19 o~ Feu- uo~- y ',-,-,' 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Released Rlg ~ 2030 Hrs. 02/28/85 EOM= 6841' RET/6950' TD 13. Casing or liner ru.n and quantities of cement, results of pressure tests NONE 14. Coring resume and brief description NONE 15. Logs run and depth where run ,ECEIVED NONE Alaska 0il & [;as Cons. Commission Anchorage 6. DST data, perforating data, shows of H2S, miscellaneous data Per¢'d ¢/6798-6801' ~ 4/HPF 5112-5129' ® 4/HPF 4214-4275! ~ 4/HPF Per¢'d U. Beluga f/5530-5545' ® 4/HPF 5520-5530' ~ 4/HPF Perf'd & Sqz'd f/6696-6706' ® 4/HPF w/200 sxs cl "G' 5280-5301' ® 4/HRF w/216 sxs el "G' 5201-5221' ® 4/HRF w/241 sxs cl "G' Rerf'd & Rsqz'd f/SllO-Sll2' ® 4/HRF w/230 sxs cl "G' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED Lawrence O. Cutting TITLE ENVIRONMENTAL SPECIALIST DATE 03-08-85 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed· ~,, ln~na Submit in duplicate Union Oil and Gas Di~on: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union February 11, 1985 Mr. C.V. Chatterton AK. Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Dear Mr. Chatterton: SUNDRY NOTICE KBU 23X-6 Attached is a Sundry Notice Subsequent showing the correct coordinates for KBU 23X-6, Kenai Beluga Unit and a copy of the Land Survey for your informaton and file. If you have any questions, please do not hesitate to contact me at the telephone number listed above. Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST LOC/tj Attachment cc: Partners RECEIVED 1 4 1985 A{aska Oil & Gas Cons. Oommission Anchorage · ~' STATE OF ALASKA ALASKA U~L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL J~ COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 84-109 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 133-20371 4. Location of Well 291' N & 1208' E of SW Cor, Sec 6, T4N, RllW, SM 5. Elevation in feet (indicate KB, DF, etc.) Pad 66' MSL 12. 6. Lease Designation and Serial No. A-028142 9. Unit or Lease Name Kenai Beluga Unit 10. Well Number KBU 23X-6 11. Field and Pool Kenai Gas Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This is to correct the coordinates on the Permit to Drill Application. 291' N & 1208' E of the SW Cot, Sec 6, T4N, RllW, SM R ' _CEIVED I 4 985 ^i:~s~a 0~1 & 6~.s Cons. Commission Anchorage 14. I hereby ~t~:r~and Signed Lawrence 0. Cuttzng The space below for Commission use correct to the best of my knowledge. Title ENVIRONMENTAL SPECIALIST Date 01-11-85 Conditions of Approval, if any: Approved by. By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate -- .... 1208' ' wc BASE LINE N89°55'OS°'E $56.17 REFERENCE BEARING Set lath on sign post at pad entrance N68°52'If"W 554.55 K.B.U. 25X -6 ' 'l/X= Y= 2~56~357.646 SW Corner Section 6 LEGEND and NOTES ~ Found GLO brass cop monument SC.~L¢ I" = $00' o Found !/2" x 24" rebar All bearings refer to the west line of Section 6 os being North. Top of well cellar elevation is 76.8 feet above M LLW of Cook Inlet or 65.7 feet above Mean See Level. Basis of coordinates is USC [t GS Tri Station AUDR¥ in ASP Zone 4. A AUDRY Lat. 60o$0'50.559" N Long. 15 I°16'37.445"W X = 269,866.75 Y = 2,582,045.45 K.B.U. 23X -6 PREPARED FOR UNION OIL COMPANY OF CALIFORNIA . OPERATOR SURFACE LOCATION: 291 feet North and 1208 feet East from the SW corner of Section 6, T4Nt RIIW, S.M., A I osko. Surveyed by, McLANE and ASSOCIATES, INC. Dote of Survey: 01/I2/85 · I I i I · I II R.F_CEIVED ~:'[!~:~) I ~ 1985. AlasKa Oil a 6,:.~.$ (;uny. CorrlmJssio] ~.nchorag,s Book No. 81 - 32 · I Union Oil and Gas 'sion: Western Region. Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union February 9, 1985 Mr. Chat Chatterton Ak Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr, Chatterton: MONTHLY REPORTS Attached are Monthly Reports for KBU 23X-6, and G-29 for you information and file. If you have any questions, please feel free to contact me at the telephone number listed above. LOC/tj At[achments Very truly yours, Lawrence O. Cutting ENVZRONMENTAL SPECZALIST RECEIVED F E t'~ 1 2 ]985 Alaska 0il & 6as Cons. commission Anchorage STATE OF ALASKA ~ ALASKA L ._ AND GAS CONSERVATION CO~v, MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 84-109 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99.502 50- 133-20371 4. Location of Well at surface 291'N & 1208'E of SW Cot, Sec. 6, TAN, RllW, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Pad 66' MSLI A-028142 9. Unit or Lease Name Kena~ Beluga Unit 10. Well No. KBU 23X-6 11. Field and Pool Kenai Gas, Field For the Month of January ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, rem~irks Commenced Operations 01-08-85. Spud well on 01-10-85 ¢ 0230 Hrs. EOM=3763' RET/6950' TD 13. Casing or liner rgn and quantities of cement, results of pressure tests Drove 20" to 126ft. Ran 9 5/8" 47# N-8O to 6950' TD. Ran 13 3/8" K-55, 61# Butt to 2532' w/1870 sxs cl "G" - Tested to 2500 psi - OK. 14. Coring resume and brief description Shot 36 Sidewall cores - recovered 14 15. Logs run and depth where run CBL/GR/VDL/CCL f/6861-2200' FDL/CNL f/6950' to 13 3/8" Shoe DIL/GR/SR f/6950 to 13 3/8" Shoe Sonio/VDL/GR f/6920' to 13 3/8" Shoe Gyros f/6861' - Surface. 6. DST data, perforating data, shows of H2S, miscellaneous data Perf'd & Sqz'd f/5110-5112' w/4HPF w/490 sxs cl "G" 4278-4280' w/4HRF w/480 sxs el "G" 3784-3786' w/AHPF w/475 sxs el "G" RECEIVED 2 ]985 Alaska Oil & Gas Cons. Corr~mission Anchorage 17. I hereby certify that the fo~Lregoing is true and correct to the best of my knowledge. SIGNED Lawrence O. Cutting TITLE ENVIRONMENTAL SPECIALIST DATE 02-08-85 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Union Oil and Gas £ ¢ion' Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union January 22, 1985 Hr. Chat Chatterton Alaska Oil and Gas Conservaion Commission 3001Rorcupine Drive Anchorage, Alaska 99501 SUNDRY NOTICE KBU 23X-6 Dear Mr. Chatterton: Attached for your approval is a Sundry Notice of intention to change plans for KBU 23X-6, Kenai Gas Field Rlease return the approved Sundry Notice to the undersigned. LOC/ti Attachments Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST ! ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 84-109 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 5o_133-20371 4. Location of Well +362' N & 1124' E of SW Cot, Sec 6, TAN, RllW, SM 5. Elevation in feet (indicate KB, DF, etc.) Pad 66' MSL 6. Lease Designation and Serial No. A-028142 9. Unit or Lease Name Kenai Beluga Unit 10. Well Number KBU 23X-6 11. Field and Pool Kenai Gas Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans ~ Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10;407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). CHANGE OF PLANS Union wishes to sidewall core KBU 23X-6 within the Beluga and Sterling Formations. The cores will be taken during the logging runs and it is not known at this time how many cores will be taken. RECEIVED ., Alaska Oil & Gas Cons. Commission Anchorage 14.1 hereby~ t~o, reg~ Signed L~wrence 0, Cutting The space below for commission use correct to the best of my knowledge. Title ENVIRONNENTAL SPECIALIST Date 01/22/85 Conditions of Approval, if any: Approved by ItRIG;HAI. SIG~IED BT LOHHIE C. SMITH A~proved C o~p"/ ~eturned(~-'5 By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Union Oil and Ga~-~"~ivi°~on: Western Region Union Oil Company of balifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unl, n August l, 1984 J. R. Callender District Drilling Superintendent Alaska District Hr. Hike Hinder AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Hr. Hinder: Per-your telephone conversation with Paul Spiro on Ouly 31, 1984, please note the following ammendments to our Permit to Drill for KTU #13-5: 4.) Surface Location: 154'S & 794'W of NE Corner, Section 7 19.) Kick off point: 450' At the surface, this well will be 70'N of #43-6X, 90' N45°W of #43-6;' llO' N2OOW of KDU #4 and 170' N45°W of #43-6A. Following kick-off, at 1350' VD this proposed well will pass 350' below #43-6 and at 2700' VD this well will pass 800' below #43-6A. No wells will be crossed closer than 200' away. Please also make the following ammendments to our Permit to Drill for KBU #23X-6: 4.) Surface Location: 362'N & l124'E of SW Corner Sec 18.) Approximate spud date: October 20, 1984 19.) Kick off point: 500' At th~urfac~, KBU #23X-6 will be~72' from #14X-6, 100' from #21-7, 187' from KU~-~I~' from KDU #1, and 2~0' from KU #31-7. Following kick-off, this ' raril turned off course to the north to avoid intersecting we' be tempo Y - , at 1050' VD. At 1575' VD i~ich will be passed approxzmately 35 away ~l will also cross 400' below KU Should you have further questions concerning the drilling of these wells, please feel free to contact Hr. Paul Spiro or myself at the letterhead address. ~.~.-S~ncerely, oc: L. Cutting B. ~de~son AUG 0 ~s~ Oil & Gas ConS. Com~Ssi°n Anchorage August 9, 1984 Mr. Robert T, Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502-0247 Kenai Beluga Unit KBU 23X-6 Union 0tl Company of California Permit No. 84-109 Sur. Loc. 362'N, 1124'E of SW cr Sec. 6, T4N, RllW, SM. Btmhole Loc. 2300'N, 1970'E of SW ct, Sec. 6, T4N, RllW, SM. Dear Mr. Anderson: Enclosed-is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is reauired as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Mmny rivers in Alaska and their drainage systems have been ~classifted as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS." 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operstions you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska A~inistrative Code, Chapter 70) and by the Federal Water Pollutmon Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Kenai Beluga Unit KBU 23X-6 _2-¸ August 9, 1984 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. VegM--~truly yo~urs, _ / . ) / .'"~ .' C, V, Chatterton Chairman of Alaska Oil amd Gas Conservation Commission BY O~ER OF THE COMMISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. VENT (to crown of Derrick or to Flare Pit) BUBBLE TANK OR HOME MADE DEGASSER LP VALVE AUXILIARY CHOKE Targeted Turn 2" '" CAMERON TYPE "F", 2" VALVES (or equivalent I ,<, LP VALVES %,~.~ ' ~~ POSITIVE ~ U--~J CHOKE ,J___g ADJ. J i% !~CAMERON TYpEL~CHOKE "% /..~.... '~ ~ "F", 2" VALVES /~. rarge, ted~b~ (or eq,u_ivalent) 4" .Targeted Turn 11 CAMERON TYPE "F" 4." VALVES (or equivalent) Targeted Turn RECEIVED J U L -~ 0 1984 NOTE: Alaska 0il & Gas Cons. 6ommission Anchorage ENTIRE ASSEMBLY IS 5,000psi W.P. MINIMUM UPSTREAM OF CHOKES KENA I GA S FIELD MINIMUM STANDARD CHOKE MANIFOLD ASSEMBLY UN!ON OiL COMPAN"F :DF CA. LiFCPNIA, :. :-- -:, ~- ..-, BAW -' , ,. NONE ':. - JUNE, 1984 Union Oil and Gas r -~sion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager 984 Mr. Chat Chatterton Ak. 0il & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Chatterton: KENAI SOLDOTNA AREA State of Alaska Kenai Gas Field Kenai Unit, KBU #23X-6 and KTU #13-5 A-028142 ... Enclosed for your approval are three (3) fully executed copies each of the above captioned Permits to Drill KBU #23X-6 and KBU #13-5. Also enclosed is our Check No. 19302 in the amount of $200.00 to cover the required filing fees for both permits. Upon approval of same, we would appreciate copies so that we may complete our files. Very truly yours, sk Enclosures cc: O. R. Callender M. Lowman-Marathon A. Lannin-O & G, Pasadena RECEIVED J U L 1 0 1984 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA Ore-%ND GAS CONSERVATION CO~"'-'--ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS ~ SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE ~i~ 2. Name of operator UNION OIL COMPANY OF CALIFORNIA 3. Address P. 0. BOX 6247, ANCHORAGE, AK 99502 4. Location of well at surface ~. ' I1;~ ' +_--4'5~'N & + At top of proposed producing interval + 1540'N & + 1510'E At total depth 'l- 2300'N--& + 1970'E -- - *.SC~_ Cor,Sec. 6,T4N,R11W,SM 5. Elevation in feet (indicate KB, DF etc.) t9. Unit or lease name KENAI BELUGA UNIT 10, Well number KBU 23x-6 11. Field and pool "KENAI GAS FIELD i 6. Lease designation and serial no. A-028142 / National Fire Insurance Co. of Amount $200,000 15. Distance to nearest drilling or completed well -t- ]300 feet 18. Approxim-~te spud date ]~bg0 psig@ Surface 1900 psig@ 6370 ft. TD{TVD) Pad 66' MSL .12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/or numbeq-lartford B5534278 13. Distance and direction from nearest town 14. Distance to nearest property or lease line South + 6 re,es + 1970 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease + 7800MD & I 7400 TVD feet 2560 19. If deviated (.see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT +~ feet. MAXIMUM HOLE ANGLE 22 ol (see 20 AAC 25.035 (c) (2) SIZE Proposed Casing, Liner and Cementing Program CASING AND LINER SE'I-FING DEPTH · Grade MD TOP TVD MD BOTTOM TVD H-40 fl ~ 0 ~nn I,+lOO' K-55 0 ~ '~2400 , o N-80 0 ·' 0 F6768 1+-6370 I '- F- l I I ~ I I Hole Casing Weight i Drive 20" 94# ~7 1/2 13 3/8" 61# '12 1/4'1 9 5/8" 47#' 22. Describe proposed program: Coupling I Length Plain I +1 ~313 Butt. ~2bO0 Butt. +6768 PROCEDURE: 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. Move in and rig up on pad 14-6 Drive 20" to +100' and install diverter. Drill 17 1/2"-directional hole to +2500' MD. Run and cement 13 3/8" casing @ +2500' MD. Install and test BOPE to 3000psi~ Drill 12 1/4" directional hole to +_6768' MD. Run logs. Run and cement 9 5/8" casing @ +_6768' MD. Test the Middle and Upper Beluga zones. Complete well as a dual Sterling/Beluga producer. that~ owledge 23. I hereby certify ue SIGNED ITLE District Land Manager The space below for Commission use QUANTITY OF CEMENT (include stage data) Driven 2260 sxs 2838 sxs RECEIVED J lJ L 1 0 i984 Aiaska Oil & Gas Cons. Commissi Anchorage CONDITIONS OF APPROVAL Samples required Mud log required Permit number I Approval date I 84~.!-~9 /,_2-"-'1 ,-~ 0~/0,9/84 APPROVEDB/ /~/ ~~ Form 10~O1 Directional Survey required I APl number ~s [:]NO I 50- ]:33-20371 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER by order of the Commission DATE August 9, 1984 ~ _ , Submit in triplicate Rev. 7-1-80 Ill. WELL CASING STRING CASING AND TUBING DESIGN BOROUGH STATE DATE DESIGN BY 1. MUD WT. I 2. #/q. HYD GR. I psi/ft. MUD WT. II #/q. HYD. GR. II psi/ft. M.S.P. psi. WEIGHT TENSION MINIMUM COLLAPSE COLLAPSE INTERNAL W/ BF -top of STRENGTH PRESS. ~ RESIST. BURST , MINIMUM INTERVAL ' DESCRIPTION W/O BFb< section TENSION bottom tension PRESSURE YIELD CASING SIZE Bottom Top LENGTH Wt. Grade Thread lbs lbs 1000 lbs TDF psi psi CDF psi , psi ~ ~" ~Z~O~ ~ ~Z~O' M7~ r~:~' ~=.~ Opens AutoHydraulic Valve automatically when diverter closes TWO 6" BUTTERFLY TIED TOGETHER SO IS AL WAYS OPEN ICL 0 SED. VALVES A S ONE AND ONE NOTE: TWO DIFFERENT DIRECTIONS OF DIVERSION ~kECEIVED JUl. 1 019g~ 'qlaska Oil &~Gas Cons. Commission '~nchorage KENA I GA S FIELD 2,000psi DIVERTER ASSEMBLY UNION OIL COMP,',NY OF C~LIFORN~A _' .: ._-.. -.~ ~, · ..'.'. BAW · r NONE '.." JUNE. 1984 ANGLED FILL UP LINE ~ HYDRIL 13 5/8" 5000psi BLIND RAMS 13 5/8" 5000psi Double PIPE RAMS (5") HYDRAULIC OPERATED VALVE / CHECK VALVE · FROM KILL PUMP GATE OR LO-TORQUE GATE VALVE GA TE OR LO-TORQUE TO CHOKE MANIFOLD GATE VALVE REQUIRED PIPE RAMS 13 5/8" 5000psi Single CONTRACTOR PROVIDED UNION OIL PROVIDED RECEIVED J U L 1 0 1984 Alaska Oil & Gas Cons. Commission Anchorage KENA I GA S FIELD B.O.P.E. STACK FOR DRILLING 121/4" UNION OIL COMPANY OF CALIFORNIA HOLE . ,'. ', BAW .. · . ' NONE -..'