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Home My WebLink About179-0291. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: N2 Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7,290 feet 6,920 feet true vertical 7,290 feet 6,978 feet 6599; 6650; Effective Depth measured 6,920 feet 6697; 6920 feet true vertical 6,920 feet 6599; 6650; feet 6697; 6920 Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# / L-80 6,714' MD 6,714'' TVD Baker S3, Baker Model D 6,599 6,650' MD/ TVD Packers and SSSV (type, measured and true vertical depth)Baker Model D, Baker Model F-1 Pk 6,697'; 6,920' MD/TVD N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: 7,740psi Burst 1,530psi 6,870psi 134' 2,425' 7,025' 3,090psi Collapse 5,020psi 1,540psi 6,280psi 4,750psi Casing Structural 20" 13-3/8" Length 113' 2,404' 7,004' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 190 Casing Pressure Liner 279' 523 7,199' 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-173 60 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 140 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 179-029 50-133-20327-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 641 Kenai Beluga Unit (KBU) 41-07 N/A FEDA 028142 Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai Gas Field / Beluga-Upper Tyonek Gas PoolN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 9-5/8" 5-1/2" 7,025' WINJ WAG 434 Water-Bbl MD 134' 2,425' 7,199' 12 t Fra O 6. A G L PG , R 2 Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:24 am, May 21, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.05.20 17:12:44 -08'00' Taylor Wellmangls 5/26/20 DSR-5/21/2020 SFD 5/21/2020RBDMS HEW 5/22/2020 Rig Start Date End Date E-Line 4/21/20 4/21/20 Daily Operations: Hilcorp Alaska, LLC Weekly Operations Summary API Number Well Permit NumberWell Name KBU 41-07 50-133-20327-00-00 179-029 04/21/2020 - Tuesday PTW and JSA. Rig up and PT lubricator to 250 psi low and 3,000 psi high RIH with GPT tool and tie into log from town. Went down to 5,350’ and did not find fluid level. Ran correlation log and sent to town. RIH w/ 2-3/8” x 7’ Razor HC, 6 spf, 60 deg phase with well flowing 550K at 57 psi. Run correlation log and send to town. Get ok to perf from 5,140’ to 5,147’ while well is flowing. Spotted shot and fired gun with 550K rate at 57 psi. 5, 10 and 15 min it was 57 psi with 0 rate. POOH. All shots fired and gun was wet. Rig down lubricator and turn well over to field. ___________________________________________________________________________________ Updated by DMA 04-30-20 SCHEMATIC Kenai Gas Field Well: KBU 41-07 PTD: 179-029 API: 50-133-20327-00-00 PBTD = 6,920’ MD / 6,920’ TVD TD = 7,290’ MD / 7,290’ TVD RKB 87’ (21’ AGL) CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20” Conductor 94 H-40 Weld 19.124” Surf 134’ 13-3/8" Surf. Csg 61 K-55 BTC 12.515” Surf 2,425’ 9-5/8" Int. Csg 47 N-80 BTC 8.681” Surf 7,025’ 5-1/2" Prod Liner 20 4.778" 6,920’ 7,199’ TUBING DETAIL 3-1/2” Tubing 9.2 L-80 2.992” Surf 6,714’ No. Depth ID Item 1 993’ Camco Side Pocket Injection Mandrel 2 4,651’ Baker SB-3 Packer 3 6,527’ CMU Sliding Sleeve 6,571’ Baker PBR Tubing Seal Assembly 6,578’ PBR 4 6,599’ Baker S-3 Production Packer 6,641’ 2.81” BX Nipple 5 6,650’ Baker Model D Packer 6,654’ – 6,692’ Blast Joint 6,692’ 80-40 Locator Seal Assembly w/ 3.72” Seals 6 6,697’ 2.992” Baker Model D 194-40, 3-1/2” 9.3# L-80 7 6,709’ 2.813” X Nipple 8 6,714’ Wireline Re-Entry Guide 9 6,918’ Fish (PX Plug w/ Junk Catcher) 10/15/05 10 6,920’ Baker Model F-1 Packer 11 7,140’ Cement Retainer w/ 25’ Cement Plug on Top 7,198’ – 7,240’ Gravel Pack Screen 1 2 Calc. TOC 3,283’ 3 4 Sands Top (MD) Btm (MD) ft Size Date Status UB7A 5,140’ 5,147’ 7 2-3/8” 4/21/20 Open Beluga 6,728’ 6,760’ 32 2-3/8” 11/7/07 Open Beluga 6,776’ 6,796’ 32 2-3/8” 11/7/07 Open Beluga 6,854’ 6,874’ 20 Open Beluga 6,886’ 6,896’ 10 Open Beluga 6,904’ 6,914’ 10 Open Beluga 6,990’ 7,010’ 20 Open Beluga 7,056’ 7,076’ 20 Open Beluga 7,104’ 7,114’ 10 Open Beluga Sands 11 Beluga Sands UB7A 6 7 5 8 9 10 UB7A ---- Open4/21/20 UB7A 5,140’5,147’7 2-3/8” 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: N2 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7,290'6,978' Casing Collapse Structural Conductor 5,020 psi Surface 1,540 psi Intermediate Production 4,750 psi Liner 6,280 psi Packers and SSSV Type: Baker SB-3, Baker S3, Packers and SSSV MD (ft) and TVD (ft): 4,651' MD & TVD, 6,599' MD & TVD, 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Christina Twogood Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng ctwogood@hilcorp.com 7,290' 6,920' 6,920' ~ 806 psi 7,115' Baker Model D, Baker Model D, Baker Model F-1 Pkrs, ; N/A 6,650' MD & TVD, 6,697' MD & TVD, 6,920' MD & TVD; N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: 7,740 psi Tubing Grade: Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028142 179-029 50-133-20327-00-00 Kenai Beluga Unit (KBU) 41-07 Kenai Gas Field / Beluga-Upper Tyonek Gas Pool Length Size CO 510A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 9.2# / L-80 TVD Burst 6,714' 6,870 psi MD 1,530 psi 3,090 psi 134' 2,425' 134' 2,425' 7,025'9-5/8" 20" 13-3/8" 113' 2,404' 7,025' Perforation Depth MD (ft): See Attached Schematic 7,004' 5-1/2" Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: April 30th, 2020 7,199'279' 3-1/2" 7,199' m n P s 666 t c YYYYes Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.04.20 10:56:47 -08'00' Taylor Wellman By Samantha Carlisle at 11:18 am, Apr 20, 2020 320-173 gls 4/20/20 N2 DLB 04/20/2020 X Perforate DSR-4/20/2020 10-404 Comm 4/20/2020 dts 4/20/2020 JLC 4/20/2020 Well Prognosis Well: KBU 41-07 Date: 4/20/2020 Well Name: KBU 41-07 API Number: 50-133-20327-00-00 Current Status: Flowing Gas Well Leg: N/A Estimated Start Date: April 30th, 2020 Rig: E-Line Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 206-013 First Call Engineer: Christina Twogood (907) 777-8443 (O) (907) 378-7323 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) AFE Number: Current BHP: ~ 900 psi @ 3,508’ TVD (Based on PT survey September 2013) Max. Expected BHP: ~ 1,320 psi @ 5,147’ TVD (Based on PT survey September 2013) Max. Allowable Surface Pressure: ~ 806 psi (Based on expected BHP and gas gradient to surface (0.10 psi/ft)) Brief Well Summary Kenai Beluga Unit 41-07 was drilled in late 1979 targeting the Upper Tyonek and Middle and Lower Beluga formation. In 1995, the well was worked over to recomplete to a 3-1/2” single string design. The Upper Tyonek was completely isolated and several MB sands were squeezed. In 2005, a workover to establish annular integrity was performed to isolate the squeeze perfs in between packers in order to obtain an MIT to verify integrity. The well was recompleted with multiple isolation packers and brought back online producing from the Lower Beluga. The purpose of this work/sundry is to perforate multiple intervals in the Upper Beluga sands. Notes Regarding Wellbore Condition x The well is currently producing 450 MCFD. x Last tag at TD with bailer 7,071’ WLM on 2/14/2014. Safety Concerns x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. x Consider tank placement based on wind direction and current weather forecast (venting nitrogen during this job). x Ensure all crews are aware of stop job authority. E-Line Procedure 1. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 1,500 psi High. 2. RIH with GPT tool and find fluid level. If fluid level is over the depth of the new perfs, discuss using Nitrogen with the Operations Engineer. 3. If needed, RU Nitrogen Truck, pressure up on well and push water back into formation. Use GPT tool to confirm water level is below interval to perf. The purpose of this work/sundry is to perforate multiple intervals in the Upper Beluga sands. Well Prognosis Well: KBU 41-07 Date: 4/20/2020 4. RU perf guns. 5. RIH and perforate the following intervals: Zone Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Upper Beluga UB1X +4,685’ +4,700’ +4,685’ +4,700’ 15 Upper Beluga UB1X +4,708’ +4,714’ +4,708’ +4,714’ 6 Upper Beluga UB1 +4,729’ +4,749’ +4,729’ +4,749’ 20 Upper Beluga UB2 +4,773’ +4,780’ +4,773’ +4,780’ 7 Upper Beluga UB3 +4,850’ +4,862’ +4,850’ +4,862’ 12 Upper Beluga UBB4 +4,923’ +4,930’ +4,923’ +4,930’ 7 Upper Beluga UB4A +4,942’ +4,950’ +4,942’ +4,950’ 8 Upper Beluga UB4B +4,962’ +4,966’ +4,962’ +4,966’ 4 Upper Beluga UB7A +5,140’ +5,147’ +5,140’ +5,147’ 7 a. Pressure up well to 1,000 psi before perforating. b. Proposed perfs also shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer and Geologist for confirmation. e. Use Gamma/CCL to correlate. f. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. g. All perforations in table above are located in the Beluga-Upper Tyonek Gas Pool based on Conservation Order No. 510A. 6. POOH. 7. RD E-Line. 8. Turn well over to production. (Test SSV within 5 days of stable production on well – notify AOGCC 24 hours before testing). E-Line Procedure (Contingency) 1. If any zone produces sand and/or water or needs isolated: 2. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 1,500 psi High. 3. RIH and set 3-1/2” Casing Patch in the tubing. Attachments 1. Actual Schematic 2. Proposed Schematic 3. Standard Well Procedure – N2 Operations ___________________________________________________________________________________ Updated by CMT 4-15-2020 SCHEMATIC Kenai Gas Field Well: KBU 41-07 PTD: 179-029 API: 50-133-20327-00-00 PBTD = 7,115’ MD / 7,115’ TVD TD = 7,290’ MD / 7,290’ TVD RKB 87’ (21’ AGL) CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20” Conductor 94 H-40 Weld 19.124” Surf 134’ 13-3/8" Surf. Csg 61 K-55 BTC 12.515” Surf 2,425’ 9-5/8" Int. Csg 47 N-80 BTC 8.681” Surf 7,025’ 5-1/2" Prod Liner 20 4.778" 6,920’ 7,199’ TUBING DETAIL 3-1/2” Tubing 9.2 L-80 2.992” Surf 6,714’ No. Depth ID Item 1 993’ Camco Side Pocket Injection Mandrel 2 4,651’ Baker SB-3 Packer 3 6,527’ CMU Sliding Sleeve 6,571’ Baker PBR Tubing Seal Assembly 6,578’ PBR 4 6,599’ Baker S-3 Production Packer 6,641’ 2.81” BX Nipple 5 6,650’ Baker Model D Packer 6,654’ – 6,692’ Blast Joint 6,692’ 80-40 Locator Seal Assembly w/ 3.72” Seals 6 6,697’ 2.992” Baker Model D 194-40, 3-1/2” 9.3# L-80 7 6,709’ 2.813” X Nipple 8 6,714’ Wireline Re-Entry Guide 9 6,918’ Fish (PX Plug w/ Junk Catcher) 10/15/05 10 6,920’ Baker Model F-1 Packer 11 7,140’ Cement Retainer w/ 25’ Cement Plug on Top 7,198’ – 7,240’ Gravel Pack Screen 1 2 Calc. TOC 3,283’ 3 4 Sands Top (MD) Btm (MD) ft Size Date Status Beluga 6,728’ 6,760’ 32 2-3/8” 11/7/07 Open Beluga 6,776’ 6,796’ 32 2-3/8” 11/7/07 Open Beluga 6,854’ 6,874’ 20 Open Beluga 6,886’ 6,896’ 10 Open Beluga 6,904’ 6,914’ 10 Open Beluga 6,990’ 7,010’ 20 Open Beluga 7,056’ 7,076’ 20 Open Beluga 7,104’ 7,114’ 10 Open Beluga Sands 11 Beluga Sands 6 7 5 8 9 10 6714' ___________________________________________________________________________________ Updated by CMT 4-15-2020 PROPOSED SCHEMATIC Kenai Gas Field Well: KBU 41-07 PTD: 179-029 API: 50-133-20327-00-00 PBTD = 7,115’ MD / 7,115’ TVD TD = 7,290’ MD / 7,290’ TVD RKB 87’ (21’ AGL) CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20” Conductor 94 H-40 Weld 19.124” Surf 134’ 13-3/8" Surf. Csg 61 K-55 BTC 12.515” Surf 2,425’ 9-5/8" Int. Csg 47 N-80 BTC 8.681” Surf 7,025’ 5-1/2" Prod Liner 20 4.778" 6,920’ 7,199’ TUBING DETAIL 3-1/2” Tubing 9.2 L-80 2.992” Surf 6,714’ No. Depth ID Item 1 993’ Camco Side Pocket Injection Mandrel 2 4,651’ Baker SB-3 Packer 3 6,527’ CMU Sliding Sleeve 6,571’ Baker PBR Tubing Seal Assembly 6,578’ PBR 4 6,599’ Baker S-3 Production Packer 6,641’ 2.81” BX Nipple 5 6,650’ Baker Model D Packer 6,654’ – 6,692’ Blast Joint 6,692’ 80-40 Locator Seal Assembly w/ 3.72” Seals 6 6,697’ 2.992” Baker Model D 194-40, 3-1/2” 9.3# L-80 7 6,709’ 2.813” X Nipple 8 6,714’ Wireline Re-Entry Guide 9 6,918’ Fish (PX Plug w/ Junk Catcher) 10/15/05 10 6,920’ Baker Model F-1 Packer 11 7,140’ Cement Retainer w/ 25’ Cement Plug on Top 7,198’ – 7,240’ Gravel Pack Screen 1 2 Calc. TOC 3,283’ 3 4 Sands Top (MD) Btm (MD) ft Size Date Status UB1X +4,685’ +4,700’ 15 TBD TBD Proposed UB1X +4,708’ +4,714’ 6 TBD TBD Proposed UB1 +4,729’ +4,749’ 20 TBD TBD Proposed UB2 +4,773’ +4,780’ 7 TBD TBD Proposed UB3 +4,850’ +4,862’ 12 TBD TBD Proposed UB4 +4,923’+4,930’7 TBD TBD Proposed UB4A +4,942’ +4,950’ 8 TBD TBD Proposed UB4B +4,962’ +4,966’ 4 TBD TBD Proposed UB7A +5,140’ +5,147’ 7 TBD TBD Proposed Beluga 6,728’ 6,760’ 32 2-3/8” 11/7/07 Open Beluga 6,776’ 6,796’ 32 2-3/8” 11/7/07 Open Beluga 6,854’ 6,874’ 20 Open Beluga 6,886’ 6,896’ 10 Open Beluga 6,904’ 6,914’ 10 Open Beluga 6,990’ 7,010’ 20 Open Beluga 7,056’ 7,076’ 20 Open Beluga 7,104’ 7,114’ 10 Open Beluga Sands 11 Beluga Sands UB1X UB1X UB1 UB2 UB3 UB4 UB4A UB4B UB7A 6 7 5 8 9 10 Thru tubing perforations. ___ ___ ___ ___ ___ SS STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. aMarathon Alaska Production LLC October 6, 2010 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Field: Kenai Gas Field Well: Kenai Beluga Unit 41-7 Dear Mr. Aubert: Marat on Alaska Production LLC Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 OCT 0 8 2010 AlosimolmoasCon.Comsion Anghmape 0 i'"I'l 1 __ 09-q n Q TI 1 2010 Attached for your records is the10-404 Report of Sundry Well Operations for KBU 41-7 well. This report covers the work performed to remove KBU 41-7's capillary string. Marathon has experienced issues with several cap -strings becoming hung up in the wellbore. Precautionary measures are being taken to remove any non-essential strings. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10-404 Report of Sundry Well Operations Well Schematic Operations Summary cc: Houston Well File Kenai Well File KJS STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMISSI010 REPORT OF SUNDRY WELL OPERATIONS RECEIVED HT 0 8 2010 Mask Oil J& G-Als Con. Commasi I 1. Operations Abandon L Repair Well L Plug Perforations L Stimulate L Other � Qin xe capillary Performed: Alter Casing E] Pull Tubing [:]Perforate New Pool [:]Waiver❑ Time Extension ❑ � Oubing Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re-enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to D ill Number: Name: Marathon Alaska Production LLC Development Q Exploratory❑ Stratigraphic ❑ Service ❑ G ,© '1 J c; ,3 11 It 3. Address: PO Box 1949 6`API Number: A03; .o0o® Kenai Alaska, 99611-1949 50-133-99999-99-N 7. Property Designation (Lease Number): ` 8. Well Name and Number: FED A-028142 Kenai Beluga Unit 41-7 9. Field/Pool(s):Q h� �yy 5t Kenai Gas Field / Be uga Pool A 10n 11. Present Well Condition Summary: Total Depth measured 7,290' feet Plugs (measured) 7,115' feet true vertical 7,290' feet Junk (measured) 6,978' feet Effective Depth measured 7,115' feet Packer (measured) Reference below true vertical 7,115' feet (true vertical) Reference below Casing Length Size MD TVD Burst Collapse Structural Conductor 113' 20" 134' 134' 1,530 psi 5,020 psi Surface 2,404' 13-3/8" 2,425' 2,425' 3,090 psi 1,540 psi Intermediate Production 7,004' 9-5/8" 7,025' 7,025' 6,870 psi 4,750 psi Liner 279' 5-1/2" 7,199' 7,199' 7,740 psi 6,280 psi Perforation depth: Measured depth: 6,728' - 7,114' True Vertical depth: 6,728' - 7,114' Tubing 3-1/2" L-80 6,714' MD 6,714' TVD Tubing (size, grade, MD & TVD): Capillary String - - - MD - TVD SSSV: NA - MD - TVD Packers and SSSV (type, MD & TVD): Packers: Baker SB -3 Packer 4,651' MD 4,651' TVD Baker SB -3 Packer 6,599' MD 6,599' TVD Baker Model D Packer 6,650' MD 6,650' TVD Baker Model D Packer 6,697' MD 6,697' TVD Baker Model F-7 Packer 6,920' MD 6,920' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Removed 3/8" Stainless Steel Capillary String. Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 800 0 400 392 Subsequent to operation: 0 715 - 374 410 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development LTJ Service ❑ Daily Report of Well Operations x 15. Well Status after work: Oil as 0 W DSPL ❑ IGSTORE] WAG ❑ GINJ❑ WINJ ❑ SPLUG ❑ 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature �(J'trl,� 41 -1-5 Phone 907 283-1371 Date October 6, 2010 AMarathon 'Operations Summary Report by Jab Oil Company Well Name: KENAI BELUGA UNIT 41-7 Qtr1Qtr, Block, Sec, Town, Range Field Name License No. State/Provinoe Country 6007004NO11 W01 KENAI I JALASK4, USA Casing Flange Elevation (ft)evation Ground El(ft) KB-Casin g Flange Distance (ft) KB�Ground Distance (ft) Spud Date Rig Release Date 0.00 66.00 91.70 25.70 11/2211979 Daily Operations Report Date: 9/16)2010 Job Category: R&M MAINTENANCE 24 Hr summary MIRU Dyna Coil to pull cap string from well. Install 6" OTIS tree cap. Ops Trouble Start Time End Time Dur hrs Ops Code ActivityCode Status Code Comment 07:30 08:30 1.00 SAFETY MTG Hold PJSM. Discuss emergency response, alarms -red flashing strobe for fire alarm, blue flashing strobe for gas alarm, muster area, wind direction, and specific job hazards. Obtain SW Permit. 08:30 09:45 1.25 RURD COIL Spot DynaCoil unit. Lay liners and drip pans. RU DynaCoil Unit. PU MIT spool onto unit. Thread coil into injector assembly. Carry injector to WH while "walking" injector down string. Release mechanical Slips. Release Rattiguns. Reduce pressure on Packoff. Remove LOTO. 0945 11:30 1.75 RUNPUL COIL PU on cap string. Pulls free I@ 2000 lbs. POOH from 6621' md. NO damage noted. OOH. 11:30 12:16 0.75 RURD COIL Lift injector off WH. Remove Donovan tree cap and install 6" OTIS tree cap. Install required 1/2" plugs. PT tree cap w/ well pressure. Test good. 12:15 12:15 0.00 PUMP TR ET Displace cap string w/ methanol. 12:15 13:15 1.00 RURD COIL RD Dyna Coil. 13:15 13:30 0.25 SECURE WELL Secure well. REmove LOTO on tree valves. Mi=obilize unit to Beaver Creek. www.peloton.com Page 1/1 Report Printed: 10/6/2010 Permit #: 179-029 API #: 50-133-20327-00-00 Prop. Des: A - 028142 KB Elevation: 87' (21' AGL) Latitude: Longitude: Spud: 11/22/1979 TD: 12/12/1979 00:20 hrs Rig Released: 1/30/1980 16:00hrs Tubing String 3-1/2" L-80 9.2 ppf TOP Bottom MD 0' 6,714' TVD 0' 6,714' Camco sidepocket inj mandrel @ 993' 1) Baker SB -3 Packer @ 4,651' 2) CMU sliding sleeve @ 6,527' 3) Baker PBR tbg seal assy @ 6,571' 4) PBR @ 6578' 5) Baker S-3 Production pkr @ 6599' 6) BX Nipple ID=2.81" @ 6641' 7) Baker Model D Packer @ 6,650' 8) Blast Jt 6654'-6692'(4.5" w/ 3.0" ID) 80-40 Locator Seal Assy w/ 3.72" seals 6,692' 9) Baker Model D 194-40 @ 6,697' 3-1/2", 9.3#, L-80, 6697'-6713- 10) X -nipple @ 6,709' ID = 2.813" 11) Wireline Re-entry Guide @ 6,714' 12) Fish, PX plug w/junk catcher @ 6978' (10/15/05) 13) Baker Model F-1 Packer @ 6,920' Fill: 7' KB (5/04) KBU 41-7 Pad 41-7 185' FSL, 4,303' FWL, Sec. 7, T4N, R11W, S.M. c C c C_ C C 12F 13 TD PBTD MD 7,290' MD 7,115' TVD 7,290' TVD 7,115' I* MARATHON Liner Drive Pipe L 20" H-40 94 ppf TOP Top Bottom MD 6,920' MD 0' 134' TVD 6,920' TVD 0' 134' " 8-1/2" hole underreamed to 15" Surface Casing @ 7,115'-7,140- 13-3/8" K-55 61 ppf BTC @ 7,140'-7,147' TOP Bottom @ 7,198'-7,240' MD 0' 2,425' TVD 0' 2,425' 17-1/2"" hole Cmt w/ 1,592 sks of Class G cement Production Casing 9-5/8" N-80 47 ppf BTC TOP Bottom MD 0' 7,025' TVD 0' 7,025' 12-1/4" hole Cmt w/ 1,800 sks of Class G cement Liner Kenai Beluga Unit 41-7 Lease: 5-1/2" 20 ppf TOP Bottom MD 6,920' 7,199' TVD 6,920' 7,198' " 8-1/2" hole underreamed to 15" " Cement plug @ 7,115'-7,140- • Cement retainer @ 7,140'-7,147' • Gravel Pack screen @ 7,198'-7,240' Beluga Perfs 6,728'-6,760' (32') 2-3/8' 4spf 11/7/07 6,776'-6,796' (32') 2-3/8' 4spf 11/7/07 6,854'-6,874' 6,886-6,896' 6,904'-6,914' Frac'd 6,990'-7,010' 7,056'-7,076' 7.104'-7.114' Well Name & Number: Kenai Beluga Unit 41-7 Lease: A-028142 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle/Perfs: 0° Angle @KOP and Depth: 0° KOP (TVD): NA Date Completed: I Ground Level (above MSL): 66' RKB (above GL): 21' Revised By: Kevin Skiba I Last Revision Date: 10/06/10 M Marathon MARATHON Oil Company July 30, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Field: Kenai Gas Field Well: Kenai Beluga Unit 41-7 Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ,~ - ~~~. ~S Z~O~ ~~~ _ ~~n The AOGCC approved Marathon's requested to install a velocity string in KBU 41-7 on June 28, 2007 under Sundry #307-215. Marathon has since elected to utilize a capillary string, to aid in water removal, in place of the velocity string. Therefore Sundry #307-215 is being closed out as a non-work sundry. If you have any questions or need additional information please call me at (907) 283- 1371. Sincerely, Kevin J. Skiba Engineering Technician ~~~~ AU G 2008 Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Kenai Well File KJS l~~ ~ ~ STATE OF ALASKA ~ -~~ ALA~OIL AND GAS CONSERVATION COM ON REPORT OF SUNDRY WELL OPERATIONS ~. . ~ ' >, _: 1. Operations Abandon Repair Well Plug Perforations Stimulate Ot#~r. ~' - ; ;' on-Work , Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2.Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame; Development Q ~ Exploratory^ 179-029 ' 3. Address: PO Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20327-00-00 7. KB Elevation (ft): 9. Well Name and Number: 87' 21' AGL ~ Kenai Belu a Unit 41-7 8. Property Designation: 10. Field/Pool(s): FE7~ A - 028142 Kenai Gas Field /Beluga Pool 11. Present Well Condition Summary: Total Depth measured 7,2gp' - feet Plugs (measured) 7,115' true vertical 7,280'- feet Junk (measured) 6,978' Effective Depth measured 7,115' feet true vertical 7,115' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 134' 20" 134' 134' 1,530 psi 5,020 psi Surface 2,404' 13-3/8" 2,425' 2,425' 3,090 psi 1,540 psi Intermediate Production 7,004' 9-5/8" 7,025' 7,025' 6,870 psi 4,750 psi Liner 320' 5-1/2" 7,240' 7,198' 7,740 psi 6,280 psi Perforation depth: Measured depth: 6,728' - 7,114' True Vertical depth: 6,728' - 7,114' Tubing String 3-1/2" L-80 6,714' Tubing: (size, grade, and MD) Capillary String 3/8" 2205 Stainless Steel 6,621' Baker Model D Packer, Baker Model D 4,651', 6,599', 6,650', 6,697', Packers and SSSV (type and measured depth) Packer, Baker Model F-7 Packer 6,920' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA Subsequent to operation: NA 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development Q Service ^ Daily Report of Well Operations 16. Well Status after work: Oil ^ Gas Q WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-215 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician - Signature . C~ Phone (907) 283-1371 Date July 30, 2008 Form 10-404 Revised 04/200 ~ ~ ~ ~ ~ ~ ~ ~ ~~~~ t~l)~ Q ~ ~oO$ Submit Original Only • M Marathon MARATHON Oil Company July 29, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Field: Kenai Gas Field Well: Kenai Beluga Unit 41-7 Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~f''.. , ~s„ M ,... a~ ~;n Attached for your records is the10-404 Report of Sundry Well Operations for KBU 41-7 well. This report covers the capillary string installation performed under Sundry #308-217. The capillary string was installed on 7/3/2008 and set at a depth of 6,621' MD. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, - <~E~N~ AU G ~. `~ 2008 --~ ' `~ Kevin J. Skiba Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS DMD ~, '~ to ~~ ~ ~,~,~, ~~ H ~~~ ~: JUG ~ 2~Og STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS -o~' 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Install Capillary Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ String Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2.Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame; Development Q , Exploratory^ 179-029 3. Address: PO Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20327-00-00 7. KB Elevation (ft): 9. Well Name and Number: 87' 21' AGL) Kenai Belu a Unit 41-7 8. Property Designation: 10. Field/Pool(s): ~D A - 028142 Kenai Gas Field /Beluga Pool 11. Present Well Condition Summary: Total Depth measured 7,290' ~ feet Plugs (measured) 7,115' true vertical 7,280' _ feet Junk (measured) 6,978' Effective Depth measured 7,115' feet true vertical 7,115' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 134' 20" 134' 134' 1,530 psi 5,020 psi Surface 2,404' 13-3/8" 2,425' 2,425' 3,090 psi 1,540 psi Intermediate Production 7,004' 9-5/8" 7,025' 7,025' 6,870 psi 4,750 psi Liner 320' 5-1/2" 7,240' 7,198' 7,740 psi 6,280 psi Perforation depth: Measured depth: 6,728' - 7,114' True Vertical depth: 6,728' - 7,114' Tubing String 3-1/2" L-80 6,714' Tubing: (size, grade, and MD) Capillary String 3/8" 2205 Stainless Steel 6,621' Baker Model D Packer, Baker Model D 4,651', 6,599', 6,650', 6,697', Packers and SSSV (type and measured depth) Packer, Baker Model F-7 Packer 6,920' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 790 0 1 390 Subsequent to operation: 0 1,100 1.6 1 415 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-217 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician Signature '~ ~ Phone (907) 283-1333 Date July 29, 2008 Form 10-404 Revised 04/20 _. ,_ ~ Fa~~t A~~1 ~ ~ 2Qd~ Submit Original Only pa1y~ ~RIGI~IAL _l Marathon '~ Operations Summary Report Mr,p~ ~ ~~~ ~ Well Name: KENAI BELUGA UNIT A 1-7 Re ort Date: 7f3~200$ Job Cate or R&M MAINTENANCE a r may Install 'heui'tree cap. PTest. RIH w! 3P8" capillary string to 6621' KB. Notify electricians and instrument fitters that need to install paver and tubing to faamer skid. 8trlllme B-tlTlme Dtirprs~ OpsCOtle Rcl~d'GOtle ps 8mRU a a'0dc Edit Comment 08:00 09:00 1.00 SAFETY NffO AF Hold PJSM. Discuss alarms, muster area, and emergency response. discuss BJ JSAands ecific'ob hazards. Obtain SWP. 09:00 10:00 1.00 RURD COIL AF Spot equipment. RU Dynacoil unit. Remaue aldtree cap. Install'heui' ree cap. 10:00 10:18 0.30 TEST EQIP AF PTest tree cap to 2500 psi. Test goad. 10:18 10:4'i 0.40 RURD COIL AF hAU pack off. Install coil in injector. Set BHA ~ 3500 psi. (8.7 ppg 7C 6700' )~ .052 = 3030 psi.) +400 psi. Pull test BHAto 750 psi. Install ackoff an WH. 10:42 10:54 0.20 RURD COIL AF Carry Injector to WH. 10:54 13:24 2.50 R U N P U L G OI L AF RIH w! 318" Dynacoil to 6621' KB. Short of frogs[ depth of 6700'.( Ran out of coil on spool.) Begin filling tube to 7511. of capacity while RIH (16 aalsl. 13:34 14:24 1.00 RURD COIL AF Land coil ~ 6621' KB. See slips. check Ratikin packing. Gheck Hydraulic packing. Set spool down in WHouse. RD Dynacoil unit. Call electricians and instrument fitter to run power and tubing to Foamer skid. Past signage on ualues. Notify operations that we are ready to install LOTO on U er and lower master ualues and swab ualue. 14:24 14:36 D.2D SECURE WELL AF Secure well and location. Tum in ermit. Si Haut and leaue loc. www.pel oton.com Report Printed: 7r29f2008 13-3/8" K-55 61 ppf BTC Top Bottom MD 0' 2,425' TVD 0' 2,425' 17-1/2"" hole Cmt wl 1,592 sks of Class G cement M MARATNOM Drive Pioe 20" H-40 94 ppf Top Bottom MD 0' 134' TVD 0' 134' 9-5/8" N-80 47 ppf BTC Top Bottom MD 0' 7,025' TVD 0' 7,025' 12-1/4" hole Cmt w/ 1,800 sks of Class G cement 179-029 K B U 41-7 ~ 50-133-20327-00-00 Pad 41-7 A - 028142 185' FSL, 4,303' FWL, n: 87' (21' AGL) Sec. 7, T4N, R11W, S.M. PBTD - 7,115' TD - 7,290' Liner 5-1/2" 20 ppf Top Bottom MD 6,920' 7,199' TVD 6,920' 7,198' * 8-1 /2" hole underreamed to 15" "Cement plug @ 7,115'-7,140' "Cement retainer @ 7,140'-7,147' 'Gravel Pack screen @ 7,198'-7,240' Tubing Strins~ 3-1/2" L-80 9.2 ppf Top Bottom MD 0' 6,714' TVD 0' 6,714' Camco sidepocket inj mandrel @ 993' 1) Baker SB-3 Packer @ 4,651' 2) CMU sliding sleeve @ 6,527' 3) Baker PBR tbg seal assy @ 6,571' 4) PBR @ 6578' 5) Baker S-3 Production pkr @ 6599' 6) BX Nipple ID=2.81" @ 6641' 7) Baker Model D Packer @ 6,650' 8) Blast Jt 6654'-6692' (4.5" w/ 3.0" ID) 80-40 Locator Seal Assy w/ 3.72" seals 6,692' 9) Baker Model D 194-40 @ 6,697' 3-1/2", 9.3#, L-80, 6697'-6713' 10) X-nipple @ 6,709' ID = 2.813" 11) Wireline Re-entry Guide @ 6,714' 12) Fish, PX plug w/junk catcher @ 6978' (10/15/05) 13) Baker Model F-1 Packer @ 6,920' Well Name 8 Number: KBU 41-7 Lease: A-028142 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle/Perfs: 0° Angle @KOP and Depth: 0° KOP (TVD): NA Date Completed: Ground Level (above MSL): 66' RKB (above GL): 21' Prepared By: Kevin Skiba Last Revision Date: 07/29/08 .., ~ _ t.. .~z Iv ~ r- ~ • • AJ ~ ~ ice. a 9,{ {5 ~~~ i ~ ~ ? ~ ~.,._ ~ t A !~ t ' °' ~ SARAH PAL/N, GOVERNOR ALASSA OIL A1~TD ~S C01115ER'iTA'1'IO1~T COrgIISSIOI~T / 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Dennis Donovan FAX (907) 276-7542 Production Engineer Marathon Oil Company PO Box 1949 Kenai AK 99611-1949 d ~(~ 1~1~.. 1 Re: Kenai Gas Field U pper 1~onek/Beluga Gas Pool, Kenai Beluga Unit 41-7 Sundry Number: 308-217 ~~ J U N ~ 2008 Dear Mr. Donovan: Enclosed is the approved Application for Sun above referenced well. Please note the conditions of approvalrse 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 wor ' day if the 23rd day falls on a holiday or weekend. A person may not appe a~i a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~~ Chair DATED thi~~ day of June, 2008 Encl. r: M Marathon MARATHON Oil Company June 19, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~u~v ~ o zoos ~1ask~ Oii ~ Say ~ `"~~~. ~~a'~1t73~33~Ot1 ~~C~s~~ Field: Kenai Gas Field, Pad 41-7 Well: Kenai Beluga Unit 41-7 (PTD 179-029) Dear Mr. Maunder: We propose to run a 3/8" capillary string in KBU 41-7. With the availability of a capillary injection unit on the Peninsula starting the week of June 23~d 2008; we are able to mitigate water loading by running a capillary string and pumping foamers. Setting depth of the capillary string should be around 6700' MD. The past capillary string installation into KTU 24-6H (PTD 199-073) has yielded an approximate incremental gain of 475 MCFD over the past 3 months. We would like to continue to install capillary strings in other wells like KBU 41-7 and be able to realize longer and more stable production. Please find attached a 10-403, current wellbore diagram, and detailed operations program. If you have any questions or need further information please call me at (907) 398-1362. Sincerely, ~~~ Dennis Donovan Production Engineer Enclosures: 10-403 Sundry Notice cc: AOGCC Current Well Schematic Houston Well File Detailed Operations Program Kenai Well File DMD KJS 6~ o ~- ~ ICJ ^~ ,°~ STATE OF ALASKA ~ ~,~C1ni A AL~ OIL AND GAS CONSERVATION COMION ~ ~ ~ ~,,~ :~ APPLICATION FOR SUNDRY APPR041$j,~ ~ ~~~ wins mrnrs~~n 20 AAC 25.280 a 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown^ Perforate ^ aiv Other^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Install Capillary Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ String 2. Operator Name: Marathon OII Corn1 an p y 4. Current Well Class: 5. Permit to Drill Number: Development ^l Exploratory ^ 179-029 - 3. Address: p0 Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20327-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: S i E ~ ? ^ Kenai Beluga Unit 41-7_, pac ng xception Required Yes No 9. Property besignation: 10. KB Elevation (ft): 11. Field/Pool(s): f~A- 028142 87' (21' AGL) Kenai Gas Field /Beluga Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7,290'- 7,290' - 7,115' 7,115' 7,115' 6,978' Casing Length Size MD TVD Burst Collapse Structural Conductor 134' 20" 134' 134' 1,530 psi 5,020 psi Surface 2,404' 13-3/8" 2,425' 2,425' 3,090 psi 1,540 psi Intermediate Production 7,004' 9-5/8" 7,025' 7,025' 6,870 psi 4,750 psi Liner 320' 5-1/2" 7,240' 7,198' 7,740 psi 6,280 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6,728' - 7,114' 6,728' - 7,114' 3-1/2" L-80 6,714' Packers and SSSV Type: Baker SB-3 Packer, Baker SB-3 Packer, Baker Packers and SSSV MD (ft): Model D Packer, Baker Model D Packer, Baker 4,651', 6,599', 6,650', 6,697', 6,920' Model F-7 Packer 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development^ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: June 29, 2008 Oil ^ Gas^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name D nnis M. Donovan Title Production Engineer Signature Phone (907) 283-1333 Date June 19, 2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: - 2 Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: APPROVED BY / ~ ~ Approved b ~ COMMISSIONER THE COMMISSION Date: // O R I G I N _ :~~~~ ~ ~QO~ Form 10-403 Revised 06/2006 (,~ ~ Submit in Duplicate 2008 Capillary String Installation Page 1 2008 Capillary String Installation Program CLU, SU, BC, KGF .and NGF WBS#s SD#3 - W0.08.18049.CAP.001 KBU 11-8Y, 33-6X, 41-7 - W0.08.18053.CAP.001 BC 13 - W0.08.18054.CAP.001 CLU 6 - W0.08.18056.CAP.001 SU 32-9 - W0.08.18117.CAP.001 GO 6 - W0.08.18196.CAP.001 Objective - Install a 3/8" Capillary String into these wells to alleviate liquid loading. We intend to treat the producing fluid level in each of these 8 wellbores with foamer. Install and Complete CICM (injection skids) to utilize on wellheads. We have seen an incremental increase on KTU 24-6H capillary string installation of approximately 475MCFD. Procedure Companies Evolved: UOSS, BJDC, BJCS, BigG • Installation Order ell Maximum Setting De th Maximum String Len th Minimum String Needed at Surface trin Size and T e lan a Connection Est'd Producing Fluid Level a Depth Gauge Ring ID run Recommended Setting Depth From PT+Ta 1 CLU 6 8042' 8200' 45' 2205 3/8" X 0.049" WT 4-1/16 5M RX39 7880' 8058' 2.300" 8020' 2 SU 32-9 6200' 6250' 45' 2205 3/8" X 0.049" WT 3-1/8" 5M RX35 TBD TBD TBD TBD 3 BC 13 8590' 8750' 45' 2205 3/8" X 0.049" WT 3-1/16" 10M BX154 7900' 10055' 2.300" 8580' 4 GO 6 10120' 10300' 45' 2205 3/8" X 0.049" WT 4-1/16 5M RX39 TBD TBD TBD TBD 5 SD 3 9290' 9450' 45' 2205 3/8" X 0.049" WT 4-1/16 5M RX39 TBD TBD TBD TBD 6 KBU 41-7 6910' 7050' 45' 2205 3/8" X 0.049" WT 3-1/8" 5M RX35 TBD TBD TBD TBD 7 KBU 11-8Y 8145' 8300' 45' 2205 3/8" X 0.049" WT 3-1/16" 10M BX154 TBD TBD TBD TBD 8 KBU 33-6X 8200' 8350' 45' 2205 3/8" X 0.049" WT 3-1/16" 10M BX154 TBD TBD TBD TBD 2008 Capillary String Installation Page 2 Installation Procedure: 1.) BJCS: (Hold PJSM and JSA) a) Complete placement of 3 new CICM skids on wells CLU 6, SD 3, and KBU 41-7, all other wells have units placed. They will complete Installation of items that are pertinent to operation of CICM. b) Move NS#3 CICM to G0#6 well 2.) DOSS: (Hold PJSM and JSA) a) Removal of all well houses to setup for BJ Dynacoil Unit b) Replacement of CICM roof on (3) new skids, after tanks are set inside containment. 3.) Big G: (Hold PJSM and JSA) • a) Complete explosion proof electrical end fittings for CICM b) Complete tubing for hookup of Dynacoil - if needed. -Pl acement of an open conduit under the well house wall for easy routing of 3/8" id tubing for skid hookup. This will prevent multiple tubing disconnects when well work is needed, thus reducing exposure to trapped pressure. 4.) BJDC: 1. Hold PJSM and Complete JSA/JHA 2. Move in rig up BJ Dynacoil unit. 3. Replace tree-cap flange with specified internally threaded flange listed above in the matrix. 4. MU BHA and secure to 3/8"string. 5. MU WHA to internally threaded flange 6. MU Trailer Haskell Pump to WHA with 1" male NPT tie back assembly 7. Pressure test flange assembly against a closed valve to 1.5 times SITP with Trailer Haskell Pump. 8. "SHUT IN WELL AT WING VALVE" -This will prevent BHA from traveling down flowline. BHA is small and capable of flowing into flow-Tee 9. RIH with capillary below "Est'd Producing Fluid Level". All strings must be set into the producing fluid level to prove the most effective. 10. Set Rattiguns and Leave 1.5 times SITP. or greater as requested by BJDC on hydraulic pack off. 11. "OPEN WELL TO PRODUCTION" 12. Leave remaining spool of tubing outside of well for soap injection skid hookup. 13. Cap the tubing with a Swagelok cap, Swagelok valve, and pressure gauge. 14. Lockout/Tagout Swab, Upper Master and Lower Master. (Install BJ Dynacoil signs on all valves stating "Do Not Operate BJ Dynacoil in wellhead". Proceed to Lockout valves with production lock and cable.) 15. Hookup injection line to CICM, and set specified rate for each well. 16. RDMO, Cleanup site, Sign-out 50-133-20327-00-00 A - 028142 n: 87' (21' AGL) le: 11 /22/1979 12/12/1979 00:20 hrs ased: 1 /30/1980 16:OOhrs KBU 41-7 Pad 41-7 185' FSL, 4,303' FWL, Sec. 7, T4N, R11W, S.M. J • 13-3/8" K-55 61 ppf BTC Top Bottom MD 0' 2,425' TVD 0' 2,425' 17-112"" hole Cmt w/ 1,592 sks of Class G cement Beluga Perfs 6,728'-6,760' (32') 2-3/8' 4spf 11/7/2007 6,776'-6,796' (32') 2-3/8' 4spf 11/7/2007 6,854'-6,874' 6,886'-6,896' 6,904'-6,914' Frac'd 6,990'-7,010' 7,056'-7,076' 7,104'-7,114' Fill: ~n~~T7 ~n~~~ itn i~im~ ~~~ ~iFs13~-I) 6977' KB (5/04) 3, 7 c 10,1 1 M MARATNOM Drive Pioe 20" H-40 94 ppf Top Bottom MD 0' 134' TVD 0' 134' 9-5/8" N-80 47 ppf BTC Top Bottom MD 0' 7,025' TVD 0' 7,025' 12-114" hole Cmt wl 1,800 sks of Class G cement 5-1/2" 20 ppf Top Bottom MD 6,920' 7,199' TVD 6,920' 7,198' * 8-1/2" hole underreamed to 15" * Cement plug @ 7,115'-7,140' * Cement retainer @ 7,140'-7,147' * Gravel Pack screen @ 7,198'-7,240' 3-1/2" L-80 9.2 ppf Top Bottom MD 0' 6,714' TVD 0' 6,714' Camco sidepocket inj mandrel @ 993' 1) Baker SB-3 Packer @ 4,651' 2) CMU sliding sleeve @ 6,527' 3) Baker PBR tbg seal assy @ 6,571' 4) PBR @ 6578' 5) Baker S-3 Production pkr @ 6599' 6) BX Nipple ID=2.81" @ 6641' 7) Baker Model D Packer @ 6,650' 8) Blast Jt 6654'-6692' (4.5" wl 3.0" ID) 80-40 Locator Seal Assy w/ 3.72" seals 6,692' 9) Baker Model D 194-40 @ 6,697' 3-1/2", 9.3#, L-80, 6697'-6713' 10) X-nipple @ 6,709' ID = 2.813" 11) Wireline Re-entry Guide @ 6,714' 12) Fish, PX plug w/junk catcher @ 6978' (10/15/05) 13) Baker Model F-1 Packer @ 6,920' Well Name & Number: KBU 41-7 Lease: A-028142 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle/Perfs: 0° Angle @KOP and Depth: 0° KOP (TVD): NA Date Completed: Ground Level (above MSL): 66' RKB (above GL): 21' Prepared By: Kevin Skiba Last Revision Date: 06/19/08 o ~r L ~ c PBTD - 7,115' TD - 7,290' MARATHON • Alaska Asset Team United States Production Operations Marathon Oil Company December 4, 2007 Alaska Oil & Gas Conservation Commission AtM: Howard Okland 333 W. 7`" Avenue, Suite 100 Anchorage, AK 99501 RE: Marathon KDU #5 -API 50-133-20319-00 ~ Marathon KBU #41-7 -API 50-133-20327-00 Marathon KBU #31-7RD -API 50-133-20347-01 Marathon BC #9 -API 50-133-20445-00 CONFIDENTIAL Dear Mr. Okland: P.O. Box 3128 Houston, TX 77253 Telephone 713-296-2384 Fax 713-499-8504 FedEx ~1~~~~ ~~ ~iPR ~' 2t~~ Enclosed is one CD containing confidential core data for the above referenced wells. The Summary of Core Analyses Results document included all the wells in one document. I've included the original document, and have also saved each well out to a separate document for your files. Summary of Core Analyses Results: KDUS_KBU41-7_KBU31-7RD BC9 Summary_of Core Analsyis.pdf Separate Documents for each Well of Summary of Core Analyses Results: KDUS_SO133203190000 Core Analsyis_Summ.pdf KBU41-7_50133203270000_Core Analsyis_Summ.pdf KBU3l -7RD 501.332034701 OO Core Analsyis_Summ.pdf BC9_50133204450000_Core Analsyis_Summ.pdf Please indicate your receipt of this data by signing below and returning one copy to my attention at the letterhead address or fax to 713-499-8504. Thank you, Kaynell Zeman Engineering Tech Received by: Date: ~ /, c.c. aw. ~ c ~- . o~ C111 ~ Enclosure 1~9-ozq n M Marathon MARATHON Oil Company December 5, 2007 • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~'~~ .~~ SEC ~: ~ 2407 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Kenai Gas Field Well: Kenai Beluga Unit 41-7 Dear Mr. Maunder: ~E~ ~ 7 2007 ~~laslca Oil ~~s ~~ns. ~r~mmissian ~r+ciaorar~~ Attached for your records is the 10-404 Sundry Report for KBU 41-7 well. Work was completed under Sundry #307-311. This sundry covers the work associated with the Beluga Zone perforation additions. Initial gas production increases by 800mcf at 455psi. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Please return any correspondences to me utilizing the address in the above letterhead. Sincerely, ~~,~~s~ Kevin J. Skiba Production Technician Enclosures: 10-404 Sundry Report Operations Summary Current Well Schematic cc: Houston Well File Kenai Well File KJ S MAM ~~~ _ ~.~ .~a.o~ RECEIV~C) STATE OF ALASKA DEC 0 7 ' ALA OIL AND GAS CONSERVATION COMMISSION ZQO7 REPORT OF SUNDRY WELL OPERA-TIOka qil & Gas Cans. Commissitrf~ n.,,.~..,.,,A.. 1.Operations Abandon Repair Well Plug Perforations Stimulate Othe perforated Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ QA/, ~l~i~ r ' Change Approved Program ^ Operat. Shutdown ^ Perforate ~ / Re-enter Suspended Well ^ ~ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Oil Company Development ^~ Exploratory^ 179-029 " 3. Address: PO Box 1949. Stratigraphic^ Service^ 6. API Number: Kenai Alaska, 99611 50-133-20327-00-00 7. KB Elevation (ft): 9. Well Name and Number. 21' AGL 87' above MSL Kenai Belu a Unit 41-7 - 8. Property Designation: ~~' Cfi~ J ~ 10. Field/Pool(s): _ 185' FSL 4303' FWL Sec. 7 T4N R11W S.M. Kenai Gas Field / Belu a Pool 11. Present Well Condition Summary: Total Depth measured 7,24p' feet Plugs (measured) 7,115' true vertical 7,240' feet Junk (measured) NA Effective Depth measured 7,115' feet true vertical 7,115' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 134' 20" 134' 134' 1530 psi 5020 psi Surface 2425' 13-3/8" 2425' 2425' 3090 psi 1540 psi Intermediate Production 7025' 9-5/8" 7025' 7025' 6870 psi 4750 psi Liner 3905' 5-1/2" 7199' 7198' 7740 psi 6280 psi Perforation depth: Measured depth: 6,728' - 7,114' SCQ~, 7 True Vertical depth: .6,728' - 7,114' Tubing: (size, grade, and measured depth) 3-1/2" L-80 6,714' Baker SB-3 Packer 4,651' Packers and SSSV (type and measured depth) Baker S-3 Prod Packer 6,599' Baker Model D Packer 6,650' Baker Model D Packer 6,697' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 770 0 350 395 Subsequent to operation: 0 850 0 275 455 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development^ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ^~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-311 Contact Kevin Skiba (907) 283-1371 Printed Name Michael A. Mullin Title Senior Production Engineer Signature Phone (907) 283-1337 Date December 5, 2007 • ~ r ~... . Form 10-404 Revised 04/2006 ~ ~ ~`~~~ ~,~~ ~~~'i, ~ ~° ~QD~ ~,~ 1 y'1 Submit Original Only API: '50-133-20327-00-00 AOGCC: 179-029 RT-MSL (Original Drlg): 21' KB-THF 185' FSL, 4303' FWL, Sec. 7, T4N, R11W, S.M. Lift threads: ??? Tree cap: 4-314" Otis • i KBU 41-7 Pad 41-7, Kenai Gas Field ~~ 3, 728'-6,760' (32') 2-3/8' 4spf 11/7/2007 776'-6,796' (32') 2-3/8' 4spf 1117/2007 854'-6,874' .886'-6,896' Frac'd ,904'-6,914' ,990'-7,010' ,056'-7,076' ,104'-7,114' 10,1 M ~rnw-nio>M L 20", 94#, drivepipe @ 134' MD (134' TVD) BIC=1530/5020 13-3/8", 61#, K-55, BTC Surface Casing @ 2425' MD (2425' TVD) BIC= 3090/1540 Tubing String - 3-1/2", 9.2#, L-80, to 6714' Camco sidepocket inj mandrel @ 993' NEW. 1) Baker SB-3 Packer @ 4,651' 2) CMU sliding sleeve @ 6,527' 3) Baker PBR tbg seal assy @ 6,571' 4) PBR @ 6578' 5) Baker S-3 Production pkr @ 6599' 6) BX Nipple ID=2.81" @ 6641' 7) Baker Model D Packer @ 6,650' 8) Blast Jt 6654'-6692' (4.5" w/ 3.0" ID) 80-40 Locator Seal Assy w/ 3.72" seals 6,692' 9) Baker Model D 194-40 @ 6,697' 3-1/2", 9.3#, L-80, 6697'-6713' 10) X-nipple @ 6,709' ID = 2.81 3" 11) W ireline Reentry Guide @ 6,714' 12) Fish, PX plug w/junk catcher @ 6978' (10/15/05) 9-5/8", 47#, N-80, BTC @ 7,025' MD (7025' TVD) Orig. Cmt w/ 1800 sks of class "G" B/C=6870/4750 Fill: ~93~~4~7~ 6889'-K~-(~~ 6977' KB (5/04) Well Name & Number: County or Parish: Angle/Perfs: Date Completed: Prepared By: 5-1/2", 20#, 6,920'-7,199' MD Liner (6920' - 7198' TVD) Cement plug 7115'-7140' Cement retainer 7140'-7147' Gravel Pack screen 7,198'-7,240' KBU 41-7 Lease: A-028142 Kenai Peninsula Borough 0° StatelProv: Angle @KOP and Depth: Alaska 0° Country: KOP (TVD): USA NA Ground Level (above MSL): 66' RKB (above GL): 21' Kevin Skiba Last Revision Date: 12105/07 ~ _ ~ _ ~ C ~ _ 1 C PBTD - 7115' TD - 7240' -~ MARATHON OIL COMPANY Page 1 of 2 Daily Maintenance/Repair Report Production Enhancement WELL NAME KB GL 24 HR PROG TMD TVD DFS DOL RPT # DATE KENAI BELUGA UNIT 41-7 25.7 66.00 0 0 1 08-Nov-2007 SUPERVISOR RIG NAME 8 NO. AUTH MD WBS SAPMBS COST Mike Sulle W00705665CAP001 FIELD NAME RIG PHONE MOC WI NRI DAILY WELL COST CUM WELL COST Kenai 10,250 USD 10,250 USD STATEIPROV COUNTY/OTHER LAST CASING NEXT CASING LEAKOFF ALASKA Kenai 0 in 0 ft CURRENT STATUS ~ 6AM 24 HR FORECAST MIRU Ex ro to add Belu a erfs 6728-60', 6776-96'. return well to roduction OPERATION COMMENTS MIRU Expro to run 2.60" GR and add perfs. All perforations are 2-3/8" OD, 4 spf, 60 degreee phased. Shut-in well- WHP-410 psi. Run #1 perforate 6776-6796' (20') (WHP 950 psi) . Run #2 perforate 6728-6760' (32'). (WHP 1230 psi.) SAF S MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP7 LAST RIG INSPECTION 42.00 N ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Wjnter SIIpS, trips, and falls. OPERATIONS SU MMARY FROM TO HRS FROM TO SUB. PHASE OP SUBOP TRBL DESCRIPTION 09:00 09:30 0.50 AF PR1 EVL RURD ELEC Startup equipment. 09:30 10:30 1.00 AF PR1 EVL SAFET MTG_ Sign in. Hold PJSM•discuss Expro JSA. Obtain Safe Work Permit. Discuss job scope. Snowed last night. Ask that crew take extra precautions for slips. Spread sand in traffic areas. 10:30 11:55 1.42 AF PR1EVL RURD ELEC MIRU equipment. PU lubricator. MU tool string. Well flowing @ 404 psi-718 mcf. Will shut in well inorder to reduce drawdown when we perforate. 11:55 12:25 0.50 AF PR1 EVL TEST_ EOIP PTest lubricator to 2500 psi. Test good. 12:25 13:12 0.78 AF PR1 EVL UNPU ELEC RIH w/ 2.65" OD GR. Shut in wing valve. Well flowing @ 410 psi. .843M cf. 13:12 13:45 0.55 AF PR1EVL UNPU ELEC Tagged TD @ 6979' KB. Logged casing and BHA. POOH. 13:45 14:00 0.25 AF PR1 EVL RURD ELEC OOH. RU 2-3/8" OD, 4 spf, 60 degree phased pert guns with PX-lfiring head. 14:00 14:10 0.17 AF PR1 EVL SAFET MTG_ Hold Explossives safety meeting. Shut down all cell phones and radioes on location. Post gate guard. (SAFE system does not require shutting down SCADA) 14:10 14:15 0.08 AF PR1 EVL RURD ELEC Arm 20' of 2-3/8" guns and carry them to the tree. 14:15 14:20 0.08 AF PR1 EVL TEST_ EOIP PTest QTS. Test good. 14:20 15:07 0.78 AF PR1 EVL UNPU ELEC OPen well RIH(875 psi on well) with 20' of 2-3/8" OD 4 spf 60 degree phased guns to perforate from 6776- 6796' md. 15:07 15:35 0.47 AF PR1EVL UNPU ELEC Run tie-in pass. Pull into position and chant ~~7F'-1;7ar~ i~n~). _ POOH. 15:35 15:45 0.17 AF PR1EVL UNPU ELEC OOH. RU run#2. 15:45 15:55 0.17 AF PR1 EVL UNPU ELEC Hold explosives safety meeting. Shut down all cell phones and radioes. Post gate guard. Arm perf gunsfor run #2 and carry to wellhead. 15:55 16:40 0.75 AF PR1 EVL UNPU ELEC Open well (1140 psi.) RIH run #2-with 32 ' of 2-3/8" OD 4 spf 60 degree phased guns. 16:40 17:15 0.58 AF PR1EVL UNPU ELEC Pull into position and shoot perforations at 6728'- 6760'( 32').WHP-1230 psi. POOH. 17:15 18:00 0.75 AF PR1 EVL UNPU ELEC OOH. RD. Turn well over to production @ 17:55. Printed: 11/8/2007 8:36:18 AM • a Q ~ d a SARAH PALIN, GOVERNOR ~as~[a~7~ O~ ~ ~ 333 W. 7th AVENUE, SUITE 100 COlY5~RQA~`IOlIT CO1rII~II55IO1Q ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dennis Donovan Production Engineer Marathon Oil Company PO Box 1949 ~ N~V n ~ 20d~ Kenai AK 99611-1949 ~ t : ~~~~~ ~ ~ ~` '~ Re: Kenai Gas Field, Beluga/Tyonek Gas Pool, Kenai Beluga Unit 41-7 Sundry Number: 307-311 Dear Mr. Donovan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (90?) 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. DATED this ~~day of October, 2007 Encl. Sincerely, • M Marathon MARATHON OII CQt11~a[l~/ October 09, 2007 Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 9071283-1350 Mr. Tom Maunder _ Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-403 Application for Sundry Approvals -Add Perforations Field: Kenai Gas Field, Pad 41-7 Well: Kenai Beluga Unit 41-7 (PTD-179-029) Dear Mr. Maunder: ": ~-..t ,_ Enclosed is the 10-403 sundry requesting to add perforations in KBU 41-7. Marathon intends to add two sets of perforations 6776'-96' (20') and 6728'-60' (32'). On June 28, 2007 Marathon requested a 10-403 to install this velocity string (sundry 307-215). We would like to add these perforations to promote flow before running the 1.75" velocity string. Attached with the 10-403 is the detailed operations program, current wellbore diagram and proposed wellbore diagram. Please send any sundries or pertinent documentation to Kevin Skiba at the above address listed. If you have any questions or need further information please call me at (907) 398-1362. Sincerely, A (~ Dennis Donovan Production Engineer Enclosures: 10-403 App. For Sundry Approvals cc: AOGCC Detailed Operations Program Houston Well File Current Well Schematic Kenai Well Fife Proposed Well Schematic DMD KJS T ~ ~ ~ /~d~ SATE OF ALASKA '- yJ ~ t i 3 _ ALASKA OIL AND GAS CONSERVATION COM~SION ` ~'•' APPLICATION FOR SUNDRY APPROVALS ~-al~b ~n nn~ ~r inn 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate Q Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Add Perforations Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: Development Ex lorato 0 P rY ^ 179.029 -- 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20327-00-00 _ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No (] Kenai Belu a Unit 41-7 " 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): 185' FSL, 4303' FWL, Sec. 7, T4N, R11W, S.M. 21' Kenai Gas Field, Belu a T onek Gas Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7240' 7240' 7115' 7115' 7115' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 134' 20" 134' 134' 1,530 5,020 Surface 2425' 13-3/8" 2425' 2425' 3,090 1,540 Intermediate Production 7025' 9-5/8" 7025' 7025' 6,870 4,750 Liner 3905' S-1/2" 7199' 7198' 7,740 6,280 Perforation Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6854'-7114' 6854'-7114' 3-1 /2" L-80 6714' Packers and SSSV Type: Baker SB-3 Packer, Baker S-3 Production Packers and SSSV MD (ft): 4651', 6599', 6650', 6697' Packer, Baker Model D Packer, Baker Model D Packer 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development 0 Service ^ 15. Estimated Date for 16. Well Status after proposed work: Oct 17th 2007 Commencing Operations: ^ Oit ^ Gas 0 Plugged ^ Abandoned 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Dennis Donovan Title Production Engineer Signature Phone 907-283-1333 (W) ~96~- Date 2• 9Q7.398-1362 (Cell) 10/9/2007 COMMISSION USE ONLY .•.r..v Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ .. Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~ ~ St... F ~t ' ~, p~.~~- QE ~ a~ ~A~ S, a ~ `~ C~C7~ ~QS~-s ~,.5~,~~~hr~ - Subse uentForm Re uired: ® 'n ~\ ~i,,OP~ S0.n•~C~ "R.)~, q q ZCtpO~'~~ r' V~\©C~~ S~~ ~ S G' ` APPROVED BY Approved by: ISSIONER THE COMMI ION Date: ~~~/~ ~'a~ Form 10-403 Revised 06/2006 O ~\~ I I V ~ ~ ~~n ~r~(~/f ~ ~ (,~ ` ~ (~ ~ , r~" sub~it;n Duplicate - - `,J"v • MARATHON MARATHON OIL COMPANY ALASKA REGION Kenai Unit Pad 41-7 Kenai Beluga Unit 41-7 2007 Beluga Add Perfs (09-24-2007) Notes: As per Clyde Scott. 1. Estimated Reservoir Pressure at based on 0.45 psi/TVD gradient a. 6776'-6796' (20') is 3048 psig b. 6728'-6760' (32') is 3027 psig 2. Current STTP is 1390 psig recorded on SCADA Aug 20~' 2007 3. Estimated BHP is 1650 psig (dry gas column) SlickIine• 1. SLICKI.INE TAG. Pressure Test Lubricator 250/3500 psig. MIRU Pollard Wireline to R1H w/ 2.750" GR to Tag Fill. RIH w/ 2" bailer to verify sand. If water is collected RIH with 2.500" or 2.750" Blind Box to Tag water level. 2. If sand is covering future add perfs OR there isn't sufficient rathole; discuss plan forward on Coil Tubing Cleanout. PROPOSED BELUGA PERFORATIONS Surface Wellhead Pressure SBHP 30% DD 30% DD 50% DD MD Net Ft TVD 0.469 psi/ft 0.96 N2 0.57 as 0.57,gas 6776-6796', 20 ft 6775-6795' 3182 psi 1797 psi 1892 psi 1351 psi 6728-6760', 32 ft 6727-6759' 3162 psi 1788 psi 1881 psi 1344 psi Electricline• RUN STATIC P-T SURVEY (IF NEEDED). MIRU Expro Wireline with full lubricator (pump in sub and flow tubes), and pressure control equipment. Hold PJSM. MU real-time P-T tools. Take lubricator and tools to wellhead. Pressure test lubricator to 250/3500 psi with water. Bleed off pressure. Take surface measurement with well open and then RIH taking static pressure and temperature measurements. POOH logging up to the static fluid level. POOH taking 3-5 minute benches at the half-way point and at surface. LD P-T tool string. PERFORATE BELUGA (6776'-6796' MD): Hold PJSM. Pressure test lubricator and pressure control equipment to 250/3500 psi with water. PU and RIH with CCL and 2.375" hollow steel carrier guns loaded 6 SPF 60 degree phased charges and PX-1 firing head. Max gun swell in air is 2.60" OD. Correlate depth to Expro CBL/GR/CCL and Array Induction openhole log. Perforate 6776'-6796' MD (openhole log depth). Flow test perforated intervals over night checking for indications of increased flow rate and water influx. Page 2 of 2 `~ • 3. PERFORATE BELUGA (6728'-6760' MD): Hold PJSM. Pressure test lubricator and pressure control equipment to 250/3500 psi with water. PU and RIH with CCL and 2.375" hollow steel carrier guns loaded 6 SPF 60 degree phased charges and PX-1 firing head. Max gun swell in air is 2.60" OD. Correlate depth to Expro CBLJGR/CCL and Array Induction openhole log. Perforate 6728'-6760' MD (openhole log depth). Flow test perforated intervals over night checking for indications of increased flow rate and water influx. CONTACTS Dennis Donovan:. 907-283-1333 (w) David Martens: 713-296-3302 (w) 907-398-1362 (cell) 832-472-6249(cell) Lyndon Ibele: 907-565-3042 (w) Clyde Scott: 713-296-2336 (w) 907-748-2819 (cell) KBU 41-7 09-28-2007 Add Perfs Procedure DMD - 10/10/2007 8:38:25 AM • M M~-a~-n~oN API: 'S0-1 AOGCC: RT-MSL (Original Drlg): 21' KB-THF ' FSL,' FWL, Sec. 6, T4N, R11W, S.M. Lift threads: ??? Tree cap: 4-3/4" Otis KBU 41-7 Pad 41-7, Kenai Gas Field ~~ • 20", 94#, drivepipe @ 134' 13-3/8", 61#, K-55, BTC Surface Casing @ 2425' Cmt w/ x~ocx sks of class "G" - 3-1 /2", 9.2#, L-80, to 6714' sidepocket inj mandrel @ 993' 6, 854'-6, 874' 6,886'-6,896' ~ Frac'd 6, 904'-6, 914' 6,990'-7,010' - Frac'd 7,056'-7,076' 7,104'-7,114' ~ ~ ~ ac ~ C ~ ~ ~ pc ~ .c it 12~ ~ 1) Baker SB-3 Packer @ 4,651' 2) CMU sliding sleeve @ 6,527' 3) Baker PBR tbg seal assy @ 6,571' 4) PBR @ 6578' 5) Baker S-3 Production pkr @ 6599' 6) BX Nipple ID=2.81" @ 6641' 7) Baker Model D Packer @ 6,650' 8) Blast Jt 6654'-6692' (4.5" w/ 3.0" ID) 80-40 Locator Seal Assy w/ 3.72" seals 6,692' 9) Baker Model D 194-40 @ 6,697' 3-1/2", 9.3#, L-80, 6697'-6713' 10) X-nipple @ 6,709' ID = 2.813" 11) Wireline Re-entry Guide @ 6,714' 12) Fish, PX plug w/junk catcher @ 6978' (10/15/05) FIII: 9-5/8", 47#, N-80, BTC @ 7,025' ' -Orig. Cmt w/ 1800 sks of class "G" 78~~B-F7~9~ -. ~~~ 5-1/2", 20#, 6,920'-7,199' Liner 6977' KB (5/04) _ Cement plug 7115'-7140' Cement retainer 7140'-7147' PBTD - 7115' Gravel Pack screen 7,198'-7,240' TD - 7240' 3, c 7 9 10,1' . ~ • M KBU 41-7 M~-rnoM PROPOSED 9-28-2007 ADD PERFS 179-029 RT-MSL (Original Drlg): 21' KB-THF 185' FSL, 4303' FWL, Sec. 7, T4N, R11W, S.M. Lift threads: ??? Tree cap: 4-3/4" Otis J Pad 41-7 Gas 13-3/8", 61#, K-55, BTC Surface Casing @ 2425' MD (2425' TVD) B/C= 3090/1540 L-80, to sidepocket inj mandrel @ 993' 3,4 6,728'-6,760' (32') 6,776'-6,796' (20') **Both Sets will be Added with 2~I 3/8" HSC 6spf Perf Guns Existing Beluga Perfs 6, 854'-6, 874' 6,886'-6,896' ~ Frac'd 6, 904'-6, 914' 6,990'-7,010' - Frac'd 7,056'-7,076' 7,104'-7,114' Fill: ~nnr~ vn in inns 69~ 6977' KB (5/04) 10,11 ~ ac ac .~ NEW: 1) Baker SB-3 Packer @ 4,651' 2) CMU sliding sleeve @ 6,527' 3) Baker PBR tbg seal assy @ 6,571' 4) PBR @ 6578' 5) Baker S-3 Production pkr @ 6599' 6) BX Nipple ID=2.81" @ 6641' 7) Baker Model D Packer @ 6,650' 8) Blast Jt 6654'-6692' (4.5" w/ 3.0" ID) 80-40 Locator Seal Assy w/ 3.72" seals 6,692' 9) Baker Model D 194-40 @ 6,697' 3-1/2", 9.3#, L-80, 6697'-6713' 10) X-nipple @ 6,709' ~ ID = 2.813" 11) Wireline Re-entry Guide @ 6,714' 12) Fish, PX plug w/junk catcher @ 6978' (10/15/05) Field 20", 94#, drivepipe @ 134' MD (134' TVD) B/C=1530/5020 9-5/8", 47#, N-80, BTC @ 7,025' MD (7025' TVD) Orig. Cmt w/ 1800 sks of class "G" B/C=6870/4750 5-1/2", 20#, 6,920'-7,199' MD Liner (6920' - 7198' TVD) Cement plug 7115'-7140' Cement retainer 7140'-7147' Gravel Pack screen 7,198'-7,240' PBTD - 7115' TD - 7240' . ~1f~1fŒ (ID~ ~~~~æ~ . AI/ASIiA. OIL AlWD GAS CONSERVATION COMMISSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mickey Mullin Senior Production Engineer Marathon Oil Company PO Box 1949 Kenai, AK 99611 SCANNED JUL ,9 5 2007 Re: Kenai Gas Field, BelugajTyonek Gas Pool, Kenai Beluga Unit 41-7 Sundry Number: 307-215 Dear Mr. Mullin: 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. DATED this ï!l day of June, 2007 Enc!. f1C1 -~9 . (. M.') Marathon MARATHON Oil Company . Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1326 Fax 907/283-1350 June 13, 2007 RECEIVED Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 JUN 2 5 7007 Alaska Oil & Gas Cons. CI,)mmission Anchorage Reference: 10-403 Sundry Notice Field: Kenai Gas Field, Pad 41-7 Well: Kenai Beluga Unit 41·7 Dear Mr. Maunder: We propose to run a 1.75" velocity string in KBU #41-7. We anticipate improving the ability of the well to unload water and to increase production. Please find a 10-403, operations program, wellbore diagram, and proposed wellbore diagram attached. If you have any questions or need further information please call me at (907) 283-1337. Sincerely, ~~~./- /5!TV-Ú/ð-T Mickey Mullin .. Senior Production Engineer Enclosures: 10-403 Sundry Notice Operations Procedure Well Schematic Proposed Well Schematic cc: AOGCC Houston Well File Kenai Well File DMD KJS 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 Perforate 0 Waiver LJ Other [] Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 V-String Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: , Marathon Oil Com Danv Development [] Exploratory 0 179-029 3. Address: Stratigraphic 0 Service 0 6. API Number: PO Box 1949, Kenai Alaska, 99611 50-133-20327-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes D~ }io A..0 Kenai BeluQa Unit 41-7 / 9. Property Designation:":-OA a -?;"~ ~._- -10. KB Elevation (ft): 11. Field/poOI(S)~I\i.G(\(;,~,> V>eo \. ~~ 185'FSL,4303'FVVL,Sec. 7, T4N, R11VV, S.M. 21' Kenai Gas Field, Pad 41-7 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7240' 7240' 7115' 7115' 7115' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 134' 20" 134' 134' 1530 psi 5020 psi Surface 2425' 13-3/8" 2425' 2425' 3090 psi 1540 psi Intermediate Production 7025' 9-5/8" 7025' 7025' 6870 psi 4750 psi Liner 3905' 5-1/2" 7199' 7198' 7740 psi 6280 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6854'-7114' 6854'-7114' 3-1/2" L-80 6714' Packers and SSSV Type: Baker SB-3 Packer, Baker S-3 Production Packers and SSSV MD (ft): 4651',6599',6650',6697' Packer, Baker Model D Packer, Baker Model D Packer 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program [] BOP Sketch 0 Exploratory 0 Development [] Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 24-Aug-07 Oil 0 Gas [] Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Com mission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Mickey Mullin Title Senior Production Engineer Signature -~..A .-Î___... ~ /LZ. Phone (907) 283-1337 Date 13-Jun-07 '~/¿tYI~/'¿'- ,. r COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ¿o '1" ót\5 Plug Integrity 0 BOP Test ¥l Mechanical Integrity Test 0 Location Clearance 0 Other: '-\5 00 ~\ C-\~a~ ~<\-ú... ~~~ Subsequent Form Required: '-\\0 t I APPROVED BY Approved by: / AWCOMMIS~ONER THE COMMISSION Date: 6..a8..ð1 Form 10-403 Revised 06/2006 np ~~I M-- ~~ubmit in Duplicate ~~ IIll $ 01 ~ RECt::.IVt::U . STATE OF ALASKA\...{'1"~"'V ....¿·~;1.t>1 ALA OIL AND GAS CONSERVATION COM ION h<-~<'6..!UN 2 5 2007 APPLICATION FOR SUNDRY APPROVALStI! k 01 & Gas Cons. C(}mmission 20 MC 25 280" as a I . . MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field, Pad 41-7 Kenai Beluga Unit 41-7 2007 CT Velocity String Hangoff Procedure Notes: . This procedure covers work to install a 1.75" OD coil tubing velocity string to alleviate liquid loading. . Contact Vetco prior to MIRU to verify maximum hanger head ID & mandrel OD measurements. BJ CoilTech supervisor will drift all WH connections prior to rig up to insure drift ID of individual connections. 1. Obtain Real-time FlowinQ Temperature-Pressure Survey. Make arrangements with the Operator to blow down well to unload fluid the day before this survey work is to be done. MIRU Expro wireline. Hold PJSM. Roundtrip a gauge ring with junk basket to tag top of fill in the production liner. RIH with CCL and 1-11/16" real-time Spartec pressure-temperature tool and GR with weight bars on wireline observing tool response for indication of producing fluid level. RIH to tag fill. Correlate depth and POOH logging to about 100' above fluid level. POOH taking 3 min benches every 500'. RDMO Expro Wireline. 2. Install Coil TubinQ Head. 3. Make flowline modifications for coil tubinQ velocitv strinQ. Plumb in and test annular flow line with a new 5K choke and ball valve to existing flowline. 4. MIRU MOC flow back eauipment including open-top flowback tank, choke skid, gas buster, and flow back iron. MIRU closed-top 500 bbl Rain-for-Rent fluid supply tank. Lay liner and berm area around tank. Load fluid supply tank with 6% KCI and heat as necessary. Deliver diesel fuel manlift and two light plants. Remove well house and lock out electrical connections. 5. MIRU BJ coiled tubinQ unit with BJ work string (if needed to clean out fill) and Maration velocity string on reel. Rig up fluid and N2 pumps. RU pumping iron and flow back iron. 6. Nipple UP BJ CT wellhead assemblv (WHA). Dual-Combi BOP (dressed for 1-3/4" CT). Function test BOP. Stab 1-3/4" CT into injector. Install BJ coil tubing connector and pull test to 15,000 Ibs. Nipple up injector to WHA. 7. Pressure test suñace lines and CT eauipment with 6% KCL water. Pressure test pump iron (200 low/4500 high psi). Pump fluid to load CT. Pressure test CT, WHA and flow back iron to choke manifold (200/4500 psi). Pressure test BOP rams (200/4500 psi). Purge pressure test fluids w/ N2 to flowbáck tank and vent N2 pressure to flowback tank. 8. Cleanout fill in wellbore. (ONLY IF FILL IN WELL IS COVERING PERFORATIONS) MU BJ CoilTech. Pull BHA into lubricator and take to wellhead. RIH with BHA and clean out fill to TD or Specified Running Depth with 6% KCL water and 500 scfm of nitrogen. Quit pumping KCL water and RIH with CT unload fluid from well with nitrogen to the flowback tank. POOH and LD cleanout BHA. 9. MU CT BHA. Nipple injector off WHA. MU velocity string BHA to end of CT. . . Page 2 of2 10. Nipple UP injector to WHA. Pressure test WHA using CT kill line (200/1500 psi). Bleed WHP to flow back tank. Prior to next Step, ensure that flowback line from WHA through choke manifold to gas buster is ready and available to keep TP at or below 1500 psi while RIH to eliminate possible CT collapse. This would serve as a backup if flow through the production flow line was unexpectedly curtailed or ceased. 11. RIH with coil tubing velocitv string and BHA with well flowing to sales up Tubing-Coil Tubing annulus. 12. Cut coil tubing. PUH to span WHA for final landing depth. Set CT in BOP tubing/slip rams. Lock tubing/slip rams. Slack off injector chain traction and roll chains to verify slips are set. Release WHP above tubing rams to the flowback tank. Nipple injector off of WHA. Walk injector up CT. Install C plate above BOP and polish rod clamp on CT. Cut CT above BOP high enough to allow Vetco to install CT connector and hanger mandrel assembly. 13. MU Vetco Coil Tubina Hanaer and Baker GS Running Tool. Swing Injector and lubricator away from WHo Vetco to connect VGCT Coil Tubing Hanger. While Vetco is making up CT hanger, BJ CoilTech to connect Baker GS tool string assembly to coil on reel trailer. Pull test CT connector to 25,000 Ibs. Latch GS spear to Vetco mandrel after PU injector. 14. RIH and land Vetco CT hanger per Vetco procedures. Verify string and hanger are landed and secured per Vetco procedures. Slack off string weight to neutral. Tighten Lock Screws. Pressure test hanger between O-rings to 5000 psig with hand pump pressure test unit (Vetco Supplied). Tighten Lock Screws. 