- JUNE 1984 VENT (to crown of Derrick or to Flare Pit) BUBBLE TANK OR HOME MADE DEGASSER LP VALVE AUXILIARY CHOKE Targeted Turn 2" CAMERON TYPE "F", 2" VALVES (or equivalent) 11 LP VALVES POSITIVE CHOKE '~'-*T~rgete CAMERON TYPE 4" VALVES (or equivalent) 11 CAMERON TYPE "F", 2" VALVES (or equivalent) "F ' Targeted ~ADJ. CHOKE Targeted Turn Tu r,~ R £ C £ I V ~,~ D J IJ L 1 01984 Alaska OjJ & Gas Cons. Cornrnissio~l Ancllorage NOTE: ENTIRE ASSEMBLY IS 5,000psi W.P'~ MINIMUM UPSTREAM OF CHOKES KENA ! GA S FIELD MINIMUM STANDARD CHOKE MANIFOLD ASSEMBLY UNION OIL CC,~,I;~A,NY OF CALIFCRNIA ...., BAW .-' ... 'NONE .-.. JUNE, 1984 SUMP I 18 PAD LIMITS : V -O. 50 0 VERTICAL SECTION UNION OIL COMPANY OF CALIFORNIA KBU 29X-8 RADIUS OF CURVATURE SINGLE SHOT SURVEY SCALE: 1 inch: 1000 Feet DRAWN: 2-18-84 R E Ei Departure ( ~ x tam ) ,( Nobis: Ail values in ~eet, Depths shown are TVD. Closure: 2169 ft ot N 30 de§ 57 min E Bottom hol~ TVD 6370 TMD 6763 Mosnettc d~clination: 24 deg E HORIZONTAL VIEW UNION OIL COMPANY OF CALIFORNIA KBU 23X-8 RADIUS OF CURVATURE SINGLE SHOT SURVEY SCALE: 1 inch: 500 ~eet DRAWN: 2-1§-84 i i i ''I I i lion 'WELL KBU ,'~'~- X- 6 (Proposed ~ompletion ) SURFACE CASING DUAL PACKER INTERMEDIATE CASING TUBING STRINGS TOP of B-4SAND AT = __. 3970'VD,-I'- 4194'MD. SINGLE PACKER SLIDING SLEEVE TOP of UPPER BELUGA AT: '-I- 4670'VD, -t- 4944' MD SINGLE PACKER RECEIVED .! U L 1 01984 Alaska Oil & Gas Cons. Commission Anchorage T.D.-I- 6370~V.D., -/-_ 6768fM.D. CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc (21 thru 24) 1. Is the permit fee attached ......................................... 2. Is well to be.located in a defined pool ................. 3. Is well located proper distance from property llne .]i~.~...]~..1 4. Is well located proper distance from other wells ................... 5. Is sufficient undedicated acreage available in this pool ........... 6. Is well to be deviated and is well bore plat included .............. 7. Is operator the only affected party , ............................... 8. Can permit be approved before ten-day wait ......................... J 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO REMARKS Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... ~ Is administrative approval needed ~ Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... ~ Are necessary diagrams of .diverter and BOP eqdipmentattached ....... ~ Does BOPE have sufficient pressure rating - Test to ~~ psig ..~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. ~f Additional requirements mdd~t~on'al' ' Remarks: ~~'~. Geology: Engi.n~ e ring: K rcs WVA ~ JKT'~.,~--HJH~ rev: 12/08/83 6. CKLT INITIAL GEO. UNIT O~/0F'F POOL CLASS STATUS AREA NO. SHORE , , , qv ~ ~ ~ O.e.,~ ~. '~ ,.~ ~ L,~ .i'7 t % ~ ~ ~ o ~z Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. LIBRARY TAPE CURVE SPECIFICATIONS Company Union Oil of California Well KBU - 23X6 Field Kenai Gas Field County, State Kenai Alaska Date 2/7/85 Curve Name (Abbrev.) CN GR GR4 DENP DEN SP SP4 AC CORR RFOC Standard Curve Name Compensated Neutron~ Gamma Ray Ga~na Ray Density P6rosity Density Spontaneous Potential Spontaneous Potentail Acoustic Correction Resistivity Focused RILM Resistivity Medium RILD Resistivity Deep . Logs Used CNCDL BHC/CNCDL/DIFL BHC/CNCDL/DIFL Scale CNCDL CDL DiFL BHC BHC/AC CDL DIFL DIFL DIFL 60-0 0-100 0-100 60-0 2-3 150-50 -.5 .5 .2-2000 .2-2000 .2-2000 i,~i',."? t 1..1985 ~lask~ Oil &,,S~, Ooas. Comrnissio, I':: :;-.,¡,\) '11 ., ~. I, '")2Y- / 0 'ì {"".- t .~ = IT'" T ::;; Q ~? ''"'I ....' '-'\. "'-¡J.. J... . ./t? ~'_~K~ ""' -, ,- 0- !%;;~r .'~ ç_C NJ!~~i} ~ p --_£1.t.?-.!-9_~___....__....._.._-_.._. .._.... "--,,,-,""'-.-..-.-.--- .. """"''''''''''''''' .....---..---.." .............""" ...... ...-.. . ..-...--.. .... ........ ... .................. ''''''''''",--,,,,,,,,,-,,,,,,,,,,,,--,,,--,,--, ~IO~~IL ¿Q;ÕF ~IFQE~_~=~'~~~-~~===~~--_..__......_---------_.._-_._...._.........~ 5NAI GAS ~I~lC KENAI ALASK~ L_.----._---_.....".....~,_..._--~,. -_.~=--====.~==.~=-~=-~-=.~~:=:~===.=.==:~===~--_..._..- ..._._----_.........._._._._-_._.._-~_._._....... _._...--..__._......._~=~~~-==~== ~ CUR V E.$ ,;': _.__.__._._-----~~-_.._._._----~_...._-_....--... .. ...._...... ............._.. """.'''-'''''''''''''''''' ..-........ .....-...--.."'''''''''-''-''''''''''''''-''--''''''''' -"---'''----'''''''''.....-.........-.........-........--........-.---.-- MLL CAL3 GR3 CN GR4 CAL5 JENP S~ G~ RFJ: Jih}'" R!~:;. 0 EN" COR B_~~_~...--_...:?£_~..__.._...._....._.._..__....... ..........-...........--...-........."-'- --.-.-.....-..-...-................' ....-........ '-"'-"""--"'- '-..... -_.......... n.......--.........--...........-."""""",,,,,,,, '''''' ...... ..........-............-..- -------'''''''..._--~_ø_._~..__._._._-----''''''',',','''',-"----"'.-"-"'¥ -....-----.... .~~ .' . __A_...a_..._.._----.....---. ,...-. ......"..._.a_._.._"...__...a......._...--....-.-.._.....a.._.- '~a., ...... ..... ..-..... ...........h..._.~ _.~-~_.._........__.....__..._......_._.....a... .~. ~a"'",._, ._.. .._~...._....~....~a........."..--.... . .., n~.... ...n ..,. ... . -....... .......' a... .... . ......"" ..,.. .... .-... .-. ... ..~.....~, ...a ....... ~ .~.. .....~......_....." ....~., ._~. .. ~.........._a. ._~ """""",~,,,._- :~.,O F-1- ? 4 'J Õ. 0.0 TO. ..Z_9jl~.!-Q.[==~:==~~~=~~~~~.~:.'~=:=~.~-'=~=~===:'=~=~.''::"=~'::::':"~'~.::"-':'~:.=.~~~':~'~.~"~~~:--...'.'~::.=::~'~':.~~~~:~:"'=:~:~.'~::.:.:"..==~~'=.'-=:':~ ~l~-~~~~.~Uit~~~~~-==~Ð~ -'-"~._-'---'---"-"-'-'----"--"-'-""-"-"."'."."""""..........,,~..........................._..............,. """"""""'~""'''.' .....,... """"".."",."".,-,"~."'."",,,.,,,, .-... -............"..,......-............. -...-.. .........~..,........ .,... "....""..". ..... .................. ""'" "~'" .. ... ".".,,,.,,,,,,,,""-'..'"'''' Z'!' .' ..'. . .' . . ..:..::.....:-_..__................._._.~.,..~_...._..~...._.---.._-_._........_"...~.__.,:_......._......._..............._.~._~. '.'" ...~.. ..................,...... ... .............,,' ~. .. ................. .... ... ... ....' . .........' .. .... ......'''' .' ........a.. ... --.----........-..--- .".~... .... ........ ,,,,,..,,. ..... .. .~~...........,......~.~..~.... ..."....... ..""'" ""."", .."'" """,,,,,,,,""" ....... .....,....~ . ... ,. '"'''' ...~, .~.,........,...",..... .....""" -..-.------...---............------,-- . ........,........,. ..~ .." ...... .., "...".. ..._...... ~....~.". .~. ~.._"..........h.."_""""."'''~'''''' .......... ........... ~ ....."-", .....,~ ._. '"'''' . ..... .. ...."" ..,,~.. .. .........",... . ..... ...' ..,.. ..... .'" ~ ...... ....".... ,... ...' .~...... ..... .... .....~, ,... . ...... ....""." .... ... ....... .~.......... .'"''''''''--''''''' . . . ..~.. ..... ...." ,," . . ...,......... ....., ......~. ,._.,..-...."...~.. "M""""'."",,,,,, ""~'~"".'~"'"'' '"'''''''''.'_.'._~..'_.''' ......._..._.~... .....-.... ........ ............ .. ..... . .".. "...~. . ,. ... . :~"""",.{$. :~" ~.:. ....:.., ' > . ~.' ¡"'.~ . . :~, .' t '~" ~., ....".. .........~. ~.. .""" .. ~,. ,....., ..."", ". .......~.... ..~.... . ...... . .......,..,~.._...........~_.., ....... ...-... . .........- ._......_...............~............. --"'''''''-'-''-''-'''''_.''''''''''''-'''-'-*''-''''''Gi:fL}:Ü~.£ë.::.,.~~..~;.;.. :~.~::.;: .:'.: '~.:.:..:,~..'.~:.:.:~.' ':.:.'~.;:.~ ~ ~':;~.'. .':' :.:...: ,~. ::::..:'~.'~,'.~, ..:,.,:\: ~'.~ ",:' ~ '::"": ,...,. . ,., .. . . . . '~".::'_.".~.::'~-'.~'~=~='==:'=~~=;LS'~::::::~:~~.:~;L;~::~.:;:.::.:.::::..::..:..',' <::.;.'.'. ::::.: ~~:~~. .., .;,~~: :::> :::,:,'.';;;.i.:. _.':~:':::::,:::.';... '" ;".,. .. .... ... ...... ."""''''''..:'':.''-'-'''''''' ---'''''''''''-''-''-'''''''''''''-''''''.''''-''''''.''''-''---'''''--''''''--- "",,,,,,,,,,,,,,,,,.,,.,,,,,,",......,,...~........,.....,,,.,...,......,,,...".........~-...~.~........,-"._...,.._-~... ..- ..~..__....... """ ............'.' ......-.."" ....................."....... ...-.. .............."......... ... ..~. ...... .~ . ........ ",'" .. ....... 'A... .... .. . .. "'" . ""'" .""''''''''~'.'''''-''''''._''''''''-''''''-''-''''''-'''--",:""..._-_..__..-....--_........."._.._......."._..._...~................._.._..... ... "" ..... ......~ "'''~.''''''''''''~~'''''~.''''''''-'' "'....-... "-"",,,,,,,,,,,,~.,,,,,,,.,.,,,,,,,,,,,,,-, ._.._,..~....... "W.' '."".",."..... ..",.. ,,,,,,"'" ."'" """""'" .. ...........""....~ -~ .....,.. ..... "W" ... ......."....,~....~,..",......"......~... '-"""" ,"""""""""""., ...... ...... ,-.-"."'" ."............." "'-...-........." ...'~...,...". .... .....~. ... . ..............,....... .._.._.................~~ .... ...... .......--.........-.....-...-....-..........--................,.... '''''. .... ..."..... . " "'~" ,... ~ .~.... .....-. ... ..,... . ..... """ . ..~..~.._"... ........... ..------..----..----- -------------.~_..__._........-..-----_._~-_..--------- . '"~ .. '.w. ... ... .-.............. '''''~' . """-""-""""""" ......w.. ....... . "'~'''''''.......... ....... ... ,,,,,,,,,, . .....' . .. ~ ... " '.~. . _.__......_...,~............._......_.~..,..~_............._,~.._-_......._. ""'."-"-""'-'-"'---"''''-''''~'''''''' ....,,,..............~........,,....,,..._,......,............ '''.'"..". ""."""""'''''''''' """,~,,,,,,,.,,,,,,,,-,,,,,,,,,,,,,,,.,,,.,,,,,,,,,,,.,,,~,,,,, .,..............."....,..... ...." "'"''''''''''''''''''''''''.'''''~'.''' '''''' .~..."....... ,.... , ...". ...~" ..' .,~.. . .'~" ...... . ..", "" ..". ..........,.. .......". .........~.,-,~.."......." """"""~."",.."""",, ..............-.. ..... ....~~" "........,.._.........................~ . . .................. ............_........._....~..- '." _.." .-.... ...._.._.'_n.._.... ~...- .....-.....""-"-....-...... ..... ... ..~....._.."...... ~..... ..,........ .. .. .. ....~ ....,.... . .. . ....w.... ..""'" .w. ~........_.......... "-"--------""""'--------------""-------------'----'-'------------'---..-----............-- ",,,,,,,,,,,,,""'" ... "'''' "",.""""",,,,,,,,,, .'" ....".......... ... ~... - ... ........... .... ......~.... ...~ .. """""'''''''''._''''''''''''''''''-''''''''-'-''-'_..~............-.-...........,,,,,,--,,-,,,,.,,,,.,,,,,,-,,,-~,,,,,,,,,,,,,,,,,,,,,, ""~"''''''''' """""'''''''''''' .......",........... ....., ..... ".' .. "'''''' ... "'"'''' ....." ..... ...". ..."..... ....., """.",,'.'" ....,. .,... .. "...." ..,,".... ." ",,"'"'''''''''' ............"". ".." "''''. .....' '"'''''''''''''''''''''''' """ """" ,..,~..,......" ..... .....~.. ." . "'"'''' "'" ..............,...""..., ""''''''''''''''~ ",.,~.",,,,,,,-,,,,,.""'._'."'...-.,...,_.. ''''~' .. .. .w...... . ......... . .... . .... .."..........-., "''''.''.'''.''' .. ..... ......, .~... . ....."_..,,.~...............-.~._.._,..............~......- -""-''''''''~' --"""""'''' .....,'~ .M ""."-." ....~..,...... ~M ...~...". .,. ..~, ..~,~....~..~,.. """" ... M...~"........, "." .'"'''''''''''''''''.''''''''' ,~" ......~." "~"""'.'''''''''''''''''''' ...,. ... ....... ... ...." .. """ "" ~ "'... .., . "".".... . ".. ....... ....... '. ............ .....,. "... ...".. '.""'''''''' ~.~.~.........., ~..... ........ "..,,'~.~ ..~.""...".. ... ...._.~.....~.. ...... ......... ." . ... -".....,................. ....~ .._.......",.....~~".....".,....... ........... .........--.--...---....-....---.-"..... ......,...__..........,"~" .. .".......~~,......"... .......... .~..."....~.....~......- ............"...,..~.. .'. .. ............_..~ """..'''''''''''''''''~'~'''''''' "'''' .... ~.... . ""'''.'~''''.'' ,..."..,......' ... . ...'.. " ., .." "'"'''' .... .' ~ .,. .~.. .""....... .... .." ..... "~."" .,...~.~... .. .. ."'.............. ..... .,......,... ..... '''.M ~ . ....., ......_-~" ....~.. ,"~M..."......, ...........~ ."..~....................,~.. '''~ . ...." ".."....., ......... .....""'''' ....~.... "'~'" "'''''' ....... ............~.... .............. .. .. ..........~...... """ ...'..h..... """"'."""--".~""-"'"~''.''''''''''-'''-'''-''''' '''''--'''''''''''-'~''''''''.~.''''''''''''''''''''''.'''''''-~'''''''.''''~'''"~""""'''-'''''''''' ""'.".'..."...." "".""'."" .... "... ...... .....~ ... ..."....... .. .,.. .... ~..'" "" .... .." . . .'."''''''''' "'"'''''''''' ...... .. ...~., ... ..~ .. ~"',... ~""'"''' ,.... .... ............. .. "'" . ..' .. ...... . . . ...."...... .. ...... ..........."'" """"'."...... . .....,."........ ...."..... ....,.~ """ ...~... ... """"""'~.~.' ..." ....~ ""'''''''''''''_''~~..."..........,..... .............~.........'_.....__..,..._.... ..-..~...... ,...~_....... "'''''''''' .............."..._'......,~, ~..".. ~ ." . ..... . ..' " ....,..."..~".".~. .. .."......,.. ..,....'" ... .........~ ...,............ ........" ". ". "'.".,..' . ..... ................... ,.." ...... """."'" .. . . ,. .." ... '.. ... ...."'" ......... . . ~.,.... ,.....~.... ... .,.. .... "..... . .~" ".... ,~-","".""'" ,~. . ..... . .. ~.. ... ......' ......... ...." ... ....... """ ..,... ""~"~'''' "'''''''''''''-'' ".....-.. ... ....... ..... "'''' , ,. ........~....... ... ..~.. ........ ...".......... ~.~, "-""-'" ... """'" ",..... ~... ''', "....,........'" ...." ~.....~....," .. ...... "... ... ".... ~.. .... .....".. '"'''~'~''''.''''''''''''' ..... ..... ..... '" .,.-' "". ..... .....",..,.. "....,. ........",..." .. ........ ,. .'.' .......'..".... ... ". ..'. .,....... ....... .... "..~ "......" ."" .. ,..." '''''''''' ..,,".. ... ..... .. .. .~... ..., "..... .. .". .. ......-.........' .............. .......,. ".......,.-,....,.. ..._.~............. .."'" ........ .' ~. " _...__......."...._-_...._.._"_.__.._........_-_.._",-,,._.._,,_..~_.._--_......-..._.._.........,.._.--.._..",~_._.................._...-...-..."........-......__......-...~_...__......._......_....~~_._---_.._.._..,-..._-_....-...__........_--.._.~......__............'--..-..-..-.._~_..-_..ü.....,,----_.__........_......_-,----'-'" .,... '''''''''''''''''' '."""'" ......... .. '''''''''''''''''''''~'''''-''''..'''' ...................~. "....~............",., ..,,~,....,,~.....,.... "...... .",,, .. ..... . .......... .......... ... ,,~......, '." ".."..' ..... .....' .... """" .' . ". " ,...., .. ,.. " ...." . . ._,... ... ... .. .. . .. ........., .."....." ....... ..~. ....... ...... .'.............". . ..... ......"...... ;)A~: 1 DATE: 2/ ?/R5 TIM~: 10:54:34 U~ION O:L CC.O~ CALIFORNIA K8U 23X-6 K~NAI GAS =IELD KENAI ALASKA ~_.__._--~--_.,.__..._---_._"_.._'_....._.._._...,--_....,....--..--..-.,,-..-...----.,,-..-----,-...,.,.,..,--""".''''''''--''''-----..''..-.." 'R"" . "'-""'''--''''--''''''--''''--''--'''''.-'-''-''-''-'-"'-'-"-"-.'--"'----'.-"""-'----'.---'-'--"-' "'....." --- f.'l. ~---_.-- ....-- -------..:...:.-------..-.-......-..... .....-......-.-,-..".-.--.-...-.---.--------...." .......... ""---"'-----' ..-.."'''--' ..........-.. -----"""-'-'''-'' .............. ....__._....... .. ....'-' ..-. ,.. .....- ..-----.....,..' . . ..... "'. ""'''-----''-'- ---..---_..___n._.- >EPTH G~ CN DEN SP~ :~l3 AC CO~R RMll q~OC O~NP ~.t . -----_. AP l' . --_.% '..__._.~_....._nG...~_ç_. .._._....._..._.~:.y_.._,,_._. ._-_.._._._.L~___.._..--.,,-_J.....T_._-_....... ......~..Lç-_._......._...._.9..:.~.~1..- ,,_...... ........ Q .H.~~. .... ....... .... ---_......."._--_.._~---. ........-.._. ~{,\.. .', '. . :,,' '..,..',. ----..'-'-''''-'--'' .-. ..-.....--.-.--.-.--...... --..--..-..--.......---.=..----....-.-....-..--...--.....---......"..--...--.....__....... ..... . ..... .....- ...-. .-..........--. ........._.--_._..._...".._-~==== ----~.. . .--.--.--..- ;<.,' ", ~""'" ,~'::..: :', ~'~,' ", ", . .' .' .. . 2 4 -OÖ-:----'--30-:-29-' 5 4 . 47-'---1"":'-5")' ---"-""5'9--~-86""'-----"-"--Õ-:--OÖ'--"""6~3-~i'5"--~-r'~-'1-2-"--"'-"-õ":'-Õ"Õ-'-"'-''''--''-Ô''~''-9--3''- .. .""6' ¿;':'7'1----"----'-"-"-'------" jf"4 1 0 ~_. 2 9 .~...32 _:,:5 ~4 :~ .!i"I ., .1~.2._?._-=~'Il_--~_Q_._-_.._._Q.~-_9..g-"..._. ..?.2.--!.._4.J._............~. t_~J...?..,,-,.........9--~2. Q. -. ..,... ...... Q..!..'9.t=:..J??._~lJ,_...=~.=== 2 4 2 0 . - 2 9 . C -J 5 4 :- 4 7 .."'" ""--'1 . 5 5 "6'7.'44 0 . 0 C 1 4 7 . 1 6 -1. 1 2 0 . 00 G . 9 7 6 6 . 71 ~~g :4~:TF'~ iJ; ~-~~= .~~'~~-~-----f~:~==tE~F=~fH=:=:l~gð::::=:~-:~F:~~-~f~-=----= ~----- . :-----......-.-------.......--.----....-.-.---.----:----.----..-.......'-.--..--.....-....."'.-. -----.. '-"""""'''---''''''---''--'--'..' ....-.-.....-..........-......-.... '........-.. -...-..-...,-......-..-..--...-, "--'--.---.-.-.----..----...... .........' -..--_.._." 12"450.31'."5'4,',.;'''.''54;.''41' . 1.55 66.95 0.00 69'.17 -1.12 C.OO 0.96. 66..71 lliEtt:lr=1SS1EJI~~~]f=a~ElI:~~:~IE:~=_E~~~~~Ir:::;-~fu~=~:== g480. 29.36 54.47 1.5570.25 0.00 180.?0...1.12 . 0.000.95.66.71 t. 4 ..~.Q~-== '3 .(f:9~'4~~~2K~) . _..=~-~1~~-:~.2~~.::=:~:-'?~-'.~:~~=':'::'.-':::_-'.-'Q_.~~_Q~.i~:.',.~~~,::':;.ß:~~:}I~~~:~~.~'~:j,'.;:.I-'I'~:-'.,'.',:,-':_:::~~,:~.:Q: g"."'''''. .....::~:Q,.;.~'9A':' .'~".".'.:~.~:.'~~:"f.f.::::.:.:::~.','..~:,::~::'~.'-'-'~:.:: 2500. 28.54 55.23 1.55 83.43 13.19 61.84 -1.12 0.23 0.95 66.66 l2JP~; , . ~~-Z ~¡~~{~=-I$~];g:=::_::".~-'-'I':;'.::~:I..,::-':~','?):';:'5?j'.:,'::~:'.:I..$:-:~:'f?"."'-"":~:~9::~~:.?;:':.!'::::'"...'.~~:'j':~"',T"I"-':'::.',.'.-'f~".;"?:'.'~...."".""""":-9:-';":?)~,.:':'--'-5'-}-;-'þ..~~-~'~~".'-":"- .'....'. ":..:~...': fJ__f..Q_~____f2_!... 7 5 _._-._2I!.._Q_§_--_.--.......1_!_~..2..._",._.? ?_~_.?.?--, .........-1., ~Lt!__fJ....._...... .?..4_.~_..?..Q_... ,. .....: ,t.!--Q.?'......__._.."....P......?,.~.. . ..... . _..Q..!. .9,.é._.... ....5...?-..:!..._9...Q..._- ----..........-.....-."-.",,. :i:S:30..' (.,1 ~ 3'2.'. 4:4 ~'.9.7 . . ... '2.09 37.5012.37 13B. 69-::';'.2.3 . 10.52 '.' .9 ~ 36 . 3t... C~........."...,'._._.... H;IS~E~~fíf~I-~£JElr-TH-:~~E:-~~:~g~~~~-~:J}-]EIF~]I~I~::-=:::=~-=~ 25 60 . 35'. 81. 44. 9 2 2 .. 1 3 41 . 4 3. 1 3 .. 36 1 ..39. 4 7 - I) .. 02 5. 36. ..1. ~~ 30. , ,31 ~.6..7. .. . ... , ." 25'7'Ü"'-"'t~:"~"61'''''''''4'(j''-'6'5 '(:'..O~ '~:'."C,~' '''~:'.7::''f3'6.~S ::.:J1' 1j~54' 11.63 ;;~.j+4 ¿S6J.' ¿ci~¿1 4.~.Ø' 2.J5 ~~.'~! 1~.~~ ~3~~.~~ ~.33 ~~~ç ?4~ ~~.:~ ".;'..,'¡ . ,-(' '6'i "'''4'':'Q-'i9'.'.' ...: nQ ¡.,~ "'l. Ai ::;¡' ,'...i",:, 'iÌ'~' ,i 1" 'f. '-','2; 1r~::;7 '.~I ~.:-: ~ ) 'f w' . ...... ., . "" . .t+ t. . -' 1_. ,..I . .;, .... . J .... . :... ...1 . t:. i' .'.., ow v. "I,. .., . .J - , ...1 . ..rI . .,} ... . ..'" .. ) .:. ~'. ,", I ~ "17 "";"'.,. 7 , ,,", 7 ~ Q 7 7,' .1': ,;;' -7 ".'"': -::.. r. .1 "",;- 7 ,"- Q ~ 7.~ ~ -' .) ,- - -: ,J - . ~ . ,. .~ I , " '- .,'~ " .- . .J I .~.. , , .J . ~ t .::J WI' . .,. ~ .- . ._; .- . . 'J . .. ..... ., ..""t.. ...w . ... .. >'~"1'''';'' .. .... '¡'''';;'- '''';:':~''''''''''.-'':;''i'''' I''':''' ... ".~... 1.:. 6 . ".. ~ '1 p. ;., 1 1 2' C' . "'~l' ...... 11 .. '74 .. -, -:" '7 1.,'" ., ~ :.J. .. c:. . , ... " :...' . ~ ',' , ,:. '...' 4 . é. \.J ;> . J .. . 'oJ, J '.J . ~J . \ '<I . -~ .- J ..~. ... t!~€mEi~¡~l~~¡~t~::'~,~i'~~,:"~iI;I!.:;:."j;¡f¡l-;-¡~}t~~:;~:=~:~-= . V',,J oJ . .) -I . '0,4 "'t -' . 76 I. . U ,.~ 71 . --,1 1 '+ . ;.. ":' 1 ~..... t 6 "'<(::.~,;,y l' 8 6 . 1 5 9 . "I '.J .- '+ . , .' ,Jw~. ~...2- 4).~1 ~.1~ ~~.~~ 1~...~ 14w.~7 ~.wW .~J 1~.~.. )~.....~ , ~~~~~~:~-~~~~ ~',~::~.~~.= ". ...~:.~:?,:..=~~~=:'..""~.:~?:::;~:I~~~.'."~::.':?'~g~';";:~'~:'~'~.'~.~:.f?:-;~..?','~.."'.:-"J'4'.{f..-';:?:'4"-~'";':,'''.-:',:Q-:;..:QI:'.'.'.:''':':''.''.'.$':~':~:~''."":'.""~:'~.:.'~"."~':.§-'.'.-":.':.:-:~~.'3'''~~.''~':9.:~.~:..-":"'"~,-=;;'~;~~~~~'''-' t ð ö :.m ... ç;.r. G '3 4 5 ~ '76 2 . 11 4 :;r. :J 0 1 2 . 7 9 1 44 II 71 J . C 1 't. ~ 4 1 4 . .: 4 3 !~ . .;:) 71u.42..36'.4¡?'.'8-5 ¿.12 49.j,¿ 1.).7,) 10-+.5) v.u(j 6.03 ..14.1)~¿..~.~..:, .........'...,.,........,... '7.2"D.:..'.."m:rð"0~"ä6-"'''''j''6-:-'rr'''--''''-''''~f~'"õ:9""""'J"Ö":""5'8'''''''''1'i~''~''6.6'''''1..tf4'''':''3''1''''""-'~Ö'~ Ú ¿. "ó".""'4' ... '1 "'¡~ . ë, ''':5 3.'""?2 .."";---"",,,,.,-,._,,,,,.,_.-,,,,,,,,",,,--,~,,-~,--~,,,,,-,,,--.,,,,,..-"."",-""_---"_,,~,.,,_-_._,.,,,,,'._._''''''''''.'-'' '-''''''''--''''''.'''''''''''''''-'..'''''.'..''.''.'~'''-'-'''''''''-'-''.-.", -'~""'."".'.'."""".' .. ."P""- .". .".. ...,.'",. ","'...._O..O..M"." ,"...."...... ''''''''''.''''''''''-'.'.''''..''.,.,..,.-..,.. .,.""",.""""-,..,,,,,.,,,-,..,,, "".'.' ". ...." ,........,.,,,,,...,,..,,.,,,......,-. .. ,... ,..,.. .".'-0".'."" .,,- ",,,..,. .'..' .. ...,.. .'". ..".. "....-....,.,..,.,."--"..,.....-.....-...-.-,,..-.. ? -30.. '43..,;,3 $, ;-,':.Z 4..~,7t. 2. '4 3 ',.3.33 1 3" 43 81 .. 7 -; 0.01 49 'J. 80 .t. 7 . 84 . 1 3.:4 ~....._..."m'_....._..._...."~'~'" .~t'4'õ'~m. "'''''''4-Ž-:-''8~6-''''''-''--313''':'''4-'8-_.__....m ¿':'1"3''''''''''4'8'';'5'.¿m . "16"'~'Ö 1"'1"'4"3 '~6 á''''':Ö''~'' tf 1""'''''''''''''5'': 62 ... 1'4 . "6'5'" ''''''''3'''1':''''''5''0 . . m:-~+~~:t~~'i~~-...~~rIF~n}f~:n~6FfrET~:':-:::~:::g~:-~:lr~~::~H~fF~TI::IT'--==~= ?~r~-;~~'~:"-'~:~~~~~t~_:~:~:=~.;-~~~~'-r.~~.:-":-~:':~~~.-1-~...";r~""'-.""'''.'?-'.~:.:;.~~~.é:'',.'':~~'r~:~~~r?-.:'-III:;:Ii:?":.-.-'~::'..""'~?"';-'Q:J'''''-'''''''':"';~",¡-'~"?"."-'''''''.2''Q''.;':Iê¡-'',-''''....''4'8'~~:~~:::?':""--'._-...,-:"-'::.~...'::~~=-",' 7¡Sj'.''''4,'.0156.6ö'1.16 76.6016..52 137.07 .... 0.1d3.84 ...8.6'1 41.91........._.. "'-"."-''''''-- 7 9----::'¡-"--'-"""--';::":;":O:'-:"1-."(""'."':'- -'¡'--"-8.""'?-~~"-"'-'._-''';.;--c''.1''-''1'''''-.''''''.-''';1.''::;--..- ""':¡--iii .."._.._" -'1'''''-;-'''' ---:;":"1--""-Ã' '-;';'''¡ :'. ... ';;"-'3"" ...,.. .. ...--... ;.;: "..,.. 'r;" =f' "''''''''---.:'''''--'~ 'q'" ", -. "".""~,- '''''''''1'''''';;''''''''- "...... ;;:';';' "":"9"""0 ... ---"-. .. . '\-'., '....' :..J .'+. ~ ..':~ ." . . '- . f . .. C. >0.) . 0 . U' I.¿' "I' . c; .. U . 0 -, , .. i.! .:,~ 'j. ~::. ,) , ." .' .' 8",(}Ö .~..... """-4'if~'"r"3''''''''' ""4ä~'''6'ä'''''''' "'" m..tm :"'87" .. m. 'i';S- ~ '4" 5' ... .' m1i~'j' ¿ m. 'f 32 ':26'" '. . . 6.m19 '..".. .m .'. ."4'~' '71. .. . "".". .7. :8:3 """ m. ''''47 '~"-Ö'4"""'- ......m""'" "'''-''''''':1 3.... u .. '+ 7. ~3 .... ) u. 6~ ........ c. 11 7 .~.3 0 1 7 .. i. 1 ~ '- . : i v . 1 a :; . t.. 2 ' . ....0 . ~'::... ~,5!... '''''''''''''''''''''''''''-'''--'' h~==}f*~JJ~fc=~t-H::H~-}£ :----H:-lg--}H':]~-- - -þ-:~~-~- .. ..i:-~~-- -:¥-J-t- HJt---- ."""'''-_.''''''''.'~~'''-' .. .... "''''_.'.'.'.'.~~''..' ... ~_..........~.~.... -".¥".."....-........".".".."'.'."-~"'.'."'" .... ".'''..''''''. . .... .,. .,.,...., .......".. . . "'. ....,..., ,... ,.. .. ..~.. . . . . ""'.~""~'" .. ,......"'." '.' .". ,..... ........,......~...... ..'''~''. ..." .' .....-¥......... ..... ..,..... ""'.'''''''' ,..."'"" "........ ,.... ..".,. .".".. .... . ........ ... ...¥" ... ... ...... . ,.. ,."....~. .'" ....... .. ""..". ~.......:-..... "..".- ,. ....,.",,_....... ~~'~".'.. ...... -::..~ ,.....,,~ '"''''.'.''''' ..... .~. . ..... .' ...... ''''''..''.''. ...... ... .....,..¥ ...' ... .. ~... .... ... ..... ... .. ........ ~ ... "'''.¥.'.'.'.''''''''.....' ."'¥.. ......_........,.........,......"...._~.¥...~.........¥....",.... ~'.....' ..,.."._",.,~......~...~ ".'.'....¥.' "". """ .............~ ."..,......., ...........~....'.~...." "......."..' ...... ...... ",.",,,. ....... ".'-" "......" ......." ,.".. '.",. ".." ~ ...... '.'. . . ... .,,, .,.... .. ~ ..... ... .. '.'''.,,, ."'.. ,.' ." "¥".." .., ,'.'. ,...... " ,.".,.,.,. ,... ...... .... -. .,... .. ... ~..,,'" . '." "".'.""""...'" .."..",.. . ..~. ..... ... . .~"..... "".." ..........,-.......,,¥ .' '..'. ",.,.~",,,,,,,.,,,,,,.._.,,,,.,,,,, ".'." .. "'~'. ....."".' '." . .""" . ..._..,...~..~ .. ..... ..........~~............ "'-~'''''' CAGE 2 DATE: 2/ 9/35 TIME: 10:54:34 UNION OIL CO.O~ CALI~ORNIA K3U 23X-6 K:NAI GAS ~IELD KENAI ALASKA -.-,.-...-------.--.-..------.. ~.~~' r~ '? T~ G ~~-~---~' 'C¡;i---"--i)~'-N----"-""---""S'?"4---'------'-ë "j),ï:"f--"-"'A-C'''-'-----''''C--Ö-~'q-''-'-''''-R M'L""C'--"" """R"¡: '6("--'''''':'''''''-''----'--Ô ¡: -N p .- -,--- fI, ~ ' ,A Pi I', ,,)!: ",--~,,-,",-~~s....._--_..~:l~-\¡ .._.._._----_.~.j~'4 - "lC-~~....___~LÇ..._,_=~.=~:~_.tj--~......"'-'''--'-''-'.o ~,tL.._..,___.._...:-_--_..~."...":L-~- ~1~':, . ---~' ,'::.. ,::..~;:" :' :,;:.,'::,':~;",},::; '}"", -~--,-,,,---"'---'-----'-----"'-"---'--"-'---_.-'---'" -..,.",..'''---''-'''--------------------------- 2 3 e D ~,::': ,i\>Z~v::'::6:~,'¡i;;' 'E';\~':"'i;"¡;' ,.' .:~: '2~-1 C---.- 6 4'-:Š-;5'----~-f¡;-~--::i-¿-133:"~ ~ --, 0 --;: :) 4 ----"'''-;':-'fT-'''''''''----ç--: "6-Š'-""""-:ff;?"7---'.'-"--"~'-" 1J9 0,.. ' ~ $ ,5,:.~",1;,1' ,,' 61,';~i5""2, ,'.:.. ~~.=:LJ..1_=r~~~? ~.~[4~~tQ_._1.1 ~]J?~~~~:~~:'Q~~~~~~~=~~~::~~::::~.=~:::1ï:=':='~~:?:~~?Þ=,~:~=~4.=(~~~£:=~~:=====,= 2900. 45.65 50.02 2,11 77.65 14.83 136.61 0.09 5,57 7.48 32.90 19'10.: .",.-$:'~:;'2'~:-'/"'~5~t"~,' ,"2'~'1C: '73~17 14.83' 128.'52 0.04 5.39 ,: 7.67 33~34 m1:-~k..~.;...-2~~: ~;~~Il[_~[}-rJIIiJH:fE~~2I=~jJj~~t~}--~IE~E~= 2940. 52.40 59.11 2.10 78.85 15.05 124.83 0,02 5.21 6.34 33,03 ,");''"\-'0' ¡'O":!O"", :J~'¡.:"'C7: '.., 00 7., 6 " '.14' 5,' 124 1. 0 ""':-- .. 71 7 /':'4 "OJ 77' ~',.." ,. "'toii;;':'.J,,",', ';"~,~"j ';!,L;i", " C:::'... c ,'¡". b '. ,0 , .,: . Ò, './. U, J," ,',1) )... ~, 2960:-'--"- 5 2 . 6 2 ~-'48:5-:f-"-''''''~r:-Õ-4--'''--f3--~-Õ-'r----''T;r:-'98-'-"'f2~:f:-'9'1"-""'"'' """ Ò':-T'9'-'"'.'''''''''.'''5-'~'''9'B''''''''--..'-''i'~-'á6''' "'''37'':'-1'7 ..,.... ,,'.. '---"-"-..,-..".....- ~1~~~=- ,4 7~.:" ~ Y;.~4' '1':"'6 9, --~-~-~,,~..i"J~3'~~==~I~;,:,4.j~~:.:~~.:I:-~~:~?~~,,::~I]~~:~4~:~:,::=~~::::: 'Q,'~j~ï~:::,,~':::::',~?._~~é'ß,',::::~".....:j~_:'~:~?~~~". ~.:.:~~t:',;:~~:1':~:':~:',:'::.,,':.~':,::~::~~~:~' ~980. 50.90 43.21 2.12 71.60 13.88 120.67 0.05 6.31 8.03 31.94 ti 9 O~~~==~ 4',1',,~ ~ 'L:~:~:' A ~~,;~:~::,~::,;:?~;:I:g,",'~:,':-:,'::,~9~:~,:~~~':,.'..",,:::::':':j'~4_',~~'~~f!"."..,:':t~Æ:..;':..:~"~,~~:'..,:':-,'-'-'.::Q':'~':Q::~:,:'~',':":,':"':,-~"."~'"~,':~'~"',,'-:"":fj:";'"9''Q'''''':''''-''''~-~~..~~j'''?,,"',.,:'''''''' "":",:~"'''''''-''''':':,..,: 3 0 0 0 . 4 7. 1 3 43 . 7 3 2 . 1 0 ~ t.4 4 -...J~ 1 91 3 ~-!l..L._.. O. 12.1 5 , 67 1 2 . 1 4 33. 4:3 ~'a1D. 4,O~:4'6:",:"5'3:~l'6, :2'.O';J 80.10 16.39132.22 J.OS 4.75 "7.49 33.69 3"cfŽ-ïj-":'-'"--s'êr:-'40''---S'4:''Õ''3'''-''''' ,."", ..." 2":"'()"2-"'''''''''--7'''9-:''''9.6''-''- -""'-S"':".g":r.--1"2"1":-¿'1.""'''' ..,' Ò"~ '1'2" ,'," ' " .' '4 "~"'6"á"" ,. 6'~ 's8 ",..""... , :5'8":"1'1''''' ,....,,,..,,..,,.,..'-' ~!o-jO~'. 55'~':1'7:':''':;;7'.,61-'' 2.<)9 78.05 15.23 121.92 0.-13 4.'51 ,~.Q7 34.20 ftf4ër~'''''''''''''''--~rr;''f6----'46:''''4-Õ'-''''.'''''2'''''~''Ö'ä"""""'is"-:''''¿'¿ ""'1'3':"'5"4""'1"'21' :98"""'''Ö'~. 6'2 '.." "'s '~. 0 6 """'''7:'6'4'' '''34':''6'5'' ,'0'" "-".."..'" i-J-''''':'~:'''''''''' -,.. i';::""" "1""'1"'"'' ..., 4'" "¡ "'''j'',i..' ..,,, '-, 1"'j'" ,'. ',~' "'i".-(" .." '1" '-i:.. ' '1.z'''';'' ¡?" '.;'';';, ~ "./' ,( 7' , .1") ,'.-:::'" ~ :.~ . .1".~' .., ".. ..". ~. ..)~.. ,. ~ ~,,~ .~. -.I' .. ......., ,I t. . I ~. :.:> ...' . ... ~ ... ....J'" ,. ' J '..' -, .~ : "-~ . .", .# ., . ",J I ':..' 8 "" ..J ,, ". ,,' ) J = ~; . :. b . ., 1 i.. 5 . 0 1, , '2 " 1 1 ~,' 1 . 1 ? 1 !.. . ;.; 1 3 ~ . .,!.. Q. :.:. 5 . :- '~~ 1 I~ " -, "7 ~ ;~ . : 7 L5'7' S'~" ""4 ;"~'-i:~-4--'" ".;~ S '~"1 ç .., 2. 'ft; .. " (,".' ¿t.' "'1 3'~"'4'4 .. i ~¿ '. .; 2 G . \J ,) 1 :J. 9? 1 3 " t ~ 33 .' !.. "? ;}:3..'::_~. ...,- ,:.~-~.._~.~... n ..i....~..~" ?'~"..,..".. 2,. ~ .J ~.. ~ 1. ö:: .1 :3 . ~ 1 1 2. 4 ~ q ç ù ..Ç'1 ~ . ~ 3, 1 ? ," ,~ 2. ,~>... ::.~, . '''''''''' ;~9:. 51.69 43.37 2.Jó 72.3'8 13.44 114.77 ].°' 7.10 Q.~6 ~5.6~ ~~~-~~ 1 t.....J . '+ 7 . c:.. !') ~ .) . I ~ C, , 1 '...J 6 1 . 7 I 1 3 . .:: 4 1" ~ :II ~ 0 "'¡"<,~::t;t,,....,O '+ ð .. :; ;) 1 "+ . '-I '-( ..; :) . :: '...; _.---"-_._----..',,-'--,,_..,----....,..,. . ' , "';v ,...,..-,..........",....,,,......,..,,..,..--..,-,-,.,--..,......,,..,...,,......-.",,,-.---..,,..... ,150. '51:.:':S:'s. ""'4'1.;,,~,4 " 2 ;.'20 65 ~61 13 It 69 120.87 "'.0,,, [;4 5.25 12..)0 27.15 "-ro""Õ' ~'" "'4¡r:-'r2'-'--4-i':"'''~r9-''''''''''''2': "fr' '''i~: "1'3' ' "1':5~ 0'''4'''''1' 2'8:"~' 'd';"""'" d ':0', "'5 . '9' Ö """1'¿-':'ö" 9 ""3', ":""0'7"""""'''''' ,".. "".., -1~-7 :y-,".-'-7:õ"-:-O:;,o.¡ ,"'):, " ~ '" '<;l-:,;;r6-;.-""-'-~--';;¡- -"'''1'--1''''-:-'''-''''''''¡.''''1.''.''''''''-;,;;;''q:''''''''..''''-"-1"";;;"".-"ï""7"'''''-''':''1':-.,'''G'.''-'''~;',~-'''' '.-, ""';;,; . ""r¡" T"'." "'"'''''' "'-~''''''''t;;\",_.......".n1''''. "'~'-"?";;;'''''' "'-'~'~f-~:-.7-"';:-''':'''''-''''''''-''-''''''''7'''~-'''._'' \w .' ~ 0 . 'i;J'::' ," ... '!'" ., ~, ¿ . ',.... ( '.., .) .. .., . :;., .... It. ,; ~ ' U " \.,: '+ .,. .. .", <..I -' . ;.. ð ... "..#! ' J 19Q., 94,.00, 42.76 2.19 75.41 14.71 11~.Q4 O.DC 4.34 8.92 27~74 : , "2"Ö'Ö:""""""'t~'6"~"15"'-""-"'''4Ö'':'ö''1'''''' """'-2"~'1 4""'"'''''5'''2-:'''ä9'''''''''''1''4'~'''2''9-'T¿;'5':'f'2'''''''"b ~ Ö6" .. '9 :' 3'8 "" '1'4': f 0 '" 3 0:'7"5" """"" '.:;'-1"'-';;'ï'-'---'--"-4--""O'---:¡-T-~"'-':;:"7-"'.-;--6"-----._"""";;'-'-'-2'-'ñ"""-".""'¿'~''''''''''~~.'o''""...... ..1""":::':""""'1"""-'''i'-----;¡''' ~"'9"'''''''--;;;:''n .,..,....-.. ."..;:;:..,......:;¡,..~........'''.... ":¡"'" ~"4'"-'''''.''' '.."1--:;;-'" '.' .;'.. ;;;....' "", , ;;.;, ":r~""-'-'7--"--"""""''''''.'''''-' ","-"""-'-' ,- i".,..,' .~Q,', ),".,4 ' 'C.J ,....'.(';, 'r. ",) "-' .u~ \).¡~¡I -'.... .J.CLI ~..4,' .. '2'''~rO-:' ....""..., 4"5"".~-"54"-"-.-4--r'~'ð"6''''--'''''''''¿=1'5'' ''''''5' Š ':- 6'S" , '1' 7~' '1"-7 '1' 4' 2 '~' ¿:o ", "'0':'06'''' '" .. '3' ~ "19 '1' "2"~ ", "97 "'" "~) 0 ':"'1"2'" , .. "," "--" '''''''''''''-'''''''''' 2:30'. 41~9~8' 3]:.,,5, ,2.16 54.~3 ,ff.itS 141.41., G.'05 3.11-' 1~.55 21~,'59 2'4'Ö"="""''''''''4'3-''~'-6''9-''''''''-4''9' .8"]"""" ,0' "2','0'8"'" "'i'3 '~"51' "15'.'2' 6 "''''127. "ië~'" "'ò' =.' b '9" """7'.;1' .g'" ""1 o. '4 Ö'" "3 4~63"" \ rš~r:'-"----'-4f4~':"l~'o'~'-- , ,4 ~~r:"~f2"."--".'''''-.2''':'''Ô 9""" ""''''''7'5-':'''8''Ö'''''.'.-i'''~r:''r1'----f'~T'2'''~--1'''j''..". ""'."""õ'~"i5'¿ ."" '.'..." "3"-~'-4'i5' .", ".'.''1'''5 ~'''5' i""'.'''''''''3''4':'''Ci' ö ._--""...__..,,-~_.._,.._-"_._.: ;-7""'1"" . ""--'.'."'''4'''''''-'-i[ri''-'_.'S-:;;;'--'':¡;''''''1'''''-''''.'--''-'-""';:;:;-"''''';;frf-'''''''''''''7'-~''''''-''''1''-.~''--''''-''''''''''1".'~--''''''.';;-~ """'.'1'...-1---;;;" ,..~~''''-'' '''''''''6''''''1'''''1'''''''''''''-'''' ..¿"..' "'9' " '7' "', ""'"'--Q'''''''::,''¡:;:''''' "-i'Ó"'-:-::¡~T'-"""_._.'''-'''' ,..,~"-_..,.._." - Iw'., . 0 . "" ',,.! " IJ . ,) (.. e,.,.,. ; 4 II..., 4 II ,- L I .. .' .. ~. . -.' , . '1... ,.' ,.' , .', _J ... 2"ä b :'.." '5 9,'''6'(,''''''''5-''3''=''1' 7' '., ''''2: "1"3" "78' :'5 '8 -" 14~' 5 2"'128- ',2 '7' ' . b .13 "4 '~ä27~t9" '31':""5'3'''''''' '-"--" ""'-".-'- ,'ëfñ'-----T-;;"--- q 'Q-:~-T-3'-".'-1-'2'"-''''''''''''''''--_.:;;''''''''''1''''' ":... .. "'. """:;-"'~¡"""""';:;;;'''1. ""'-'''''''''''''''1.'' "'f""-;-"i ':;;;"""'1''':;: ''":¡¡'......' ;r1"'''''''''''''.'''''''''~';;;'' '''''''''1''''1.' ,,"- '--"1''';;;':''-''-''''1''''--'''''- '-1""'-':;;"" ....::;" :;;;"'-"'"-''''::.