15. Release 3" GS Running Tool. Sit down weight on Hanger. Start pumping 6% KCL water at approximately 2 BPM through CT to release GS spear. Watch for weight change to verify release and pickup to unlatch spear. Stop pumping when spear is unlatched and above mandrel. 16. Purge KCL water from CT remaining on reel trailer with nitrogen. Allow N2 to vent to flowback tank. Pressure Up CT with N2 to remove shear plug and aluminum pump-off plug off the end of the CT. Pressure up CT string until shear down plug and aluminum pump-off plug release and fall down hole. 17. Purge N2 from CT remainina in the well. Allow N2 to vent to Flowback tank. Have a gas meter onsite to monitor LEL. Once methane is detected send production to sales. 18. FLOW TEST WELL TO SALES. 19. RDMO and release eQuipment. RD flowback iron. Release tanks and all rental equipment to vendors. API: '50-133-20327-00 AOGCC: RT-MSL (Original Drlg): 21' KB-THF 'FSL,' FWL, Sec. 6, T4N, R11W, S.M. Lift threads: ??? Tree cap: 4-3/4" Otis KBU 41-7 Pad 41-7, Kenai Gas Field J 7 9 10,11 Beluga Perfs 6,854'-6,874' } 6,886'-6,896' Frac'd 6,904'-6,914' 6,990'-7,010' - Frac'd 7,056'-7,076' 7,104'-7,114' Fill: 7032' KB (7/97) 7029' MD (7/97) 7025' KB (3/02) 6909' KB (5/03) 6977' KB (5/04) 13-3/8",61#, K-55, BTC Surface Casing @ 2425' Cmt w/ xxxx sks of class "G" Tubinq Strinq - 3-1/2",9.2#, L-80, to 6714' Cameo sidepocket inj mandrel @ 993' 7) Baker Model D Packer @ 6,650' 8) Blast Jt 6654'-6692' (4.5" w/ 3.0" ID) 80-40 Locator Seal Assy w/ 3.72" seals 6,692' 9) Baker Model D 194-40 @ 6,697' 3-1/2",9.3#, L-80, 6697'-6713' 10) X-nipple @ 6,709' ID ::: 2.813" 11) Wireline Re-entry Guide @ 6,714' 12) Fish, PX plug w/ junk catcher @ 6978' (10/15/05) 9-5/8",47#, N-80, BTC @ 7,025' Orig. Cmt w/ 1800 sks of class "G" 5-1/2",20#,6,920'-7,199' Liner Cement plug 7115'-7140' Cement retainer 7140'-7147' Gravel Pack screen 7,198'-7,240' OPOSED KBU 41- Pad 41-7, Kenai Gas Field J API: '50-133-20327-00 AOGCC: RT-MSL (Original Drlg): 21' KB-THF , FSL, ' FWL, Sec. 6, T4N, R11W, S.M. Lift threads: ??? Tree cap: 4-3/4" Otis Belu~a Perfs 6,854'-6,874' } 6,886'-6,896' Frac'd 6,904'-6,914' 6,990'-7,010' - Frac'd 7,056'-7,076' 7,104'-7,114' Fill: 7032' KB (7/97) 7029' MD (7/97) 7025' KB (3/02) 6909' KB (5/03) 6977' KB (5/04) 7 9 10,11 L 120",94#, drivepipe @ 134' 13-3/8", 61#, K-55, BTC Surface Casing @ 2425' Cmt w/ xxxx sks of class "G" Tubinq Strinq - 3-1/2", 9.2#, L-80, to 6714' Cameo sidepocket inj mandrel @ 993' 7) Baker Model D Packer @ 6,650' 8) Blast Jt 6654'-6692' (4.5" w/3.0" ID) 80-40 Locator Seal Assy w/3.72" seals 6,692' 9) Baker Model 0 194-40 @ 6,697' 3-1/2",9.3#, L-80, 6697'-6713' 10) X-nipple @ 6,709' 10::: 2.813" 11) Wireline Re-entry Guide @ 6,714' 12) Fish, PX plug w/ junk catcher @ 6978' (10/15/05) 9-5/8",47#, N-80, BTC @ 7,025' Orig. Cmt w/1800 sks of class "G" 5-1/2",20#,6,920'-7,199' Liner Cement plug 7115'-7140' Cement retainer 7140'-7147' Gravel Pack screen 7,198'-7,240' e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~etí?l! -z( n{CG P.I. Supervisor Ì")é (., DATE: Monday, February 13,2006 SUBJECT: Mechanical Integrity Tests MARATHON OIL CO 41-07 KENAI BELUGA UNIT 41-07 Src: Inspector G(' o'Ý\ ,1 \ Reviewed By: P.I. Suprv...:::¡g.2- Comm FROM: Jeff Jones Petroleum Inspector NON-CONFIDENTIAL Well Name: KENAI BELUGA UNIT 41-07 API Well Number: 50-133-20327-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ060206112113 Permit Number: 179-029-0 Inspection Date: 2/6/2006 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 41-07 Type Inj. I TVD I 4651 IA 1060 1650 I 1650 1650 P.T. 1790290 TypeTest SPT Test psi I 1162.75 OA 0 0 I 0 0 I Interval !NIT AL P/F P Tubing 520 520 I 520 520 I Notes Post W/O MIT. 0.5 BBLS 50/50 methanol pumped. I well house inspected; no exceptions noted. Monday, February 13,2006 Page I of I e e Alaska Business Unit Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 November 15, 2005 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 $ANNED DEC 1 4 2005 \Î(\-oo/i Reference: KBU 41-7 Workover Sundry Dear Mr. Aubert: Enclosed is the 10-404 Report of Sundry Well Operations for well KBU 41-7. This Beluga well has a bottom hole location within X mile of a proposed gas storage well. Prior to the workover, we were not able to obtain a pressure test on the well casing due to squeeze perfs above the production packer. During the workover, the upper tubing string and packer were pulled. Isolation packers were installed above and below the squeeze perforations and a packer was installed just beneath the proposed storage horizon. The casing above the storage horizon is now capable of passing a mechanical integrity test. The squeeze perfs can be accessed by sliding sleeve if necessary. I have also attached an Operations Summary Report and an updated wellbore diagram which details the completed work. If you need any additional information or have questions, I can be reached by phone at 907-283-1333 or bye-mail atdmtitus@marathonoil.com. Sincerely, i' ,".t'··. '-. ,¡j4Ø..i.,.....'#." 1_.: k,: i"'fl'> Denise M. Titus Production Engineer Enclosures: 10-404 Sundry Operations Summary Report Well Schematic STATE OF ALASKA . AL. OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS RECEIVED NOV 1 6 2005 Alaska Oil & Gas Cons. Commission 1. Operations Abandon U Repair Well L::J Plug Perforations U Stimulate U Other U Ancnorage Performed: Alter Casing D Pull Tubing D 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. Current Well Class: 5. Permit to Drill Number: Name: Marathon Oil Company Development D Exploratory D ':,-.., ':f ;,)' 3. Address: P. O. Box 196168, Anchorage, AK 99519- Stratigraphic D Service D 6. API Number: 6168 50-133-20327-00 7. KB Elevation (ft): 9. Well Name and Number: 101' above MSL KBU 41-7 8. Property Designation: 10. Field/Pool(s): Kenai Unit Kenai Gas Field/Beluga 11. Present Well Condition Summary: Total Depth measured 7290 feet Plugs (measured) 7115 true vertical 7290 feet Junk (measured) N/A Effective Depth measured 7115 feet true vertical 7115 feet Casing Length Size MD TVD Burst Collapse Structural 134 20" 134 134 N/A N/A Conductor Surface 2,425 13-3/8" 2425 2425 3090 1540 Intermediate Production 7,025 9-5/8" 7025 7025 6870 4750 Liner 3,905 5-1/2" 3905 3827 7740 6280 Perforation depth: Measured depth: See attached True Vertical depth: See attached Tubing: (size, grade, and measured depth) 3-1/2" 9.3ppf N-80 6714' Packers and SSSV (type and measured depth) Baker SB-3, S-3, Mod D, Mod D 4,651' /6,599' /6,650' /6,697' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BFL NOV 1 7 2005 N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 720 0.5 vac 655 Subsequent to operation: 0 975 0.5 0 860 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory D Development 0 Service D Daily Report of Well Operations x 16. Well Status after proposed work: OilD Gas 0 WAG D GINJ D WINJ D WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: 305-244 ~ Contact Denise M. Titus f\ P';"::a::: D'~:w Title Production Engineer Phone 907-283-1333 Date 11/15/2005 Form 10-404 Revised 04/2004 Submit Original Only ~ e e KBU 41-7 PERFORATIONS/STIMULATION SUMMARY DATE MD TVD NET SPF DETAILS SQUEEZED: 12/15/1995 5334'-5353' 5334'-5353' 19' 12/15/1995 5641'-5655' 5641'-5655' 14' 12/15/1995 5761'·5775' 5761'-5775' 14' 1/11/1980 5905'-5909' 5905'-5909' 4' 12/15/1995 6128'-6138' 6128'-6138' 10' 12/14/1995 6494'-6504' 6494'-6504' 10' 12/14/1995 6668'-6680' 6668'-6680' 12' 12/13/1995 7178'-7180' 7178'-7180' 2' CURRENT PERFS: 1/8/1996 7105'-7114' 7105'-7114' 9' 6 2-1/2" HOLLOW CARRIER 1/8/1996 7056'-7076' 7056'-7076' 20' 6 2-1/2" HOLLOW CARRIER 1/8/1996 6990'-7010' 6990'-7010' 20' 6 2-1/2" HOLLOW CARRIER 2/8/1996 6904'-6914' 6904'-6914' 10' 6 2-1/2" HOLLOW CARRIER 2/8/1996 6886'-6896' 6886'-6896' 10' 6 2-1/2" HOLLOW CARRIER 2/8/1996 6854'-6874' 6854'-6874' 20' 6 2-1/2" HOLLOW CARRIER FRAC STIMULATE: 4/16/1996 6854'-6914' 6854'-6914' 60' 88,500 LBS Carbolite 4/16/1996 6990'-7110' 6990'-7110' 20' e e Marathon Oil Company OperaUons Summary Report ' Date KENAI BELUGAUNIT 41-7 KENAI BELUGA UNIT 41-7 WORKOVER GLACIER DRILLLlNG GLACIERDRILLlNG C $µþ Fr0111- To Höursq¡jè'cåäè Phase Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . 8/28/2005 09:00 - 09:15 0.25 SAFETY MTG_ WBPREP Objective of work to be done: Description of Operations 09:15 - 10:00 0.75 SAFETY MTG - WBPREP 10:00 - 11 :00 1.00 RURD - SLlK WBPREP 11 :00 - 1;3:00 2.00 DRIFT_ TBG - WBPREP 13:00 - 14:15 1.25 TAG_ BOTM WBPREP 14:15 - 15:15 1.00 CLNOU TBG - WBPREP 15:15 - 17:30 2.25 WAlTON EQIP WBPREP 17:30 - 18:30 1.00 SI;:TREL PLUG WBPREP 18:30 -19:15 0.75 SETREL PLUG WBPREP 19:15 - 20:00 0.75 RURD - SLlK WBPREP 8/30/2005 08:00 - 12:00 4.00 PREP - LOC_ WBPREP 14:00 - 14:15 0.25 SAFETY MTG_ WBPREP 14:15 - 14:30 0.25 SAFETY MTG_ WBPREP 14:30 - 15:30 1.00 RURD - ELEC WBPREP 15:30 - 16:00 0.50 SAFETY MTG_ WBPREP 16:00 - 17:30 1.50 CUT_ TBG - WBPREP 17:30 - 18:00 0.50 WORK ELEC WBPREP 18:00 - 22:00 4.00 WAITONORDR WBPREP 22:00 - 23:00 . 1.00 SECUR WELL WBPREP 8/31/2005 06:30 - 06:45 0.25 SAFETY MTG - WBPREP 06:45 - 07:00 I 0.25 SAFETY MTG_ WBPREP 07:00 "07:30 I 0.50 RURD - OTHR WBPREP 07:30 - 08:30 I 1.001 PUMP _ WTR_ WBPREP 08:30 - 08:45 0.25 SAFETY MTG - WBPREP 08:45 - 09:30 0:75 PULL_ _I EQIP WBPREP Page 1 of 12 Start: 8/27/2005 Rig Release: Rig Number: 1 Spud Date: 11/22/1979 End: 9/30/2005 Group: A successful Mechaniéallntegrity Test is required for the annulus of well KBU 41-7 before the State will approve òf Pool 6 gas storage. The well will not pass the required pressure test in its current configuration, likely due to squeeze perfs above the production packer. In order to obtain the required pressure test, the tubing and packer will have to be pulled and re-run. To mitigate the failure, the casing will be pressure tested and repaired if needed. The replacement packer will be set above the squeeze perfs and just beneath Pool 6. This wiH permit future MIT$ to reflect the integrity of the casing in KBU 41-7 from the base of the Pool 6 to surface. Sign in and obtain work permit. Discuss job. Meet on location with rig foreman. Well is very close to rig. Discuss procedures for bleeding lubricator, etc. RU wireline unit to tree. RI w/ 2.80" gauge cutter. Not able to drift nipple. POOH. Get hung up for 30+ minutes in packer at.6525'.Jar free and POOH. See some markings on GC. PU 1.5" bailer. Run through tubing string and past nipple w/ no problems. PU 3.5" tubing brush and run through. Crane truck experiencing hydraulic problems. LD lubricator and swap out èrane. PU lubricator and tool string w/X-line running tool and PX plug body. , RIHand set in nipple at 6708', POOH w/ no problems at 6525'. PU prong, RIHand set in plug body. RD slickline unit Disconnect power, remove wellhouse. Wireline arrive, sign in, issue work permit Hold job sight safety meeting. Talk to rig, fill out JSA RU e-line unit with cutter. Pwh=900psi. Annulus on vacuum. Hold radio silence safety meeting including production and rig personnel. . Begin rádio silence. · RIHw tubing cutter. Correlate to 1/2jt above K-anchor. Make cut at 6500'. Line blown up hole. Have to pull hard to get e-line free. Pwh=1200psi, Pann=vacuum. At surface, stuck with damaged line in grease tubes. Counter reads 160'. Close BOPs and discuss. Bleed 1200 psi WHP to production system (60psi). Well will not bleed down entirely. Plan to kill well in AM w/ hot oil truck. Will cut wire above BOPs, clamp and pull w/ extra lubricator and packoff instead of grease tubes. Sign in pump,truck and vac truck personnel. Issue permit and discuss job. Hold location safety meeting, filÎ out JSA. RU pump truck and vac truck to flow cross. Pump fresh water down tubing. Stop occasionally to bleed pressure. Pwh=50. Hold safety meeting with wireline personnel. Discuss procedure for stripping damaged wire out of well. With 50 bbl water pumped away, SD pump and bleed remaining 50 psi Printed: 11/9i2005 4:23:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: e e Page 2 of 12 Marathon Oil Company Operations Summary Report KENAI BELUGA UNIT 41':'7 KENAI BELUGA UNIT41-7 WORKOVER GLACIER DRILLLlNG GLACIER DRILLING SUb From;.. To HoÜts Code Code Phâsè Date 8/31/2005 08:45 "09:30 09:30 - 1 0:30 16:45 - 17:00 17:00 - 17:15 17:15 - 18:00 18:00 - 18:45 9/3/2005 18:45 - 19:40 06:00 - 1 ioo 12:00 - 14:00 ~ 14:00 - 00:00 00:00 - 06:00 9/4/2005 06:00 - 08:00 08:00 - 10:00 10:00 - 12:00 .. 12:00 - 12:30 12:30 - 13:30 13:30 -16:00 16:00 - 19:00 19:00 - 20:00 20:00 - 02:30 02:30 - 03:30 03:30 - 05:30 05:30 - 06:00 9/5/2005 06:00 - 08:30 08:30 - 09:00 I 0.75 PULL_ EQIP 1.00 RURD ELEC . 0.2~ SAFETY MTG_ 0.25 SAFETY MTG_ 0.75 RURD_ SUK 0.75 ENGAG FISH WBPREP WBPREP WBPREP WBPREP WBPREP WBPREP 0.92 RURD_ CML WBPREP 6.00, MOB RIG_ MIRU PJSM. Prep carrier, spit pits and pump room. Load out generator, boiler house, and water tank. Prep to move carrier, mud boat, sub, cuttings tank, pits, pump room and parts trailer. Move and spot boiler house, pits, pump room and sub. PJSM. Set sub, mud boat, carrier, generator house, water tank, cuttings tank, catwalk, and trip tank. PJSM for crane work.ßet Outrirrers,Dog&Choke Houses,Stairs, Landings Flowline,Panic Line, Conex,FuelTank And Windwalls.Rase Derrick. Set . Pit And Pump Rooms Together. R/U Mud Lines, ChokeLines And HP Mud Lines. Scope Derrick Up, R/U Catwalk & Beaver Slide. Run Elect. Lines R/U Drillers Console, All Rig Service Lines. PJSM;RìU Torque Tube & Top Drive, Mix 400 BBI 6% 8.55ppg KCL Brine. No Accidents/ Near Misses/ Or Spills. Connect service lOop to top drive unit. Rebuild choke manifold valves10,11,12. Check koomey bottles. Check out rig watch system. 2.00 SER,VIC RIG_ WBPREP Replace valve stem on #1 koomey boUle and recharge. Install bales and elvators. 'Service top drive. Change top drive'compensator. Safety inspect rig.. Test run pumps and top drive. Pull BPVand R/U to circ. well. R/U epoch rig watch. Safety meeting prior to starting well. .. Pump 8.6ppg KCL brine down TBG, Hadreturns after pumping 40bbls. Returns were 100% diesel. 2.50 SLPCUT DUN WBPREP Slip and cut drlg line ana Inspect brake linkage while wait forvac trucks. 3,00 CIRC_ MUD_ WBPREP Cont. to pump 6%KCl brine(got back total 220bb'ls diesel. 200bbls foamy surfactant, last 40bbls mud contaminated brine). PJSM ;Set BPV, N/D Well Head / Tree N/U 11"5m X13 5/8" 5m Adapters Spool N/U R,S,Rd,A 13 5/8" 5m BOP Stack, Accmulator Lines ,Choke & Kill Lines. R/U Drip Pan And rFlow Line. C/O Pipe Rams. I PJSM; Pull BPV, R/U Test Joint. Test Annular, Upper Kelly Valve And Choke Maf. Valves # 10, 11&12 To 250/3000. Choke Line Api ring Leaked. Adapter Flange Also Leaking. Repair; Replace Api Ring On Chòke Line/ Hammer Up Adapter Flange Test annular, 3.5" TIW, kill line check valve, upper kelly, CMV1,1 0, 11,12 250/3000psi 10m in., Test Lower Kelly, inside and oûtside kill line valves CMV#2-10, 2 7/8" X 5 1/2" variable rams, HCR, inside choke line valve and blind rams to 250/3000psi 10min(noAOGCC or BLM witness), Pull TWC. Install 3 1/2" Landing joint. Perform Koomey test. 2.00 MOB RIG_ 10.00 RURD_ RIG_ 6.00 RURD_ RIG_ 2.00 RURD_ RIG_ MIRU SIDET MIRU MIRU, Start: 8/27/2005 Rig Release: Rig Number: 1 Spud Date: 11/22/1979 End: 9/30/2005 Group: Description of Operations off tubing. Open wire rams, check for pressure and break lubricator. PU lubricator and Hn 30'. Line pulling easy. Hand pull line out of well bore to end and find no tool string. Line appears to have been pulled 'out of rope socket. Shut in valves and RD line. ,Call out slickline truck. Sign in slickline, hold mtg, and issue permit. Survey area, fill out JSA. RU slickline RIH w/2.75" bell guide and 1-3/8" JDC. Latch e-line fish at 6449' WLM. POOH. RD slickline Accept rig F/KTU43-6XRD2 @ 06:00hrs 09/02/2005, 2.00 CIRC_ CFLD WBPREP 0.50 SAFETY MTG_ WBPREP 1.00 CIRC~ MUD_ WBPREP 1.00 NUND 6.50 NUND WLHD XMBO BOPE XMBO 1.00 TEST _ BOPE XMBO 2,00 REPAIR RIG_ XMBO 0,50 TEST _ BOPE XMBO 2,50 TEST _ BOPE XMBO 0.50 TEST_. BOPE XMBO Printed: 11/9/2005 4:23:08 PM e e ~ Marathon Oil Company . Operations Summary Repo,rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KENAI BELUGA UNIT 41-7 KENAI BELUGA UNIT 41-7 WORKOVER GLACIER DRILLLlNG GLACIER DRILLING Sub From.. To Hours Code Code Phåse Date 9/5/2005 09:00 - 10:00 10:00 - 11 :00 11 :00 - 11 :30 11 :30 - 20:00 1.00 RUNPU TBG_ CMPPUL 1.00 CIRC_ CFLD CMPPUL 0.50 RURD - OTHR CMPPUL 8.50 PULD_ TBG_ CMPPUL 1.50 PULD - EQIP CMPPUL 1.50 TEST_ BOPE CMPPUL 1.00 REPAIR RIG_ CMPPUL 2.50 PULD - PKR_ CMPPUL 2.00 REPAIR RIG - CMPPUL Page 3 of 12 Start: 8/27/2005 Rig Release: Rig Number: 1 Spud Date: 11/22/1979 End: 9/30/2005 Group: 20:00 - 2) :30 21 :30 ~ 23:00 23:00 - 00:00 00:00 - 02:30' 02:30 - 04:30 Description of Operations PullTBG hanger to rig fioor(string wt 50K).UD landing joint. Circ. B/U(small amount of formation across shaker at about 1/2 B/U.). RlU Weatherford CSG tools. POOH UD 3.5" 9.2PPF N-80 Butt TBG. UD Total Of 215 Jts, 2-3.5 Pups 15' Long and chemical injection mandrel w/controlline. RlU D/P Spinners, Tongs C/O Elevators & Rotary Tools M/U Test Joint SetTest Plug, Attempt to Test Lower Pipe Rams. Pipe Rams Failed To Test (LeakingBy Ram Seal Face) RID Test Jòint Wait On RT>TS ( Storm Packer) To Secure Well Bore For Ram Block C/O, P/U & M/U 86.1/4 D/C & RTTS Packer And SSV. Set RTTS 35' Into Well Bore To Secure Well. M/U Test Joint! Set Test Plug Replace Rams And Ram Carriers On Lower Pipe Rams. Test 4" Rams, 4" TIW, and 4" IBOP to 250 /3000 Test Good. PulL Test Plug RID Test joint. Un Seat RTTS Packer / SSV And Lay Down. Stand Back 8- 61/4 De's. Run wear bushing. P/U Baker 81/8" overshot guide w/3 1/2" hollow mill and 3 1/2" basket grapple. C RIH w/6 1/4" collars and 5" HWDP from derrick. PJSM. P/U 4" DP while RIH wlfishing assy#(P/U total 197jnts). Tag TOF@6487'(P/U125K, S/0125K, ROT125K). Mill over fish and release K-anchor w/20right handed turns. Cont. to circ.until B/U complete. MonitorWell; Pooh ($LM) To BHA. No Gain Or Loss. No Correction To Pipe Tally UD Mill And Grapple. Recovered 14.60' Of Cut Off Jt., 4.05 Pup And K Anchor. PJSM; M/U Baker 81/2 Mill And Grapple Assy BHA RrH W61/4 SDC& HWDP From Derrick RIH W/D/P To 6500 Tag Packer Top At 6506, Sting intoW PTR Mill Extension,Set 10k Down/ P/U To 30K Over String Wt., Confirm Grapple Latched Up Mill On Packer From 6506' Up Wt. 125k/ Dn. Wt 125/ Rt. Wt. 125 K Tq ~ T03K 178gpm,895psi. Mill packer at 6506' to 6508' pumping sweeps(4BPM,800psi,15KWOB, 85RPM). Cont. to mill packer @ 6508'(having to work pipe and dry drill due to packing off). Cont. to mill packer @ 6508'(as soon as packing of stopped, circulated gas to surface, 4BPM, 800psi,,15KWOB, 85RPM). Released PRT by pumping out. Pull up hole to confirm release. Attempt to get PRT to latch in packer no success. . Monitor Well, Pooh F-6508To BHA. No Gain/Loss PJSM: Stand Back D/C, Break Down Junk Baskets & Clean Out Recovered 20-25# Of Material M/U Mill BHA#3 RIH RIH W/ DP To 6507 Mill Packer F-6508 To 6509, WT. 9n Mill9k t018k/ Tq. 2500-6000, Pump Rate 90 Spm=325Psi/ Mill w/o Pumps.Break Packer Free. PRT Grapple Failed To Catch Packer Chase Packer To 6628' (Top Of Packer #2) Set 20k Down, AttemptTo 04:30 - 05:30 1.00 PULD PKR.:.. CMPPUL 05:30 - 06:00 0.50 PULD - BHA_ CMPPUL 9/6/2005 06:00 - 07:00 1.00 RUNPU WBSH CMPPUL 07:00 - 09:00 2.00 PULD - BHA._ CMPPUL û9:00 - û9:30 0.50 TRIP - . BHA_ CMPPUL , 09:30 - 16:00 . 6.50 PULD - bp - CMPPUL 16:00 - 18:30 2.50 MILL_ FISH CMPPUL 18:30 - 19:00 0.50 CIRC - CFLD CMPPUL 19:00 - 23:00 4.00 TRIP - DP - CMPPUL 23:00 - 00:00 1.00 TRIP - BHA_ CMPPUL 00:00 - 01 :00 1.00 TRIP_ BHA_ éMPPUL 01 :00- 04:30 3.50 TRIP - DP - CMPPUL 04:30 - 06:00 1.50 MILL_ PKR_ CMPPUL . 9/7/2005 06:00 - 08:30 2.50 MILL_ PKR_ CMPPUL 08:30 - 10:30 2.00 MILL_ PKR_ CMPPUL 10:30 - 17:00 6.50 MILL_ PKR_ CMPPUL I CMPPUL 17:00 - 17:30 0.50 MILL_ PKR_ 17:30 - 21 :00 3.50 TRIP - DP - CMPPUL 21 :00- 23:00 2.00 TRIP - BHA_ CMPPUL 23:00 - 23:30 0.50 TRIP - BHA_ CMPPUL 23:30 ~ 02:30 3.00 TRIP - DP - CMPPUL 02:30 - 03:3Ö 1.00 MILL - PKR_ CMPPUL 03:30 - 04:30 1.00 MILL_ PKR_ CMPPUL Printed: 11/9/2005 4:23:08 PM ~- e Page 4 of 12 Marathon Oil Company .""'<:,_ ._.'..". _.,:¡_,...-.-_____.-.-.-.: ,.__.,.1, . OperafionsSummary Report Legal Well Name: KENAI BELUGA UNIT 41-7 Common Well Name: KENAI BELUGA UNIT 41-7 Event Name:' WORKOVER Contractor Name: GLACIER DRILLLlNG Rig Name: GLACIER DRILLING Däte From" To Hours ·,Code SÜb Phase Cöde 9/7/2005 03:30 . 04:30 1.00 MILL PKR_ CMPPUL 04:30 - 06:00 1.50 CIRC,- CFLD CMPPUL 9/8/2005 06:00 - 07:00 1.00 CIRC_ CFLD CMPPUL 07:00 - 11 :00 4.00 TRIP - DP - CMPPUL 11:00 - 12:30 1.50 TRIP - BHA_ CMPPUL 12:30 - 13:30 1.00 TRIP BHA_ CMPPUL 13:30 - 14:30 1.00 SERVIC RIG - CMPPUL 14:30 - 16:30 2.00 TRIP - DP - CMPPUL 16:30 - 17:00 0.50 WSHOV ISH CMPPUL 17:00 - 18:00 1.00 CIRC_ CFLD CMPPUL 18:00 - 00:30 6.50 TRIP - DP - CMPPUL 00:30 - 01 :30 1.00 TRIP - BHA_ CMPPUL 01 :30 - 03:00 1.50 TRIP - BHA_ CMPPUL 03:00 - 06:00 3.00 TRIP - DP - CMPPUL 9/9/2005 06:00 - 06:30 0.50 SETREL PKR_ CMPPUL 06:30 - 12:00 5.50 TRIP DP CMPPUL - - 12:00 - 13:00 1.00 SAFETY MTG_ CMPPUL 13:00- 14:00 1.00 TRIP - DP - CMPPUL 14:00 - 16:00 2.00 TRIP - BHA_ CMPPUL 16:00 - 18:00 2.00SERVIC RIG_ CMPPUL 18:00 - 19:30 1.50 TRIP - BHA_ CLNOUT 19:30 - 21 :30 2.00 TRIP - DP - CLNOUT 21 :30 - 23:00 1.50 CIRC_ CFLD CLNOUT 23:00 - 02:00 3.00 CIRC - CFLD CLNOUT 02:00 - 05:30 3.50 TRIP - DP - CLNOUT 05:30 - 06:00 0.50 TRIP - BHA_ . CLNOUT 9/10/2005 06:00 - 08:30 2.50 TRIP - BHA_ CLNOUT 08:30 - 09:00 0.50 RURD - SLlK CLNOUT .. 