¡''-;:''''-¡:;-¡:;:'.''''''-''-''''.'''--'--''''' ...., ..,. ,-. ,- - . 1...'. '+ ð. ,;.. " "'t '. (.. Ò 0 ., . u, ' -'. ..,::... '"j :;; . ~ :.; . , ;.: . - i.. .. j , ,~ 'I .:- ',.. ) 5'15"0:"""4"7";'3-9""""""'4'6":'"'43 '" "'" ' 2'~ "6 .':3"2"""""'13:89''''1'2'7'','''7'5'' '''Ö~'f6'''''--¿;::'9'á'' '''9 ~"1Š '3'4':'.'29 ,,,., ;¡-'"1"""""--.'"''''-''''7.''''7-.''''''''' ;:;:-''''-'-''''''''._-''''-(f-'-~7--6-''''''-''''' ",..... .......:;;¡".." ..1" ';;0;.'''''''''';:'''6'''''''''''' '¡''''';:~''''.''-''' ""'1.'" ";'f'. ."".,"'~.,.""" .."'1''''''j'' ~i" ''''.J'''''''''':~'.'''''''' ""." "'.,,~-'''''O'''''''';-'''''.'''''''''' '"1''' ~::;;.. "'.'4"-"l"'"'''' ... ... .1' "";O;""i";:;'" ,.".. ''';¡''..;¡' ,._~;;¡;;...;¿--'"., ,.. ...,....--.-..":....".,,.... , iJ. '. ö ;' '-to .,., ... G.. U ~ . . y ö ~ . i.; '+ G .; J \,...' ö J.., c;: . ..;, j, .,;':¿' ... r:fG"':"''''''''4'''t-:''-ir3''-''-''''''4'6''~''~r2''--'''''''' ""'?''':'''c';~''''''''''7-9' '~.., '2!5"""'''''''f6'-~'.'1''''3''''.'l''3''~~''':' '6' 3 " ,"'" "''''-0' ~ '1 .~" ".,., ..".., . "4'~" Õ"C.i ".. .., ..' ,. j": .'''67" --.. "'3'5 ~,..;.¿' ~... ...'..-:.....-:-..-- ", ... "--'''''- ~B~-=:flj-I=:~1~~j:::::~r~&:.--~~-:~{-+1~H:--Hi-;:~-r-.u-6-: g~- . ..1t:i:j-- -T~-:5rj%~f~~=-::::-~~==. ''''''''.'''Y'''.''''''''''''-'''''''. ......."... ....... '.',..".., ~...'.._.. ...-.......----....."."......,,- "."'''''''''''-'''. """,,,,- ,....... . '" . ...""'" ,. ",,,,,,'" ..""".,.. .., ,...... ""."0"""" ..... ...... . .''''''. ........ ... .......,."'" ...." .. ...,... .......... "" .... . ..... . .....". "".,"'" '" .'''' ....-.. .. .. ........., .. "'.'."" "''''''''' ........ ........ ... ........'.'" ..""'" .. ... . .....,...~... . ''''''''''''''.'''''.''''~'''''''.''.'''.''''''._'._'-'''~'''''-''''''''","'.....", """",'"..''''''''''''''''''''....''''''' ..... "'''''''''''''.....,...."........,.''''''''''''''''''.....,...,.....,"."."" ""''''0....., .....""""...,.. ....."...".......,..'" .."..........."............,.' ..." .... . .."""'"'''''''' '"'' . ......."..... ... .... "."...""..,., .".. . .. ....,...,..""...,... . .......:'''.'''.'..' ......-.............-,..............."""",,,...,.. .............. """""'-' ",,,,.,,,,,,,,,, '......, ..,............. .......... "".....'" .." ... ."'" '"'' ':>~Gë <. DAT~: 2/ c/S5 Tlr1E: 1D:54:.34 UNION OIL CO.OF CALIFC~NIA K3U 23X-6 KENAI GAS ~IELD K:NAI ALASKA "-",,--,,,,-------~-.'~'--"-'-"-_."....__...A_'''''._.,,---_.._--~_.. __A. ---" ._"".._0......-- . ..- .._~.. ..."-' ..""."'. ... .. --....' ."..-.... ..-.. . .-.... . "....-" ...' ".'-.""..'." '__""._"'.,.._.,....._.".~ "-....---.. - .,"-" .."--- )"Ë D fH-'----G-~"-"--';:N--~-~~::=:~:¥.:}I===~~}'.{~::.~~:',:~=:ç~A~:l~~,=.~~::~~-~~.':~':~::~.:ç.:Q~~~::Þ~_:.~::'.~,-~':3--9I"Ç.':"n ._" ..... ~:Ë:~I~.Ç,,, ...".._,.:::"..",."~=:',:-ç~~H~..=_~'===. ;,' ~_.._.__._..~.?I.._., % .- ._G.J_~..._..,_... ..._...!.~!..Y.._---",,_.._----_..J N...----..____.IT """'- ."-,_..,_...~.I.,,..ç---..... ...." -..." q..~i.~:L, ,. ,'''.m''" " .9. ,j.f~L..., ". -- ...,," .... .----...____,..I .' ,... ..--n_,- '--_._---'---'~ .-..~--._.~..-.._-_.--.._---_.....-..._-...--.-._-_._._-..-----,.,~---"-"-,--,,.,--._-,-,,.,,--_._----"-"--"--._.."-'-..-,. ",.. ',,- .,. ..-, ---------."-0_.'_-'---'.----- --_.- ~'fu~':, ' --.-- ....- -. ...--...- ..-...-.----...-' -''''---''''--''--''''-'''''-'--'---''--'--- ..,...".......- "'-'''..-,o-...-'' .."..,.. ,-, ,,,,,..,, ""'"."'"'' ,...., ...., ...", -.. --",,"" .._... --.. "...-, ..--".. ............. ._".... -""'--'-'-' _"---'--'------''''---'--- (%1~,". _......_-,,-,.__._,._-~._-~.~~-~~..._-,-_._..__..__. "-"""-'-""-"_'n__."-'" _....~~~==~~==~:==~~=~~~==~~~~=::~~~=~=='.',=,~=:'~~:='::~:'~:,'=:,::"'~~:~:::':':::,:'::~:~~::~' ,"',',"'" -'-:~.'..~~=,==~~::=,:~-~=~ 33~C. 46.;3 48.90 2.12 71.27 14.3~ 125.?2 :.03 0.96 5.38 32.J9 ¡~3 ~Z...g._~._..._-~~..,,,!~~~~~ 9 . 43L,_.._._~:~..Q.?.'=~...._~_,9_~'.7:J~~~~~T,I~]~?.~~=U~'~':4.!t~,~,'~.-'~'.:Q:~~.::Q,::§,':',,,:,,~-~,~:.,.?:~;'~-'~',:,::'-~.'~"':"~,-~:,O!',',~,. ,::,,'-,:')~(~,"II...::,_~',~:,::~:-=:':~..~~: 3380. 48.09 59.76 1.93 79.86 16.32 125.72 8.08 4.67 6.38 40.44 7ti't9 ii" ' "1.9'"'''' '''''.1' ""3' , "'5' rF ..~ .1 ~ ' D... ~ 1 11 1'? 6 1., 6 "" 7 ,.. 1 1 .. 2 7 .. ""';-'9-"'-------:;~":':::'''''-''---'''-'.'--''._'''- ':~ .J', ~. "t." '.J ,..:...' (. . ¡., ..... b . -" '- ~. . t; '..J . "+ . (';) . ~ . ,) ~ . :::> t, ~-:;~:-":'----ï-7-'-O-4 -"-;--5' '-:'3~'--"''''''''~' ...m1"''''~:;'- '''-'-6''-::'''''''' ;"'2""""""""'1"-""'4"''''--''5'';;;'-''''''1'-''';'- '....':¡ ';'-"""''''-'''~;';;-''-'O'-' .~ -'''' , ""7"" '4""0"'"''--''''''' .;:;.'.. ',:' --.; . ",',' '''':::'-1''''''':;'' "4"""""""""'" ""'" --.. -...... ....~IJIJ. L.+.I' 4.-.,.1 :::::.,oJ . ).ð.. ."j 1o.,......î...J4 û.,,.,, '.' C'-.;fÖ.).) ~'j 1 ,... 4 1+ " I 4,' .. "- . r 0' ? '"\ D 7 7- -;;;-5 -'1--'5-"--'--'-:--'''''''-1--''~j'''2'-''''''''''''2''.'-;:"-- "''''''''''--r¡ -'--1'"'' ;;.,-' .......'--..;;:".. --~ -.:.-'.-...' '...." '7 ,. '''''7''''''':':''''-'''''''7: -^-----'7:i" '7"'---'''''''''''''''' ,.,... ..... ....---' " '... '.J. " ' . * ' ' . :> b '. ,*", - . vi. v' . 4 Ó ,_.) :.... tJ , . - b .) .1 'f . ... . . --~"-'~'-'-'-'--"'-"-'--~'-"'_¥_'----~'----""'~'-~"--.,~._-.~u.,._,.....- "--0. -."""""'-.-...-.-.' .-...¥....'". ,.. ".'",", " . ......-.......---"-¥.-.--..--...--..-.-..--..__.."h.,,.... ._..Om'." .-....-..-..... "-".'. ""m.',,, ,'.0 '." _....- .........-..' ".., .".....____".n mO'" '..." . .. ..u..... '.". .. "'''''''''''-0. .... ... ... "'" -_.. . "...".,.. ".. .' 3420. 49.76 45.51 1.99 81.59 15.47 133.52 0.08 6.35 7.35 40.04 ~-----.-._,.--,-....--_.._._._----_..._...",_.¥. .... ...-.._-_..---_..._.__..._..-....._...~._._...__.__.,.._~......,.....--....--. -""-............ -''''''''''''.U'.-'''-'' ",-...,..., ,,-.,....-.-..' ...""--..'".''' . """.""" ".' ..... ,"'" ,", ..,.,,'."'''' "'..",," ._,.. '''. . ,. "" ,,'''''... .....,..,.-"'- " "......'..n,,,."._-...--.-- .,.-- "-""'.".""'''''--''-''''-'" '\l430. 54-'.'~,5,', '40'.';7, , ~.13 ,,'82.8015.41 100.'2,6..0.14 .35.79 7.83....31.-64 ... ..... -34 4'èY:'---"4'''ir:-r9'-----š--f:3-''f-'-'''''-¿--:-'f1-''-''¿r¿-~-8 8'-""-1-5---~-'4"3"--"'1---2-7':"4"¿""'''-'.'(j -: 0'8"'''' "'"-3'''~'''i3''' """" 5' .~5' 9'" "32:"5"7'"""'''' '''''''''' ..".. 3~;.:~. :.:;.....~. ~~;.?~) ?~.1- ::~:~."?~ 1~..1;:; 121c,::'~ .~.~~ ~.~,,"? 7.:::. }_.4...2..q~=:='~5~~~?~~'~~:~~f§=~~1I~~,~:~~-~_:::?,:~'::i~I",,'~'.::.I:,Q:,,;'-~:'E~~:.=~,:f~,~:::,"þ'~~?',-,',~I::?T:'~,',:~.'.~"','.":".':'."":;;::';, Q:~"".""."".'''' ".~,.:~" -~,'~.""" ",..,. .'." ",¿,"~",'s" ~" ,'" , ,_~,1"., ,.~;, !!", .'", 3500. 50.91 48.62 2.06 80.26 17.20 123.47 0.19 4.18 5.84 35.70 '~;~?~I:¡~L'~:':,:."......_:L?,:.;'...Z~,~~;::.~::~,A.~t:~i.~._'....,,,,..,..,~..~, i. q,{Q.~" 4$,." ,,14,~ ~?,' ,1 ,1..' 9:, !':[Q~=--. Q,.1,q '" ---¡-: <;;2", ,-,,- ,,~-;3Q "J ~~,~~1.?,...~-",:"~:..~:~-- à2..¿O!_..._,,,2,,f.--!,,..?.:6.,..,,,.~,,Q....Q8,.,, .2.",13, ,.63...4Q. 13.,?6,.12.1..76 0.Q6 9~7,~.. .1,O.~3, ,31.~.7.3,., ~5:;j. 4?~}.3. 5~.,~:.t 1.g.J ~::~2.~!~ 1~.29. 12~:..'~:,!: .J.:;:) 2B,.7,~ 1::.76 51.£..4 3 5 4 ~. . ~ ~ . 2 ., 5 .~ . 6' 6 1 . 7"? ~ 1 . :: ~~ ! 4 . 7 ... Î ~~~ : . '::: :.~, [~ ,. : ~ :: . ~.. ~ : ::' . :.. ~ ~ ,~;. . :-- ~~" 3 5 ; :j . ,~ 7 ~ c ~..~ ,., :. '5 ~ ,(} 9' 2 . 1 ,5 :3 :J . 3 1 1 i. . .,; 5 1 ¿ ,e. . ,J' 1 ~J . ~: t:.: 5 . !J 2 7 . l. .~ .~ ,~ . 5 .: 3 5 .:: : . ~ ... ~ r- ~~ :; . 7 t.. 2 . 1 I~ 7 9 . ~~ (:, 1 0 . b 3 1 2 1 . r~; I,~ ;J . 1 2 3 . 5 1 .~ . .' ,,,, ~. ~ . ..:.. :~ 3,':; 'i;:' .' .'"'' 4 T;"ç ~~ .." .,., 4, "ž"~ ;:f' ~ . 1 3 7 ':' .. ,.. 2 1 it . ~ C 1 2 ? . :~: 7 C' . 0 ~ .j . ,~ 9 ;' . -'~. : 1 . :~ .:' . . , , . . '3. ~ ': ~ . ~ 2 ., ~ 3 ~ 2 . .,;, "'''''~I~''~'""'. ~., 1 -:: :: ~ . 2 Ö 1 ~ . 9 r; 1 2 .3. .~.+ J . C ~~ :: . ~ o~ C . ~ ~ ~ = . '- .) ,3"05 .;.~ ~' " "~ .:: ~ t} ;::' ~I~ :~ ."4 :3 ~~ . 1 7 3 ::J . ~~; Q 1 5' . 1 3: 1 2" . 3 -, J . 1 2 ~~ . ;~,rS :~ . :~' ~) ; .~ . ~~ ~~~ ' . ;$ .j =- :. . ~ ;. . 1 1 i~ , . :7"::;' '" '7 . 2 :.~"" '') c' . "J"'9 1 "~"'." i L~ " 1 ~ . 2 :;, :J .' 1 1 3 . ':'. 5 :.~ . "; . ? ::~ . : .~ ) :~ f:''- . . ~ 'f~'''? 6 . .. "',~"5'c' ~,;;3.., ,2;..... 1~) ,77 . 7.1 1 3 . ~~,;: 11.F".:; ~J 'J . G,~~ 5 . '3. ¿ '7 . E ~ :~~ '~ .:~ :'." ~ : ¿ ~~ . ~~: . = :. .~ .:.: . .3 7 ~~ . 1 1 '.., ., . ;., '..: 1 ~ . ,~-: 1 1 I~: . ? ::¡ :: . , 1 5 . ~~ 1 "7 . '7 ;: ,: r.: . ~.:., ~ ~~ .3 :. ". "''':~ ~"'. '2"j~"" .._, l' ~u~.. :. ~~ ¿ . 1 .: ':' ;. . 3 ~ 1 ? . ¿~: 7 1 34 . :~ 04 !,_I . i.) ~,~I 1 J . 1 r: 1 i . " " :. ~ ~ 1 1 ' . ,,,,,, .. , J - .. - . .:. ,. . i~,~ . ~~ '?". ~ :; ~: . 1 ': :: I~ . ~ :.. 1 :: . -. .,~ 1 - .. . .:: '''. ~~ . ~.~ 1 1 1 . ',: "7 ~ : . '~7 : - . ,:. ~ ;~~';;;;i"~--ï-;:;;--~"~.'''''''''-4'''-1''---:-::''-ë'.''-''''-'.'''''-;;;¡"...'-'.';;;¡.;;: "'''''''''''.'''';;':'''i.'''''.'''''-:;';''-1'''''''''''-- '"1''''''' :';;"""';;;""--;;;""'''.''1''''''';-''1. ""...".. ::,,";4 ..... "'m~.."'.._"~"';;:""""-- ""1':;-''''''ì''''~;'''''''''''1''''ï; "".''"7,''':';';,''.. ..,.., ':;;'--4""'''''''-:'';;; -,""""..'''''-''-' ."'".",..''''' , ...'-- ) ..; ,.' ,J . ,!. . Y. J t" ,.' ..) ,6' .:~ . c')' ;. :..¡ . ~ ,'- . 'i. Ÿ -'+. 'I.... 'J . Ì..¡ ) , .:... . .... 0 .' . .; u .). . t. ' ".'''5'O''''~-l''7'''-'-'''''~rr:'''Sff'''''''''' "" , .., "," '1" ~g.4 "3"'" -..,..'" ...., ," ,,,,,.,. , '1,3"~'2' 2'" 1". .." '" ,,'" 48.9246.86 79.04 0.07 3..71 6.18 31.05 :~~TG''''''.'''''---¿-~~~~--4'-7 -~--0-;¿-"-"''''''''.''''::;-'''':;¡'--¡;'''''''''.''''7''-''','~j.''''''~~'.'~''''''-.''''4-'j'' ."-'"~'.'~'''''''''1'''''5'(-;'''''''5''';¿''' ""''''''''':;;:;''''''~~'''7 "'''''''''''''''':::-.''.''ii';.,'' ".....' ''''''''''¿''''-''¡;';'''':j'"'' ." ,,"" ...;;.:;;,: ~'''-'';''''i':''''.'''.''''.'''''-'''-''-'''''''.' , w 'I...; . . ..) . " ~ '. ". '!oJ .."t' .(... J ".J ~-~ . "\0,,1,' .... I .:¡,;. .. ,. ",,' '-. ..., " ,-, ....1 ,J . ..,) , ~ . ,...,..~ ....; . 1,: .. .)..,J . 4t wi .."..,,, ¡-Z':"3"'ã'"'''-'''''ï';'S''':''f3''''''''''''''''''''''''''''' "'2~äi ., ' ".' """''',, . 4~13 ,,""".,.., "¿i'~'Ö.6-""""""""'" ",...... ;720. 46.76 62.97 1.62 77.56 16.06 131.55 0.04 15.34 8.84 62.50 ."?--:':~_.;;';"'--"'-'''--'''.!'''',J!:\, '''.7'.?':.''--'~';¡-:-7'-'''-''''7-'1i-''''''-''..'''''''1''''-""""9:".";;''''''''''' ~.''i'''''-'3-''-¿¡'-'''''''''--1'---;';::''-'-'-;:;-'''5'''''-'-''-1'''''''-3'''7''''''''';:;'''1''''''''''.''''''''.'''.''';:';'''''.''''';:';;'''''7"..", ..."".. """"'/,".'''''',''/'''''' .." "''''''r¡'''.'':,;;'' .~., ..... ',....': ";::':'''' ..~:;;-':::;...--... "..,'......-"'.'..--'''..- 'I ~ J .. ~ "'I '. :if','" ,?',..' .,- . ~ t.):.... ';¡ :) . ,) , "" .. ~, t; . ,) ..i . , :.+ .., ,. j {. ~ ¡j.. :; y' -';;r45":""~~"":"?fr''''''-'''':~'';j'~'T''~'''''''' """"i'~"''':~'~,'''A :="t~j:' '--'T~'~")')"f2'f~' 1'2" "", ].' c '¿.' , "6 :2 :?, ' '7 ~'j ~. ..¡~ '3 ~¿ i' "" ...., ,..""" "7'5.Er:''''.''''''''''.r7:'4'2-'ã7~~J:6'-'''--'.'''-'''1''''~''.¿"'3--'-'''''''''E'Õ'':'''5''8''-'-'"'.T6''''~-:j''6''.'' '1""3"5':""1"2."'.. "'.""""5"~'Ö'5'."'.'''''''''''1''3":'''5 '1""""'''''''~:'4'~'''Q'~3''''''''''.'''';' i'. ':'.'~',:;''''''''''''''''.'''''''''''''''-''''''--'' "7'~;'tr:" -"'-""54-:-"3"'2"'"'-''' 4t~-":"--6j""""""'2~'f7''' '7i~ i f 'f5'~ . " 5 '12' 8'.6'7 ..' Ö' .Ö 8' ", '4".7 Ö ' , f ~ 8 Ö' 28:"9'4" ....",...,........", "77-tj":"-'-45:-;24~4~-5'":'''6?r'---'''--''.-'2-.:''f6'''''''-''''7""'9 ":" (;'2''''''''' '1""7"~"1."2""'7f2'7":'8'Õ:'"'''-''' """"j"~'"f2'''''''''''''''-'''3''':'8'4-''''''''' ."""'S":"f4' ".""" "2'9":"'7""4'''''''''''''''''.''-''----'-:---'''- '7"8"{f':' " "2'2-:"6j"'"~'ä:'Ö4''''''' i~äb"i"i.'á6"'i' 4"~.ijf3'3.'fÖ ""~'5~'Ö1' "".6'~'i5' '39'~"56' '5f~j8' 7 ,... ,... ... - 1"--;;::-"'--''''--:;;---;-.---:-':::.::;''.'.''''.'.''''.'''''''':'j""''.'' "?)' ,...., ... ,,,.. '.;.:: ';.;:' ,... ';';:"4-' """.'''.1'' .~¡... ""':::,' ".." .'" ... '~:;:';':'--'.":;;' ;;,... " ',.,,'. ... ...,.' ;;::; "'..";;"";;"'" ..., ..1'" ''Ï''.'' Õ .1'"'''' ".. "." ~~~"" ":;";;; ,.,.,.. ",'. "':; .,;..,,,.~O "j£'" .""".'."".." ...."......,,'''''''' '"f \..i . ') ö.'~ ¡;: Ó . ,:;):> ;,... .' '..; 4 ') -.. .') ~ . (') "" ' .~) . ( :> u. u U v.,. ~ ,: . .') j ,):'",,,.' 'älYij"'~" "")3:"'4"1"'" "'~5'tY' :'30'" ,,,. '''2'.:'13' "5' 8~4 '1' 2 ~'35' "~' 70"0 . 0 ä '2 b . 6Ö' 4 2 '~ 0 6 31'~ "46 "" . ...' ~. ,?g".~, ,~ 6 . 5 5 5 1 . 1 ~~-¿".:"'T;-"-"'.'''7' ;i":.'ö'~r''''''..''1);':''R' :3""'''''.1'2'',' =".1"'2''''. "" "'''Õ'~' Ö' 6' ".""" "'.~~'''=-ði ....,,,. "'...""~;'~ "9'"1"'" """'2'~'.;~?".~--"""-"'---" '_."""."'''..-'''' ....._..-....,~-.........._~. ~"....~...n.... ............_-,. .......~ _.-...... ...._..~.. '-'''''''-.,.. ..-.... .. ",,"'" ,...... .,.."....., .,.n R.,..... ... "... .' 0' ".' '. ..,m . .,.. .. ... ,. ""¥" """"', ,. ..., ".. .....". ..... ,.,."... .,..." "",m...."", ... - ,.... ... ''''''''''''.. ,,~... .... .... ,.. .,~.... ''''..., ..... ~ ,. ... .. . ~... . .. ~ ...... .. ,.,."'" ...."., -~..~....-.,.~.. .,... ....~..~.- .... ." ...".~-~.. ".... .,,~,... -.... .. . "~"""""" ",,~......... ....... . ......"... ....... ... .. . "."", . "'~ """"" ..... . ..... ......... .... ~.. ... "'-"."""'......., .~......."'"'''''' ~...,~.. "".. .... .""-' ,'"'' ." ....,..,... """."'.." "'O'"''O~''''' ....... ,,,,~,.-~,,,,,,,,~, '... ......... ......".. ".. ....... ...." ". ,. .... .'''' , ...~. ...,.,.... ... "-'~" .......".. "..,,"'0. ..."""'''''. ""'"'''''''''' ,~.. ......."'"'''' . "... . , .. .. .. ., .. . ... -.... .... "0' .... ... "... . .....' ' ..... . . ........ ~. ' " ..... . .." ........., ... ..... . -. . ".. ,o",,,"'''''~'''''''- . .. . ." . ..... ~....._.......". . "....... . .." ...... .........'''''''' ... .. ...........' .......~. ..... ." , . ....~............ ..." .. . '.- ...... .. ,..... ~~G= 4 JATE: 2/ 9/85 TI~E: 1C:5~:34 UNION OIL CO.O= CALIFORNIA K3U 23X-S ~ENAI ~AS FIcLD K~NAI ALASKA ~' ,~ . ~,'~"\ ----_..._-_a__.------~-_.._.~-__..._n._._._--_._.. -------"--..~A.--"-.A..._-~.. --_'.A.'-."_-'----"-- ...,---.,,-- '..." ..." ......-.-.~.. -...-"-..'-.--- .... ..--. ....-_n.. " .. ... .'.".-- ... ~...,.. ..0_.'- .....0 ',,-_...~-,.__..-...__...._-,..- ".-._.___n. IE~Trl ~R CN JEN SP~ CAL3 4C CO~D R~LL ?=o: J~NP f'l. A P ! . '_.__._-~~---_Ji"L~_..__.~=liY_,.~.',~~::~==~~':=ï~._...,....._._I..T ....-.... n. . .- "_,_~.,,LÇ..... ..._--.....,-Q.,~ M,._,_....... ....._..?..tL~t__....,.. ......".. ,._-"......._._......~--=,== (tit ' --~~~~---~_:_-"~==-='=-=~----_._,.,....".......,..,'-, ,,,,_.....,,.,,,,,_..._-,=~~.=~~:.'~===-=~.~'==:'==~,~-,--.,_..,_.--."..._,_..,"-"...,"'--,.._-_.._.._---~= - ...----- ------_._----_.__.. --.---.----- ~u. . ~. I" -_._---_._______A_._._...._...._.~.....,_.,..... _...."~-~_._.._..~,._-_..._...........,,....._....~....~,.,-_......_.._~..._.....- .. ...,., n ,.. . .".. ... ... -, - .."'.-"-..'..--.-."-. -_...~-~.,---- _...- 3840. 38.4° 42.65 2.1~ 70.05 14.37 134.79 0.06 4.4Q 10.27 31.73 }~',8 5 Q:,.!~i,,!:I_~~,_..~.4 '+ . 0 2-_,---~..!J_~._,-- ..,,_t~,.!..!._Q_._._...14,,!'J...f__...l,f..l._I!..._?.~~_."_.'n,... ..Q....I!".Q"'?'...,.. .._".....,.~,_!_.~. .Q..",.--....}._.....~.Z_..~......J.J_,~:.._f.]"".."_.,,_...._....,,..,-_.. 3860. 47.30 41.84 2.16 78.8~ 16.99 123.05 0.10 3.21 6.42 29.61 J.i.3;3 {O ..L_- 51~.S 1 "-' 6 0 ~~4..,-,--"~~~_.1..t_.~:=~~~:!_-~:'?=--_~I~--,~.,i,.?,,,...",,1, .?,~4::.~::~~:,~:,~~'~:,'~Q:~::Q',~",,~::~~,~:4~:~§:'9":~~':~,..::':,:."~:~-ß~~'~",.':"""",~.,f",!_,.?,2_..".~',~..=='==,::~ 3630. 49.74 40.57 2.24 77.17 14.39 120.13 0.03 3.11 5.48 25.04 ;;3 ,~~ã. ,~~~:5''tr:6~2-- 2 9".' it 1-===_0~9.,I~~:=:~:~~A.I~:~::~~..1,l.¡~=?=:':~iI~;':I.~~::,'~,:,::~",::':_¿.:~:...õ.~',~':'::".-,','::.:':'~,~::',:El:'-"::':~j5::::::1_""f','-"'...""~'."$,"~,~~?~'~~','.-"::::~'~~~:.-'=:--: 3900. 51.27 26.62 2.09 53.16 12.61 160.89 0.04 11.36 26.78 33.83 {1,9 1,~t~_...JtZ.i"l.J{-~~:,J.l.:~~ L§:,~.~::.~..,.,:?.,,!_,,~- ~~_.,,--..,..,_?..?._~,_1.9. .._,.--J...?~,!. QJ...~".".Z~;..!..,.l.Q"."....,....., -Q"!.Q~?",,-,,, ..?..!_? .1"" .,~.} !;, p, ,2 ?~." ft.?,.., "', .,." .Oo',-, "'- .... 3 9 2 D . 5 1 . 77 25 . :3 1 _._~~¿~_5 3 ~~....-J 2.:J 6 1 0 8 ~_2 6 .._~1.....0 L_,,_L9_.!_1.2..,_.JJ~_Ii......_J_I. o_~,,,---,,-- :3930. 52~D3, 42~40 2.1' 51.07 13.26 149.99 0.06 9.94 23.04 31.12 _;?,,9 ~._Q~.~~----~~--!-..:U=~=,...~,"~,-~J--!~,~=~~~.'..--?.._~:Ir'.~~=l~â::~:I~~~:~.~.=f~~~~I:Q~~.~j.:.?.,::~~~:::j,,',?,-,~:'::.::.:::g:,,~;::IQ':'~,"~':'.":-.:,~~.;:':?,~,:~,':-,'.::..'....O!,'.~::'§'-¿::::."':,..,:?'::?~,~~.~?~~é,:::,~:::~''',:, :":'~:,,::~:':''',::,''.'~ ,;~",9 -~g-~"....._:.~.,lJ1ÆQ:~~,_~~~:~~~!!.IQ.:,,_--..._.:?:._!,J,,~~'-""'" ..t?!5,4..,..,....J ,?....."Ç.,.Q.J ,?"~~..~,.~4.,,Q,!Q ~ ",A.9 ?,? " g f; 31 .J? , ,'.. 39 60 . 4 5 . 41 39 . 43 2 . 1 ~_Il~ 30 _12. 9U.. 1 9 ~-_-.9-!...O 7 _-2..JJ..__3. 8 5 __.-:2ELJ..~_,__- ~l.~Z.Q_,!.__._,-,~,è..!.:"~.1,,_.,,......,..~~Q.,! ,~,l.",,, - ..,,2,..--J7... ","," 2J,~.5. ,?........J..~,..~..9,9...,J, ~.J....J ,} .. "...... 0 .~ .,::, ~., , , ..,þ" .",t,?" " ..1..;3., ?Q... , .2. ?....) 7,...... " _:L!~8 o_.!-_,_,,_4 7-!..~_?_,_.._.."~1..~_"2J..,__,,,,,,,,. f.~", ~J,.."....."2,Z,~..g,.2......""J.,:?"..!..9...~"".J.,f,,,$, "...,~,;s,. ,,,,,,....,, ,P ,,,.. .9.7"" .'.. ' ,,?~,...3. ,5.,.., ", "J..,,2.._I'.,,~, ,4 "" ,? 6 ....f.t~?.. ,..,,,".. m' ,,- "--"'-- :.J,.~..:7,g",!.,:...,...", A},..~..,!}:..t......" "J.~",..."'!,l_,,,:..,,. .,4_. .1,] . ...~.. 1, ...7.7 "J.? ,,!? ,~,....J ...1.0.. C) l,).~ 1. Q. , ,l).,þ,? ,..,.2. 4 ...,,1...,7. ",ç? ..jj,. , """ 4000. 45.83 32.47 2.15 52.98 12~63 112.28 0.08 12.38 27.38 30.36 ''t' 0 1 r¡ I 7 ' L ' , .~ " 7. '2 1" i'. 1 .~ 1... . C- 1... "? c'. ..,,.. 3-m-1--2'--~-~-:; -, ';¡::)' ' :,...,' ,""... '+ '.'1;,1,'+ ,..";;,!t,,4:,., ,.',1 ;;6..", ',.:0-:':, ';:.;.)4 V.W..."U ¿,ó.,t> -,,::...46 41S2. 4~.3? 44.27 2.J9 58.23 13.32 128.45~,,'O~1J 6.45 12.5; 34.:~ 1?fTo-:-----S-6 ~ tf¡j'""-:--l;:r::: 7 "2 . 21 76 . t 9 1 4,. '27, '1 1 6 . 8 J "'""8 '. 09 ? . 9 :; 7":.'''Ö'ff'''''''''2'¿'':''''S'''''.. '..,,,,, ......." ""--'.'" .-'""'1"-3"¡~"---.--4:-¡-"~;"'~;i"---'-'7T~'~'--:,",-,,,,""''' .."",.. ";''''-''''3'''''''1''''''''- ""-""'7""'''''''''-;~"ï.:'':-''''--''''1.'''f''''''.::''''T''''""1"'''5';:-:;''''. ',i""5"""'''''''':~'''''''';:;¡' 'il"""'"'' "'"'''''i'''-''::':,'i'''.''' ,. '.. .":¿ '"._.~";;;;"..., ,_.,.. 'j ';;:;," """:¿'''T'''''' .-'''''''------''''''''" 4,' u. \.' '. ö, ,-' "'. . ... ...' ,- . " . !'J.?,."....; ...,.' . '"+ Ö w. 0:.. . '+ '- " . \" .... -' . .' ..... .." . ~~ ( - 'J. ,.' ;,.., ":r1'.4"(r~".--''''''.'5'4'':--5'7'---'--4''2--~'''r6.'''''- "'2"":2"1' "'7'7--:"56 ,'.' """13' :"33' "1"1"6':""6 ä ,..., "'Ö':"Ö'-¿ """""'3":9'2' ""5. i '8' '2' ó ~' 56' "4'"f)-5":-~~-'--":f4"-:-6J----~'-3:6'.:'''9l'''''''''''''''''2''~',Tr"""")'''r~'7''¿''''''''''1''r:'á-b'''''''''i''~r5-~'i5'f'''''' :J ~ ë '4'''' "'5"~'4 6' ..." "i '~'i:;'1'''''''' "3 ¿ '.'''iLÇ' ".....' .."_....,,., :;T';"::"-~."''''''''''''~'''3''";'T'~''-'-''''4-:r:'''4''3 .''''2 ."1'5' "',E: '3 ~." fX'~;' 3'" "f¿ 2"~'¿s; ",j~c i" ').G 1'" " ,? ~' ~"~' 3 .: "~44' '''í'-~1''''-7;;;'''---'-''''.''''-'''5-'''1-'---:¡"~''1''~'"'-"'-;;;':-';;--'.',::'=;'.."'" "..""..""'.;;;-"..- "'1"""::;:' ,..' ""'" "';;;:""'6"'"''r-=;';;:;''' . '-"1" :;;;'''''';~'''::;';''''''''1'..''':;'~;: '-"'''''5''','''''''''''''''''''''',:::;'''''' -h" ';....- ""''''.'' ...,;:; """"'''1' "'1'" .....".", 1'" ..,~;; .. ".'-1""5' "." ..'..'''...';:. ,""""';;;;':""" '.", " ...'" ,'" ..'''. ...--... '+ i v. ' . .~ \,; "Î. , . '+ , ::. ¿ ;> , '. '.i L I ~ . "I j: '- ":I. - 1+ V . \,¡:; (.. . '..). - ' ~) ;.. . r.:. ,,:, 7~"-f8"Ö'="'''''''''''''''4'''9'''~''''j''O'--''''''''''5Ú''=''Ç9''''' "",..,...., 2',:.., 9 " '" ""7)~"~ 4 8 '" "'1'''3'' ~'''~''i'' "',.2 f ".~ '(j Ö ,,' "'0 . Ò 8 ""4 "~A '6 '" "6"'~" ii'" "2' j ..~. ~9",6""" , ",,',,''''''.-- 4T"?"[j"':"'-----"" 4' ;r:'-¿~~-----'-4-,-":-Õ2""-"'"'''''''''' 2"~'1" 7" "" .." -7"'6'''~''''4''9''''''''-'''1'3'':' ':rr"-"'1"1'''.~r:'''3' r"'"'' .." ,. ";j.'~''''1 ~j""'" "'"''3''':''5''8''' ,.,.,....', "';~, ":"1""~r" ''''''29'':-'3'''':~'''''''''' ,.....--. ---...".....,-.. . .. ,. . .. ... ....,... . ..,_..... .....,....,...........,....,... _. .......' ......_...~. ..,~...............~....,. .."-,.",,,.,,,,,..~~....,,,,,,.,,,,,,,, ...,~, ""'."'., ...,.. .,.. ..,. ... ,. ,~..., ", ..... ........., '..'...... ....,. ."" "'.. .....".""'''' ...... ~...,....,....,. .... ..""''''''''' " ...., .. ,...... ....'''''' ."', " ,. .... ...."'. ",....." '''' " .... ...., .."."''''' ' ~_?"-Q-Q,,,~.._.,_.._,,4 9 ,~,~_?_._-.!!1...~-?2..."".,_.....?,,!...?..g.... ...,. ....I..~-"~..?,~..,,,. ..."l,~.,~.".~,,7.,..,J ,. J.,.'?""!..I.~,,. ".,.,'" "q, ,.,..G. "1?, ,J."~,,..? .?. ."., ".." ..... ".?~,.?.J,,,, ,...".,...?.?..!,..?.,~~-_....""",..,_..,..,-,.."..,.. 4210. 50.73' 5¿~57 2.14 55.16 12.d5 13'.58 0.84 5.80 8.3~ 31.21 ';Ç2"2Ö'=""4'3:"šf9""""""3'~r~"9'"f'" . 1'1 '49.08 "1 i ~f4'ö.' 42" 0.03 8.42 14. 71 3 2 ~'92' 4"2"j'':].' :...." """"'4'6":"7"Q"'''''''''''--'':r2'':'''Ti'''''''''''''''2''~''1''1''..,,, "")1"~""j"?' ,,,.. ,,, "1'-~i"':"5'4"'''''fi~''1' "'-.'2)'5"" ",..",,, '"5':' ö' 4'" ""'"''''''~r:'i4''' ,,' '" f[ ='f'~"'" """"3 2 '="~i!;""'''' '" "'''' ,,,. ,..,..-- ' ~. 2."4.';~ ~.... '''..4 2" '~. .1"""5'" _..,.....,.,~~.~,.¿..,~.....?"~..".. '" ~2'" ~""i""3'"'' 5 5 . :~ 3 """1 ':2..~. ",~ L. ""1'''' ~ ,"" ~"'~~ f.. :. . :! i. '1 '3'''~' 5' 2 ,.., 1 .~, . I.. 5. "'.'~""i ':""~.';~5..'...' "......"" Z"'2'5'5 "~.. '''''''-¿;''5-':'l''ër---''-'''~r(r:-4 Z~""-"".""2":'''fL' .. "'"'')'.'ð-'~'''3'''3''-'''''''.T''r~~:r~r''-'f~f9''':'''3''~,J'''''"......"" ~5':"'ë;-'¿ ,.... '."'''1''5''~'''1-'i''''''.'''1''-;.'':'. '1"1" '-"-.' j'Ö ':.'7""4'''''''''''''''''''' "-,..,-,-..,,. 4260." 4"1'~"9"ä""""2"9"~"'''6'à' .13 '4ä~s'j" '''f2'~' "1'44'."4'Ö "Ö '-ïJ'(Ç"''''9'''~Š6,' "r9'~' <is'''3f:Kz''''''''''''''''' ,,,.. ¡.";r7..t)".:'"'-''''' '~"Ö-:-š~-B".-"--'Tö":-~rö"'.""""""".2"':-1'.'¿"""'"''')'''~r:''5';j''''' """"1"2":"'8'4"" "fJ~;~'''~''''f:;'''''' .."".. "Ö"~ "j' s .. '1Ö ". 'i 1""""'''''1'6'''':''''4'7''''.' '.,., '3'1":'4'1''''-.'''''''''''' .."... ".,..... ~...~..¿~::",!~;...,~"..", "'..'."".~"'''2'.'~''''.:?''''~..'''..'...'''''".'''''4..'~~;'''.~.'''' ;~" '. ' 'I? ~ ""1'~' ~~ .; . ~ "~"'" "'1~.'~ 1"" £.' "'.'1' 1 '1 . .",j 5 : . 1.~ ",., :3 . "7" ,~".., ""~i .~~i ~.";:~" 9 '" "~~.'~'~ 6"5" 4--2'9~~'~' ,. , "'''''4''9 --:. ~r¿--"---"t;'-T:""9-3'''''' ..,-".,,""=-' :" i" i' """ "".::;'''i''~'''~''6 ...' ""'."1'~~ '~"'3":?" ""11"3" ~,. ..~'4 ", "'. ". '" "'" "¡j'~' '1'.'6 ", '." " .', "',~"~' '~..~"" " i ~ '5. ':š'" ..,.." :: 'j ':";~?'" ,',""" "" '."'"'' ... .... 43 ÕÖ"~"4'5". "'1'5"'"'' .'2~13 Š '2.9 21"3 .'¿'f '1 2 9. 3 8 O. 0 9 8. 8 6, ' 1 2 . S 4 1. '." ''''''-'''' 4'''3''1'''5--:' '''''''''''''''4''''~''1''"'5'''''''''''';~çË,'''':'''3'''~f ,'... ,..'" "'2'''~' 'i~~' ,.. '7i '~' 2: Ö ..... "'"''''4'''':'''''''5''' ''''1''2' (':'''2ïj''''.'''' ".,.... t':"'''4' .'", .""'"'''3.'':''' q" 3 ,..., , '..' i 0".' '4"¿ , ",.... '2' '5":""2 '~~r'"''.'''''.''''''''''' ..-."-....,,.. .~...'-"~.' .. .,-_....~... ~....,.......'...,~.'~~~...........,~..'~..~_......,.... ...--.,.'I"''''''''--'~.''...''''''.'~.~'~.''''''..' .....,.....~."... ...... ......"... '. .... , .' ,. ,...' ,.."...... ,.. .."..." ..,.. "...... ......., ..., ..~. ,.,., ..,." ,. ",.,". ,.,.. ."., ".'.. ..., '..~. ,.... ...., ,.....' .,.,. ~... ... .,...,,,, '.'''.. ...... .. "., , .,., "'. ,. ".'''. ...., ..", .'''.'. ._''''''~.'' ,~,. ".." .....,. , "..~".......,~...., .'." _m'... ..",............, ~, ." .'.'.'''''''''.'.'''. ,...~.". .....' .....,.., .". ..." ,.. ~ ...,,'~._. "".' ."~ '''''''.''''..'.'~.~'-''. ".~~...,,"- "'."'~" "...... ,.' .,. ..." "... ... ,." ~ .., ,.. .... .,.. ..,,, ., '" ,..' , ...,...... ,~",... .' ..." ". ' ,. ." ",..,~.""",." . ,. .." .... ,.. .'. .', ... ,''''. .. , . ".'. .... ... -. .... .. ....... .,. "..,.,...,.. '. ,,,,,.,,... '''' """ "'" '.' .. ..,. ",_. '.',,,. ",...' ,...... ,.., " ......,.", ......."...........~ ~, , ,.. '" "... ..,.,..'..'" ~ L'. G E ;" JAT~: 2/ Q/~5 TIM~: 10:54:34 JNION JIL CO.OF CALI~ORN;A K2U 23X-6 K:NAI GAS ~I~LJ KENAI ALASKA ~--_.-_._...-__.._--_._-_.. -. _.'-'-'--_._'~---''''-~'--'-'''-'._'--¥'-'''-'''--''-'-'-'..--'-'-."--'--- )EP~j..=.~=--" G R"-=.=~c-~T==--=~~~QI:!:{~:=~::~~-~~~~!!~=:=~_::~'~:ç'~.~~~~f.:'=~==~~~~:~',~::'~~-.::::,:=,~Q£f:[~~:~~', ::, :~'E:~~ç~~~_:_~::R":: -6c"" '.. :',,~ "_'=9~~~~~'''P-''''~~,~.~==~ ~i~ ....!,--,,,----~p l..._-~----,_..._..J~_...",----_..~~_!..I_"_...__--..,,--_ii...Y__._--_.,,,,--,",--;"'~~----_.__..._.._I...!....... --. ,,_.._n"'" ..,_tS....LÇ,..,--.." ........, ._9..~ ,~..,.. --"'-" , n q..j..~:!,.. ,.... ,_...... ,........_.,,_..._._.._!~_.. --..---",--.- ~\:'" ---_._:_~~~.._~-~.~~=~~~==_......=~:==-~~::~:,::::~~::='._:':=~~~~-===~~=~~=~.~~~:.~':~:~==:~~:---".,_..,: ','. ' '" ----....,- '..,,-' ,....".....-..,.-,..".......---, ._" -"--"-------,.-".--,----.- t.~ ð-:-=="~ ~ '.~:~~"'" '~5 . r¡:-'''---'-''-=¿-:'-2'6'''_''~~~~''~'~~:':;''='''1-~''':'' ~ 4'=:~~=~':~~~~~==-'~Õ-~ ;]'9'-----"--'"3-:"'2:1''' .", '-'''-5''''~' ~i4"'''--'2'''j''-:--r5'-''----- _.n--,____, ~-3ð-;--- 45..,90' :3 5:. -; 9-"-'-'-""""Z''':''1--9-''''''-'.!,i;--:-Õ-{''-- ''''-f~r:'õ-'r'-fr7-~'';-5--''''-'''''-'"''(f~''T1---'''''' "'4"'='-2"i--"'''''''''Š''~'~3.2'''''''''-''2'-f:-;i¡f''''--.., ,-........--.--- 4 3 ~'-J':'-''''-4'S:-7"7---''-31-. 2 0 ---"---'2"-:-~rõ'-'" '--5' S--:""2""5'''.-'''-'1''2''~--Ëft~--~f 3i'~ ""iT"'"'''''''-''(f~."ij''6''''' ,.' ""~'r~"'6'?"'" "'''1' Ö'.' 2 5'''' , 3':f:'-s- Ö'''''''''''--'''-''''.'''''-- .~--- "---"-"--,,,--,,,------,,,,-,,,,,,"""'----'''.'''''''---''-'-'-'----"'''-------''-''''''''''--'''''-----'''''''--''--''-''--'''-''---- , --,-- ;:'f;f] 5 o. , 42 ~ 37 ' 3 4 . G B 2 . 0 9 3 2 . 6 ., 1 2 . d 41 3 2 . 9 5 C . 0 6 3 . 1 2 ' 1 4 . 1 9 '3 4 . 1 9 'E 3 7 ,,"\ "'-'-1 -""-8--:-3''''-;--:: "3 6' ~1-";:':-"7--'~1-1'''-''-''''';--7''-'''-''-';::--O''----'-'1"''''''--'~-''¡''''''''1'''''-'3'-''''~'''--'''' i":;-'-"----'--""~"-""-¡';;'-"';:"".''''._' "''';:;---'''::';; li"'-"'"'-,--''',''''''''' -~- ~_.. "-"._-~'-;';¡"-"-7--1-- "-"""" ,.....'... .."..,..,,-.-- .'-<1- ,~i " ...' ., ".' ",'. " 'ö ,- . '+" b' ... . v 't ~, . oJ j :...i . 'J ~ ~ . '- ' . .) 1....' ..... "'. ; --4~-7:""~5"'¡;;'-'-.--'-1-6"----';;-?-"- --'7 ;'::----'-;:"-7---'--- ,.." ~"-' """1" "";:;;''''''''''' .... ..4-"'''9,'-''--2''-';-' .. ""'''1''''''-2'''''-''-;--¡-'''''-.1-''''3'''.'~ """'-'¿-'.;;'-' "'''.''''''''--''-¡:;-'''''o'''''' '7"'"'' ..,-..- "',;:;;;-'"'';';''"':''' ....... "-1""1"'" ...~. 9""",,,,' 3,,, .1" " ..,,_.,,¿"';:;:.. _.. "...,'" "...., , -...--_.."..",_. ,J:.)u. ,"+, .)¡;; ..;"., _.,) .,¡.~.,) .ö<+, ,,,...--' -.). 't.l.it, -~..- .,,.\.,.;;c D1.9_,~...,.,__"i!:..~._!_1'¿:,.:_,L}'4'-,!1.I_:.,__,_..~_!._t¿--,._..,~~-~."!,..t~,,....._J _?..~.JL~",.--.1,..I~_!,,_~--~..-- ",-,....Q" ,!.Q Z..., --..."" ",$.,!, ~ ,~.., "."..1..'1, ....,~..?". ",', "'" ?1. ,8! }..Q.., ,,,......--.., .,.. ,,,,,, "..' 4400. 46.33 32.y1 2.14 47.32 12.d4138.12 0.06 3.38 11.72 30.ò9 '';J , 1 "' I '1 .. 7 3 '", ., t1 ... 1 - . ,', "? ~ 1? ,.', 1 3,.., 7 .. --~-::------"---:::---1 0 --'-1-1-'--7"1--3' ~~---- ,~ "-t LJ. ,,+'.. ,. '. ',' ,::> .. c.;.Y' .: ,,') 40 ",' ,,' ~ . ð 4- ...,.. j u . U Ó ìj . I. .. U . '¡;", G ' 4"~"r:-:'-'''''-:-r=-9-4---3--2'.;§-2-'-'--''~;''~' '1" 4"""-"-"4"'6 -:91"""-' '--1-'~~;.":-:~-f" T"4'ë':""f~;"""""'"'' ':5": "-s 7.' ".. """""7" ~'''š',?'''' ,."., 1"1' "~""2:' '.'-'''3'''':-':''.'~''~;''''''''-' ",....,..,,,.....,,_......,,, T"-3-"¡;';----"--¡--'---'''Z-'''''''--''-'î-;:--''-:,,-''S'--'''''...-"."" "';;;,.., "'1"" "-4' ..' -.", """"I" ..4-'"'''' "-7'" "';':" "'''''' ".'1'" ','" "'þ"i.-'" '''1'''' '4"'.':S'" '" '~' 7' . '.. '''''-''.,~'''' .. Fi""'i"" ,'.."..," "'..;¡;.. ...". ~ ":;;;....' ", ""1"" ..1'''' ..... "'A "m -".' '"i'''1''''''' "- :;.-';;;::..-.......-.....-.......'" ,." ..... '.."..' j+'-+. W.'",+,(>,-,,-?,fW,",'..,,,,;¡:UII!V "G,.', '"t.). -",_oJ l..:::', ,.;.....:J 5.~.t.. .6-..;.;. II.' ;;"4'Z; 'ër:-"'--"5õ-~--r8~-'.-"3'-r:-';i9'."""""""'i'."i"'3"...... ""'it,,?':' ',61--'" .. '1' i "." ;;2'" "1" 3'8"~.1'6'" ., ,", 6 '.: Ö {., ", """ '" <~ ':'5Ö" '1'1" '~ "7 6 ' 31' '~. 35 ",,, .'" T-;--;:-~-"""-"--"ï-ï'7"""-1''''''::;'~:'--1---'''Q''--;- --"-,,, "'''''2' ""''''''''''1- ..,~' ""-"--";;:"3""""""~~;¡. .,. '""'''''1'''''''''2-''-''''''~~. ~ ."--,, ";t'''.~''1'''' "---;':"¡ """ "--,, "";i---- r: :::''''''''''''''' "'''ï.. '''' '1'" ..1. ".. ..'.... '1"'" -;:;'." -~:...'"¡''.''''''''''' ;:;. ; ""-..-:; ";;:.""-.' -'''''''- "''''''- :.. "+ :;¡ v . "+ "" ,..::: ,+" - ;::; '''.' ::;... ,.;:",; . ~ (1 ." .:) ""; -... " '.J , v . :.) . ~'J) '.J . w).) £~:~~~9~:~~:~~~~?J~"'T"~~~}I;"}~::=~:.:~:~~?~,,~:I~::~_..::.~~~~.:.;,:.~::r',,:::'~,,:':1','2 ,':~,.:8 ,"?:,~::,~j'.':I,'~:,,:;:'f:$.'., :" ..""" :,:.Þ:,:~::',Q,f" ,,,.' ::,,' '"",:,:,~,..' ~::~:§ ':, ", '",..j.~',:§' :ê:",""""',.2.. 5.,",~,')' ,4..:':",,,...,,,_.,,~ ~:'.:~~:.:~:~:..., '¡~, . ., 0 I 7 'I 1 " I "1 '9 1 ' .... 1" ¡:- ~ .. 1 1 - ~I .., 1 ~ I ? '.'1' :J 1 r: ....., " ,'" ~.., ?., - .,. !.,:!..L".~....!.._."-,..:~,....,,.~.._'!-,~---,,:!_-,-_!_,.....-"..,'-''',.......~,~, ",,¥. .., "JI;$, ~., ".,...., """,.?",Y ?, ..-'. ~~ ,:~",?_.., "" ~ ,~, "",.,~, ." "" ,) . ~ > ,,,,'!.. ~,,\i,t., .:~r.,,,!,,.(,r ."" "..'"'''' 4480. 43.03 52.80 1.76 63.80 13.48 125.13 0.05 19.29 13.06 53.68 .. -'" -...; ) . J 1 . , 1 -- 4. n. ,'",4 . l, I ".,7. '- 1 -' . ... 1 ,-, '-. . - '",': J,#I .... ~, ,,,', i. 1 " I ~... . .... ... ,", . . '" +600. 48.32 37.86 2.15 53.36 13.35 11 .12 0.04 5.06 .04 30.26 '''~4 .1-;':;""--'--:-¡-r;'~ '7 ,,-5'--:'~-73-7"-'-"-6--7--""-'.'---5'''''' ""1""-'1-"-." ""-'''''~';;:-''''''.i)"';''-. ".-- -1""'''i''''-''''''''1'-' 1'_'''.'''''';,'',;;.' if'.:i"';:-t"'" ." .... ,.. :O"-""""f" ::;)"'''''....., "-7'''''' ""., ~:r¡" ,,,..,....,,, '~. "". "~~"1""-'''''' """..¡:' .) ":":"":~":r" -, ."",.. ,. .,.,., ...,,,,,,,.,,....._, , ~ -.,; j .. ... .,.... . .f). ......~ .. ~.. , (.. . ", ..".' . U .." ....1 . J ,~."" . .'..J t. v'.. . " ..." '....'. WI ..,I '... ~ ..J- ~..... ...... ,-... ... . ;';-¿"~"~" '--:Çl~'-:'l"'1"'''''-'''--3''~':''3:':.r' ""'"z:'lj''' "')"~":"5Ç'" '''''r~~.'i2-''f3'''Z':'5:''''''-'''''J'':''G3' "2"~'i'7 ""1'Ö":6',?" ""3 1~'71 .. . ~63J., 46~~9, 3'3,.89 2.13 5~.11 13.4,6 132.~O 0.01 7.'8 9.53 31~79 :"6~5- ö":'" """-""4~:8 : 6 d~.:., ,',",lö :'.3ij---'---'-""~F':'" f"2"'"'''''' "4'5--:-'¡-5 --'-""-'''f:T~':? '''5'''- -'1'4'2 -:' '~5'Ü""''''''- ':"Ö '~-6'2" ...'..' ", ".' ';"~"5-'9"'''-'''' "1"'1'''':'.9''''9'' ...' """~3"1""~-.ii '7'------'''''''-''''''''--'''-----'-' ,"':j' ;;"'ð'''~' .''''''''-~-~;':-~rð---''-':''1'''':''i ~~ ",,,,,,,,, ," ".2'~ '1"";' '''4' '7 ~'" "4 š" "", '1 ",2'~ .':3 '3" "", .,' 1'" ,~"~'14 -, '., '" "':;' ~ ", :~' ¿ , ' "¿'~ 'L' 3' "9"~'¿S"''''3'(} ':-- 2:' ':~,' ",... "," ,..",.",,,'., ,"" .,. ..-:-7 "'''----T-'-9~-'' 7-----'.-::¡-7-".--"'1' ". ';:,¡.,"---.., ".""-;;'''''' '-1'" -.¿-"...---....' ï' "'T."" -'-'Q-'7""-"-. ""-""',.-- j'''''''-':;-;'¡'--'1'' --1--4-'''.''--:;' "¿ ,.--, ".,., '. '~. "":';;;"c---- '._'''''''-.. .-,;;: "-.';:;.".";:;;". '.,,_. ,....,... ';:;:;... -";;)'ë"."