09:00 - 12:00 3,00 WORK SLlK CLNOUT 12:00 - 12:30 0.50 RURD - SLlK CLNOUT 12:30 - 15:00 2,50 TRIP - BHA_ CLNOUT 15:00 - 17:30 2,50 TRIP - DP - CLNOUT 17:30 - 18:30 1,00 WORK PIPE CLNOUT 18:30 - 22:00' 3.50 TRIP - DP - CLNOUT 22:00 -22:30 0.50 TRIP BHA_ CLNOUT 22:30 - 00:30 2.001TRIP - BHA_ CLNOUT 00:30 - 04:00 3.50 TRIP_ DP - ICL~OUT 04:00 - 05:30 1.50 I CIRC_ CFLD CLNOUT 05:30 - 06:00 0:50 TRIP - DP - CLNOUT 9/11/2005 106:00 - 08:00 2.00 TRIP - DP CLNOUT 08:00 - 12:30 4.50 REPAIR RIG - CLNOUT . Start: 8/27/2005 Rig Release: Rig Number: 1 Spud Date: 11/22/1979 End: 9/30/2005 Group: Description of Operations Engage PRT Grapple. No Indicátion If Succéssful. Drop Bar Open Pump Out Sub /Pump 40 BBLHi Vis Sweep At 120 SPM/ 330 PSI/233 GPM Clean Hole Cont circ / cohd fluids, clean fluid after metal returns with sweep. . PJSM, flow check"POH 4" DP with.fish Flow check, handle BHA #3, no fish·retrieved MU BHA #4 (Spear assy), flow check, RJH same Service rig Flow check, RIH 4" DP to tag fish at 6628 ft Spear fish (packer), confirm engaged with pump press Drop bar, open circ sub, circ while fill trip tank . PJSM, flow cheèk, POH with fish (packer) on 4" DP Flow check, handle BHA #4, no fish retrieved MU BHA #5 (New spèar assy), RIH same Flow check, RIH 4" DPto 6600 ft at 0600 hrs Spear pkr, confirm engaged with pump press / string wt. PJSM, flow check, POH 4" DP with fish (packer) Weekly safe meeting, all personnel Flow check, resume POH 4" DP to BHA Flow check at BHA, handlè BHA #5, laydn retrieved fish (entire pkr assy) Service rig . MU BHA #6(2 1/16 stinger / clean out assy), RIH same Flow check, follow BHA with 4" DP to 6637 ft Circl cond fluids, increase vise for clean out Circ sweeps, recippipe to 6ft above plug Drag / junk initially, slight drag at end eire, varied quantity metal/ junk at shaker. Flow check, POH 4" DP to BHA Handle BHA #6, approaching boot bskts at 0600 hrs Cont LD BHA #6, boot bskts / string magnet full junk. Clean same. PJSM, rig up slickline for magnet run Flow check, RIH magnet to tag at 6647 ft, can not pàss, POH, run magnet without skirt, can not pass 6647 ft, POH, RIH guage ring, can not pass 6648 ft, POH wire line. Rig dn wireline equip, release unit. MU BHA #7 (Mule shoe / 2 1/16 stinger), flow check, RIH same Follow BHA with 4" DP to tag up at 6650 ft Can not pass pkr top. Attempt work through, no success. PJSM, flow check, POH 4" DP for mill/ motor. Lay dn BHA #7 . MU BHA #8 (mill/ motor assy), RIH same, surface test mtr. Flow check, follow BHA with 4".DP to 6603 ft. Fill pipe with full returns at 2500, 5000 ft. Attempt circ at 6603 ft, drill string plugged, attempt break circ various methods, no success, PJSM, flow check, POH for plugged string, 6000 ft at 0600 hrs. Cont POH 4" DP to 4000 ft Repair rig (Hyd leak, brake disc) .. Printed: 11/9/2005 4:23:08 PM e e Page 5 of 12 , Marathon Oil Company· Operations Summary Réport Date KENAI B'ELUGA UNIT 41-7 KENAI BELUGA UNIT 41-7 WORkoVER GLACIER DRILLLlNG GLACIER DRILLING Sub Fröm- To Hour$ CddeCOôe Phase Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 9/11/2005 12:30 - 14:00 14:00 - 15:00 1.50 TRIP _ DP _ CLNOUT 1.00 TRIP _ BHA_ CLNOUT I 15:00 - 16:30 1.50 TRIP BHA_ CLNOUT 16:30 - 21 :00 4.50 TRIP - DP - CLNOUT 21 :00 - 03:30 6.50 MILL_ JUNK CLNOUT 03:30 - 06:00 2.50 CIRC_ CFLD CLNOUT 9/12/2005 06:00 - 06:30 0.50 CIRC_ CFLD CLNOUT 06:30 - 09:30 3.00 TRIP - DP - CLNOUT 09:30 . 11 :30 2.00 TRIP-,- BHA_ CLNOUT 11:30 - 12:30 1.00 TRIP - BHA_ CMPRUN 12:30 - 15:30 3.00 TRIP - DP - CMPRUN 15:30 - 16:00 0.50 TEST - PKR - CMPRUN 16:00 - 17:00 1.00 TRIP - DP - CMPRUN 17:00 - 18:00 1.00 TEST_ CSG_ CMPRUN 18:00 - 21 :00 3.00 TRIP - DP - CMPRUN 21 :00 - 22:00 1.00 TRIP - BHA_ CMF'RUN 22:00 - 02:30 4.50 TEST_ BOPE CMPRUN 02:30 -05:00 2.50 PULD - PKR_ CMPRUN 05:00 - 06:00 1.00 TRIP - DP - CMPRUN 9/13/2005 06:00 - 09:30 3.50 TRIP - DP - CMPRUN 09:30 - 12:30 3.00 CJRC_ CFLD CMPRUN 12:30 - 14:00 1.50 SETREL PKR_ CMPRUN .. 14:00 - 21:00 21 :00 - 22:00 22:00 - 01 :30 7,00 TRIP _ DP _ CMPRUN 1.00 TRIP _ BHA_ CMPRUN 3.50 WORKSLlK CMPRUN I 1.50 RURD ~ CSG 3.00 RUNPU ¡TBG_ 3.50 RUNPU~TBG_ 1.00 PULD EQIP 4,00 RUNPUL TBG_ I 3.00 TEST_I PKR_ 01 :30 - 03:00 03:00 - 06:00 CMPRUN CMPRUN 9/14/2005 I CMPRUN CMPRUN 06:00 - 09:30 09:30 - 10:30 10:30 - 14:30 CMPRUN 114:30 -17:30 I ' CMPRUN Start: 8/27/2005 Rig Release: Rig Number: 1 Spud Date: 11/22/1979 End: 9/30/2005 Group: Description of Operations Flow check, resume POH 4" DP to BHA Flow check, troubleshoot motor / mill, clean metal shavings from same, re·test motor at surface, RPMs erratic, lay dn motor. MU new motor / mill assy, surface. test, RIHsame Flow check, follow BHA with 4" DP to 6648 ft. Circ DP volume at 20 std intervals, confirm string clear. Commence mill junk at tag up 6648 ft to 6999 ft (mill out to 6 ft.above X nipplel plug) Circsweeps, re-cip pipe, (large quantity shavings at shaker) Cont circ clean, no stick / drag at pkr I.D. Circ sweep, clean shaker. F'JSM, flow check, POH 4" DP to BHA Flow check, lay dn.BHA #9 (mill/ motor) MU BHA #10 (RTTS / seal assy), RIH same Follow BHA with 4" DP to pkr at 6650 ft Stab in pkr, attempt test seal bore, no test, pkrleak. POH to 5000 ft pkrdepth for csg test Set RTTS, test 95/8 csg to 1500 psi /30 min test successful, no re-test POH 4" DP to BHA Lay dn BHA #1 0, seals partial damage due to pkr bore Test BOPE, all components, 250/3000 psi Test successful, no re-tests Witness waived by Mr John Spaulding AOGCC MU pkr / seal bore assy (no seals), RIH same. Flow check, follow.pkr with 4" DP to 2400 ft at 0600 hrs. Cont RIH Baker S3 pkr on 4" DP to 6650 ft Circ / cond fluids with Concor 303 / Greencide. Sting in existîng Mod "D" pkr at 6650 ft, drop ball bar, set pkr at 6578 ft with 3000 psi, build to 4000 psi / 30 min. Test successful. Bleed press, shear PBR seal assy. PJSM, flow check, POH laying dn 4" DP to pkr run tool Lay dn pkr run tools, clear floor PJSM, flow check, RIH slickline, pull RHC prong / valve body. Slow going, latch up problem. All tools retrieved. Release unit. PJSM, place tbg run equip irig floor, RU same. Commence run 3 1/2 completion assy: Seal assy, Loc sub, tbg pup, jt tbg, XO, Sliding Sleeve, XO, tbg pup, jts 3 1/2 L80 1ST 9.2 tbg. Depth 1379 ft at 0600 hrs. Cont RIH 3 1/2 tbg to inj mandrel depth PJSM, RU Pollard / equip, MU injection mandrel at 1000 ft Test connections,MU ini tbg, build / hold pres~ at line. Resume RIH 3 1/2 tbg (9.2, IBT Mod, L80), sting in PBR at 6578 ft, space out, install tbg hgr; terminate control line, sting in PBR /Iand tbg hgrwith 67K. Final depth...PKR 4650.51 ft, Inj Mandrel 992.64 ft Sliding sleeve 6526.69 ft, seal assy6570ft, mule shoe 6580 PJSM, Test hgr 5000 psi /10 min, test tbg 300 psi / 15 min Drop ball bar, set Baker SB3 pkr with 1800 psi, Build to 4000 psi/30 min, test 95/8 X 31/2 ann .. Printed: 11i9/2005 4:23:08 PM e . Page 6 of 12 Marathon Oil Company ...·.·.·'.·.....':·..·.'.·,"d,..,._._-,.-·,'>._,:.."-".,."_".,'.','",.,',,_,,,'.":.'.,.', Operations Summary Report 3.00 TEST PKR_ CMPRUN 1500 psi /30 min, all tests successful, no re·tests. 4.00 RUNPU SLlKGMPRUN PJSM, RU slickline, pull ball bar / RHC plug. Slow going, difficult latching bar and plug. Rig dn Pollard, release unit. PJSM, Test tbg 2000 psi /30 min, test successful Flush pumps, lines, BOPE, all related equip for nipple dn. PJSM, nipple dn BOPE for prod tree. Prepare nipple up prod tree. PJSM: Install Tree, Test Void To 5000 psi For 15 Min (Test Good) Remove BPV,lnstall Two Way Check, Test Tree To 5000psi For 15 Min. (Test Good) Pull2 Way Ck. Valve Install BPV. Pjsm; RID Load Out BOP Stack, Accmulator Lines,Gas Buster Kill & Choke Lines, Mud Lines, Cuttings TankAnd Top Drive. Unplug Pits & Pump Room. Load out Trailers. Pjsm; LID Top Drive, RID & LID Torque Tube. RID Stairs & BOP Conex, Mud Manfold, RID Monkey Board,Load Lines & Guide Lines. Pjsm; Lower Bneaver Slide & Scope Down Mast. RID Service Lines To Rig. Pjsm: Crane Operations, RID Stairs, Trip Tank, Choke House. Legal Well Name: Common'Well Name: Event Name: Contractor Name: Rig Name: Date From - To KENAI BELUGA UNIT 41-7 KENAI BELUGA UNIT 41-7 WORKOVER GLACIER DRILLLlNG GLACIER DRILLING , "'." . <',.,.' , ,$Üt> Hour~ CodeCodê Phase 9/14/2005 14:30 - 17:30 17:30 - 21 :30 21 :30 - 22:30 1.00 TEST_ PKR_ CMPRUN 22:30 - 02:30 4.00 CLEAN~ TANK XMBO 02:30 - 05:30 3.00 NUND BOPE XMBO 05:30 - 06:00 0.50 NUND TREE XMBO 9/15/2005 06:00 . 07:00 1.00 TEST_ TREÈ XMBO 07:00 - '08:30 1.50 TEST_ TREE XMBO 08:30 - 12:00 3.50 RURD - RIG_ RDMO 12:00 - 00:00 12.00 RURD - RIG - RDMO 00:00 - 04:00 4.00 RURD - RIG - RDMO 04:00 - 06:00 2.00 RURD_ RIG_ RDMO 9/16/2005 06:00 - 12:00 6.00 RURD - RIG - RDMO 9/28/2005 07:15 - 07:30 0.25 SAFETY MTG_ CMPPUL 07:30 - 09:pO 1.50 RURD - SLlK CMPPUL 09:00 - 09:35 0.58 WAlTON EQIP CMPPUL 09:35 - 10:20 0.75 TAG_ BOTM CMPPUL 10:20 -17:30 7.17 BAIL_ FILL CMPPUL 17:30 -18:00 0.50 RURD - SLlK CMPPUL 07:30 - 07:45 0.25 SAFETY MTG_ CMPPUL 07:45 - 08:00 0.25 RURO - SLlK CMPPUL 08:00 - 09:00 1.00 BAIL_ FILL CMPPUL 09:00 - 09:40 0.67 TAG - BOTM CMPPUL 09:40 - 10:20 0.67 TAG_ BOTM CMPPUL 10:20 - 11 :30 1.17 RUNPU~SLlK CMPPUL 11 :30 - 12:45 1.25, BAIL_ IFILL CMPPUL 12:45 - 13:30 0,75\ BAIL_ IFILL I CMPPUL 113:30 - 14:30 I FILL CMPPUL 1.00 I BAlL_ I 14:30 - 15:30 1.00 I BAIL_ FILL CMPPUL 15:30· 16:30 1.00 BAIL - FILL ! CMPPUL " .. 9/29/2005 Start: 8/27/2005 Rig Release: Rig Number: 1 Spud Date: 11/22/1979 End: 9/30/2005 Group: Description of Operations PJSM; RIO & Load Out Dog House Stairs, Wind Walls Derrick House, Gray Iron & Fuel Tank. Complete Crane Work. Split Pits. Pjsm; LID Derrick, Prep Loads, Ready Carrier, Prep Pits & Pump Room For Transport. No Accidents/ Spills Or Near Misses PJSM; Complete Crane Work, Split Pits & LID Derrick Load Out Gen House,Pump Room,Pits, Boiler House Pits,Boilerhouse, Mud Boat& Subase RID Camp Rig Released FromKBU 41-7 @At 1200 Hrs. 9/15/05 Arrive on location. .Discuss work RU slickline unit. Stand by for production to RU control lines PU 2,.25" LIB. Run to 6700'KB. See imprints of metal. RIH w/ 2.25" DD bailer. Comeback with metal, debris, and dirty water. Repeat x7 to depth of 6702'. Rig back slickline for night and plan to continue following day. Arrive at office, sign in and hold safety meeting, obtain work permit. RUslickline RIH w/ 2.25" DD bailer to 6702' KB. Work bailer, POOH w/ nothing. RIH wi 2.25" LIB to 6702'. At surface with large piece of metal stuck in LIB and impression of several more pieces of metal. RIH w/ same to 6702' KB and tag. POOH w/ impression of several pieces of metal. RIH w/2.70" magnet to 6702'KB. Tag multiple times and POOH w/ smallmétal shavings. RJH w/2.25" pump bailer to 6702' KB. Work bailer and POOH. Empty bailer. RIH wi 2.25" DO bailer to 6702' KB, Work bailer and POOH w/large piece of metal and 1/2c shavings. RIH w/ same to 6702', Work bailer and POOH w/lump of metal shavings. RIH w/ sameto 6702'. Work bailer and POOH. Empty bailer. I RIH w/ 2.25" pump bailer to 6702'. Work bialer and POOH w/1/2c .. Printed: 11/9/2005 4:23:08 PM Legal Well Name: ' Common Well Name: Event Name: Contractor Name: Rig Name: Dàte 9/29/2005 9/30/2005 10/1/2005 . 10/2/2005 10/3/2005 e e Marathon Oil Company 'Ope,raÌions Summary Report KENAI BELUGA UNIT 41-7 KENAI BELUGA UNIT 41-7 WORKOVER GLACIER DRILLLlNG GLACIER DRILLING Sub From.. To Hours Cadé Code Phasé 15;30 - 16:30 16:30 - 18:00 07:00 - 07:30 07:30 - 08:15 08:15 - 09:20 09:20 - 10:30 10:30 - 11 :20 11 :20 - 12:20 12:20 - 13:20 13:20 - 14:00 14:00 - 15:00 15:00 - 16:00 16:00 - 16:50 16:50 - 17:30 17:30 -18:00 07:15 - 07:30 07:30 - 08:00 08:00- 09:00 . 09:00 - 10:00 10:00 - 10:45 10:45 - 11 :30 11:30-12:10 12:10 - 13:00 13:00 - 13:50 13:50 -14:50 14:50 - 16:00 16:00 - 17:00 17:00 - 18:00 18:00 -18:40 18:40 - 19:00 07:15 - 07:30 07:30 - 08:00 08:00 - 09:00 09:00 - 10:00 10:00 - 10:40 10:40 - 11 :40 11 :40 - 12:30 12:30 - 14:30 14:.30 - 15:00 15:00 - 16:00 16:00 - 16:30 16:30-17:10 17:10 - 17:45 07:15 - 07:30 07:30 - 08:30 08:30 - 09:30 1.00 BAIL_ FILL CMPPUL 1.50 RURD - SLlK CMPPUL 0.50 SAFETY MTG_ èMPPUL 0.75 RURD - SLlK CMPPUL 1.08 BAIL_ FILL CMPPUL 1.17 WAlTON EQIP CMPPUL 0.83 BAIL_ FILL CMPPUL 1.00 BAIL_ FILL CMPPUL 1.00 BAIL_ FILL CMPPUL 0.67 TAG - BOTM CMPPUL 1.00 BAIL_ FILL CMPPUL 1.00 BAIL_ FILL CMPPUL , 0.83 BAIL_ . FILL CMPPUL 0.67 BAIL_ FILL CMPPUL 0.50 RURD SLlK CMPPUL 0.25 SAFETY MTG_ CMPPUL 0.50 RURD - SLlK CMPPUL 1.00 BAIL_ FILL CMPPUL 1.00 BAIL_ FILL CMPPUL 0.75 BAIL - FILL CMPPUL 0.75 BAIL_ FILL CMPPUL 0.67 TAG - BOTM CMPPUL 0.83 BAIL_ FILL CMPPUL 0.83 BAIL - FILL CMPPUL 1.00 BAIL_ FILL CMPPUL 1.17 BAIL_ FILL CMPPUL 1.00 BAIL_ FILL CMPPUL 1,00 BAIL_ FILL CMPPUL 0.67 BAIL_ FILL CMPPUL 0,33 RURD_ SLlK CMPPUL 0.25 SA.FETY¡M,TG._ CMPPUL 0.50 RURD_ SLlK CMPPUL 1.00 BAIL_ FILL I CMPPUL 1,00 BAIL_ FILL CMPPUL 0,67 REPAIR EQIP CMPPUL 1.00 BAIL_ FILL CMPPUL 0.83 TAG BOTM CMPPUL 2,00 BAIL_ FILL 1 CMPPUL 0.50 RURD SLlK 1.00 ENGAG FISH 0,501 RURD_ SLlK 0.67 BAIL_ FILL 0,58 RURD_ SLlK 0.25 SAFETY MTG_ 1.00 RURD_ SLlK 1;00 BAIL_ FILL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL Pagé 7 of Start: 8/27/2005 Rig Release: Rig Number: 1 Spud Date: 11/22/1979 End: 9/30/2005 Group: Description of Operations large metal pieces. RD for night. Arrive at gas field, hold safety meeting, obtain work permit. RU slickline unit RIH w/2-1/2" pump bailer to 6703'KB.. Work bailer and pooh wI lump of metal and packer chunks.. Strip threads on bailer and have to sènd to shop for service. Wait for replacement bailer. RIH wI same to 6703' KB., Recover 1/4 c metal pieces. RIH wI same. POOH wI 1 piece rubber, 6 pieces mètal RIH wI same, POOH w/1 piece metal. RIH wI 2-1/2" LIB tag at 6703'KB. Impression of several metal pieces. RIH wI 2-1/2" pump bailer. POOH wI several pieces of metal + 1 rubber. RIH wI same, recover 3 pieces metal. RIH wI same, recover 1 large piece of metal RIH wI same to 6704'KB recover 2 pieces metal. Rig back for night. Arrive at office. Hold safety meeting, obtain work permit. RU slickline·unit. RIH wI 2-1/2" pump bailer, recover 1big piece metal. RIH wI same; POOH wI 2 pieces metal. RIH wI same. POOH w/1 piece metal RIH wI same. POOH w/1 piece rubber RIH w/2-.1/2" LIB to 6704'KB. Tag. POOH wI impression of large metal chunks. RIH wI 2-1/2" pump bailer. Empty bailer. RIH wI same recover 2 pieces of metal. RIHwl same, recover 3 pieces of metal. RIH wI 1-3/4" hydrostatic bailer to 6704' KB. Work and POOH wI empty bailer. RIH wI 2-1/2" pump bailer, recover 1/2c metal. RIH wI same, recover 1/2c metal RIH wI same, recover 1 large piece metal. RD slickline for night. Sign in at office. Obtain work permit, hold safety meeting. RU slickline unit RIH wI 2-1/2" pump bailer to 6704'. Recover 1/4c metal chunks, RIH wI same, recover 1 piece of metal. Rebuild hydrostaic bailer RIH wI 1-3/4" hydrostatic bailer tOJ6704' recover 1 c metal shavings. RIH wI 2" LIB to 6704'. Recover impression of several pieces of metal. RIH wI 2-1/2" pump bailer to 6704' KB. Wire broke while bailing. Wire appears to have been cut. Put new tool string together and add more lubricator for fishing. RIH wI 2-1/2" JDC to 6678' KB. Latch fish. POOH wI fish. 1 piece of metal in bailer. Retie knot, cut 50' wire, and swap to bailing tool string. RIH wI 2-1/2" DD bailer. Recover 1 piece of metal. RD for night. Sign in at office, obtain work permit, hold safety meeting, RÚ slickline unit, rebuild hydrostatic bailer. RIH wI 1-3/4" hydrostatic bailer to 6704', Recover 1/2 c milled metal. . Printed: 11/9/2005 4:23:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1 0/3/2005 1014/2005 10/5/2005 .. 10/6/2005 10/7/2005 e e Marathon·Oil Company " :. ...... >' '" .. , Operations· Summary Report KENAI BELUGA UNIT 41-7 KENAI BELUGA UNIT 41-7 WORKOVER GLACIER DRILLLlNG GLACIER DRILLING SUb From ..:. Tö Hours Codê Codé Phåse. 09:30 - 10:30 10:30-11:15 11:15-12:10 12:10 - 13:00 13:00 - 13:50 13:50 - 14;20 14:20 - 15:20 15:20 - 16:10 16:10-17:00 17:00 - 17:30 08:00 - 08:15 08:15 - 08:45 08:45 - 09:30 09:30 - 10:30 10:30 - 11 :15 11 :15 - 12:15 12:15 - 13:20 13:20 - 14:00 14:00 - 14:45 14:45 - 15:45 15:45 - 16:30 16:30-17:15 17:15-18:00 07: 15 - 07:30 07:30 - 08:15 08:15 -09:30 09:30 - 11 :00 11:00-11:50 11:50 - 12:45 12:45 - 13:40 13:40 - 14:30 14:30 - 15:15 15:15 - 16:00 16:00 - 16:40 16:40-17:15 17:15 -18:00 07:30 - 07:45 i 07:45 - 11 :00 11 :00 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 15,:00 II 15:00 - 16:00 16:00 - 16:25 16:25 - 17:00 117, :00 - 17:45 17:45 - 18:00 107:00 - 08:00 I i 1.00 BAIL - FILL CMPPUL 0.75 BAIL_ FILL CMPPUL 0.92 BAIL_ FILL CMPPUL 0.83 BAIL - FILL CMPPUL 0.83 BAIL_ FILL CMPPUL 0.50 TAG_ BOTM CMPPUL 1.00 BAIL_ FILL CMPPUL 0.83 BAIL_ FILL CMPPUL 0.83 BAIL_ FILL CMPPUL 0.50 RURD - SLlK Cfy1F>PUL 0.25 SAFETY MTG_ CMPPUL 0.50 RURD_ SLlK CMPPUL 0.75 BAIL_ FILL CMPPUL 1.00 BAIL_ FILL 0.75 ENGAG FISH 1.00 BAIL_ FILL 1.08 BAIL_ FILL 0.67 ENGAG FISH 0.75 ENGAG FISH 1;00 BAIL_ FILL 0.75 BAIL_ FILL 0.75 TAG_ BOTM 0.75 RURIJ_ SLlK 0.25 SAFETY MTG_ 0.75 RURD_ SLlK 1.25 TAG_ BOTM 1.50 ENGAG FISH 0.83 BAIL_ FILL 0.92 ENGAG FISH . 0,92 ENGAG FISH 0.83 ENGAG FISH 0.75 ENGAG FISH 0.75 ENGAG FISH 0,67 ENGAG FISH 0,58 ENGAG FISH 0.75 RURD~ SUK 0.25 SAFETY MTG_ 3.25 RURD_ SLlK 1.00 ENGAG 1.00 ENGAG 1.00 ENGAG 1.00 BAIL_ 1.00 BAIL_ FILL 0.42 TAG_ 160TM 0,58 ENGAG FISH 0.75 ENGAG FISH 0.25 RURD_ SUK 1.00 CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMÞPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL I CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL ICMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL CMPPUL Page 8 öf 12 Start: 8/27/2005 Rig Release: Rig Number: 1 Spud Date: 11/22/1979 End: 9/30/2005 Group: Description of Operations RIH wI 2-1/4" pump bailer. Recover handful of large metal pieces. RIH wI same, recover 1c metal pieces RIH wI same, recover 1c metal. RIH w/same, recover 3 pieces metal RIH wI same, recover 2 pieces metal RIH wI 2-1/2" LIB to 6705'. POOH wI impression ofVery large metal pieces. RIH w/2-1L4" pump bailer. No metal RIH wI 1-3/4" hydro bailer. No recovery RIH WI 2-1/4" pump bailer. Recover 1 small piece of meatl RDslickline for night, will look for different tools at shop in AM prior to retu rn. Obtain work permit, hold safety meeting. RU slickline unit. RIH wI 2-1/4" pump bailer to 6705' KB. Recover handfull of metal chunks, RIH wI same, POOH empty RIH wI 2.70" magnet, no recovery. RIH wI 2-1/4" pump bailer with modified bottom, no recovery RIH wI same bailer, different bottom. No recovery RIH wI 2-1/4" magnet. POOH wI metal shavings. RIH wI same, recover shavings Rlh wI 2-1/4" pump bailer wI modified bottom, no recovery. RIH wI hydrostatic bailer. POOH wI nothing. RIH wI 2-1/2" LIB. Shows very large pieces of metal. RD slickline. Sign in, issue permit, hold safety meeting. RU slickline unit. RIH wI 2-1/2" LIB on 3'\bow spring to 6705'. POOH wI impression of large metal pieces. RIH wI 2-1/4" Bakèr magnet. POOH wI large metal piece RIH wI 2-1/4" pump bailer wIno recovery. RIHw/2-1/4" Baker magnet. POOH wI nothing. RIH wI same plus 3" bow spring. POOH wI large metal piece. RI H wi same. Recover large metal piece. RIH wI same, recover large metal piece. RIH wI same, recover 2 pieces of metal RH wI same, recover 2 pieces of metal. RIH wi same, recover metal shavings. RDslickline Arrive, sign in, hold safety meeting, issue permit. RU unit, crane truck will not start. Trouble shoot and make temporary repair. RIH wI 2-1/4" magnet to 6705' POOH wI large piece of metal. RIH wI same, recover metal pieces. RIH wI same, recover metal pieces. RIH wI 2-1/4" pump bailer. Recover 1cup metal. RIH wI same, recover nothing, RIH wI 2-1/4" LIB to 6705'. Impression of metal pieces. RIH wI 2-1/4" magnet, no recovery, RIH wI same, no recovery RD for night. I Held PJSM, filled out permit a~d discussed todays actions, .. Printed: 11/9/2005 4:23:08 PM - Lègal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1017/2005 10/11/2005 10/12/2005 e Page 9 of 12 Marathon Oil Company Operations Summary Report KENAIBELUGA UNIT41-7 KENAI BELUGA UNIT 41-7 WORKOVER GLACIER DRILLLlNG GLACIER DRILLING SUb FrOIn '~ To Hours ÇÖdé Code Phase .. 08:00 - 08:15 0.25 08:15- 09:00 0.75 09:00 - 10:00 1.00 10:00 - 10:10 0.17 10:10 - 10:45 0.5.8 10:45 - 11:00 0.25 11 :00 - 12:00 1.00 12:00 - 12:15 0.25 12:15 ~ 13:00 0.75 13:00 - 14:00 1.00 14:00 -14:30 0.50 14:30 - 15:00 0.50 15:00 - 16:00 1.00 16:00 - 16:45 0.75 16:45 - 17:30 0.75 17:30 - 17:45 0.25 17:45 - 18:00 0.25 18:00 - 18:30 0.50 08:00 - 09:00 1,00 09:00 - 09:30 0.50 09:30 - 12:30 3.00 12:30 - 13:00 0.50 13:00 -13:30 0.50 13:30 -13:45 0.25 13:4þ - 14:00 0.25 14:00 - 14:50 0.83 14:50 - 15:30 0.67 15:30 - 16:30 1.00 16:30 - 16:55 0.42 16:55 - 17:30 0.58 17:30 - 17:45 0.25 17:45 - 18:05 0.33 18:05 - 18:30 0,42 08:00 - 09:00 1.00 09:00 - 09:30 0.50 09:30 - 09:45 0.25 09:45 - 10:00 0.25 10:00 - 10:30 0.50 10:30 -11:15 0.75 11:15 -12:00 I 0.75 12:00 - 12:451 0.75 12:45 - 13:30 I 0.75 13:30 - 14:45 1.25 Start: 8/27/2005 Rig Release: Rig Number: 1 Spud Date: 11/22/1979 End: 9/30/2005 Group: Description of Operations PU tool string, MU 1" spear, PT with WHP, RIH with tooi string. Tag up at 6705' KBD on slick line, Work tool string POOH with spear. OQH with spear, RIH with 2" magnet to 6705', work magnet, POOH slow DOH with first magnet run, nothing on magnet. MU d 2" dump bailer, RIH to 6705' KB, worked bailer POOH wjth bailer OOH with bailer, nothing in bailer. MU 2"magnet RIH with magnet, work magnet, POOH OOH with magnet, no metal on magnet. MU a 2.5" LIB, RIH with LIB, Set down at 6705' wireline KB. POOH LIB had cut marks around the circumference of the LIB and has part of a slip inpressionin the middle of the LIB. MU 2 .25" magnet, RIH to 6705' KB, POOH with magnet, nothing No progess in two days with current fishing tools..MU a wire spear to try and mix up the stuff in well., RIH Wrok tool, POOH OOH with wire spear, MU 2.5" LIB, RIH to 6705' WL KB, sat down POOH OOH with the LIB, MU 2.25" magnet, RIH with same POOH with the magnet, nothing on magnet. Had wire line crew lay down unit for weekend. Talke dot foreman about rounding up diff\~rent fishing tools than currently have on lease. There are a couple of other fishing tools we could run if they can be located. Crew left lease. Note: no pregess in 2 days MI spot up expro. Held PJSM with personnel and secured a work permit. MU CCL with 6" pup below. PT with WHP. ~psig. . RIH made log to tag depth. Correlated the log back to Bakers Oil Tool c;ompletion outline determined that the Top of fill at 6703' KBD. The fill is in the top of the XO w/7" L TD8RD box X 3 1/2" IBT pin, whidh should be very close to the top of the prong. MU a 2.25" lib and RIH to top of fill, POOH OOH with liB, found a defined dent in LIB MU a 2" magnet,RIH tagged fill, POOH OOH, recovered a 2.5" X 2" by 1" slip, RIH with magnet, tagged fill POOH OOH with the magnet, recovered a 3" flap piece of metal. I MU the LIB, RIH with LIB, tagged fill POOH OOH with liB, found a 1" piece of metal stuck in the lead {ace of the LIB MU magnet, RIH to tag top of fill. \ OOH with magnet, recovered small piece of metal. Lay down equipment for night. Expro left lease. MI spot up expro, Held PJSM with personnel and secured a work permit. MU CCL with 2.65" centralized magnet. PT with WHP. 0 psig. RIH tagged up at 6704' KBD. POOH OOH with tools, magnet had small chuck metel with metal shavings. RIH to top of fill, POOH OOH with magnet found nice chunck of slip attached to magnet RIH with 2.65" magnet, RIH tagged fill, POOH OOH, recovered more metal, part.s of packard slips. RIH with magnet, tagged fill POOH OOH with the magnet, recovered a more smaller pieces of metal. Printed: 11/9/2005 4:23:08 PM e e . Marathon Oil Company ,Operations Summary Report , Page 10 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KENAI BELUGA UNIT 41-7 KENAI BELUGA UNIT41-7 WORKOVER GLACIER DRILLLlNG GLACIER DRILLING C SLIP Frdrrl- To Hòurs ·òd~·, Code Phase Start: 8/27/2005 Rig Release: Rig Number: 1 Spud Date: 11/22/1979 End: 9/30/2005 Group: Date Description of Operations 10/12/2005 10/13/2005 14:45 - t5:30 0.75 15:30 -16:15 0.75 16:15 - 16:45 0.50 16:45 - 17:05 0.33 17:05 " 17:30 0.42 17:30 -17:45 0.25 17:45 - 18:00 0.25 18:00 - 19:00 1.00 08:00 - 09:00 1.00 09:00 - 09:30 0.50 RIH with magnet, tagged fill POOH OOH, recQvered only shavings, cleaned off magnet face RIH with magnet, tagged fill POOH OOH, recovered only shavings, cleaned off magnet face. MU 2.5" LIB RIH with LIB, tagged fill POOH OOH, 2.5" LIB had impressicn of the prong fishing neck.MU 2" RS pulling tool RIH RS pullipg tool, work tool string latched up cn prong. Set jars off, POOH OOH with pulling tool no fish, sheared RS. RD for night. ,Wireline crew left for night. Held PJSM with personnel and secured a wcrk permit. PU lubricator and tool string. MU 2.5" RS pulling tool. . RIH 2.5" RS pulling tool to 6702'KBD, work tool string, latched up on prong. Set jars off with aprox. 700 Ibs over over pull 4 times, sheared off fishing neck, POOH OOH with tool string, RS sheared, no prong. Re pin RS. RIH with RS to 6702' KBD, latched up on prong, Pull aprox. 800 Ibs , over pull, set jars off 3 different times, tool sheared, POOH OOH with RS no prong, reset pin, RIH to top of fish at 6702' KBD latched up on prong, work tool string pulled aprcx 800 Ibs over, three times, set off jars each time, sheared pinon tool, POOH OOH, pin sheared on RS, MU2.5" SB pulling tool. RIH with 2.5" S8 pulling tool, latch up on prong, work tool string, pull 1200 Ibs over. re load jars, Work jars several times, pulled out cf rope socket after jars went off with 1600lbs over pull. POOH with out tool string. OOH with wire, secured well. MU additional lubricator and retied rope socket. MU 2.5" RS pulling tool on baited 2" OS with 1.0" grapple RIH to fish tool string, tagged fish at 6700' KBD, PU wieght increased by 150 Ibs, POOH with too.l sting. OOH with tool string, fish recovered. Secured well, lay down tcol string The SB pulling tool pin was sheared, Rig down unit. Wire line crew left lease, Ncte: plan to. rig up slick line to fish prong tcmorrow. . Held PJSM with personnel and secured a work permit. PU lubricator and tool string. MU 2.5" JDC pulling tool. RIH 2.5" RS pulling tool to 6704' KBD, work tool string, latched up on prong. I Work too.l string for a while at different PU weights setting off jars and 'resetting jars, shear off too.l 'string, POOH Cut wire, retied wire and added 7' stem, total stem at 1 T. Had to replace the chain cn wire line drum. RIH with 2.5" JDC to 6704' KBD, Latched up on prong, work too.l string, pl,illed prong, POOH OOH with prong, MU2.5" DD bailer, RIH to 6704' KBD, work bailer, POOH OOH with bailer, found several small pieces of metal in bailer and bottom of the bailer was beat up. \ Lay down lubricatcr and secured well for night. Held PJSMwith personnel and secured a work permit. PU lubricator 09:30 - 09:45 0.25 09:45 - 10:00 0.25 10:00 - 10:30 0.50 10:30-11:15 0.75 11:15-12:00 0.75 12:0Ó - 12:45 0.75 12:45 - 13:30 0.75 13:30 - 14:45 1.25 14:45 - 15:30 0.75 15:30-16:15 0.75 16:15 - 16:45 0.50 .. 16:45 ~ 17:05 0.33 17:05 -18:00 0.92 10/14/2005 108:00 - 09:00 1.00 '09:00 - 09:50 0.83 09:50 - 10:00 0,17 10:00 - 13:00 3.00 13:00 - 17:00 4.QO 17:00 -18:15 1.25 118:15 - 18:30 0.25 18:30 - 19:00 0.50 10/15/2005 08:00 -09:00 1.00 Printed: 11/9/2005 4:23:08 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date e Page 11 of 12 Marathon Oil Company ~.. -.- ........ -.- .. .... ....., Operations Summary Report KENAI BELUGA UNIT41-7 KENAI BELUGA UNIT 41-7 WORKOVER GLACIER DRILLLlNG GLACIER DRILLING Cd SUb FrC>rh- To HÒÚl',š '.0 eBôde Phase 10/15/2005 08:00 - 09:00 1.00 09:00 - 09:50 0.83 09:50 - 10:00 0.17 10:00 - 10:30 0.50 10:30 - 10:50 0.33 10:50·11 :15 0.42 11:15 -11:30 0.25 11:30 -12:00 0.50 12:00 - 12:45 0.75 12:45 - 12:55 0.17 12:55 - 16:15 3.33 16:15-17:00 0.75 17:00-18:15 1.25 18:15 - 19:00 0.75 19:00 - 19:30 0.50 10/24/2005 08:30 - 09:30 1.00 09:30 - 13:00 3.50 13:00 - 14:30 1.50 10/25/2005 07:00 - 07:30 0.50 07:30 - 08:50 1.33 08:50 - 09:15 0.42 09:15 - 11 :45 2.50 .. 11 :45 - 12:00 0.25 12:00 - 13:00 1.00 13:00 - 13:50 0.83 13:50 -14:00 I 0.17 14:00 - 14:30 i 0.50 14:30 - 15:20 0.83 15:20 - 15:25 0.08 15:25 - 16:10 I 0.75 16:10 - 17:00 0.83 I Start: 8/27/2005 Rig Release: Rig Number: 1 Spud Date: 11/22/1.979 End: 9/30/2005 Group: Description of Operations with WHP. WHP= 200 psig. MU 2.25" drive down bailer. RIH to 6704' KBD, work tool string, POOH OOH with DD bailer, small pieces of metal MU 2.05" magnet RIH with magnèt to 6704" work tools, POOH OOH with magnet, small amount of shavings with not metal pieces. MU 2.75" LIB, RIH tagged up at 6704' KBD, POOH OOH with LIB, Goòd impression of the plug, dècided to RIH and pull plug MU 3.5" t3R pulling tool. RIH tpo 6704' KBD, Tagged up, plug released. Well overbalanced caused the plug to drop below the tubing tail @ 6714" KBD. Waited few minutes for well to stabalize, work tools up through tubing tail toXnipple. U-bolt broke on the wire line drum, Shut down unit, secured the well. Replace the u-joint on the wire line drum, continued working the tool string, sheared the FR pulling tool POOH OOH with GR pulling tool, repined the tool RIH with the GR to 6978' KBD, latched the plug, set off oil jars three times, sheared pin. POOH with out plug. RD unit, crew left lease. NOTE: Left plug in fill at 6978' KBD BJ coil arrived on location, heldPJSM and uptained a permit. Spotted equipment and crane, nippled up BOPS and N2 iron. Layed down liners and kttty pools for drips. Rigged up· equipment should be ready for pressure testing equipment tomorrow. BJ crew left lease. BJ coil arrived on location, held PJSM and uptained a permit , Started equipmerit, PU injector take to well. Had vac truck pull a load of 6% KCL and have delivered to Coil for PT. Load coil, PT Packoff, WHA, choke and iron. Test BOP's shell test, Blind rams @ low = 200 psig, high = 3500 psig. Tubing rams @ 330 psig, and 3350 psig high. BOP's teste good. Cool down N2, Start RIH with CT. WHP= 0 psig When CT @ 500' CTM bring N2 on at 375 SCFM. Continue RIH, no H20 flow to tank. ,CT at 3800' CTM inCreased N2 rate to 500 SCFM" Move coil down to 3800' CTM Returns to tank; continue down hole with coil, WHP = 111 psig, N2 rate dropped back to 375 SCFM Coil at 6705', still good H2) returns to tank, total of 30 BBLS to tank, WHP= 55 psig. Continue with flowing well to tank, N2 rte at 375 SCFM, WHP = 233 psig, total of 54 bbls H20 to flow back tank. Move coil down to 6852' CTM to fix coil rap on rell, PUH with coil, lost the pump belt on the N2 motor SD pump. and switched to the other unit. Shut dwon N2 , WHP @ 225 psig, still slight returns to flow back tank. POOH with CT. OOH with cOil, Total H20= 64.1 BBLs to flow back tank. Maintain flow to tank while production switched over to production flow line. Printed: 11i9i2005 4:23:08 PM LegalWell Name: Common Well Name: Event Name: Contractor Name: Rig Name: e e Marathon Oil Company Operations Summary Report KENAI BELUGA UNIT 41-7 KENAI BELUGA UNIT 41-7 .WORKOVER GLACIER DRILLLlNG / ... GLACIER DRILLING From-To HOUfS Code'ðd~è Phasë Date 10/25/2005 17:00 - 18:00 .. Start: Rig Release: Rig Number: 1.00 RD coil. WHP= 192 psig 8/27/2005 Spúd Date: 11/22/1979 End: 9/30/2005 Group: Description of OpE;!rations Printed: 111912005 4:23:08 PM API: '50-133-20327-00 AOGCC: RT-MSL (Original Drlg): 21' KB-THF 'FSL,' FWL, Sec. 6, T4N, R11W, S.M. Lift threads: ??? Tree cap: 4-3/4" Otis U 41...7 Pad 41..7, Kenai Gas Field J 1 7 9 10,11 Beluaa Peds 6,854'-6,874' } 6,886'-6,896' Frac'd 6,904'-6,914' 6,990'-7,010' - Frac'd 7,056'-7,076' 7,104'-7,114' Fill: 7032' KB (7/97) 7029' MD (7/97) 7025' KB (3/02) 6909' KB (5/03) 6977' KB (5/04) l 20",94#, drìvepipe @ 134' 13-3/8",61#, K-55, BTC Surface Ca Cmt wI xxxx sks of class "G" 9.3#, L-80, to 6714' mco sìdepocket inj mandrel @ 993' NEW: 1) Baker 2) CMU sleeve 3) Baker PBR tbg seal assy @ 4) PBR @ 6578' Baker 6)BX 7) Baker Model D Packer @ 6,650' 8) Blast Jt 6654'-6692' (4.5" w/3.0" ID) 80-40 Locator Seal Assy wI 3.72" seals 6,692' 9) Baker Model D 194-40 @ 6,697' 3-1/2",9.3#, L-80, 6697'-6713' 10) X-nipple @ 6,709' ID ;:::: 2,813" 11) Wirelìne Re-entry Guide @ 6,714' 12) Fish, PX plug wI junk catcher @ 6978' (10/15/05) 5-1/2",20#, 6,920'-7,199' Liner Cement plug 7115'-7140' Cement retainer 7140'-7147' Gravel Pack screen 7,198'-7,240' (-.:.~·'\);~.'I'¡' JL\\.J. \. ~.'I? i'"I~L'-' "" . I ! ¡'\ I, ': ", " '1 "",, U' '--.I 'YI :,. I:W " ¡: I ~ n ,.,1 ;' .;-)\i 'I ; .' a'l ~ w J:Jw '. J....::¡J /~~ .G=J ;1 'I :!:¡ 'i'L 11 '1 :' " :-J !U'l:II;¡ .1 . " ·1 I, \,:::.J U C-I) --, ~ r-::"" :~-, --. ~\ () '1 1: :11" ·1 ,"') '\ 'I ,,/ i"1·· / \ \ .r' ! /1 '. '. t .~I .I,',i .I " \ . .¡ I \ ill ' I·' . "'. :.1., .1', .. .\ J "',' :", ' '¡ :,' '~':,'~, :1," \ " ", ,\ .: ,W I, :1 .1 I W." ."\. \1 1\ \ .1 L \ ,I ~ " .' ) _..-, \ _~", .1,\. 1,...,\ 1). \ '.; , I:'" I '. .:; .;'. \ i·/ ,\.1 U .~ ,-.) :-' '~) i.J '-\!-J ....!I FRANK H. MURKOWSKI, GOVERNOR ALASIiA OIL AlWD GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Denise M. Titus Production Engineer Marathon Oil Company P.O. Box 196168 Anchorage, AK 99516-6168 _O'~C \1q , Re: Kenai KBD 41-7 Sundry Number: 305-244 SCANNED AUG 3 1 2005 Dear Ms. Titus: 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. Please provide at least twenty-four (24) hours 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 oliday or weekend. A person may not appeal a Commission decisi to uperior Court unless rehearing has been requested. ( S· c . Jo air ,.- DATED this2day of August, 2005 Encl. 'Î ~ , , M MARATHON Alaska Business Unit Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 August 24, 2005 ..... ~ E t''' ¡!f'C~ R(" !f ~ ,1 '\' ~¡"..,"" . ~_ .~ "'''', , ( I'; . . \1...... ~~~ """~, \., I:,~-- AUG 2 4 2005 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 A~ It:;' Oil 81. G3S Cen~.'?". ~!aSh,," J Þ.í1t;,\~':]i sq;;¡ Reference: KBU 41-7Workover Sundry Dear Mr. Aubert: Enclosed is the 10-403 Sundry Application to workover KBU 41-7. This Beluga well has a bottom hole location within % mile of a proposed gas storage well. In an effort to test the mechanical integrity of the annulus, we noted that the casing would not hold pressure. /This is likely due to historical squeeze perfs above the production packer. / A workover is proposed to pull the existing completion, test the casing, and re-run the tubing. This will be completed in such a way that a mechanical integrity test can be obtained to verify the integrity from /' the proposed storage zone to surface. The recompletion will isolate Beluga squeeze perfs behind pipe with a sliding sleeve to permit access if needed. This work is expected to begin immediately after the sidetrack on KTU 43-6xrd. I have attached a procedure and a proposed well bore diagram which describes the planned work. If you need any additional information or have questions, I can be reached by phone at 907-283-1333 or bye-mail at dmtitus@marathonoil.com. Sincerely, ÇJ;I ~ (Þ'\. ~,v\ r Denise M. Titus Production Engineer Enclosures: 10-403 Sundry Workover Procedure Existing Well Schematic Proposed Well Schematic (]R~G~(~AL Abandon U Alter casing 0 Change approved program 0 2, Operator Name: Marathon Oil Company 3, Address: 1. Type of Request: \I--l4 Atfi~t~1 t~ t) . STATE OF ALASKA IJ~. "/26 /AUG 0 4 2005 At ..:iKA OIL AND GAS CONSERVATION COMMISSION I-)H J:J . APPLICATION FOR SUNDRY APPROVþ"1ffisk8 O¡1 & Cas COíí2.. Cf)m;¡¡¡~si,Qr 20 MC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: 5. Permit to Drill Number: Development [] / Exploratory 0 179-029" Stratigraphic 0 Service 0 6. API Number: Suspend U Repair well [2] Pull Tubing D r 1"1 (, h ¡: i ¡ ;:) ìl p. Perforate U Waiver U Annular Dispos. U Stimulate 0 Time Extension 0 Other [2] Re-enter Suspended Well 0 Workover 50-133-20327-00 ./ PO Box 196168 Anchorage, AK 99516-6168 7. KB Elevation (ft): 101' above MSL 8. Property Designation: Kenai Unit 11. Total Depth MD (ft): 7290 Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 6854-7114 gross, net attached Packers and SSSV Type: 9. Well Name and Number: KBU 41-7 / 10. Field/Pools(s): Total Depth TVD (ft): 7290 Kenai Gas Field/Beluga PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 7115 7115 /' Plugs (measured): 7,115 Junk (measured): N/A Collapse N/A Length 134 Size MD 134 TVD 134 Burst 20" N/A 2425 13-3/8" 2425 2425 3090 1540 7025 279 9-5/8" 5-1/2" 7025 7198 7025 7198 Tubing Grade: 6870 9190 4750 8830 Perforation Depth TVD (ft): Tubing Size: Tubing MD (ft): 6543 Same 3-1/2" 9.3ppf Packers and SSSV MD (ft): N-80 Baker SAB, 2ea Bkr Model D 6521, 6650, & 6693 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16, Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Denise Titus Printed Name Denise M, Titus Title Production Engineer 8/31/2005 13. Well Class after proposed work: Exploratory 0 Development [] 15. Well Status after proposed work: Oil 0 Gas [2] / Plugged WAG 0 GINJ 0 WINJ o o /" Service 0 o Abandoned o WDSPL Date: Signature fl/¿~, h"D W\-I Phone 8/24/2005 907 -283-1333 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 Other:T -e s t- Sundry Number: .3o~-:J-l/Y BOP Test M Mechanical Integrity Test 0 Location Clearance 0 &0 pE +0 RBDMS BFl AUG 3 0 2005 ~ r' s (, s 00 (? COMMISSIONER BY ORDER OF THE COMMISSION Date: ~I/ C)f~IG!NAL Form 10-403 Revised 12/2003 INSTRUCTIONS ON REVERSE Submit in Duplicate ( M MARATHON ~ Marathon Oil Company Alaska Asset Team KBU 41-7 Kenai Gas Field, Pad 41-7 W orkover Procedure RW.05.12563.CAP History: KBU 41-7 is currently a 3-1/2" Beluga zone completion in 9-5/8" casing. The well falls within a 'l4 mile of a proposed gas storage well penetration in the Pool 6 zone. All wells within the quarter mile must be able to prove annular integrity./The annulus on KEU 41-7 is typically found to be on a vacuum and will not pass an annular MIT. Objective: Pull the existing tubing/packer completion and recomplete to verify pressure integrity from the base of Pool 6 to surface in KEU 41-7 Procedure: 1) Prepare wellbore for rig mob and fishing a. Remove wellhouse. Make note of presence of gas/water/condensate observed in tree. b. MIRV Pollard Wireline. Drift tubing string. Set plug in tubing tail at 6709'. Bleed any pressure off of tubing to verify plug integrity. If there was no initial pressure, pump to pressure test plug. Bleed off when finished. c. MIRV APRS to make cut 12 jt above packer anchor at ,..,,6505' . 2) Prepare wellhead and location a. Call out ABB Vetco to install BPV s and prep wellhead. b. Mark tree orientation in cellar. Disassemble flowlines and control lines making note of where they are stored. c. Set BPV. d. Complete dirtwork as needed. 3) MIRV GD #1 a. ND tree and NU BOP stack and test. ,/ b. Pull BPV. 4) Pull completion/mill packer a. Pull 3-1/2" tubing and send for inspection. b. PU drillpipe and packer mill with plucking assembly. RIH to packer and mill until free. POOH w/ packer body. /" 5) Test casing and existing tubing/packer isolation a. PU RTTS on drillpipe. Set RTTS at 5000'. Test casing to 1500psi. If test fails, move RTTS uphole until a 1500 pse pressure test is obtained. Continue .-/ diagnostics to detennine leaking casing section. Provisions will be made to patch casing if not able to obtain pressure test above 4675' . b. PU tools to test PBR at 6650'. RIH, engage tool and test PBR to 1750psi. IfPBR does not pass, consult packer representative and discuss forward options. 6) Run 3-1/2" completion as follows: a. PU equipment as follows: Packer seal assembly xo as needed Ijt 3-1/2" IBT mod tubing X nipple Ijt 3-1/2" illT mod tubing Sliding sleeve 3-1/2" IBT mod tubing. xo as needed Baker Hyd set packer xo as needed 3-1/2" IBT mod but tubing spaced out as required to hang tubing in tree. b. MU 3-1/2" tubing string and accessories (strapped, numbered, and rabbited) and Rill c. Space out as needed to land packer at 4675' (just beneath Pool 6). d. Circulate completion fluid and annulus corrosion inhibitor. e. Sting seals into existing packer at 6650'. f. MU Vetco tubing hanger spool. Install packoff and pressure test tree to /" 500/4500psi. 7) Prepare to set packer a. Pressure up tubing against plug set in original tail pipe. b. Pressure up packer as prescribed by packer rep to set (may see a few shears prior to setting). 8) Pressure test the casing a. Pressure annulus to 1500psi wi no pressure on the tubing. ND BOP stack, NU /. tree and test to 250/3000psi. 9) RDMO GD #1 10) RU wireline unit to pull plug in tubing string. a. Rlli and pull plug in X nipple at 6709' if unable to pull plug due to debris fonn milling packer, shoot off tubing tail. 11) Test well to production. a. Jet open hole section if required · , Nt 1lARA1IIO. ~ API: '50-133-20327-00 AOGCC: RT-MSL (Original Orlg): 30.6' KB-THF , FSL, , FWL, Sec. 6, T4N, R11W, S.M. Lift threads: ??? Tree cap: 4-3/4" Otis BeluQa Perfs 6,854'-6,874' } 6,886'-6,896' Frac'd 6,904'-6,914' 6,990'-7,010' - Frac'd 7,056'-7,076' 7, 1 04'-7, 114' Fill: 7032' KB (7/97) 7029' MD (7/97) 7025' KB (3/02) 6909' KB (5/03) 6977' KB (5/0"1) 7025' KB (2/05) ii KBU 41-7 Pad 41-7, Kenai Gas Field ~ ..... ... I 1~·>...'.. I, : , ~ ,ì I ¡ _.........,.._..'...",....r. T .. ~.';I~ -- =- =- ::J =:II =- =- =- t .J :::ax: ==-=-= .A :::IE :::IE I PBTO - 7115' TO - 7240' / ~ 120",94#, drivepipe @ 134' ~ 13-3/8",61#, K-55, BTC Surface Casing @ 2425' Cmt wI 692 sks of class "G" Tubinq Strinq - 3-1/2",9.3#, L-80, to 6,544' Cameo side pocket inj mandrel @ 923' Baker 80-40 K-Anchor @ 6,521' 194 SAB 40x32 Packer @ 6,527' X-nipple @ 6539' 10 = 2.813" Wireline Re-entry Guide @ 6,544' Baker Model 0 Packer @ 6,650' Blast Jt 6654'-6692' (4.5" wI 3.0" 10) 80-40 Locator Seal Assy wI 3.72" seals 6,692' Baker Model 0 194-40 @ 6,697' 3-1/2",9.3#, L-80, 6697'-6713' X-nipple @ 6,709' 10 = 2.813" Wireline Re-entry Guide @ 6,714' IE=: -= J: -= -= c: Ie: ~ L :aar::: ZE:=: ~ 9-5/8",47#, N-80, BTC @ 7025' ;.: Orig. Cmt wI 1800 sks of class "G" =-= I x: -= 5-1/2",20#,6,920'-7,199' Liner Cement plug 7115'-7140' Cement retainer 7140'-7147' Gravel Pack screen 7,198'-7,240' Gravel Pack screen 7,198'-7,240' Cement plug 7115'·7140' Cement retainer 7140'·7147' 5-1/2",20#,6,920'-7,199' Liner t l~ \: 9-5/8",47#, N-80, BTC @ 7,025' Orig. Cmt wI 1800 sks of class "G" 3-1/2",9.3#, L-80, 6697'-6713' X-nipple @ 6,709' ID = 2.813" Wireline Re-entry Guide @ 6,714' Baker Model D Packer @ 6,650' Blast Jt 6654'-6692' (4.5" wI 3,0" ID) 80-40 Locator Seal Assy wI 3.72" seals 6,692' Baker Model D 194-40 @ 6,697' 8ak~r Packer @ appro>: .';!:QZ§:: ~3-1 12" TUbing ta:: vlff sl:díng sleeve, st;ng into existing ísotm¡on $eGt:on r~ E.~!j\i: Camco sidepocket inj mandrel @ 923' TubinQ StrinQ - 3-1/2",9.3#, L-80, to 6714' ~ 13-3/8",61#, K-55 , BTC Surface Casing @ 2425' Cmt wI XXX>< sks of class "G" ~ 120", 94#, drivepipe @ 134' ,// PBTD - 7115' TD - 7240' ~ ~ I [ W .. Fill: 7032' KB (7/07) 7020' MD (7/07) 7025' KB (3/02) 6000' KB (5/03) 6977' KB (5/04) t ~,l ~~ ,',',',','!if.'!i!'. .:J" 6,854'-6,874' } 6,886'-6,896' Frac'd 6,904'-6,914' 6,990'-7,010' - Frac'd 7,056'-7,076' 7,1 04'-7, 114' íE ~ ~.), ~ ~ ~ ~ r ;e;; té BeluQa Peñs ..........L gJ i ~ I-I lB.···..·, . J.:.J dfim~ .