-""'''-';:;'':;;,'-"-;~-'~.'' '''-'''''''''''--'''' ........, ""--' . ó- 'J. . '* ..é ..:.:J , . '.. : ~". r:....~ .... '+ . . (., . (=...; I. ,.f ..' U . l} ,; Y . ,-1 ..~.' ':-' . "'1 .:' .:J :.J - u. ¡:) )~ "Q-o""--"-"--'-'--ï1i-~-¡i":-;'--"""'''.'f-6''-'. "'--'~-";":""._' ", .""'."".'-2"-':"" . ..1' .... 4'"'' ,.., '." ¡"'"j,"-'"'';:''' ';:" '''-''''''''''1''.''3'''-'''''-'' .4'-' '~~. ---'''-;;.-1"'''-''1''''''''.'-'¡'.-:;;¡'''''''''' ".....'" ",;;.'''.' '''0':'- f""""'" ..... '7 .."... ...:;;;:" F. ".... ,,,.. """;;.,"" "'¡:.;.' moo ,...- ::j"'ö "..."-¡--;;;. .,.".........- ..""-'"'''''' "'.-"'''---' ",.' '.' ..t4...,'..0.,,' .- '."+'-+ "'"'" foI.-...,,,.)' III'.... ¡ .:,}¡ ,w. I.." i .¿>..J 'fl.,,,..'; ;_. .,,:...) -;;---1" ¡.;; """."".-7"!-9'~4.--;~--"":"'''~7-:--:~.Q''''''. "'--"'-,"'---',"'7f"" .'"'.---:;.'''/'''--''' 7"';;ï"'-'" -"'-1"~'''.' --'5'1'" ,.. '1";;;;"~-'" i' ";':"'''' .'....' oo - :J.""'"'' '~)".'i"""""'" "'" "" ,"'''' "i..;. ".",,,,.. ". --Q:' ....,..:~. .¿¡..'...." -- '''S'';; ....'., "';;-7"'- "'''........_'--:''''..''''....._..._.._..~- ( '.J III "+,. '.. .; þ. .., " ... .... ,.;' ) "+ . , L .... . - , J t." '" '+ " ~ . l .:.¡. , .. ~'!' .. . ., '." .... '). .. 'i~tÖ='" '"''''46'':''2'ä'''''-'3''4'~'''41''''' "i'~' 27' '53. '16 " "fj'~1'¿'1 Ö b~ 1'~i Ò ~ 1 b' ' "9~ 't3 9'~i5 "" "2' 3:''''6'6.'' "-"oo" .."" -"7'--3'-J';.~--:--ï.-::r- ') ,"') -7-:-¿-"";' -;;.... ""-"-""""? ""''':i-- "j"'" ,.--." ':':'''í'' ""''''ï::'' '2""-' ...".".. .001-- "~'''--'':';:' '''~'.'''''''1'';;:';''n ".---" ì'-'~¡;""'.--' ,. ..," ":~." ". ';"-1"""""- ""'''j1: -...... ;.,":;¿-- ..., "'''''1' "~;;';"--" ::;'0"'"'' ""."1"'''''5' ~_.-:~..;:~ ,,- --"-'''-'' "-"-"""'" ...,,' ""--.." , ,,'. ... ..:> 8: Ii:. "" :>., . '.'''' - . -' '.,. .~ "+ or ...... .' . -..J .... . V .... .. .0.+ .) .... I . .., . ~ ,:,) V . ,.' . . . ", ü....!. ", ... ..." .., ",,,,,.. , '('''~'': ...~" ....)' š'~"'~r ~r'''''''' '~33'~". 2';"".' ":¿~i6 ' '3¿ ~" 3'¿- "r'~:}?'''' frj)' ~'" ~T .'"'' '~: '~ 1'2"'''''' ...¿ ~ :5'1'" ,',' '3 '~2~' "2:3. '.:; ? ' . ~f~~~=~l~~if¡r~~i~~~¡i~=~~ 7'9"5-:'''''''.'.'''''-~Ç2-~''':2""'7''.'''''--4--~l''~-''rij' ""-"".'''~'''''~'''T7' '.......... "7' ',ç.""ö" ~... ,,' '''1' 4-.~' '9 ').". ... l' 5'1' :" Ö".;ç ..... '.. ",,'.. ö '~'1:3 "... ,""'" ''''''''7'~' '2":3' ...",." '."""9":'j~"3" "'''''''1'''t:,''~'6''-7''''''.'.'''---''-'-''.''"--- -""'-j """'~ ..n. . ...... .... ""--'-"""'''-''''-~--''- ..~-...~......., ..."~ ..~..._..._. ....A..__'."-'.'"-''' ._~.....¥"..-¥..... -."." .....¥"... '¥"'" . ~ ...". .' 'n,. '" ~ 'W"" ,...-...... ...~.. ,". . -,,"'¥'" ... "..~.. ... "._n ..'.... ". ... ".... . . " .."n,..' . ~_.. . '" --. .".. ,'n . ,"....' ....... 'M. .. ....... .., ........ . .... ..... ... ....... ..... . ...... "..'..~' . ..,..'" ".'~"..... ..." - ."",.., .... ......... " ~""-"'.."'.". "'...-.. ....'"'''' ......... .. ...,........ ...""'..."".""""""". ............ ..... . . ""'''''''' ..... . .... ....,..... .'." .""". ...........-...".... ..............-"..... R_'~..'~'''....'''''''''''''''''.'''''''''''R''''.''.''''''.'''''.'''.'..~''''''''''''.'...'.'''''''..'.'''''' ......... ,...." ......,.... ... .... '.'R'''.'.'.'.... .................,. ..........~...... .............. . . '..., - ...", .....".. ..' ..,...... .... ..... ..,.. .... ..... ... """.. ".. ..., .. ... ..~ ".. .... ..... . ... ... .. ........... . ... '.' .. '.'.'" "'."""""_'R'.'~"" .... ........... . "'.". ..... .. .......... .... "..""".,., ."""" ... ..... . .... '.'" .....''''' . . .....-.." ..'~'. .. ...... ..... . .......... ." .. ....." ............~ PAGE 6 )ATE: 2/ °/85 T¡~~: 10:54:34 U í~ I ü N 'J I L C:). 0 t: C.A L : FeR N : .~ K 3- U 2 3 X - 6 KENAI GAS ~I~LD KENAI ALASKA ~---_.__.. ""---" .R.""'-'"''''''-'-.--¥-'''------'--''¥-'''--''¥--'''_..._......-......_..~_..,'..-~"._._..._-_.._._._.._- . .."'-'."'-'-'--"-'-'--- ~'~" . --"-~---'------_.~---...---...._......_n .__'_~"'_-_"'_'__'-.-'_-'_-'-"'-'_._'-"-"'-'-" .._.R..,"..-.." -'---_._'-~'_._' ~---_.....__.__.._.~_._.-.__._..._.,_.- .--......... ..n.' _..- _.. "._...-_.. "'."'--"."'.. ......- ..n..,.. n ,'n -."-'0_-".-- ,,--'.-"-----' )E~Trl GP CN J=N SP4 CAL3 AC CORP ~MLL ~~OC JENP ~r ':.-=~- .. ,[\'p'!-" -~.~~_--L_,-~§. Tç..._~~~~~.=~M~=-~=--==-~~Ï~~-=:=:=~~C[=~~=:.~~' ~~[[::,:=-~~.... :'. _,2.tjt:!,._...._..........._.Q,I."1..~~...,_..--,----..,--".._---_:}~--==== !L, " ' ,¡".::,~, :,\,:;:.~::" .:' -, :":' -.-----..---.----,,-..-,----,...,-.-----.------..-..,,-----..,--..---,,,o_,,"--,-.._._--_m._,_--"""'" .. "'-"-"'---""""-"'---''''------.-,-----.-.-,- ~'~J O~'- "6;:;'~'!.';~'~'~;~- 2 -. ~L~--=:il--:]"ITQ1~=--=LÞY-=='~:-~=~-=-== :(Ì+81 0 . ;,4..:1'8" ';'J.$ 2' 1 . a 7 81. 09 1 5 . 20 1 21 . 34 J. 0 Q 6 . 74 9. 69 47. 46 ' ~ . .. ----_"___'0__" .. --..,'.. ,..-.----..-----,--....--.-,--.,--"....--,-"-...-,,.-.--.------,....,-".......--,_.." "-"".' .. ..,,- ..'- ...... '-'.--..",--..". ........ _..,,00.. ..-..... -..--....-... ,.. ..'oo,...-...., ,,-oo....., .....-..."...-....,--, ..... ... ......."...-----..-- 4~~D '9 QO '~47 ~'7 77 ~^ 14 nz 1°7 96 ~ 11 3 4~ . Qn '3 11 ¡:,ã 3 {) ': ' ,', 56'.':"'b':j-.::,:: '",' ',~. ~.''': ,'Q'1~,_n ._, ,~..:?:".i.g,.,-=:~j".:...~-¡_..."_,,.._1..1_:~ž.~ê~:~J~tQ~:~~:§'~",~:,=~~=:jt~~=:~::::::=~4':~:?~-::~:':,:,,'=',',::~-,:':~'h.~~~:~~~:?~~~~,~1, ,~::=~~~'=== !~,~" ~ ~': '~~:~~,:"':'~ ~"'.'" ,.,,:~~~~~_t-===!_:..l~~:.:==~~f~::~:~~==~-,,~..;,Í~~:J=~,..~:~i~~:-,~,".-,:~..~:,':!~.:~~B1:=:::,:::..,::'J,~_:,&~~:~~'::=::::~,',::,~î:ä-,','-:",''':'~'l~~~g~~::=::~.~:~::~,:=~~~::.:~. i§,_<:_O_.!-- 4 4 . 2 6 3 3 . 5 6 _...__R.!.".1...,,~_..,_... ,...?~--!..~.2,,,.. ._..,_...1_,~_!.,.?..é _.,.J....~,_?o,.'!..., .1",.2 ,.".....,....Q.""!""Q..,f..,...,, ,.,.. ,.._"z..~"..:?".4_....._"-,, ,tf.._~.. -9.~.~.. ....,.IQ...!I,,_9 3__...",... ..,..--.........."..,.. ~" $ '7. 0 . ',-~ 4 9:.4 ~:..~.:~,-~?I.._,,~--~,_......? -,~ JJ- _'''''0'' ?J,,,.~ -~..Q.........,J_?_.!".l...9,,_J_,_f.~,:!L~.:?..- ...... ""Q..,~"Q..?"...."-"--...,,-~,....,,~_J,--,,,,,..1..~, ,." ,?â...., "'~, ,~.~..,,~~Z..,,--, ..,... ".", ..,0_'''''', 4 8 8 Ü . 45 . 4 9 3 6. 5 1 2 . 1 5 "'- 5 3, . 4 Q.._-..11 . :3 L..1~~! 5 3 0 . 0 ,f__J3.:...!..~1J-!-?_Z- 3 9 .. ~1......._,--- 4 '8 '!..Q..!.____.:.~;i!. 4 7._,~ ' 3 0 '. J~2 ',~-"?_~J.._?."--._._...;tf,,_!,,,~--~-,,,_...--..,l.f,.!,_:~4__,,1 f,..?,,!..:L1..,,_._.. ,...,!;),,,,!...irt,,._--.,..,...7..,!".J_, f :... ., ,. ..JJ..~....Z,.?.."",,-- .",~,Q..,!!.J..~,:~."" '''''-'''''--'_''''0''''-- 492D. 45.38 35.16 2._lL.-.2.L.59_--_1f_!ß4 .113.~f...__- ,,0.03 6.36 ,,10.61_~e.1.g ?~-,9.~?Q~-,.._~4..Z:.:~2_.d.~"_~_~~1.~~"Þ..:~L...,,.._',,-,...?...!.,.~... , , ., 5..4 ,.,! ":;~...?,,..,...,...,.J. ,f ..!"þ.,-:! ",."..1.? ,:Þ ,!'....Þ.,,-~, ,"""" ... "Q,,~, 0, ? ",,,..., ,) ",.."7..3.",,. " ,..,. ,5,~? 9."""", , ,2, ~"',!_,.?,.? .,,,,--,,.,, " .."" ,,' .."....", 4960. 43.67 27.31 2.10 48.98 12.85 122.75 0.01 7.11 10.77 33.22 ¡-ffõ':-'----"4 '-0' ~' 7'-3:,-ë-"~.r3-~-f:f-o.-"-"-"~\-~"oo1"~r""" '-6-5::~8à"'"'' '.'--r~r:"'-§"¡-'''1''r<T~-'?''3''-'.'''''''''''Ö'='''Ö "2:"""'''''''''''''.4 .'~'.ii--'''''''''-- "";Ç~'''ä''2'''''''''.j''ï''-~''.~f2''''--' ..".."..""-.-,.-"-,,.-.,, 1~~fii~di~+1~~~=!t'l~~f~;~~'~~~îI;Í,~£i?~~~i~:~-:~'~¡,;":~;~Íill~~~!~~-~~~~ <)7..... i.t",,-,41., -(.~,,",,,...,1 '....',.'''+, ,....1.6.... 1"N.':f~ 1,11.. '.N' O.U,-, ......1" ,....eo --' ~,,'t......~ ;'~:97J . '''''''--.4''9:-;it?~'':N--'1¿;~:~-~'1'''''''''''''.'''''' "'~2":"'2"'7"-""--')'2":"1'" 2"..""''''--''l'''T:-'3'1''''''-'l''Ö.~Ç:''9'3'''''''''''''''Õ'':'"Ô''~''' ..,., ,., ,...,.. ~ ,.~ '4 "Ö.' ,., , ..... ,,' "7' '~., '2"7" ..,..' ""¿'i':,,:¿ "t:-- ,,, ".-:'....."_...",...."...,""..,,... -"rëfö ":......... '5"'4:':""6"'2"''''''''''''''3"'8'- :91] .rf"''''''''4'-5''~''1''9''''''''1''''3''=''''5''f'''''.1''Ö6~ 7'7"""'0 "1'0 :8 Õ:9. 24 26":"'63' "",,,,,""""'-"""'" :11''tf:'~'''''-''4~5~ ~',5'¡-"~'" 415':"5 ";-"--''''''''--2'''':'''3'''4''''.'''''''''''4''7' '~.. '~"'f5"""""""f3"-:" "i'¿" ':..."'" "=i"¿ "~ "9"~r" ..,'",,' ,,' \j"~'l'c" , 7" '~" s'Ö""''''''''''1''1--:'''i-Ž-"'''''''''-i'?:-:'',!j'''')'''-- ,---,..."..._,.,. ,',' ,,,. '. _.f"¿"c":"""""'."")j'--:'.'6'6"""32''':':~i'''.'''''¿-='S4"'4'0 ~'6¡'9' "''''1'''2:''9'¿- 1'c)"¡;:'z'f ",," "';5":';]:3" '1 ¿'~2'4 2t¡'.S ,f¡ '1'd'''~'i''; """'"'' 1;C. 5G.7~ 46.41 2.34 66.64 13.56 112.91 0.08 7.34 8.S8 13.62 -1--i,-F;:--:---.--t:;-r~~-~.r"--7 ¡r:-"'''''''' "'5'''--''-.~'''r:'''""'''.''''¡:;'''1.'''''''''''''Q'-c.:' .....".. '1"-;';;'-"'''''1'''''Ç''''1-'''r;''(j' "''''1' ~ ,,' ,"''''''''~''''-¡;;,;:r''-'''.'''-j:'''''-;;¡''1' """"-""'''1'';;;' """:1"";5"'" "''''''''1''-:~''~ .''',:~'.¿''-'''''''''' """"",,'-""--"""'"'' J W . ~ '* . ~. I o":,, :.,,¡ ::,). . J ~. . ..<' .~.I ..,' ,-" . "w .~ 'O)." \..' :-. ì .J' ...J . v . ....; * ~ I tJ . =-- ~,) ."t . -- :J l"ï;"j"~ '" "~":"~":~i'5"""""",3"i~'"'2'~''' .J;"¿~:.,3 j '''13 ":2 ..~, ""~"":j:~~. "~;"':S:"j6' "12. ?~:.. 'i7~'?s' "'1 (='~;'1 "oo ~f"~7-ër:'--'"'' '''¡~-~~66-.::''''-'''3'~6' :-7"3"-""""''''''2'';''3'6''.-'''-.''6-:~r:''"f':3''''''''''''''-'f"3'.:"~çr--.'-"" 78',~"4'1""-""'" "" 'Ö':"Ü'š ."..,--... '4":'"91''' "', '1" ~f~"'5 4'" .. "'''fi::4''i~''.'''''''''''''''-'''--''-:''-'--'-~ 1 äj:" '.""'~--~r:":rö".' '"''4""2':'.''=/9'''.'.''' "2.'~"45'" 0j"~:> 7' ""1'3':4 '1'" ''152 '.2.-+ ' " ò ~' t; "'" 7'''~ 8 3 ' E, . Ò 3 "1'5 ':"'t':s" ,'.. ".." l":rer:'-"-"""':rçf.:-r9""'''.''-4'~r:'''3'Ö''''''''''''''''~:':' '1"") ."'., """,; '1-~"'2'~5-""'''''1'.)' '''~''t:;.''.--'f?f5''~'''~~ç' ""'" "--"Ö"~"'Ö3--"'''''.'''''7-': "1"6 ",.," ","Ö ,. :'4'3" """"".~r5':""tj"Ö' ,""". ,.."...".....".,......"..,,-..,. 2'j.Y: 47~"'?~'" ""3'1"'".'::'4''''''' ";2.3~' 4'~' ~'''s61'''¿''~}r '?'~"..~:~ ~~" J e Cì 57. ¿i "f1. '~2'13~' 5':~:"""'"'''''''''' 2'rÕ""':'"--'''''''-'5'j''~.-'7:S''--~--'4';~':-ë'~T-''''-'-'''"".z":""rS"-""""-3"Šr;","-Î)'" ',.. .." "f~-""~ '1""ç ""'''''?"1''6''':'''9' 2"" ,., "."" "5' :'" cf~r"""" "":5' ~"2 ¿"""""''',o''':''š' )'''..-'''.. ft:~"<Ç2-. '.''''''''''''-''''''''_'''''_'0..",_.-- '2"2'Ö:"4"¿''':2-5''''-''''''''4''i5'~'3i 2 ~j 4' '4¿ '.1 '2" ".1 j~' 61 b 2."6 j' """Ö. 1 5"14 ~" 2"3""2 5 . 51'1 9 :"Õ 5 "..,,,.. 2-3'Õ-:'.'''''-''-''''š-~r:-~'3',Š-''''-'''--''~r4.-:'''''~3''4-' '.'''''.''''''2':' '4"1""""""" '3","~' 9"b""""-'"'T'S:''4""3''''''' "1"5"4 '":--2;'''Ö'':''''''''''' ''";5'''':' l' 'õ"'"" ..' '1'2' '~"6'7 ,.- .,. .1'1"'~' "Ö 3' ",,' '''.''1''4 .t4"''--'' "'''''''--'''''''''''''-''''--'''.. fit;~~~t~¡f~~~:~f~~tÍ-~=U-~~;~~~ -:~II~~]!~~~:!i--.~.~.~:~J~'~:'~I:¡~.'."..' ._I~-:.~~.~'--nf~-f- ....-. - .-~=l DAG: 7 JAT~: 21 9/9~ TIM~: 10:54:34 UNION JIL CC.O= :CLIFO~N!A K3U 23X-6 K2NA: GAS PI:LD ~=~A~ ALASKA k. . - ;, .. . ~.__...._--_.__.~_._.._._......:..-_-.:-._--_.-.._.._-_._~..._..__.. .---~-- ..--...-....,.- --'-------"- .-..--"..--".' .--.-".. ..._.a..." .... ..0 ..... . ....-_..._, ,-,-"",'"-.'--'-'--.'.-- .-..--. --...'. .._a".... "'_.0.. .'m..'. ...--.. ," - _on'. "--""---'-." "....-"" -.'.' .__n.."'_--. ~..._.. ..u .. .---...-..'.__0...__.". )E~TH GR eN O~N SP4 CAL3 AC :ORR RMlL RFOC JENP ff:-- ._._.._"'_...!~! -: "~~._~~._n.. ......,-",~~t. ,~~==~:~~~~EfŸ~.:_~~=~===~=I~~=~~~,=t}._-===~-=-~-,~~~.~==[8,E:~==~~:~:'~Q'~~~1.. ,_.. n"__~'~::==--;.--,,-== ~~, \ ----.---...--..------.---...--- ._.. ......-..--.....---.-..--..--' -_.. ._-_.~.~-_._.-._...._..._..._..__..._....-.._.'_'_A~__'--'.~.'----_.._....'~.'.. ..... ".A.. '.. .. ... .....-.-. .-..-...- --_.__...-._._---~- l~:' -,,-,-_.._,----_.~~......:..__.......:-.:.~~,~------..,,_..._,,- "", .--..........-,,-.....- ""-"----"'---'---'-'''----' .. . ..",'" ... --_..._-"_..._,,~===--_..._-_..,-,--,,-_..,,,..- ---'-"---"'--'''-'----'''-''--''--- -....-..--. '--""""--- 5230. 52.02 31.14 2.37 67.29 12.97 107.94 0.05 7.00 8.03 16.96 !'29û.41.~4 l1.~9~""-2~33--5-2.S912.Q5' 1Õ1.49 0.05 "15.71 31.0ó 19.4", , 5' 3 "õ"Õ-:'------"'-'5-'---:-Ô9--4;5":'-~3--3""-'."'''--r:--3'O--''''-"''''5''Z;':6'g-''--''--';r3' -~--2'4''''-''rð''1-: ""3"-5-'''' ., "'''''''''o'':''''Ö'''s' ,," ''''1'-8''-~'''6'' ,6' "m'~"'i:'"4- Ö ...'" " i 1" ~-' 2'5"'"'''---'''''-''-----''' ~: 31 o. . 4 4:' ~ ;2'1': ',: ¡..O~"'21 ' ' 2. 3 7 5 4 . 1 7 1 3 . 4 6 9 5 . O;i 0 . 0 '9 9 . 3 9 1 :. . 6:f 1 7" 2 1 5 3-Ž-0;---47--:-3" 5 3'8-. C 4--"---¿-:-~fl"'''--'f2'''~''¡;f''-''''''''1''-~f~'.-7 9'.""'''''S)'{:''1' '3"""'''''''''''6':'0 '7'.' .._, ... "'7": '4'''3''''''''''''''-'''7 :'69' "'''''17''':''1''''';'''''.''''''''--''''''-''-'''----'' :$,' 3 3 0 . ~-.. 5 6. l4.,:",' ," 3.:8. '. '9 ï":-~':"'-'-2':"'Z"'1:---"-f2:"-~r8-'---1 3 .8"3'-' '-1"{54 ':-'1--'Š"~ ------'- (j":- Ö";;('''''--'-'6'''~-'1'1-'''''' ,....' '--"5' :--3"6-'-"'--1"'4'-:-7-7"-----'---------- -5 ~,,~Q~==f;~-ž-7'-"5'[~~Q====[~~f~:~=~~=~:~..~,:.~~~I.:~~~j~~~~~~Q'-:;~~~,~~'-~I~:';':,~~9.~:~',:,~:~~~:..9...'~=Q],-..,:~~~~:.-":,.~:,--;,,,,?t..'~,:-:'-=f~--':,;',:9'~.:".''-'...}.:?~'-!~"é.-'~,,~~:'~:~,':~,::.:~:~..:.-..~~~~~ }S'350. ..5'6~'1:,ti'.3',4:.'53 "2.40,' 65.'1,1 1,3.59 Q5.,39 0.08 11.97 1G.69 15'.38 ' ,5 3 6Cr:--'6'Õ.-:TI"'~" 3 8:45'''''.'''''-.''--2-~-4-1--'''-''-6-2-~-3'~9''-'-'-r~f:--5'7 "-"'rÕ-5--~-'2'3.''''''''''''Q''-:'Ö'''9'''' "-- ,,'... '7':'55'" ",." "" '''9'' ~'''3'1'''' " ""1" 4 ":"";-0"."'" "'"'''''''' ""........... , x-----"--_..._'_.""~_.. _.."--~..."---.._-_.__."..__.._....-.._--,-_._.,-".-..-....,,,,-,-,,..."".-,-,-.., "..--.... "........ "''''.. ........,_..., ......"'" ., "-""'"''-''' .......... .......... ............... ............ "" , ..,,-- """'''''.-........ """'oO "'.., ..' "'''..---......-.........., '...... """--"",-"-",,.,, ~Þ:',3 70. '4 8'. 3. $' '.. "k4 -: 5 :5,' '2'. 4.1, 7 5,.. 5 7 1 3 . 6 5 9 7 . 7::; C . 1 0 4 . 61.. 3 . ? 1 1 4. 5 1 , 53 s'f:--Š-7 :6~9~ 9 . 21 ----Z;-¡':-'--"'--"""'¿'T":"S"6''''''''''''''1''3''':''''s'i''''-'1'"ëi'2"~"7-ä'"'' '-"""'''èf~':-ô"9-'"'.'''''''''-''9''''~'-fO'''' ,.., '" 'ri>?3 ,., .", "'"'4'':'-7''0''''-''''''''''-''-'---''.''''' 5.3'90,. ,4S~,7::$.',:", ,3.t.",.,Q, ,2.4'.7 74.03 -13..,3""2 1J9.27 0.09 5.9) ""-"9.0310-:"72 5-4-ð"3-'~----:g"':'.;~'6--3~.=-"9'75'---'''''''''''?''''=-~~'.:~,""---''''5'':5'''~T',~' "."'1,~"~"?'~ ''''''1'' j L ~. ':;,':j'"'' ,', "":5':'5;" '-~"".'?"~ "'ο".~ 5 "1 i :..;:~.....".." .....,,'" l£I~~-'.~-::.~:~~~:~,=-~~?~-=,~~=}~f~~'!.[.~:'~:':'~:-:~-";".-'I~I::,:':,::',,:,:'-2"?::;_4':~--~:.::~,,': ,I~:~,,~:~:,I.:?..:~:~1'~?.~;::;,~-~:'::~"",.:::,~-', ':',:"9:,:~':"Ç:'2''':'' "."','r'1":':ë,'''~:-::'' """.2 "4 ..,,~ '3''1. '" "-..,1, ',~':-~"'?~'-§", ,," ':",,":::::,,~"~:.~-'::"',~'- W~~~E=tttjI~!t~jì~!tjl~~~:~~--:~t~t: ::~tlt~:_~tU:u_t~:lf__~_:~=~:= $A'50.' 45j6'6',3'g'~6,6 ,':- 2'.41 42.'67 14.J2103.23 0.33 7.22 Q.';8 14.66 ' 5 4-;;-E::"-""'''''-56-:.3~;-'''''''''_'''''_C-_'"'f&¥~\Ú::si ':"3',; """'.'1'~~':".'6T" ...., "1"'~"~''''~':''~.''''';; ": '¿' ~ '1"'~'" ..,.. ,j'.",.:': .~'"'' "¿..~ , "":, , , '1' 5"~' ~ 5'" '17''': 'f:,""--~:" ", ,,,.., ,.. oJ ¿ .,..... . -,. ... ,.' .~ . ' \..; "" . - , ..) -' . ,,'; ,~ 1 :,.,. ,. ..,¡ "~ 1 ~ ...J . ,,'" '''; ""." ~J1." t ¿ , :. oj V ... "I . ) 7 ,- 1 . 7 ,.. ..---,,--,,--.. -"._- """-"--'--'-'--'-.~"'----- ' .%, " ¥ ---. "..... .-..". '" ....' ...... ,"'''' '''-'''-.......--....-' - ''''-''"..'' ....."...." ",.. ".,., ;;,50. ,54"~','3'6,.':",,'.4t.'l9 ' ,2,.33 51.7,5 13.7,.~, 1~9.3ïJ "\~'j.O'S 9.1510.52 16.'25, r5"'~rÖ':-"""""'''''Š-9-:9-7-'-''''''-ri:' 8""'5"'"''''''''''-2'':''':3''5''''' """~f9":"54"" . ""'1' 3"'~'4'~f'" ""f'Ö3:~57"" '"'.,, ", '" 6 '~"1 '9" , '''7 '. 3',8' "'''16' ~ "5 '1" " "1'8':"0'7'" '"'''' ",,,..,,- "..,,, [2,l,-'9~,~=-':-'~=:,?_..?,~~=tQ= - ',?,§~=?~::~.'_."~''':'...:.~~:;'~:3~?-:'~'''-''~~',:?'~~~'-~~',?..§,-':'-,".-':::I.J,:;~4':~, '~,~':':~::-~,~::;~',:r;~','.' ''''-''::::'::'',~''~: 1::,1::',-",':":",",:,,::",:ß.'~'~,,"'?...f"-""':":":.t",~. ,;"'$..'~':',',-"..,"".I',:r....;.....§}:'-:,-::.,~"-:''''''~:..'':.:'-'-'~"'-'" ~...?_~~,.9....~.._,,__,,___2 ,,?,,"~S ~--_._} 7_~,,-9...~-- ..,.....,...?.. ~..,,?,2--_- -- ...,?_.?"..,~... J"l...,,--_, 1. ..?." ~....~".9.".., J..1"J".~ ,.Q..?"............,..,-Q.._~.--tç. ,,, ,......' ...,.:3....~,}...~, '" ..,J,~_.~,,--.? _.(~- ......, . J. ~,,!-- 9...1........,...._-"....,."" "" --'" ....- ¡;) 9 0 ~ ' 5 8- ". 8 4, ' :'" ,:)'8 . -5 4' ',? . 3' 8 4 1 ..-3 9 ,1' ::. '. D 5' 9 :; . 5 8 (; ~ 0 B 3 - ~ 1 1 1 .. 3 2 1 6 ~ ) 0 ' ÇKÖ'6--~'-""""'Š-'7":""5"Õ"'-""""3'3"':'-5'tf'" '.""2 ~j é"-"'''''''2.'2-'~'-f4''-''-'''r3''~'2''3''.''1'6:f:'3''i''''''''Õ':'69'.' '7.3'8" ".9'~6'8'''16': '3'6' ,', ."., '" .,..,,"'..,,' ". ~'¡-"1.' --:-O--'-'---¿-~'-:-'~"l":"'--'''''4'''-' ~""""1' ,''1 -.- ."-"-'-"-;':'-"''''';-'';''¡----.'.''-'-7-- ;;;.'--'''7-'','-'''-.''~''f; -..., -;:'-¿;-----Ã."';;¡-"1-''''-'' ;;,.- ;;;..... ".. ", ";;;;'''- "'(1"';~" ,.....-- ....;~.. "'"9''''' :¡"".."..",. .,. ";"..., ."Si"'i' .... """1' '''ï'''''.''''''0.' ..':-,..... "........~..,. -.....".... .., .".. .... !. "'"' , .. .,"" , . '.G '+'.. :, '-¡:;:'., ,v.' It. . ...' ,I ,,;. I.. '.,) . (;) 0 t:;.: ..J:> :..; . \'o' ;::;. )" ..' 0 . ..' "... , ,+"", ..'~ "'+ "6'30'. "')ait'S,6"",'37'."~,'1 2.42 62.99 l4.1g' ':;9.28 C.1':) 7.Q3 7.,;-9 13.94, ' 6,50'. ,5:4'.'1'6", '40',,',2'1' 2.35 67.12 13.71 1'a1.~4 0.17 5.35 8.5H 13'i"40 . " , 670., 5~ì'.'2.1 . 34~84', '2.3;3 48'.10 14.40 97.36 O.D? 6.58 1Q.J7 1~",.,t7 ' -;s""àÖ~ ""'"''4''7''':''4'''8'''''''''-3".8''':''8'3''''''''' "i~"42'if:"7 '6' ""14'~ '6Ò'''9'à'~'29' 'Ö'~Ö 6" 5'~'r6""" 'Ëf:1"¿" "1 r:-ifZ"-'" """,,,,,,,"'"'''''''''' ~lElli~f:.I~~fr-IfIE]IIri!_EH~~J~~r~J~JI==~IEJ.F.~ff=:~== 710. ;1 ~4,5' ",47.6.5 ,2.:')0 71.15 14..5.5 1DB.21 0.0<5 7.J9 8.65 21'~:42 ' '7'2C..~m.'''5 ~'~'~'7"""-""3'i~"4 ¿'" '''Oo' '" ~"~"~' J' ""40 '="1'E" "f4'~"11'" "'" ç'j'''. :; :;" , 'Ö.ëE ""1" Ö"~ 3 5" 1'2.' if' "1 Ç:"'3'3' ',""....,,'" 7"3'tT:''''.'''''''',''é5'':-2;4---'-'':'''4''.i''':''2'5'''''''''''''-'--'''~~"~."I5"--""----7";?":"äf """".--f4"~"~~";'''''-''''- '9"¿""'.'''';çr.'''''' ".. 'j' ~'/j9.'" .. "",. '"6'''~''2''':3''' ,'," ..'.. '¿:"7"¿" ""''''1' ~;:'::::;Ö'5"" "-"""".'.-"""-"""..,.-... "7'4'6 "~" ''''3'';2'':''"7'8' '''-''-z;''{r~-'9-1'' ".." ""'¿"'~"'3'9." '" 6 ä':'9"~' ""14"~' '4'0 '1'0 ,3'~"4Ö" " Ö .'69" '" 4. 2 ¿.'" "6~'9 4" '1'6'~""Ù1'" .."""'''" ",.",.."", --'"'''''''' ~,-,?:'~q~.;,':~.~~~:,~~?:::~,:~~''-~''l'-~~,~'-.'~,-~'''~.''rr"'''-'.'' ,."'''~~".~ '~~'?--:""'" ".~"',~" '~"'q~'''_..'''''.''1'.~''~'' j ':4"""",","q'.'? ,,~"'1,'1, "" '.." ,-'" ". :5 '~..'1"3' .:.... "'" ,'," ~ ,'; "~-q" " ... "'..~,.;,..~. ~t, ""'.,, i ~.,:;-'~?!~'.':'" '''.--''':..':,'''''':'-'~.''~'':=:,' --~....~....... .......~. ..... ,. ....,._,.,,,,,,,,,,,,,..,-,-,~,,,-,,,,.,,,.,,,,,,,.,.,,,,,,,,,,,,.,,,,.. "'.'...........--.......-......... . ....,.... ....."...... ..., ... ......,,,,. ...... ........ .'. ... ....~ ........ .'..".'" ,,,. ..'.... ... ........ ....-........ .... ... ....... "... "'...¥" ....... ......... .R................" .....R...... .. . ....... ".'..'..'''''.' ..... .. .... .'..'''' ........ . ..... ..." ...". .. ... .." "",,,,,,.,.,,,.,~,,._., ...." "'oO....... "'n......................""''''''''''''''''...'''''''' ",'n......"'....... ""'..''''" ""'".....""...'" .""". ..-. ....~....... ".""'" ".",-..",. ,.,,,,.,,.-.,-.,,,, ...._...,,~. .'''''''' ~-'.- .""'" .'''..n. . . .......... "'no..."'-. ""'.."". ..... ""'..,..... .... ..,.... ..., ........... . . .............. ..............,..... .. ,. ""..' .... ............ .............. . ".... ".." '.". ................. ...._... ... .,.. . ..... .., .."" . ,,,..' ~ .".. .."....... '..' .". .. . ...... .... ... . .... ..... ........,........' ...... ..~....." .'''' .".'..'" .. ,....... .... ."..'. .. . ...... -.. ..... .. .....-..........-.............."" ... .. ... ..... ... . .. .. ... .. . ... . ...... . . " . ... . ........" .. .. ~ ....~ .' .... "~~'. P,~GE ~3 DaTE: 2/ 9/85 TIM~: 1C:54:74 JNION OIL :J.OF :AL:~O~NrA K3U 23X-6 KENA: GAS F!~L: KENAI AL~SK~ "':"----_._--__~_~_a___.._---_..-...._--...._-_.._-_._-_.._-..._--. .~~n'__n- .~.__...._- .'._"".'--'-"--'--'_..."----"'~-'---"'-"-'-'-'-'.__..__n"" ", "."- ...... '.".'--'"-.'''--''''' ,,--".'-'-''''.'' "...n. ..".,,,,. ".,",.-. .....-_0_'_-..,.,- -- -"."... m'-- . - . --. "..-'. "".---."-'--.'--_O_...'_O.,-_,'''._n. -'--n._O.--..._-- )E~Trl GR CN :EN S?4 caLJ AC CORR RMLL RFOC DENP :'T' . A P' or ~I ,- ,...::--.--'...... ~,' \,/ ~ ~, T .T -.... / r" Uli ~ fA v''''\ U ~f; ._---;;,::-"'-- ~---- ",.L -'--"'---' ._--_._~.__---':!-.._.__._..~?.__...~- .....-.--.---".-:..:-_!_- ~'-'--'-'-' -_.._m--____.. n~ -=-.. ~. _.~__..~__n_"~_.~_... __...a_. . .-.-.-- ~-_.,.._.t.~._.a.. ~-"..__.... -"..- .. .,_..._.~.._-,_".__I ~."!....,- .. .. - m . ._._...__....~.~..~: ~..._.....~.._a-. . --..- ....-¥ -.~'-'a .-- ,... - . ..!.t. --. ~~.__...~.- .--. - ..~ ---...- \, ¡: ,~', , ---.---.---..--...--, ...~.__. .~.. ..h_. ....---. --- ------ .__...-~.~_.._._--,._--_..._. --~-._---,.__.._---- -_...._,.~_.- '.~'. ~_..._.. .a.,.. ~u._.a_. --~._- --..--. --.__...~_..._._._--_.. -.. --.. ,- _a- .._.._"a.... _.. .- .._-~-_.-..~.. - ..'-" .. ...~... . ~__.._a.. }'~' ------~--,-~--,--,_._._-_.,_..._"",....._"'.....__._"-_........"'."'-"-"'-'--''''---'----'--'''' ,.-'''....,-....., ,.~=-~~..~,-,._-_..--,.,..--.,-,.._"~=,:':=~=~--_.._,.,._,_..,-...---.....,,'" --_._,..."'-_.....~-"',_.- -,------_._. 5760. 55. 96 35 .79 ;~ . 41 72. 99 1 3 . '9 Q 1 J C. 3 J 0 ~ :J 5_. 6 " 9 f~_~~l~_~..~_.._.._- jJ,7 70 . 5 0 ~3 ,63 7 48' 0 0 2 . 3 Ó . 4 q . 3 t 1 3 . 5 6 9 1 . 9 0 Q . 0 5 1 G . 5 3 1 7 . 5 4 1 7 . t. 4 '5 730:-----46 '-"3-5'--"'''''-i.:-3 . 3~3---"2 '-.34-"'''---'7"9'":~'''5-'---''''-'1 ~r:"7""7"'''-'f3''õ''':'-Ö~3'''''''-'''''''ëf:''b''';--'''''' '''''3-~--'f5'''' "'''5''''~''4'6'''''---'''1'''8"''~'''8''6 -"""'----..-...'-"'"'' " 7 9 iJ--!___4 4 . ''-L.~' , .3. '9 ~ ~~?_-_.._._. _Z_~.,,_L5_.- .:~,?, ?.~Q~r~=J:_~._;'I;'=~~~~~:~.::~~:4:,'i::::,:'~::"'~':"::9.:' ~..:.'1::':?....' ..::: :1:';~':'~~:Q,1.-..~'..::~:j'~:"~ '§',.g..:",':::,:'-.I.:~~;:,~~"I::::''':', ":':.:':-::....~:::~: 53~C. ~:.26 4~.17 2.37 5~.~~ -1~.15_1:1..~__.:!8~___~~~~__9~5~_16~l_____- 1810. 60.&1, 36'~43 2.37 55.2314.14 10'*!3J.1~ 6.00S.9~ 16.7~ ,. . -5-§2~~~~-'-~~ 3 i__- 4 ~.~;~TK=:~:,'=~_'I~~~..~.I~~~::-::~.',~:':~':'4:~':,.:~':,::I:~.:~:,:I;~,~:~'~r.Q:,þ',':~..,~..:?.:.:,..,~' ':,::,:',}2~-~:j:':~L:..:::".::,....":'é:'~~::',~:;'þ',::,:,,:':':~~~:.:::?:,:~':I:..?_::':: ~::.'If",:;l~I::'~'~~',:.',:::,:,"",:~'::,',:::~~:. ':5,830. ,3.'52:35.31 2.3930.54 1t..15 '?(~.2.3 '2.D4..10..17 14.66 15.9.') '5 8 4-tr:----z'-ã-:-;rr'-""" Z"i}":-s :ç--'----"'z- ~'-:3"2---"-"5.-7-:-f6-""""'''r4'''~'''';ifr'''''-'''9-f~-''f6'.... """""'õ-~'-- 67"'" "'''''''''''4'':'' 3"'9 "., .. "f 2 '.3'7 ,.." " '''2 Ö:"2' 9 -- ,".. ',...' .'.. ," .,,'.,- ' :"'5- :J ::: r' ---'--~/--'-4-':;-:-'-3 ;;;-';~'-7'-"'-""""'''-'''~'---"'-;:'-'~''''-''''"'''.''7'''''''3:-'''..m'1''''''ï~.''''''''-'1'''''':''-''''-¿''~-''''--'';;~''¿. "';":" ,....,.. '-r-: ""'¡;'¡':~,"" "'..'..'¡ "'"'6'"1''''' ,'... ,', '"';''''q''~''''' '"'''1''' ' ~;""6"';:':;'."."'.""'."."""""'''-'''''-'' " t;,).,i J . ,... it It ''1 .. ..,. ¿ 11 '+ "+- . U ,"!' . .... -' .,. ...' . , '- '.J . '-' .., .. .. ð . v -' ... '-, -Š-86'ëf:-".'--Š-'''8:00"3 4 . f-r----'-'-2:":ff'-"-"4"'4'-~'-1'ì'¡"'''''''-1''4--~'4'-i'"''''''''''9'7'':''6--8''''''''' ". ''b''~''õ''8''--''--'"'6'':'"32''' ""'."1""'f'~ '1' '0'" "":r:S'''~''''7'1''.'''''' ..... '" .".. .. ,," 5880. 44.01 34.05 2.26 47.90 12.32 100.22 -0.01 11.04 13.76 23.35 5390. 36,.50 '~6.15 ?3347.81 14.1'95.53J.07 9.3~. 15.~7 19.43 ~~---~-~-:3j--~~'~~~~~~=~=~~~-~=j.~~~==~~~~~'þ~," --,:6~~Ó:~_~~"~",~~;;:~~~-~~~!~~,,$=-_:j-~..;~~~_.__..-,~~~~- ~2:';..1..;"..,~,,,-,-,-~..J~~~~~,,-,._.._~...~,.~_J..,~..,.,-,,"""""f,,!.,~..?...,..~3,~~.~.4;.,, "l.l,,~,,;~.ç:. ,,' '" .:7.;.. F5 " ,2.~, X:~, ..3 7. ,~?, ,2,?~ 1 , ", ~,. S':)... 59~O. ,3.)~ j4.5¿ '.j5 ),.6~ 12.95 9~.~1 w.~) 6.05 15.jO 10.j9 ~-'r~";;'-'l"".. ,...,.. "'ï'-.,--'-r¿-"7'-""--;-'¡-:'''--1--':'''''''-'''''''''-'''';;;''''''""'=i'''::':'''.'''''''''''''' ';:"'=;"""';¡"':~,'''''''''' "'''''''1. "--;;';;""'''''':::'''9''''''''''''''''0-1''''''''':::::''';'' ."..". , ..,. ;;'. ,...,., ';';;';;';" .,,-,. "."1." '''''J'''' ''''''''':,'''';;;;'''' ,.. ...,. "1'''''¿' "'''5'';':; ..." '''''''1'''''''';''''''''''''''-;''''/'''--'' .... ........".... '.''''--'''''''' :') ~ 'l u . "+,.. .), ,,+:.... r:. ¿ . ...¡ Ó ::> j. ,''1 ,,~ . ,~, . ' '. . y:", ,.J . ,:: c::. ¡. t 'of ..J . ~ ,) ~ . ;).. S'1'ÖÖ":'''''''s'd''':''¿':g """'''':r3':-ïj-1''' '" "2'.:3 á "7 6'~' 3 8"1 4' . ;2 3' '95' '-1' 5 " o.b i' " "6.2 6 "7~ ';9 5' f6~'" 35' .. 1 1';' , , ": 1 -;;; ~"{ '~'"' :~ 7-1 1S-----1 1 1-4-'~-~~¡-"--l-;1-1"--"'-'-~-"'~ ;;i,'--''''-''''':j'''._''';'~;;¡-'-''-1-:;::''.-T=:--'----'--- J """ . ,.I 'to:- .. (.1 . ...""" .. .") ..' ,. . .) .,., t' . - ....~ . . . ,"'". J "'. ~I . ....,.' -' . ...' '.... J . ,,J .,.... .,.I . ... ....~ ~ 12"'6 .S'Ö:";§ 3"-""'-j5":"3'3"'2 : ~3'3"59':Ö 1'13 :8:3"'94: '2'1" '0. û;3" Sa 78' 'fÖ~' 42 f;~:'''1 f' [tI:]I[]IIE~EE~]~~~'~}~~:n~~r~IrIr~~rZI"._::IIL.:.i.:Ir-:'-lE~E_-~-~_~~~ ) 1 7;,; . :) 3 . 1 f J.. ) . 1 7 ~ . 3 i..J ) 'J . ö 1 I 3 . '- ? ,",' 5 . f':; ...1 . t,; 9 7. . U.;, J 1 m,. ~,6 , ': 1 . ~]m..., ",'" ;t=li~~~~f~~~~4!~!~~.~--:1~;:1¡--: :~!-~:n:: ~I¡~[:ff - ..':n;-u..--'-.-.-lJI~ -- - ---i-~.~~ - . - .-. ~~-~l¡~.Ii' i'~'.::':~~:__:-:.-: ............ . ....,. "".".'''''' , ........~_....,,, .." .,. .. ",....-..... . -'''~~'.'''''''''''''''' ~~..~._" ,..... ...,.'.... ..."...~ ..... .-...,.. .'. .' .... ., . ..... . ... , . ... ... ~ .., ...~, ..- .. . . .... .., .. ..." . ...... .. ......., , . . .... ., .. .,~,... ,. ,. - -"...... ".. , -'... . ...- .,. . ,.. ,~,.,._""",~.". ".,. ._" .". "'.", ..~",.,...,... "'.''''''a.... ".-"....~_.. ..~.............".~.."-,..."....,~,.",-"...""""".....",,-,.,,"".""-'.'" ..., . ,"" ,.~".,. ..""""'''......-..... """..."'~""'.... ,..........",""..'..' ,....,..,~........"...,..,.",."...."..,..".... . ..... .. ,. ,. u"..'''' ~,.."" ." .... ,< ..... .~... .. ..,. n' "" '''' .. .. ...' ." ..- . p~:;: ,;. ~~TE: 2/ ?/~5 TIM~: 1C:54:3~ UN:O~ aIL CJ.O~ :A~:FC~N:A K0U 23X-6 K~NAr ;AS ~I~lD KENAI ALASK~ - ... .... .---......-.-------.-.--..---------.- .-.. .-_.... ...--..." .""_".0" --....-... .._...,...._.. ," "~""-'-'"'' ....-........ --....... ... ..... ... ...- . .... ....m, ..---'" .,......m.... .'''''''''' ..-....... '..---. .....-.-... ---....---.-.---.-.-..-.------..------.---... ..."-"" .--... ----......-----"- ) E ? -7":i"---'''--------G~-'- -'--'-ë'~--"---""-"--"'-' '- 5'~ "I~T'" --''''''''---;5 '¡:)~4-----'-" ---.-'-'c '4'L."3' ..,....-... ''''Af'''''''' ,........ ""-:'"O''"R-'R-''' -""''''''R''¡:,''CL' ...",n, '-'R' ="0 C" ,..' ..", ""C:' §-~Të ---, .- .......--.. _.. ~.-._-_._-"'._'-----""-_._._"._""'._----"-'.__._'.'-.---.-.. --- -------~---------"- rr' ApT 0/ ~/r ~v T~' TT ~/r ~UV ~~M ~ ~_._~... ..".....-.'. ..._.._.__:.:...--_._--~._--_._---~_..~-~_. ..._-_...~._. ._."~-~_.'-'.~~..__"'A_'_.'_..~.~--'-~~:_:_~~"--_.'---- ._--"'._".h'___..'~'_._.._-"'_:~-'-~-"~---'''. ... -. ~.. '... -.... ..A_.~. ..~..:_......\. ... . . .... . .... ... ".".".A.~.-..'--'.' "~_..'A~.._"--~---- '''--''--''--'-''-'--'-....-'.'-'.--'-- <.. --_A_.__A__.~_- -_...._.~._. ...-...- . . .._h-- .~. --- ._.~...... ..~_...._. -.... .._._-_....~.....~_.. ..A_._- '_._.'..-'.A---..'~'.'---"_.~-_.._'" .'- ~A.--_..._~....- '..""__-"'A~_"_-. .~. __n -..~ --.. ~_....__.-. ..A ..--.. ......n-"'.A..._~........,..._. n ..,. ..-. ..A .'....'.._'--~. ..~'."'-"'-'."-'" ....-.-- ~-_.'-'--" ~--. --'''------'-.-'---------'----'----'''--''-----'''--'-- -,,- 62"-4-5-~"---'-'5"5.-. 7 5 --- 3 6 . '2 C "--'--'-¿":'-':ç6"""'--r4"":'-f¡--'-. -1"3" ~"'4--f-- "-"-~3:~-ë5T""'-" ----""Ö-:-53"'-'-'''''-- '--;-~"-2"4 """'--1" 2'''~-5''3-'''''-- "1"5:-0:9'-"'-'-"'."-'" -"-'--, ~I~~~=_48.48. ~Õ.o'~,,=~~=}~~}}==j]~~I:=:~~I¡==~þ~~~""::~:~'~=I~~~~~~~J;[j~==~=~= 6260. 59.27 38.23 2.37 58.44 13.56 ,104.26 O.C6 6.00 11.24 16.67 :."'/i 2_?..Q,~-,,--~~2l_!~~ j ,-_.~' 6_!-~:~._., ,..."..,"'~..~...?~~-,,,.. .._",j ,~~~,~~,çf=~I~~:~;~-~,:.~,~'..~,~~?,~,,:?), ..,,,,~~~:~':;~~",;-~-QJ~,~~:'J:~~,:-;[~-~':':~--::"9~~~:~ .~"" " ., ",1..,?, ~,.,..~",?,' ,.=.~::'~',~~:=,:= ~?_~..9.""!.",,.._._?~_...,!_.6 2- 3 1 . 3._~__,.._---_.?_~_?_-_..._~._~...,!,-~.2........ J..~..~~?..?_,_..__.- '!_?__~__1.1~ ...".......,..~ ,!g.'p'.... ..." " ?..~.. ~:?j... ".., JJ"..I!,.,?,~._..--... _..Z..!,_.?...?, ,,__,..n..,., ,,---.--...-..-. Þ 2_!,,9_.!.._,.__...~~E~~1L.._.-1...?,,!.J_?...- _....._,.f~,...!,.II........ - .~,~,,!...?_?_.... ,...,1..,?n.'.'~'~, ..... -- ,??~.!..5_,:~- ,- ,..."...,9...!J...J,." ,... J....9..!..Q. ~",....._J,J-- !",4..~,,,"'_--m!!?,,,!...:ê..1..- ,,'" ,---.,---.....",... .,.. _Q.}_Q_9_..'!______~_L!} 6_..._, 3 ~~~.2..._.." ....._?_,!_..~,.z.._.._.. .:~',J"..!_.4,_?_.,,,,,,J.J,,,..:!...9..? ......-....7. ?...!...?..9...." ."" ,..9...!. ,9] ......"..JJ..!.A_9." "J, ~..~ _?J?..n"",1..~¿...!_._9..2.. ".' ,,'.. ......-..'-'" :6,3 1 0 . 4. 9 '. 8 '6: '37... '8 0 ' 2 . 4 ? 2 g . 7 5 1 4,. ;:~ 4 B 7 . -:}:: 0 . 0 ,3 7 . 9 ;:, 1 4 . 6 4 1 '3 . 7 a -6"'~3"2 '0":""''''''-''49 . 8 1--4 6 ~~~f9---"-'" 2 ~-:f3.-'''-''t;'-~r~''-'86'''-''-''1-':f:--7''9''-'''''''8--9-':""2-'9"--"-"'" -"rj"":' 'Ö6'''''''''' '" . 7"~ 2' ¿ , ""," , 9" ~ '6"4 m ",- ."" "1 li'~"'1'ä"""" ",."----,..,..,,,'- ---, --__"""'___R._"__'-_._""'-~-_._'-'''''..''..''.''-_.''''..'--''-~-_.'_..'---'--_._.'----'_._---'-_._"'_¥._-_..--'--"-'-_'..--.,._..__.....~--_._-----_.-.-.._-...------"""-'----"'----.--'''-''--'------'-- i6 3 .~,Q..~-_._, _2..Q, .4' 8 ,,' ': 3} ._~lL._..__, --..~-~, ..?..?..,-_. -- ?.,§"~,, Q-Q...,,-, '. J.",?...~ ]5- ,..-- ..--.9..~.._~._.?,.4.., .., ,..,..,." ),_'!..9.~,.,,, -.""" ?'!:... ~:5..." ,..",."" ,?.., ~, g "... .1",.,?",....,! .~... ,. , ,--",. _.. ""''''-' 6340. 49.03 36.48 2.41 54.50 14.53 95.60 0.02 6.19 10.28 14.73 ~~~~~3?~~~:."~'~:~,I~~~q~?=,~~:~:'~~?~;~'!~?:'::,:~:"::"~-;'~,~,~,j,','.:' ,,',""".~"?~,;':~~:1',"~':,,:",~t,~";'.?'..'3.",""" '" '~,~~:';."?'þ::" ", "',',,),";"9 '~' "~'" "5' '.'" 8 6 '" ',"""'..'''8.: ';""5' ,?,","'''' ",'''j'''4,'~~~'?',,~'''''''''' ''''',~,'~:::':,':,'~:~::-'', _?_~~9...Q_!--_.__..?..1~.Q_...._-} 8 -_'!...?.?...... . ." ,., ,.~._~...I~"_,,,.,,,, ,.~..,:?. "~. ~ ,?". .." ,.,.1. .?,. ~ --~~"..".. ""..§. ~, ,! ..?'..Q,..."" ..", '.'. Q ,,!.. ,Q ,§ ,- ~. J. .Q. .""" "." J...2 "..~.. ,,?..?.., .., ",.. J ,:~ ,-"".9 .'?, ,,_., ,.' ,.,....' ,. .. ,.."... .-.. '6370. 44.59 38.13 2.40 57.80 14.52 78.66 0.09 6.52 16.20 15.34 -6'''3''8''ö'~''''''''' ".. '4"6':'3-6-~--"-3Õ-"~-2'"3"'.""""''''''2'':.''S'5-'-''''''66.":'7"'6'"'-''''''f3'''~'''5''3'''-''''7ä':''¿'7''''''''' ""'''Ó''~.''Ö6 ,',,", '6". Ò'Q" '1'1" ."6'0'" """ Ó"~"'1"7' ",,' ',." '.. "'". ".. ,"," -;-7~~'-F''''-'''''- "---4 -1--'7~~-;;-"'-:;'--;;;---'----'-2'-"'--'i-;:;:"'"'-'''''':;;;''7'''''"'"'''''1''''' "'" "'"'''''.,''' 5'-'"'''7''';;''' ";;" .1' "," "':;':~ . '.''''''.'- ":;;',"""';;¡ ;;.~....." "1" ";".' " ~'~" ,.. '1' ..,;" ... 7" Q ".. .. .:.;" ~,' .", ,:~:.. :.;..::' '" . ...,.n" ..,,--..'... 0 .J ~ i"; . , . .. ~~ '...,. i ..) , , *..1 t. '~,!. ..... - . ~) ~; 'i. ') t ~-' . \,.t U '- . -4 , b . . :::: i,... (. ( '"6"4"O-Ö'~'''-----42''':.3.'1-.''