~íbtlì1 1111 .... '.... :I -~~ .X .~m;;r:': ............ ""- . .............. . U '~I - Lift threads: ??? Tree cap: 4-3/4" Otis A , FSL, ' FWL, Sec. 6, T4N, R11W, S,M, RT-MSL (Original Drlg): 30,6' KB-THF .... API: '50-133-20327-00 AOGCC: K( U 41-7 WO PROPO~-=D Pad 41-7, Kenai Gas Field ~~) ,I' '\ ~: MEMO TO EACH WELL FILE LISTED BELOW Date January 7, 2004 Two previously undefined intervals, the Dl 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 KEU 23X-06 200-023 KTU 32-07 181-153 KEU 31-07 168-049 KDU 2 195-055 KEU 31-07RD 184-108 KTU 13-05 174-050 KU 14-06RD 199-024 KEU 33-06 178-055 KDU 5 195-054 KTU 43-06XRD 177 -029 KBU 13-08 203-066 KEU 43-07X 185-181 KEU 33-07 199-073 KTU 24-06H 202-043 KTU 32-07H 195-054 KEU 43-06XRD 179-029 KEU 41-07 169-012 KDU 4 184-108 KTU 13-05 179-030 KEU 43-06X 199-024 KEU 33-06 199-025 KEU 42-07 200-188 KEU 24-06 202-025 KEU 41-07X 200-179 KEU 44-06 SC!~~~~E[) J,IAN 2 «» 2004. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner 5i~lci°~ Tom Maunder, P. !. Supervisor ~llu,..o \ FROM: John Crisp, SUBJECT: Petroleum Inspector DATE: May 10, 2001 Well House Inspections Kenai Gas Field Location 41-7 May.10, 2001: I traveled to Marathons Kenai Gas Field to perform Well House Inspections on Location 41-7. I inspected 10 Well Houses on this Pad. 4 Well Houses were new Sioux round Well Houses that are insulated, lighted & heated. 4 Well Houses are older style Sioux round houses w/insulation & lights. 2 Well Houses are rectangular houses w/heat & lights. Ail but three cellars inspected had water standing up to Pad level. The cellars w/o standing water had been cemented by the Rig. Ail Wells have Surface Safety Valves. Marathon Rep. Don Erwin stated that the valves were tested annually. Mr. Erwin also stated that new wells drilled & completed near Residential areas near the Gas Field could possibly be completed w/Subsurface Safety Valves. SUMMARY,: I inspected 10 Well Houses in the Kenai Gas Field on E~ti°n 41- ii~!~7, All houses were in good shape. Attachments: none C~C.; NON-CONFIDENTIAL Marathon Oil Company .ONFiD£t TIAL Alaska' ,ion Domest~u Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 June 11, 1997 Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Wondzell: Please find attached Form 10-404, Report of Sundry Well Operations, for the KBU 41-7 Workover. If you have any questions, please contact me at 564-6315. Sincerely, "/,,.'/'/? /"' / -Michael R. Olson Production Engineer Attachments cc: CEF A subsidiary of USX Corporation Environmentally aware for the long run. CONFIDENTIA STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown.. Pull Tubing X 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 185' FNL, 4303' FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval t39' FNL, 4303' FWL, Sec. 7, T4N, R11W, S.M. @ 6854' TVD At Effective Depth 128' FNL, 4303' FWL, Sec. 7, T4N, R11W, S.M. @ 7115' TVD At Total Depth 126' FNL, 4303' FWL, Sec. 7, T4N, R11W, S.M. ¢¢ 7290' TVD 12. Present Well Condition Summary Total Depth: measured true vertical Stimulate X Alter Casing __ Plugging Repair Well 5. Type of Well: Development X Exploratory Stratigraphic Service Perforate X Other X 6. Datum Elevation (DF or KB) 107' KB feet 7. Unit or Property Name Kenai BeluCa Unit 8. Well Number KBU 41-7 9. Permit Number/Approval Nu~lb~j) 95-089 ~,~ '~ ~;~ 'VL~ ~9. 10. APl Number 50-- 133-20327-00 11. Field/Pool Kenai Gas Field/BeluCa 7290 feet Plugs (measured) 7140' Cement retainer 7290 feet 7115-7140' Cement plug Effective Depth: measured true vertical feet Junk (measured) feet None Casing Structural Conductor Surface Intermediate Production Liner Length 134' 2425' 7025' 320' Size Cemented Measured Depth True Vertical Depth 20" Driven 134' 134' 13-3/8" 692 SX 2425' 2425' 9-5/8" 1800 SX 7025' 7025' 5-1/2" Gravel Packed 7240' 7240' Perforation Depth: measured true vertical See Attached Perforation/Stimulation Summary Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3-1/2", 9.2#, N-80, 6544' 6522'Baker SAB 84-42 X 32 Packer 6650' Baker Model D Packer 6693'Baker Model D Packer ORIGINA. L JLli:l 'I 2 199'/ 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) See Attached Perforation/Stimulation Summary, Operations Summaryl W~~~ Treatment Description Including Volumes Used and Final Pressure 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation 1300 259 Subsequent to Operation 1800 0 0 1620 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of Well Classification as: Oil Gas X Suspended Service 17. I hereby certify that the foregoing is true and correc~to the best of my knowledge. Signed .~_~L~/¢~- /' ~/ Title Production Engineer ~rm 10-404 Rev. 06/15/88 Date 6/11/97 Submit in Duplicate CONHDENT AF DATE SQUEEZED: 12/15/95 12/15/95 12/15/95 1/11/80 12/15/95 12/14/95 12/14/95 12/13/95 KBU 41-7 PERFORATION/STIMULATION SUMMARY PERFORATIONS MD TVD FOOTAGE SAND SPF 5334-5353' 5334-5353' 19' M. BEL. 5641-5655' 5641-5655' 14' M. BEL. 5761-5775' 5761-5775' 14' M. BEL. 5905-5909' 5905-5909' 4' M. BEL. 6128-6138' 6128-6138' 10' M. BEL. 6494-6504' 6494-6504' 10' L. BEL. 6668-6680' 6668-6680' 12' L. BEL. 7178-7180' 7178-7180' 2' GUN TYPE NEW PERFS: 1/8/96 1/8/96 1/8/96 7105-7114' 7105-7114' 9' L18 7056-7076' 7056-7076' 20' L17 6990-7010' 6990-7010' 20' L16 2/8/96 2/8/96 2/8/96 6904-6914' 6904-6914' 10' L14 6886-6896' 6886-6896' 10' L13 6854-6874' 6854-6874' 20' L13 FRACTURE STIMULATE: 4/16/96 6854-6914' 4/16/96 6990-7010' 6854-6914' 60' L13-14 6990-7010' 20' L16 2-1/2" HOLLOW CARRIER 2-1/2" HOLLOW CARRIER 2-1/2" HOLLOW CARRIER 2-1/2" HOLLOW CARRIER 2-1/2" HOLLOW CARRIER 2-1/2" HOLLOW CARRIER 88,500 lbs Carbolite rev. 4/10/97 OPERATION SUMMARY REPORT WELL: KBU 41-7 W/O . 11/24/95 1 0 9.850 ACCEPTED RIG AT 1800 HRS 11-23-95. PULLED BPVS. R/U LINES TO KILL WELL. MIXED KILL MUD. 11/25/95 2 0 9.340 FINISHED MIXING MUD. CIRCULATED ON LONG AND SHORT STRINGS TO KILL WELL. SET BPVSi N/D TREE. N/U DOPE. 11/26/95 3 0 9.800 FINISHED N/U DOPE. TESTED DOPE. R/U FLOWLINE AND TRIP TANK. MIXED MORE 9.8 PPG MUD. CIRCULATED LONG AND SHORT STRINGS. PULLED BACK PRESSURE VALVES. R/U DUAL LANDING JTS. PULLED ON TUBING TO UNSEAT DUAL PACKER. R/U WIRELINE TO FREE POINT LONG STRING. CIRCULATED LONG STRING DUE TO GAS. 11/27/95 4 0 9.800 FINISHED CIRCULATING. CHANGED OUT L/S LANDING JT. R/U WIRELINE. RAN FREE POINT ON L/S. MADE CHEMICAL CUTS AT 6618' AND 6382' CIRCULATED L/S. 11/28/95 5 0 9.800 FINISHED CIRCULATING. PULLED PACKER FREE. R/D WIRELINE. R/U TO PULL TUBING. L/D 28 JTS ON BOTH STRINGS. SHORT STRING STARTED FLOWING. SHUT IN WELL. CIRCULATED BOTH STRINGS ON OPEN CHOKE TO KILL WELL. PULLED AND L/D DUAL TUBING STRINGS. 11/29/95 6 6382 9.800 POOH L/D DUAL TUBING STRINGS. WELL FLOWED. SHUT IN. CIRCULATED BOTH STRINGS ON CHOKE. POOH L/D DUAL TUBING STRINGS. M/U BHA. RIH P/U DRILL PIPE. 11/30/95 7 6382 10.200 RIH P/U 3 1/2" DP. TAGGED FISH AT 6375'. CIRCULATED GAS OUT ON CHOKE CBU. PULLED 5 STANDS, WELL BUBBLING. RIH. CIRCULATED OUT GAS AND RAISED MUD WT TO 10.2 PPG. POOH 21STDS. M/U PACKER AND STORM VALVE. SET SAME AT 110' W/ MILL AT 5201'. POOH, TESTED PACKER. P/U STACK AND CHANGE OUT TUBING SPOOL. 12/01/95 8 6382 10.200 N/U TUBING SPOOL AND TESTED SAME. N/U BOP'S AND TESTED SAME. RIH AND SCREWED INTO STORM PACKER, UNSET SAME. CBU. POOH, L/D STORM PACKER. RIH, TAGGED FISH AT 6375'. CBU. POOH. M/U OVERSHOT AND START RIH. 12/02/95 9 6614 10.300 RIH. LATCHED FISH AND JARRED SAME 30' UP HOLE. CBU AT 1 BPM. DROP DART AND SHEARED OUT CIRCULATING SUB. CBU. MONITER WELL. CBU. POOH WITH FISH. L/D FISH, REOVERED 239.02'. NEW TOF 6614' R/U TO PICK UP WASH PIPE. 12/03/95 10 6614 10.300 P/U WASHPIPE AND RIH TO 6587'. CBU. WASHED OVER FISH FROM 6614' TO 6681'. LOST TORQUE. POOH. LEFT ROTARY SHOE AND 7.4' OF WASHPIPE IN HOLE. TOP OF WASHPIPE FISH 6670', TOP OF TUBING FISH 6614'. L/D WASHPIPE FROM DERRICK. M/U 2 7/8" HOLLOW MILL AND OVERSHOT. 12/04/95 11 6707 10.300 RIH WITH 2 7/8" OVERSHOT TO 6600'. CBU. LATCHED ONTO TUBING FISH AND JARRED ON SAME. RIH WITH SPUD BAR ON W/L TO 6881'. RIH AND FREEPOINT TUBING. RIH WITH 2 1/8" CHEMICAL CpT~E~ ~,~ALBE TO GET PAST JARS. POOH. M/U 2 1/8" JET~U~4~A'ND~R~f. iicJ~ ~UBING AT 6707' ..... LDNI-IL)LN-I-IAL OPERATION SUMMARY REPORT WELL: KBU 41-7 W/O . A!~8~ ~iJ A ~'~ , :::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::;::~::;:~;;;:i i 1~ WLM. POOH, R/B WIRELINE. CBU. 12/05/95 12 6705 10.300 POOH. RECOVERED 90.97' OF 2 7/8" TUBING. M/U SPEAR AND RIH. CBU. WORKED SPEAR INTO WASHPIPE AND JARRED SAME FREE. POOH. RECOVERED 7.4' OF WASHPIPE. RIH WITH SPEAR AND WORK INTO ROTARY SHOE. POOH. 12/06/95 13 6705 10.400 POOH, NO RECOVERY. RIH WITH SPEAR AND ATTEMPTED TO CATCH ROTARY SHOE PUSHED DOWN HOLE TO 6704'. POOH NO RECOVERY. M/U 8.5" TAPERED STRING MILL AND RIH. MILLED FROM 6500' TO 6510'. RIH TO 6775' AND STARTED MILLING WITH STRING MILL. 12/07/95 14 6705 10.200 MILLED TO 6684'. CBU. TRIPPED FOR NEW MILL. MILLED FROM 6678' TO 6703'. CBU. POOH. L/D MILL AND P/U WASHPIPE. 12/08/95 15 6705 10.300 RIH WITH WASHPIPE. TAGGED UP AT 6681'. COULD NOT GET PAST TIGHT SPOT AT 6681'. CBU. POOH. L/D WASHPIPE. TESTED ROPE. P/U SMALL WASHPIPE AND RIH. 12/09/95 16 6920 10.400 RIH WITH WASHPIPE. WASHED OVER TUBING FROM 6711' TO 6920'. CBU. POOH. L/D WASHPIPE. M/U FISHING ASSEMBLY AND RIH TO 6711'. MILLED OVER AND LATCHED TUBING. JARRED TUBING FREE. CIRCULATED OUT GAS. POOH. 12/10/95 17 6920 10.400 L/D TUBING FISH. RIH WITH SPEAR AND BHA. SLIP DRILL LINE. RIH. REPAIRED RIG. RIH TO 6920'. SPEARED FISH. CBU. POOH. L/D FISH. FULL RECOVERY. M/U STRING MILLS AND RIH. P/U KELLY. 12/11/95 18 7240 10.400 MILLED FROM 6635' TO 6809'. WASHED TO 6920'. CBU. POOH. L/D 8 1/2" STRING MILLS. M/U 4 1/2" MILL AND 3 1/8" COLLARS. RIH TO 7210' CBU. REAMED TO 7240'. CBU. STARTED WIPER TRIP. 12/12/95 19 7240 10.400 MADE WIPER TRIP TO 6500'. CBU. POOH. M/U DUAL CASING SCRAPERS. RIH TO 7240'. CBU. POOH. R/U E LINE. RIH WITH USIT. STARTED LOGGING AT 6900' 12/13/95 20 7143 10.500 RAN USIT LOG FROM 6900' TO 5000'. POOH. RIH WITH PERF GUN. SHOT SQUEEZE PERFS FROM 7178' TO 7180'. POOH. RIH AND SET RETAINER WITH E LINE AT 7140'. POOH AND R/D E LINE. RIH WITH RETAINER RUNNING TOOL. SLIP AND CUT DRILL LINE. RIH TO 7143' DPM. SQUEEZE CEMENTED WITH 10 BBLS OF CEMENT. CBU. SPOTTED GEL PILL TO 6700'. POOH. 12/14/95 21 7143 10.500 POOH. L/D RETAINER STINGER. M/U 9 5/8" RETRIEVABLE PACKER AND RIH TO 6700'. SET PACKER AND TESTED BELOW TO 3500 PSI. POOH W/ PACKER TO 6197'. SQUEEZED PERF'S AT 6494'-6504', 6667-6682' WITH 130 SX OF CEMENT. REVERSED OUT. POOH TO 5565'. CIRCULATED AND CONDITIONED MUD. POOH. 12/15/95 22 7143 10.300 POOH, L/D RETRIEVABLE PACKER. M/U CEMENT DIVERTER TOOL AND RIH TO 5753'. CIRCULATED. WASHED FROM 5753' TO 6376', TAGGED CEMENT. CBU. R/U CEMENT LINES. SPOT BALANCED CEMENT PLUG FROM 6376' TO 5656' LUNj-IL LN I I^L -- OPERATION SUMMARY REPORT WELL: KBU 41-7 %4/0 . POOH TO 5656. REVERSED OUT. SPOT BALANCED CEMENT PLUG FROM 5656' TO 4936'. POOH TO 4800'. REVERSED OUT. BULLHEADED 21BBLS OF MUD TO SQUEEZE OPEN PERF'S. WOC, MONITERING PRESSURE. 12/16/95 23 7143 10.250 BLED OFF PRESSURE. POOH. TEST BOP'S. P/U 8 1/2" BIT AND BHA. RIH TO 2514'. CBU. RIH TO 4794'. WASHED FROM 4794' TO 5177', TAGGED CEMENT. CBU. TESTED CASING TO 2000 PSI. DRILLED CEMENT FROM 5177' TO 5268'. 12/17/95 24 7143 10.200 DRILLED CEMENT FROM 5268'T0 5393'. CBU. TESTED PERFS. DRILLED FROM 5393' TO 5707'. CBU. TESTED PERFS. DRILLED FROM 5707' TO 5830' CBU. TESTED PERFS. DRILLED FROM 5830' TO 5955'. CBU. TESTED PERFS. DRILLED FROM 5955' TO 6049' 12/18/95 25 7143 10.200 DRILLED CEMENT FROM 6049 TO 6175'. CBU. TESTED PERFS. DRILLED CEMENT FROM 6175' TO 6406'. CDT, THREW A ROD ON ONE RIG ENGINE. DRILLED CEMENT FROM 6406' TO 6503', FELL OUT OF CEMENT, REAMED TO 6549'.CBU. TESTED PERF'S. REAMED FROM 6549' TO 6705'. CBU. TESTED PERFS. CLEANED OUT TO TOL AT 6920'. CBU. POOH. 12/19/95 26 7143 8.340 POOH. L/D DC'S. P/U MILL, 5 1/2" AND 9 5/8 CASING SCRAPERS AND RIH. TAGGED CEMENT AT 7105'. CIRCULATED AND DISPLACED MUD WITH WATER. CLEANED PITS, FLUSHED LINES. PREP TO POOH 12/20/95 27 7143 8.650 POOH TO BHA AND RIH TO 6915'. CLEANED PITS. PUMPED PILLS, CIRCULATED FRESH WATER UNTIL RETURNS CLEAN. DISPLACED HOLE WITH 6% KCL. POOH. 12/21/95 28 7143 8.650 POOH. L/D SCRAPERS AND DRILL COLLARS. RIH WITH ISOLATION PACKER ON E LINE. COULD NOT GET PAST 6496' WLM. POOH. RIH WITH PACKER ON DRILL PIPE. SET PACKER AT 6693' DPM. POOH. M/U PACKER #2. RIH WITH PACKER ON DRILL PIPE. STUNG INTO PACKER AT 6693'. STUNG OUT AND DROPPED SETTING BALL. 12/22/95 29 7143 8.800 SET TOP ISOLATION PACKER AT 6551'. CBU. POOH. RIH WITH RTTS. SET RTTS AT 6530'. TESTED BELOW RTTS TO 3500 PSI. POOH L/D DRILL PIPE. L/D KELLY AND SWIVEL. M/U PRODUCTION PACKER. STARTED RUNNING 3 1/2" PRODUCTION TUBING. 12/23/95 30 7143 8.850 RAN 3 1/2" TUBING. EXTERNALLY TESTED TO 5000 PSI. LANDED HANGER WITH PACKER AT 6521'. CIRCULATED AND INHIBITED KCL. SET XX PLUG AT 6538' WITH SLICKLINE. PRESSURED UP AND SET PACKER. RETRIEVED XX PLUG. TESTED ANNULUS TO 500 PSI. TESTED BELOW PACKER TO 3500 PSI. 12/24/95 31 7143 TESTED BELOW PACKER TO 3500 PSI. SET BPV. N/D BOPE. N/U TREE AND TESTED TO 5000 PSI. LOADED OUT RENTAL EQUIPMENT. RELEASED RIG AT 2000 HRS 12/23/95. . CONFIDENTIA . · OPERATION SUMMARY REPORT: POST RIG WELL: KBU 41-7 DATE RPT DEPTH MU'.r.~ WT. DAILY OPERATIONS SUMMARY 1/5/96 7115' RU HES braided line unit. Swab well down to 5135' RI'H and pull dummy valve at 906' RIH w/ chemical injection valve and set at 906' 1/8/96 7115' RU SWS and perforate 7104-7114' (L18), 7056-7076' (L17) and 6990-7010' (L16) w/ 2-1/2" Hollow carriers, 6 SPF, 60 degree phasing, 10.5 gm 31-O charges. Q = 900 mscfpd, . 500 psig FWHP, 0 bwpd. 1/19/96 7096' RU HES. RIH w/ tandem electronic gauges making 10 minute gradient stops. Tag fill at 7094' Record FBHP at 7052' for 6 hours, SI well and record PBU for 72 hours. 2/8/96 7096' RU SWS and perforate 6904-6914' (L14), 6886-6896' (L13) and 6854-6874 (L13) w/ 2-1/2" Hollow carriers, 6 SPF, 60 degree phasing, 10.5 gm 31-J charges. Q = 1600 mscfpd, 1300 psig FWHP, 0 bwpd. 3/21/96 6923' RU Dowell 1-1/2" CTU. RIH. Mix up and pump 12 bbls of sand slurry from 7120' to 6810' Wait 6 hours and tag sand plug at 6923' PU to 6903' and CBU. PUH to 400'. Blowdown well w/ N2 and POOH. RD. 3/26/96 6990' RU HES. RIH w/ 2.7" GR and tag fill at 6990'. POOH. RIH and pull injection valve at 920' RIH and install dummy valve at 920' POOH. RD. 3/30/96 6957' RU HES. Make multiple runs to dump 20-40 sal%d using dump bailer, and paoking same w/ blind box. Top of sand plug at 6957' RD. 4/16/96 6957' RU Dowell frac equipment and PTS test equipment. Install tree saver. Frac L. Beluga w/ 88,500 lbs of 20/40 Carbolite traced w/ Sc-46, Sb-124, IR-192. Flowed back 46.1 bbls, well dead. RD frac equipment. RU HES. RIH and attempt to pull dummy valve at 923' Could not locate due to sand. 4/17/96 7125' RU Dowell CTU and cleanout to 7125' PUH to 6000' and blowdown well w/ N2. POOH and RD. Q = 3250 mscfpd, 1570 psig WHP, 0 bwpd. 4/23/96 6944' RU HES and pull dummy valve at 923' RIH w/ 10/64" double check orifice valve. RIH w/ 2.73" GR to 6893'. Could not get past liner lap. POOH. RIH w/ 1.8" swedge to 6936'. POOH. Made several trip w/ 2" bailer from 6928' to 6954' RIH w/ 2.25" bailer to 6941' Recovered frac sand. 4/24/96 6944' RIH w/ 1.75" bailer to 6944' RIH w/ 2.25" bailer to 6923', sitting down on liner lap. RD. 4/30/96 7124' RU Dowell 1.75" CTU. Cleanout fill/sand to 7123' PU to 6000' and blowdown well w/ N2. Tag fill at 7124' POOH and RD. 5/1/96 7131' RU SWS and RIH w/ MIST tool. Tag fill at 7131' Make two passes from 7131-6150' Intervals frac'd: L13, L14, and L16. 5/9/96 7132' RU HES and RIH w/ 1.8" swedge to 7132' (fill). POOH-. RD. 7/13/96 7130' RU HES and RIH w/ tandem electronic gauges making 5 minute static gradient stops. Tag fill at 7130' Make 1 hour stop at 6952'. POOH. RD. 3/1/97 7096' RU HES and RIH w/ 2.25" GR to 7096' (fill). RIH w/ 2.74" GR to 7096' POOH. RD. 3/4/97 7096' RU SWS and RIH w/ PL. Make multiple passes across L13 through L16 perfs. Make stationary stops CONFiDENTIAC S~¥ J~E~O~: ~0~ ~I~ WELL: KBU 41-7 DATg RPT DF, PT!{ MI~D WT. F, ATT.Y O['ERATIC;N:~ :';U.~IMARY above and below perfs. Unable to get below the L-16 perfs w/o the spinner jamming. POOH. RD. 6/6/97 7096' RU SPIDR gauge at surface and perform isochronal test: Q = 1403 mscfpd for 2 hours, SI for 2 hfs, Q = 1337 mscfpd for 2 hours, SI for 2 hours, Q = 1640 mscpfd, for 2 hours, SI for 2 hours, Q = 2075 mscfpd for 2 hours, SI for 2 hours. AOF = 2726 mscfpd. 6/8/97 7096' RU SPIDR gauge at surface and perform PBU. RECEIVED ,IUN 32 1997 :Oil & Gas Cons. Commis~ Anchorage Hanger (25 7-30 60B~0 734 ID2 964~ [ubin9 (3O 6 6543 5 OD3 600 ID2 984) Conducto~ (0 0-134 0 OD20 O00) Produceo[~ Casing (00 7025 0 OD9 626) Surface Casng (0 0 2425 0 OD!3 375) Camco Iniectfon Mandrel (922 7-929 6 OD:5 938 ID2 964) Baker 8040 K Ancho~ (6520 6 6521 5 OD4 750 ~©3 250) 194 S,aB 40x32 Packer (6521 5 65270, OD:6 125 ~D 3 250) Camco X Nipp]e (6537 46538 6 OD4 O47 ID2 613) '¢¢~relh~e Reentry Grade (6562 8 6643 5 OD3 906 ID2 984) Baker Mode~ D Packe~ (6650 4 6654 3 OD6 125 ID4 000) Blast Joint (6654 3 6692 1 0©4 500 ID3 000) 8O 4O Locato Seal Assembly w; 3 72' Se~ds (6692 1-6693 0 OD5 047 ID 3 000) Baker Mode~ D 194 40 PacKer (66930 6697 1 OD8 12o ID,4 000) lubin9 (6697 i 6713 A OD3 500 ID2 984) Camco X Nipple (6707 9 6709 3 OD3 500 iD2 813} W~reiine Reentry Guide (6713 4 6714 1 OD4 250 ~02 984) Perf (6854 06674 O} Fract~Jre Treatment (6854 0 6914 0) Pelf (6666 0 6696 O) Perf (6904 0 6914 O) Packer (6920 0 69270 OD6 750) Production Lner (69200 7198 6 OD5 bOO Wt20 00) Fracture 1 reatment (69900 70100) Peff (6990 0-7010 0) Pelf (/056 0 7076 Fill (7086 0-7115 0 OD4/81) Peri (7104 0 71 ! 4 0) Cement Plug ¢1 i 5 07140 0 OD4 516) Cement Reta net {7140 0 7147 0 OD:4 5!6) Grave~ Pack Screen (7i98 6-7240 0 OD5 50O Wt15 50) KBU 41-7 L15 APt 50~133-20327-00 6/10/97 Alaska Region Domestic Production Marathon Oil Company June 2, 1997 Mr. Jack Hartz Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Hartz: P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Please find attached a completed Gas Well Open Flow Potential Test Report for Kenai Gas Field Well KBU 41-7. The test was conducted on May 20, 1997. Marathon respectively requests this information be kept confidential for a period of two years for strategic planning purposes. Sincerely yours, Michael J. Stover Advanced Reservoir Engineer attachments RE ¢E[VED JUN ,5 1997 AlasJ~a, .0il & 6as. Cons. ~Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la. TEST: INITIAL x lb. TYPETEST STABLILIZED~ ~L--/ NON STABILIZED ANNUAL MULTIPOINT I--I CONSTANT TIME SPECIAL OTHER ISOCHRONAL x 2. Name of Operator 7. Permit No. Marathon Oil Company 79-29 3. Address 8. APl Number 3201 C Street, Ste. 800, Anchorage, Alaska 99503-3934 50- 133-20327 4. Location of Well 9. Unit or Lease Name At surface Kenai Unit 185' FNL, 4303' FWL, Sec. 7, T4N, R11W, S.M. 10. Well Number At TD KBU 41-7 .... 179' FNL, 4268' FWL, Sec. 7, T4N, R11W, S.M. 11. Field and Pool Kenai Gas Field/Beluga 5. Elevation in feet (KB, DF etc.) 16. Lease Designation and Serial No. 107' KB above MSLI A-028142 12. Completion Date 113. Total Depth 114. Plugback T.D. 115. Type Completion (Describe) 12/23/95 7290'MD/7290'TVD 7240'MD/7240'TVD Single Tbg. String / Cased Hole 16. Csg. Size Weight per foot, lb. I.D. in inches Set at ft. Perforations: 5 1/2" Liner 20 4.778 7240'M D 7104'-7114' 6854'-6874' 17. Tbg. Size Weight per foot, lb. I.D. in inches Set at ft. 7056'-7076' 6886'-6896' 3 1/2" 9.2 2.992 6714'M D 6990'-701 o' 6904'-6914' 18' Packer set at ft' 119' GOR cf/bbl' 120' APl Liquid Hydr°carb°ns 21' Specific Gravity Fl°wing fluid (G) 6697'MD ...... 0.5597 22. Producing thru: Reservoir Temp. °F. Mean Annual Temp. °F. Barometric Pressure (Pa), psia tbg. [~--~ Csg. ~---[ 118.9 33 14.73 23. Length of flow channel (L)6714, I Vertical Depth (H)16714 Ga. %CO~ 1%N~0.204 0.161 %H28 I Pr°ver Meterrunl Taps0 x 24. Flow Data Tubing Data Casing Data Choke Prover Orifice Line Size X Size Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. (in.) (in.) psig hw °F. psig °F. psig °F. Hr. 1 3.826 X 2" 748.225 8.65 61 1,931 70 .... 2.00 2. 3.826 X 2" 748.225 8.65 61 1,929 56 .... 2.00 3. 3.826 X 2" 748.225 8.65 61 1,850 57 .... 2.00 4. 3.826 X 2" 748.225 8.65 61 1,718 60 .... 2.00 5. 3.826 X 2" 748.225 8.65 61 1,620 60 .... 120.00 Basic Coefficient ~J (24-Hour) hwPm Pressure Flow Temp. Factor Gravity Factor Super Comp. Factor Rate of Flow No. Fb or Fp Pm Ft Fg Fpv Q, Mcfd 1. 17.4 80.4 762.9 0.99904 1.336664 1.058109 1,403 2. 16.6 80.4 762.9 0.99904 1.336664 1.058109 1,337 3. 20.4 80.4 762.9 0.99904 1.336664 1.058109 1,640 4. 25.8 80.4 762.9 0.99904 1.336664 1.058109 2,075 5. 21.8 80.4 762.9 0.99904 1.336664 1.058109 1,752 Temperature for Separator Gas for Flowing Fluid No. Pr T Tr Z Gg G 1. 1.118082 520.6 1.525 0.893181 0.5597 3. 1.118082 520.6 1.525 0.893181 CriticaIPressure 682.35 "'~ ' ' - ' 4. 1.118082 520.6 1.525 0.893181 Critical Temperature 341.6336 F'~'"b';Rev."?. i'i20!118082_ 520.6 1.525 0.893181 ,. i ~,J f\] ~ "[~ kz~AOGCCGAS.XLS CONTINUED ON REVERSE SIDE Submit in_duplicat,Q. Alaska 0ii & Gas ~Jons. Anchorage Pc 2,710 Pc~ 7,344,100 Pf PF No. Pt Pt2 Pc2 - Pt~ Pw Pw~ PcF - Pw~ Ps Ps~ PF- Ps2 1. 1,931 3,728,761 3,615,339 ...... 2. 1,929 3,721,041 3,623,059 ...... 3. 1,850 3,422,500 3,921,600 ...... 4. 1,718 2,951,524 4,392,576 ...... 5. 