-''J~r:-'9-1'''-''.'''''''''~'r. 3 9"36:'~"4 r" "ij':'3"z"""'aà:i4"" 'Ò ~ (1S ,,' "ä.2,2 ""1:3'.5 i 1 5.'1'6 ."" ':6-4-1- '~r~""'--""'4-2-.:7~Š---"--:3-'f:;.Ef2'-'--'-"-'-."2,"':". 4~Õ''''''-- "'3'"tf::."Ò"9'--'"'' -'1"2':-'5'''2''''''''' "'',3'' B"':"4 '-f' -.- ,.. "" '6":"'0' 4 ." ,,,.,,,,., ". '6 ~'à1' " ,,", '"'r6'''~--ff6''''''' """'{'5 "~'T~~-,""" "._"..._".......-,-.., '" ... .,1 .... . ,) 1 . -..J \, .., . ~,h£,~'", t. tIt,Jt .J ¡,r,Q: Z,... t¡"~i":.",, q,,;~,,»I. 4~,;,.;:,:¡) ,t\ì)¡ ,.. "~ ;,'"" ...,. - ~ ~ . , .. 1 ¡:... I .. . - .. ~;~~~~~~~~~~~~~J~~== 6 ) 1 U . '+ (j '. 41- ,4 1, '. :: 1 ,'. ..; ;0 '.;...~ 1 ;;: . ~ ' 11 5 . ¡J.S :J - V ~, 'i . 3'~ 1 ~ . 11 1 ! . '-~ c.: 6-S-3"\~r';.-"''''_.-''-õ':7:''i}5.'-:--5-:'5"''{j.---''''''.''' ...t~"'4'Ö'."'''.'- ",'''r~'..(ç:~'*''';.*''*';'';*, "...... . If£; ,.~' K:!:--- ." '" ,""m ö' '~' Ö'¿ "*"*"*"*- * :;; :*' '*' *' ;'.;; '*' ;"; ...., -, ''''''';j ..:" 'tfÜ"'-"""'.'''''.''--''''''''.''- ö"'5""4Õ':"*';";;'":¡'.;"";'''''-''''''-':;'': '"j":" , ""'''''''''''''''2''.'''' '6'" "'E"q'~" '41'" '" ", ,..- ";j"~ :j": """i ", Ö "~' "1 .2 ,,,, "'m''';.j' '~"b't" *' *":þ ;;; '*;.""."" ,,'. '5.: '::'0" """ j ~. '5 ,~~1'"'' '".", . " r~=~::Q,~:~:'!:~~~~~..,~~~~~~.~,~"~::~~~'þ.-.:;~~2:i2'~'''''~,,:,',':::'.~~~;_:,:~'~~:,'':~..:'.::'?,'1.',::~~'':é.~:':..'- "'~,:::.,',':.~::~~:,'::i,1!'~:..,,)~I;r~',~4."'?,':: '''''''':','::'':,;>~';':j,',~¿''~',:.'' ''''''''':,:'ç'.',;',,:'';~:Q'' ". "".: ':",':' q'''~'5''þ''-:'-~:' :::..:~'..~"Q"Q':-,""""'''''''''''''''.'','::', ',,',.'" 6560. 55.7C 33.37 2.41 64.11 13.04 90.00 0.C4 9.47 11.36 14.53 6:r7~r:-'--"--4-¡r:25-~~--:r~5":.-:5"5-"'.".""-'.2-~-'~f7-.'..-...;", ~f:" 7--ð"--''''''''f.2'':''çT'~' -'''--~;'9 ' ~?'. 3'" ",.,.,..... "'.,,. 5:'6':3 "'."""'1' 5':''''3 ",6""'"'' '1' '2' ':'-9"{:>"'''''' .' "1'?":'''~T3 "..,-,'._.".." "'."'''''.''-''.'''''- 6")~~Õ-':-.'-.---~5'3":-8"9'" ".'--'J:r:'-rz'"''-''''' '"2."~-"3"7"'-"""'.'5":S ---~"~f¿ '''''''''''r3'~''1'Ö "m__" "'.~fÇ--."'1'- 7--""" '.' '.., ö":"'Ö"'3'"'.''' ''''.'.'''''7" ': 'O"s""--" .,.. '.1' 3'~' "4'0''''''''''--:1''"7 :'-fT"--''''''''---''''''--.'-.--'' 6"6-ÖO'''.'''.'4'1''':''27'''''''''''''';4''3''':'2"''6, ''''''''2 ':3";5" ""68.05" '13:1 Ö9Ö~' 7;6 '6.65" 7:"41' "1 'b~';3i' ""1i'~"5'9' ",,,,..,,,,,-...,.. ¡'''::-'-1'''-;;;'--'''.'''..-7.'':;;''-:-:._~.';;:;--''''--f.--1''-''~."i "2''''.-.' '.''''''''-'''';;;-''''''''2'''''' ',' ......",' """';--' '1' .., .." :~-:).. ."'"'''''1'''-::;;:--''''::ï~;';~-''''''' "..;;::".;:;-'....-.;..- :...' ..",..,_....,-::.; "-";;;';9'."."""'''' "'"''1''' "-;:';----' "';;;¡.' ';'- '''''''''.''1' '.';--.""'7:.:::;' .. ......", ::~...; '''''."~~:~,,.;'~'_. ".. ..".,......"..." ....,",.":. "" ,) '..). 4"~ . ~. é.. ' ,.; .. '..', !.,.. . '+ 'J. '-:/ ... ,) iii '''; .) .:' '1 . Ú Ó U . i.J :.J . ->,. í 4 . ..... .:;, c: "+ . Y Y , ,Ç3;5'-:-'~-5"b~~-Z'B:.'-~4-ër:-[~f'."''''-''--''' 2.-~'-'3'.?""".""5"9'.:'"~f4''''''''''' '1"~Š''':'.':Y7 "-''''..'.'i¿''~'' 1"5 " ",...- "ë.ï ~'{j""'.;'" ,.. .. ''''9.'~'1' 6"'" "Tl"~"l'~i'''''' '"1') ;'''5'''j''.'''''.'.'''''''''-''--''-''.'.'-' s-6"4'''tf:'''''''-'5'2''''-~''7'.6'''''''''43-='''-i5''''''2='3'4' "57.67 "'13. ö'1" '91'~3f " ö~ Ö 9 '6~Ö11'5 ~ 58 ""18 ~,8'è,"'" ~ 6 5 C ;--) J :-:-4 7'" , 4. O. 5 Ü ---,-" 2 ~~r;;"--'~f5 . s "~f? ~ g ~3 9 :3 . ~j'~---5':-6~š---'-'-r~-'~f5-'-'.-:f2': 2 1 1 ;.S .' 5 2 '-6'7".{Y:''''''--'''-'4(T:-(S"q-''._--'3'Ë'''~'-'3. ¿-'-"..,' ..,..', ""2".~' -4' } "'-..' ''''6'' i"~"S' i .. "'''''''f}''~''j'?,''''''.''''~~'i''~--f ',,,!;.- '.'"'' '''Ö'''= '~J'4""" ...'........;' '~"9"i"" ''''''''''''3'' =' "7' '1" '.. ",.' 'f'5'" '::'."31"-- "....... -.-"-'--"'-.""."-". ;6'b}~''''''')'l'.' 64 '¡+'r~"¿'~ ¿-:."'6"4~ 'f..5:'1'~';~s':"ië;j.~:¡' '7 ~3j' 1 ,: .1 ~ ", 2 ~~'~;'1'" :;'7'J"~5 ,..:" -""'4 Ç':2'j ""-';g'f:'jj' ,..~ '~Si4 T ~ 5 1 'j ~ : (i i:1Ö. ~3 :: . C 01 :;.4' i 23 . 3 6 '1 ,j' ."¿~: ,,,,,,"'''''' ;'7"'r'Q-":'-'''''''''3'.r.:-'2-''¿-''''--'''':?;''j''~'''ò''3 ...,.. .......- "'~":"'.3''',Ç'''' """'~-"9"'." '~f5 .."...,",.. ~".~"":Tt;"" ,.."....~..~.~ ' ¡i~'".''' "".. ')5":' {YO""""'" '''á ~"3;~ ". ." "1",3" ~ 1 i." ",0 'f'0,"::~j"~" ",.. ""'.' .." ,': ',"":"'.'.'''. "".,.",.,.",~. "'..........~..,...~...'~.."'" .",,,,,.,,,,_.,~",.,,~-,,,"_¥"'.A..~.~.~.~.........,,..~~...~...,.. .., "~'''~....'. ..~,.......~....... ..- ,..... ....... "".'.'..'.'.'. . .-. ..... .... .., .........'".m.....'''''''..-''' ..-..... ........ ... ."."",~"... "'M.'. .. ~.... . ..'.'''" .. ...... .. ......,....- ..~..... ...,."'...._.....~.......,......... ."A "...n.'_..' .'.."..- ..... ~ ..~ ..... "'A""" ... .......~.. .. ........ . ........... .....~......,... ,., ""..'."A".""'.'."--'.¥'."~"""_A'~".."-"""-""".'"'M"""'"M..''''''~.''''''~''''''''''.''''''''''' ....,.,,,,, .......",~. ...".....,.-.... ...,~..., ...........,......~..... .,.. ~..., ...,...,......". ...'."''''. ."...........- .... . .... "'.m ..... .. ................ .. ... .. . '.."''''~.' .. ....... ..... ... ..'."...... ........... ........ ~.... .'. ...... .... ... ...........-. ... ....~ ..... ..~.....,.. ..... "",M...- '."A.".. ... ~. ...~............ ....... ".. ..., ..... "~ ...00. ... ~.. .' ..' .. . .~... '.. .. ...-"...-.... :)C\ G E 1 J O~TE: 2/ o/S5 TI~i~: 1J:5~:34 U~IO~ OIL CO.OF CALI~C~~!A K3U 23X-6 ~¿NAI GAS ~:=LJ K~NA: ALA5~A ._._--_._--_._-------_.............,.,~..~...¥.............."¥........~...... ._.."_._.~"-"-'.'-- ...- ...... ...... ...-.. . ..".......-.-......_'..n.... ........... ..... _.........~ ~"'--"--"-"'-- i:' ~T;-----~~--- C r'-----:; -~--~:-.._..._..._,.._' ~~'3':'-"--'---"-:"~"L"~:'''''- ,.. , '-'''Ä 'c .......-................ ':~~ (j"R -~.. ,. on , "~ ';" "L:-L-'- "-'''-'''~''';':''C';:'' -- ."...,.. --"''''''''''-5-~''~'''=~-''''-'--''''-'''---' ------'_.'.._-'-------"'----¥_-"'---~-~"--~_.¥"_.'''n--------..--.-..--.- ~-- -"--~-"--'-'-' ..-_. --- -.."...---......----.-----..----.-.---.-,...---.....-.,--.--..-. . .-.... -----. ".' . -......---.. ".'--".". ...--.-- {r. 1\ f"\ or ;/ ,- / ,... r!, V T !\; T ~ u I .~ n ~ ì>' (" '-.; 'vl ~: ~-_.._-~...- n__.__~~------~_._....."':!..-_---_.~_._~...__.._..... .~_._.~.:-..:.-..._~._.. ---.--. .--. ---.----.=- ...!_..~. "'''- -~....._.~.~.~~ ......!.---.-..---,..-.-.-..-.. .:.~... n.. ~._.... .~.. . .....~-"'.~ ,,--,,-~.,...~. ...: ,'....n. .-.. .. ...._.~.........:......_.\._.._. ..-. .-. .-. ... ... .~.. ."'-'-.._m..._.' . _: :::...~.~_.__.~----- -_.._._...__.._--_._----:-.__._.._..-.~ '''--'---''~-''_._'''---'-'-_..'''_.n__.._.__._._. --..__..-...~_._.__..__.-..~...._...._.._.....-...._.._-_...-""------.....,-..----.-------- ,"W" .......-..---- ---_..-.._-_.~.._.__._--_._._... ._.....__._.....~_.._-~.._..._--------_....._.._--_.,.~_.._- -- --...--. .-. ._..._,._-----_...~_. ..,..."..---. -.. . -- .h ...-. . '..- ,.... '"'''' ........... .~_. ....~_.~~. n... ... ._"..... "..''''~''~''-'-'- ..~_. , .. ."..-..-"" ''''~'''..n''. -,.. . .~.....__. ...-.,..-. "---""'--'--'-~"-".'"-'''-''' "'.".- .....- .... _U"'"''--''''''-''''-''' .. .....,.. n.,.. ---.....-..".. .......-.......-_. ..-----...-. ....--.--- .--.....--,.....-..-...- '"'' -.-.-.. --.-'-""-'''-0- ----. ~---_.._---~-~_.__.._-_._...--.O_--'--'._'~~---"'~----'~- .__..._....,_....~---_..._._--".._---_..._-".. .--. .-. ~_. ._. .---...-- "'''.''.-......,---,......-..-.....- ._..' ~. .~.._,-_...- ..-..-.. ~_...__...'_._._--_._~----- 6 7 2 0 . 5 5 . ~ 0 4 1 . 1 J ¿ . :) 5 c 4 . 4 6 1 3 . J 5i 4 . 3 3 Q . 01 ,j . 5 1 _..1J..,.!_..,?",_?,.........._.._,Lê....~_.~.1.n'.........".._._.. ._,-.... ;:97 .~,~~..!..._.._..,_4._2..~' 0 -~ : :3 6 !_t~-_._,,--,.._..~...!....1,,~....__.......QJ,__!..L~.. ..,,_J.- ~--!, "J.~~.._-_..._l..f...!..._5."..1.,_."......".., ;)...~.. .Q...1. , "..,.l.P..! ._~_..~_....., ".,'., J..,~,.~. J..?, ,..", ,..,1 Þ.. ..,J....?" """ ,....-....,- --... 6 7 .., J . : ~ . S ~ 3 6 . ,j 5 2 . 3 7 5 ~ . 7 5 1 .) . ': 2 ¿ ~..~.J_..z._........_.._;~~-~..~_..._,...tç..~--_?J..........,.,t?..~--~..J. ___..."L~, ,~._9-..;~..--_.,.,..--,---".._-_.- l~ 7..?_9._,!,...____2 8 ~.1_Q:---' 40 ~..iL__..,_- _?_!..~_.?,..._"...__?.,.~~_.- ?_Z..._",..,..j_l__~...~..!,,--....., ß--9...... .~,?, ,.....,........P., !"Q...§..., ,.. - ,', ...... 7." !.. ;?..~.... -".. .1..~, ,!. ..,?,1 ..,."", t~ .. ~ .,9...7.... , . ,. ". .. "....".... 6 7 b 0 . 5 2 . 1 5 3 4 . 82 2 . 39 4 G . e 4 1 2. 7 9 25 é . 5 1 ._.._:_Q....!._QJ..._.......,~L~,.!.._4_4.."..,...",,~...;3...~,.~_.:~~......., "J...?.,.!!--9_Z-..-......----.---..-. ~6770. 56.18 4D~a' 2.41 62.12 13.01 90.4° 0.03 7.33 9.97 14.74 6:r~f6:---- 5 '9 .' 9 9 4 0 . 9 7-'=~~~~~~:1'~::,~~~:~I'~:~~_I~,:'-,~~.'::I:.3--~~Q.:ç~~~,',::,~::~:~'~':,~~:Q-':,'~,,:::~::',::~:~::;'-9~Q::'-,:.:,':::,.."::?::~""?'-~:,,,'-,::'-~:'.T::?~~~j",: ::§.,,',:,,':'--,X:,~.:~~II.'~:~~.:~:::::~:,':::,:::::':.-~~~ <6-790. ,52~'$,f.'3'4:.,,4'1 '2.3337.75 .12.76 "::;~.64-G.D2 13.-9-3 23.Q4 19.6:3.. ..' 6-ê.2?::9.-':~:::=:.:_~i~~~~2~-=~~]~~~~:]"~[~::::::~:,::[~~:'I:~"..~.:_:::':~:'~"~',-.ê~'~':::,-'~:':'~~::}~?:~-';I?:"..':::",:'?"~,','~':,~.'.?',''-':'-''..:-.-'' :þ".~:','9.,,'?''':'' ",. ': :1':"~ ::':-'.~',~',':'" "",' ,z.:',?;, ,~....9:.::S,'- ',':",' :,',f::ê'."~:::Q,,?,_".,:'-:,::'.' ","'.::'::~':':::. :~ Q 8 1 J 11 -; [),. 5. a <3 4,. : 5, Q' 2 . 2 6 4 1 . 5 7 1 2 . g 4 9 5 . L 1 8 . ::; 5 1 3 . 8 Cì 2 2 . -:;. G 2 ~ . 3 9 -¡-;:;-2""¡:'¡-'-'''-' .1:' 4. 88 I ñ--4-:i-'----'::;'-'-'-4-"';--'".''''' ""-;:':-'7--"-"--;;-Q"---"-"'''1''''::;-----1'--'Q'' "'''''''';;'''':;'''''''''> -'6-.'"-''' ,", ,.. 'n'''''-(1'':-''--'' -,..... ""7'"'''' :--;: '.' "'1""F\ m_,:;:; "". ""1"" '''';.;'' '"'''ï'''''~''''''' ,..., ....' , . ...,...............-...- ¡""c¡w. ). '... "+,,,. oJ c::. 1..1 , .'1. .,). (; ic..!:), ",.'wI) .tÖ ...;.öw ).-+,) 6 .3 4 0 . 5 7 . 3 S 3 6 . 0 6 2 . 3 9 5 7 . 5 6 1 2. 9 7 8 6 . 0 0 _.Jd_.!....O 2 -1 C ..4 2 ,___L!~_.!..2..~___1.2_...!..,IQ_._.._...._"-"....."..",,._.. ~~~~.~...Q,:~ ,_.".._..'.:_~ ~,..!_:,~_?~:..._,,_.:~J..~,,~.Q... ....,.. gOo! 4,1::_.,.41!". >.,4..... -- . ,1...f...,!,:~_2 .,.,.,~,?..,!.,Q.} ,... .;.? "J~",.J':~,1...~,. ,4 4 J ~, ,", þ'~ " ..., ,.-- "'" ]jJg~_Jt~iliJl~;;;;JL~~ ,~I; r,~ -- ,~t~ t t ~t~}:; ;,; ~:}t-~ 6830. 66.15 40.07 2.39 52.21 15.07 ~3.91 0.04 6.54 9.88 15.75 ~~~[~i~~~~~ ~1!~itit=t~~~;tl¥~~:'~~~,t~~::~::'.::~::c~"~:-,~,~,;~~~;:,',~,,;~<~,~,~:~~=::'~-~:n~,~~t:*~------ I.,Y....,'...,. J.,)"",. .!.JIoJV ...;.01..' v.u.... -.J.-...,...J l....-..J',,; "'-':' Y'4""'", .J.0\) I'J."'~.... 'J."'..\"'.: ~:§~?:?"~~-'~;:'.'._"""",']:~:--~g:~,::~,=:=]._!;.9. Q"q. ).1: ) !Q ~Q ~.').c '.) .p C1., ~"').Q'p, "J. co ;J":"'5';j-""'f~ ~",::"þ">'.'._""."-"-"..."'''~' 7C~J~ 0.00 J.OO 0.00 O.OG 0.00 0.00 C.OG 0.00 0.00 160.00 -"'~~~--'"-''''''.'-''''' ..,.., ....... ""-"""''''''~'.''~'''M'''''''''~."",,,,,-,,,,-,-,,,,,,,,,-,,,,,"""'" -'~.,.'.-,_.".......... ... ...."...,.. .. ." ."... ~_... .'.' -~ - .......,........." -.. ......,-.. ......,.....~. ..._,_...._.~. ..~"''''''''''''''''''''''''. '''''''~''''''''''''''-' """. ..n M" ........., .....n.. .. ."',.... ......".......... ........,... .. ~..,.... ...." ",..". ...... ...."......" ,,,.m ....... ''''''...,.. """ ...~......~"...,...........~.... ....."".. ..'.. .".."..."....................~..............".,.... .............." '~"..'''''.'' ...~..." ......... ...-.. "'~""""""'"''''~''''' ....~... ......., ."" ............' ....". "'~"'~""''''''''~'' -'-"-"-"-'._".'-"---"''''._--_.'-'---'~-''_.'''''---'-'.....-...~---..-......._...-.....-...._.. ...-..............-"...".-..--...... ,~"-",,,,¥,,,,,,.,,,,-,,,,-,,-,,,-,,,,.,,,-~,,,,,,,,-,,,,-,,,,,.,,,,,, ..... "'''-'''''-''''''''''''''''''~'''''''''~~'''''.''.' ".". ..... .... -..............".... '-'''''''''. .............. ... ....¥.."",........ ....... ._..~.. . .... . ..... ..". ".'.... ..-... .'-"'~"-~.""""""".""". '"''''''.''''-''''''''.~''~'-''''~--'''-'''''''-''''.''' -_._.~...... .. ..... .,\.......... "'-'-'"~'''-''''~'''''''_''''''...m...'''''''',-''''''''' ~... "'" ~ ... . . . ~ .. .',',~-'N"'" . .~. ,.~... ..,--., . .':':':'~ . ~!I'.~--- -----""""-''''''''''''''~''''''''''''''''''------'''''''''''-'''''''''--~'''-''----~--''-'''''-''-''-'''-'''' _.~_......~..._...._..... ........ """'-"""-'"'''''''''''-''-''''-''''--'''''''''''''.'''~''-''''' ..-.. ''''''' ...,..... ........ ---------"-'---'-----'.--.-----.----.--.-...-- _.~_... ...... .....-... .......... . ........ . ..._.........._.....""~""" . .. .......-.............. ..~ ... .......... ..~..... .~.... ....... ...., ....."" ~....... ~........... "~""""'.~."~'''''--' ....-.._.~.......,.,. ..".~... . ...... ... ............." ..~"... ....~.. """."""'~'" . ,... ...~ .... ....~¥.....~_..~....." "....,,, ,........... ,~".... "~'''' ...'...,.........." .....'...... .'~.....'~..-.. """....p""'''''¥''''''''-'''''P''''''''' ...-...... .-. "'....,, ~..,... "... ... ..,. "'"'''' "....... . .... .."".. ...."...~.' ... .."" ...., "" '......,,, ". "",,,." ,"'...."'- .. ."."" ...... ... ....... ",,,., ,,,. "..... .. ... """,,,'" ..."..~.. ". .... .....' ... "..... .. .. ..... ..", "..". "".' .... .' ... ~. ...,.,.,." "'" .......... """ . ". "".'''''''''''''' ......-.",... '"'' .. ...¥..." ,,~.. ...,......~_.. "-"".""'-'.~'" '''''''''~'' .'..,. .... ...... "-"'-""-"-""-"--"'''''~'-'''''''-' .._.,~......"......"....~..",.........._. ........~. "... ..~., ... .....~. """'.",..' ..~"."...,,,..,.,,.,, ....... "... .....",,, ...'.. ,.. ... ......"...... ...., ..,. . ..,~ ".,,, .... . ~.. .,. . "" .. ~ .... '" ... ... ",,, ."..,.,.. ,... . . .." "'" .... ... """"-~ ..... ,. ". ..,... ...""-"'..' ."'" ".... ......-.............. .....'.... .,..-....". ........,..... "'~"'~'''' ~""-'."'."'-"'~''''''''P'''''''''' "'~""-""-"-"'~-- .. ~.... .. .... ..... "'"'''''''' ...'" . ., ... ... ... ....... .." .. "",-.... ... .~... ... .... . """-""""""-"'.""""'-"-"'-"'."~-~'~~"¡.~ . ~.~~'~-'_'_"-'~"'_~-"-'''--~---'._----_._-''-''''''-----'--''''''''''''''''''''''''''................_.......----._._...__..._...-.......~._-----............_---...............-._....._.........-. .' ........~. '-." ..'" .. "........ .... ~". ...... . "-""'"''''-'''''''''.''''''''''''' """""~'-'.'-""-""".~"'"'''''''''''''''''''''''~-'''''~''~'''''"""""""""""~"._'''''''''''''-'''''' ..,..'. ....... ... ..."...'..... '.. ..'~ ..., ","''''... ".....".., ". ..."'.."..,,. ,,,"'.,,..,,.'''''' "... .....,...-....".... "" ..".. . ....,.. ,..', . '......,,~.. ...... .....- ,..... ...".. . ...' ... ......-..",. ...... '" .,.".. ""'-"'.. "'''''''.'''.'''''''''''~'' . .'" ...... ... ..... ....,. .. . ..~ ........~. . ~'"'''.'''''''''.''''''''' ""'"''''''''''''''~''''''~'''''~'''''''-''''~'''''''''''''''''''''''''"'"''-''''''~''''''''' """"""""'" ...~..,.,..",........... .......... ....,........ . ..."......... .. ",".",,,. ........,. ... ..' .'.. ... ...."..,. ..., """"""-"'"'''''''''¥''-.'''''''''''~''''''''''''''' ~.~~."-'=.~.~ ."~.~.~",.,..~""""",..,.,....,."..,,,,..,--.,...,,,....,,,,--,.,,,.....',....................,,.......,...,.,.,..-,............_.._..._.,,..-'''''''~--'''''''''''''''''''''''''''''''''''''''''''--''''''''-''-''''_''''''''~__M_''__~~._.........._..¥_.-'~'''~¥'--'''-_¥_-¥_'__'''M''''_~''''''''''''''''''-''''''''-'''''¥'''''-_..--.._-,..............~...M~""""'.."-""'M"¥"'_"'''-,,,¥,,...¥_..--...._--_.......~ ~ .... .....~... .... .....~.. . """...........,...-,........,..,..,.....~".....~.~....,,,~.........,,..-'''''''''''''"...m.''....~..."".. ..........,.,,,,......~..,.... .~....... ................,... ... ".... ..."... ......... .., ..... ."..¥.. """''''''' ....""''''''''''''''''''''''",,, ............