1,620 2,624,400 4,719,700 25. AOF (Mcfd) *2726 n 1 Remarks: Modified Isochronal Test performed with 2 hr. flow periods and 2 hr. shut-in periods. Flow period No. 5 collected after 5 days of continous flow following the deliverability test. Test performed 17 months after initial completion to allow addition of select intervals. *The AOF may be understated due to some liquid loading in the 5 1/2" liner and 7" casing. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~? ~ Title Advanced Reservoir Engineer Date 6/2/97 DEFINITIONS OF SYMBOLS AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/ %/ hw/Pm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor = %/ I/Z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air = 1.00), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60° F.) per barrel oil (60° F) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equiation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static presssure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60°F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless $ ]997 .0il ,& Bas Cons. Com~Ss~"" Anchora~ie Form 10-421 Rev. 7-1-80 kz~AOGCCGAS.XLS Recommended procedures for tests and calculations may be found in the MANUAL OF BACK-PRESSURE TESTING OF GAS WELLS, Interstate Oil Compact Commission, Oklahoma City, Oklahoma CONTINUED ON REVERSE SIDE Submit in duplicate Well 41-7 - Surface Isochronal Well Test (5/20/97) Q Pwfi Pwsi Delta P (mscfd) (psia) (psia) (psia) Actual Calc. Pt. Type Flow Time (Ps^2-Pf^2) C (hrs.) S.I. Time (hrs.) 1,403 1,931 2,320 389 1,337 1,929 2,317 388 1,640 1,850 2,325 475 2,075 1,718 2,320 602 1,752 1,620 2,710 1,090 n = 1.0000 (mcf/psi^2) AOF = 2,726 mscfpd 1,653,639 Isochronal 2 1,647,448 Isochmnal 2 1,983,125 Isochronal 2 2,430,876 Isochronal 2 4,719,700 0.00037 "Semi-Stable 120 "C" 0.00037 AOF value may not be representive due to suspected par~l~i~l~i~' 10,000,000 1,000,000 100,000 KBU 41-7 (5~20~97) MODIFIED ISOCHRONAL TEST Alas.k.'a ~0ii & Gas Cons. 60.,m · Transient Data .... ,:, Stabilized Point 100 1000 10000 Q, (mscfpd) h:\excel\kenai\beluga4174PT.XLS 6/2/97 Alaska R~ .~ Domestic Pruduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 June 21, 1996 LETTER OF TRANSMITTAl_ Alaska Oil & Gas Conservation Commission Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 The following well logs are enclosed: Description Kenai Gas Field ~~"~=~ KBU 41-7 ":. Multiple Isotope Tracer Survey Beaver Creek Field Beaver Creek No. 1-A Qp-7 '- ~.c}, Completion Record, 2.5 HSD, 8-May-96 Completion Record, 2.5 HSD, 10-May-96 Print Film 1 1 1 1 1 1 This data is considered confidential until the normal release date. MARATHON OIL COMPANY kz/H:\wp~expl~aogctran.ltr Enclosures Received By: Date: Alaska Oil & Gas Cons. Commission Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. eery MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 3/30/96 FIELD: Kenai Gas Field WELL #: KBU 41 -7 FILL DEPTH /DATE: 6957' wlm TUBING: 3.5" L -80 8rd EUE CASING: 9 5/8" DATE LAST WL WORK: 3/30/96 TREE CONDITION: good WORK DONE: Wireline bailer sand back BENCHES OPEN: L13, 14 PRESENT OPERATION: Added add'I sand above L16 (L16, 17, 18 sanded back PROBLEMS: SUMMARY OF OPERATIONS 0800 3/30/96 Arrive at location. Check in w/ Production personnel. RU w /L. MU 14' x 2.25" dump bailer. 1100 RIH w/ 14' x 2.25" dump bailer. Sat down in tree. POOH. Pin did not shear. RIH w/ 5' x 2.25" drive down bailer to 1000' for gauge. POOH. 1130 RIH w/ 14' x 2.25" dump bailer to 6972' wlm. Dumped .30 FT3 20/40 sand. POOH. 1230 RIH w/ 16' x 2.25" dump bailer to 6968' wlm. Dumped .35 FT3 20/40 sand. POOH. 1350 RIH w/ 14' x 2.25" dump bailer to 6965' wlm. Dumped .30 FT3 20/40 sand. POOH. 1515 RIH w/ 16' x 2.25" dump bailer to 6965' wim. Dumped .35 FT3 20/40 sand. POOH. 1600 RIH w/ 14' x 2.25" dump bailer to 6965' wim. Dumped .30 FT3 20/40 sand. POOH. 1645 RIH w/ 2.65" blind box to determine top of sand. Tagged top of Packer @ 6635' wlm. Tagged top of liner @ 6905' wlm. Tagged top of sand @ 6955' wlm. Determined top of sand to be at 6970' md. Dumped total of 1.6 FT3 of 20/40 sand. 1730 RD W /L. Complete job log, Operations Report and ticket. 1900 SDFN. Depart location. (Bailer spec: 2.25" OD, 1.992" ID, 0.0216 FT3 /FT) 0800 3/31/96Arrive at location. RU W /L. 0900 RIH w/ 16' x 2.25" dump bailer to 6953' wlm. Dumped .35 FT3 20/40 sand. POOH. 1015 RIH w/ 14' x 2.25" dump bailer to 6955' wlm. Dumped .30 FT3 20/40 sand. POOH. 1100 RIH w/ 16' x 2.25" dump bailer to 6953' wlm. Attempt to trip bailer. POOH. Bailer did not trip. 1200 RIH w/ blind box to compact sand plug. Tagged sand @ 6955' WLM. POOH. 1300 RIH w/ 14' x 2.25" dump bailer to 6955' wlm. Dumped .30 FT3 20/40 sand. POOH. 1400 RIH w/ 16' x 2.25" dump bailer to 6950' wlm. Dumped .35 FT3 20/40 sand. POOH. 1500 RIH w/ 14' x 2.25" dump bailer to 6948' wlm. Dumped .30 FT3 20/40 sand. POOH. 1550 RIH w/ 16' x 2.25" dump bailer to 6950' wim. Dumped .35 FT3 20/40 sand. POOH. 1630 RIH w/ 2.65" blind box to determine top of sand. Tagged top of Packer @ 6635' wim. Tagged top of liner @ 6905' wlm. Tagged top of sand @ 6942' wlm. Determined top of sand to be at 6957' md. Dumped total of 1.95 FT3 of 20/40 sand. 1730 RD W /L. Complete job log, Operations Report and ticket. 1900 Depart location. Cumulative sand dumped: 3/30/96 1.6 FT3 51LANNED JUN 21 1012 3/31/96 1.95 FT3 Total 3.55 FT3 Top of sand plug @ 6957' md, 33' above open L16 perforations. WELL TESTS: MMSCFPD BWPD TP CP DATE BEFORE: AFTER: COMMENTS: well s/i DAILY COST: $ 2900 CUM: $ REPORTED BY: Howarth /Cox MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 04/16/96 FIELD: Kenai Gas Field WELL #: KBU 41 - FILL DEPTH /DATE: 6957' 3/30/96 TUBING: 3 - 1/2" 9.2# CASING: 9 5/8 "15 - 1/2" DATE LAST WL WORK: 3/30/96 TREE CONDITION: Good WORK DONE: Set sand plug w/ bailer BENCHES OPEN: L13,14 PRESENT OPERATION: Preparing to cleanout well w/ CT L16,17,18 covered PROBLEMS: Frac went away smooth, CT having problems w/ gelled fluid. SUMMARY OF OPERATIONS 0830 Continue RU Dowell frac equipment and CTU to frac L13 and 14. PTS RU flowline from well to test equipment. 1745 Conduct safety, operations and environmental meeting w/ DDweII, PTS, and Haliburton. Check gel properties. Good. PT PTS equipment to 1950 psig, Dowell equipment to 7800 psig. Stroke tree saver - WHP = 200 psig - had to pressure well to set tree saver. Pressured up control line to 3200 psig, and back side to 500 psig (took 48.5 bbl fresh water to pressure up annulus). Pump 3000 gal WF135 pad at 5 bpm. SD for 15 minutes. ISIP =2696 psig. Perf friction negligible. At 15 bpm, pump 500 gal YF135 pad, 500 gal YF135 w/ 4.0 ppa, 1000 -gal YF135 w/ 6 ppa, 3500 gal YF135 w/ 8.0 ppa, 5500 gal YF135 w/ 10.0 ppa, 66 bbl of WF135 - In the last 20 bbls of 10 ppa stage, increased sand concentration to 12 ppa and did not cross link). Slowed rate down to 5 bpm w/ 15 bbls to pump to try and force screen out - no luck). Final stage flushed to 137' from top perf. Total proppant pumped was 88500 #, left 3300# of sand in wellbore. Total load fluid to recover is approximately 478 bbls. Proppant was 20/40 Carbolite. The sand was traced as follows: Sc -46 (5mCi) in the pad, Sb -124 (5 mCi) in 4 -6 ppa stage, and IR -192 (35 mCi) in the 8 -10 ppa stage. Max surface treating pressure was 4375 psig. 2105 Flowed well at 3 -4 bpm immediately after SI pumps to flowback tank. Produced 35 bbls of fluid in 10 2115 minutes. Flow stopped. SI well and RD tree saver. P increase to 710 psig. 2220 Open well thru PTS equipment. Flowed 10 bbls in 10 minutes. Flowed 1.1 bbls in the next 10 minutes. WHP = 0 psig. 2250 RU HES wireline. SI well. RIH and attempt to retrieve dummy valve at 923'. Unable to locate and latch valve. POOH. Frac sand in OK -6 tool not allowing it to open. RIH w/ Merla KO tool. Same problem. POOH. RD. (Will try and pull valve following CT work.) 0015 4/17/96 WHP = 340 psig. Flow well while RU CT. 0230 PT coil. Had leak in 0 -ring. Also had some problems pumping fluid. Nozzle was partially plugged w/ rust. Fluid also appeared to be crosslinked ?! Restab injector head and pump clean fluid through coil. 0600 RU to break gel and continue w/ cleanout. Total load fluid recovered approximately 46.1 bbls WELL TESTS: MMSCFPD BWPD TP CP DATE BEFORE: AFTER: COMMENTS: DAILY COST: $ Incomplete CUM: $ REPORTED BY: Olson • • MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 04/17/96 FIELD: Kenai Gas Field WELL #: KBU 41 -7 FILL DEPTH /DATE: 6525' CTM TUBING: 3 -1/2" 9.2# CASING: 9- 5/8 "/5 -1/2" DATE LAST WL WORK: 4/17/96 TREE CONDITION: Good WORK DONE: Attempt to changeout dummy valve BENCHES OPEN: L13, 14, 16, 17, 18 PRESENT OPERATION: Flow testing well through PTS equipment PROBLEMS: SUMMARY OF OPERATIONS 0600 Add J218 breaker to frac tank to break 200 bbls WF120 (crosslinked?) gel. Circulate through pump. 0800 PT to 4000 psig. Good test. RIH w/ 1 -3/4" CT w/ 5' stinger, double checks, and wedge tool pumping 0.5 bpm. Increase rate to 1.0 bpm across injection mandrel and several times to cleanout out sand packed around valve. Reduce rate to 0.5 bpm and continue RIH. Traces of frac sand at surface. Lost prime to pump from frac tank due to viscosity of gel. Transferred gel to 2000 gal tank adjacent to pump. Continue pumping @ 1.75 bpm. Note small amounts of frac sand at surface. At tubing tail (6544') circulate bottoms up. 1100 Continue RIH taking 50 -75' bites. Circulate bottoms up at 5 -1/2" liner hanger. Good frac sand returns at surface. Increased rate to 2.0 bpm and RIH to 7125' taking -50' bites. Did not tag up on sand plug - did not see a hard crust. No problems going through 5-1/2 liner hanger. Did sit down on isolation packer at 6650' once - picked up and went through ok. PUH to 6540' pumping 2 bpm and run back to bottom (7125' CTM). 1440 Circulate bottoms up chasing sand up to the tubing at 6000'. Returns were initially frac sand followed by sand from sand plug back (100 mesh and 30/60 (green) sand came up first followed by the 20/40 sand). Wait for returns to clean up. Start up N2 pump and circulate N2 at 300 scf /m from 6000'. Flowed back 49.5 bbls - shutdown N2. Pumped a total of 500 gallons. WHP increased from 0 to 780 psig w/ a total of 84.5 bbls water produced. RIH pumping N2 at 300 scf /m and tagged bottom @ 7125' CTM. No indication of any sand. Increased N2 rate to 2000 scf /m and PUH to 6500'. Cut rate to 300 scf /m and POOH. Shutdown N2 at 2000'. 500 gallons of N2 pumped. WHP increased to 1400 psig. 1940 RD CTU. Rate/WHP decreased from 1100 mscfpd and 1400 psig to 225 mscfpd and 400 psig as water was unloaded. Continue to flow well to cleanup through PTS equipment. Note: A 220 bbl closed fluid handling system was set up to reuse the produced frac gel fluid for the CTCO. A total of 602 bbls were circulated. 04/18/96 Time mscfpd whp bwpd 0100 1830 1150 318 0200 1928 1250 702 0300 3608 1180 162 0400 3827 1240 108 Currently choking well back to 3000 mscfpd to increase WHP. Will open well up as WHP increases to 1600 psig (est. 42% drawdown). Well still cleaning up. Have not produced any frac sand. Water samples do contain approx. 4% shale. 4/19/96 Transferred production into MOC system. Well making 3250 mscfpd, 1570 psig, 0 bwpd w/ a trace of shale. Total load fluid produced back = 320 bbls (67 %). WELL TESTS: MSCFPD BWPD TP CP DATE BEFORE: 1900 0 1015 2/96 AFTER: 3250 0 1570 4/19/96 COMMENTS: DAILY COST: $ 260,100 CUM: $ 260,100 REPORTED BY: Olson 41k 1111, MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 4/23/96 FIELD: Kenai Gas Field WELL #: KBU 41 -7 FILL DEPTH /DATE: 6941' (4/23/96) TUBING: 3 - 1/2" 9.2# CASING: 9 5/8 "15 - 1/2" DATE LAST WL WORK: 4/17/96 TREE CONDITION: Good WORK DONE: CTCO, unload well w/ N2 BENCHES OPEN: L13, 14, 16, 17, 18 PRESENT OPERATION: SDFN, continue bailing in am PROBLEMS: Frac sand covering L16, 17, 18 SUMMARY OF OPERATIONS 0700 RU HES wireline. PT against WHP. Good test. 0945 RIH w/ KO tool to 923' and pull dummy valve. RIH and set 10/64" double check orifice valve. Pump methanol through valve. OK. - 1110 RIH w/ 2.73" GR to 6892. Could not get through. POOH. GR was marked up on the bottom - indicating hitting liner lap. 1250 RIH w/ 1.80" tapered swedge to 6936' - tagged hard bridge (went through liner lap ok). Sticky to 6928' - pulling 125# over PU wt. POOH. Found frac sand in tool joints. 1500 RIH w/ 5' long 2.00" pump bailer to 6928'. Recovered small amount of frac sand. 1610 RIH w/ 5' long 2.00" drive down bailer to 6965' broke through hard bridge at 6936'. Recovered full bailer 1720 of frac sand. 1835 RIH w/ same to 6954'. Recovered full bailer of frac sand. 1925 RIH w/ 5' long 2.25" drive down bailer to 6941'. Recovered full bailer of frac sand. 2030 Change out wireline units. SDFN. Clean up area. Secure well w/ night cap on tree. WELL TESTS: MSCFPD BWPD TP CP DATE BEFORE: AFTER: COMMENTS: DAILY COST: $ 2361 CUM: $ 260,100 REPORTED BY: Olson •\ MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 4/24/96 FIELD: Kenai Gas Field WELL #: KBU 41 -7 FILL DEPTH /DATE: 6923' (4/24/96) TUBING: 3 -1/2" 9.2# CASING: 9- 5/8 "/5 -1/2" DATE LAST WL WORK: 4/23/96 TREE CONDITION: Good WORK DONE: Bail frac sand BENCHES OPEN: L13, 14, 16, 17, 18 PRESENT OPERATION: Flowing well PROBLEMS: Frac sand covering L16, 17, 18 SUMMARY OF OPERATIONS 0830 Arrive on location. Conduct safety /procedure meeting. RU. 0930 RIH w 10' 1.75" drive down bailer. Sat down at 6936'. Work to 6944'. Recovered full bailer for frac sand. 1100 RIH w/ 10' 2.25" drive down bailer. Set down at 6923'. Could not.work past. POOH. Recovered 3/4 full bailer of frac sand. Note marks on bottom of bailer - indicating sitting down on liner hanger. 1500 RD and move equipment to far side of pad. Plan to flow well to allow additional cleanup of perfs. Will RU CT next week and cleanout to bottom and run MIST tool. WELL TESTS: MSCFPD BWPD TP CP DATE BEFORE: AFTER: COMMENTS: DAILY COST: $ 765 CUM: $ 3126 REPORTED BY: Olson • • MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 4/30/96 FIELD: Kenai Gas Field WELL #: KBU 41 FILL DEPTH /DATE: 6923' ctm TUBING: 3.5" 9.2# CASING: 9 5/8" & 5 - 1/2" DATE LAST WL WORK: 4/24/96 TREE CONDITION: good WORK DONE: Bail sand with slick line BENCHES OPEN: L13, 14, 16, 17, 18 PRESENT OPERATION: CT cleanout - job complete PROBLEMS: Sat down on isolation paker while RIH SUMMARY OF OPERATIONS 0700 RU coil tubing unit. Spot equipment for cleanout. Moved PTS open top tank to stage area next to coil unit for flowing the well into. MU 1.75" CT with stiffener and wedge tool. PT coil to 4000 psig. PT flow lines to the PTS tank to 1500 psig. NO leaks on CT. 1500 S/I well , RIH pumping at .5 BPM with 30 # gelled 3% KCI water. WHP =1440 si at start of clean out. P 9 1600 Vac truck arrived to transfer water from Open top tank to mixing tank for reusing gelled fluid. 1700 RIH bleeding gas to open top tank, wind blowing from east to west. CT sat down at the packer at 6653' CTM. WHP =660 psig, 65 bbls pumped through coil. PUH made two additional trys to clear the packer. Screen plugged off in the batch mixing tank. S/D pumping to clear the screen in the hose. PU to 6553. RIH at 19.5 fpm cleared the packer. 1800 RIH to 6900'. Start PIR at 2.0 bpm, move coil to 7000' pump bottoms up while picking up CT to 6680'. RIH to 7045', WHP =20 psig, bbls away= 155.6, PIR =2.0 bpm., PUH to 6500' pumping at 2.0 BPM Small amount of frac sand in returns. 2015 RIH to 7123', pump bottoms up to surface. 305.5 bbls pumped. Returns have small gravel, clay, and frac sand in sample. PUH to 6500', WHP =18 psig. 2040 RIH to 7122.0' PIR at 2.0 bpm, returns down to small amount fac sand. 450 bbls pumped through CT. 2100 PU to 6500' PIR at 2.0 bpm. 2200 RIH to tag bottom, tag at 7123', WHP =20 psig, 525 bbls pumped through CT. PUH to 6500' no sand in returns, WHP =18 psig, Pump 37 bbls before shuting down the pump to let sand settle back in well bore. Total pumped through CT =622.7 bbls of liquid. 2300 RIH with pump shut down to tag fill @ 7125' ctm. WHP =7 psig, CTP = 9 psig., based on last returns and tag at 7125', PU to 6000' to pump N2. 0000 Pump N2 at 300 scf /hr rate. 250 gal away at 0045. 5/1/96 N2 returns to surface pressure up on tubing to 1561 psig, pumped 600 gallons on N2. 0115 RIH. Tag fill @ 7124'. 0150 POOH with CT. At 0205 depth = 5767', WHP =1610 psig. 0255 RD unit. Left well SI. Will run MIST tool 5/1/96. 0700 note:WHP =2250 psig WELL TESTS: MSCFPD BWPD TP CP DATE BEFORE: 2916 1180 0 4/29/96 AFTER: COMMENTS: well s/i DAILY COST: $ ,, ,; ; 1,9- -, CUM: $ REPORTED BY: Cissell • ) err) t3 UNION OIL COMPANY KENAI BELUGA UNIT 41 -7 DAILY NOTES November 18, 1979: Magcobar engineer on location. Still rigging up. November 19. 1979: Rigging up. Raised derrick @ 1600 hrs. November 20, 1979: Rigging up -drove 20" conductor to @ 113'. Filled rig pits with water and began repairing leaks. Began mixing mud for spud @ 2300 hrs. November 21, 1979: Completed rig up. Prepared mud for spud @ 65 sec /ot funnel viscosity and mud weight @ 64 PCF. Rigging up Quadco mud separator system. November 22, 1979: Well spudded just after midnight. Drilled ahead through sand, gravel, clay sections to a midnight depth @ 1630'. Quadco unit working well, cutting sand content from 10 +% at flowline to less than 0.25 %,.at suction. Shaker screens (B40 and S40) have tendency to blind off from sand, but otherwise no problems noted. November 23, 1979: Drilled ahead to @ 2510'- T.D. for surface hole. Circulated 2510' hole clean and POOH. Picked up new BHA and RIH. Reamed @ 130' to bottom and plugged bit jet. Worked free and completed reaming to bottom. Circulated @ 2 hrs. and POOH to run casing. November 24, 1979: Attempted to run 13 3/8" casing, but unable to get past 2514' obstruction @ 154'. POOH with casing. Picked up bit and BHA and RIH. Reamed through tight area. POOH. Pulled bell nipple out of hydril - stripped some nuts and bent matting surface. Made repairs. RIH with "stacked hole" assembly to bottom, Reaming - plugged bit, and had to make a round trip. Novmeber 25, 1979: Completed reaming to bottom. Circulated and conditioned hole and 2514' mud. Increased funnel viscosity to @ 70 sec /qt. and circulated hole clean. POOH. Ran 13 3/8" casing to bottom. RIH to stab in collar with D.P. November 26, 1979: Completed RIH and stabbed into float collar. Circulated with 2514' B -J unit. Attempted to cement, but many problems. Circulated all cement, preflush, etc. out with rig pumps and replaced B -J with Halliburton. Circulated casing at midnight. November 27, 1979: Cemented casing with Halliburton. PO011 with D.P. and wait on cement @ 10 hrs. "Top job" for 13 3/8" annulus. Pressure tested casing head to @ 1500 PSI - good. Began nippling up. Casing set @ 2425'. November 28, 1979: Completed nippling up operations. Attempted to run GYRO Survey - no go. Tested BOPE and manifold equipment. Laid down 172" drilling BHA. Picked up 124" bit and new BHA. RIH. Drilled out cement and shoe. Midnight depth @ 2582'. •J • } November 29, 1979: Drilled ahead to @ 2865' and POOH for new bit. RIH and • 4200' drilled ahead. No hole or mud problems noted while drilling or tripping. Maintained, mud weight @ 68 - 69 PCF with a funnel viscosity of 55 - 60 sec /qt. November 30, 1979: Drilled ahead to @ 4520'. Short trip - pullled tight 5017' through coal zone @ 10 stands off bottom. Reamed back to bottom, circulated hole clean and POOH for new bit. RIH and drilled ahead to @ 5017' @ midnight. Viscosity increased, so increased amount of water additions for control of fine drill solids. No further problems noted. December 1, 1979: Drilled ahead to @ 5604'. POOH for new bit - hole tight 5870' coming out. RIH and drilled ahead to midnight depth @ 5870'. Gel strengths increasing, possibly due to fine drill solids. December 2, 1979: Added light CLS treatment to reduce gel strengths after pilot 6320' testing. Drilled ahead to @ 6130'. POOH for new bit. RIH- hit bridge @ 8 stands off bottom. Worked on to bottom and drilled ahead to @ 6320'. Noted substantial pump pressure loss. Circulated carbide - suspected washout. POOH - found washed out D.P. December 3, 1979: RIH and drilled ahead. Mud weight increased to @ 73 PCF, 7010' so increased water addition. Added Duovis. and Drispac for control of desired rheolo¢icai properties. Necessary to vacuum off @ 100 bbls. excess volume. Drilled to @ 7010', made a 10 stand short trip and ran back to bottom. Circulated and conditioned mud and POOH for logs. December 4, 1979: Logged until noon. RIH and drilled @ 15' to @ 7025'. Circulated 7025' bottoms up and POOH to run casing. Vacuumed off another 100 bbls. excess volume. December 5, 1979: Ran 9 5/8" casing without problem. Circulated casing @ 3 hrs. 7025' Cemented - noted @ 75 bbls. mud loss during displacement. Wait on cement. December 6, 1979: Wait on cement. Nippled up and tested BOPE. Laid down 8" D.C. 7025' Picked up new BHA. RIH to casing shoe. Level derrick. December 7, 1979: RIH. Pressure tested casing - good. Drilled out cement, float 7031' collar and casing shoe. Drilled @ 5' new formation. Tested formation to 0.65 equivalent gradient. POOH. Ran GYRO survey and logs. Preparing to RIH. December 8, 1979: RIH and drilled @ 7129' - core point. Circulated bottoms up. 7129' POOH. Picked up core barrel and RIH. December 9, 1979: R.IH to core - noted well flowing @ 24 stands off bottom. Picked 7129' up kelly and shut in well. SICP - 1200 PSI. SIDPP - 100 PSI. Circulated through choke and increased weight from 72 to 78 PCF. Stripped into hole until 5 stands off bottom. Circulated bottoms up. Stripped in to bottom and circulated bottoms up. Increased mud weight to 80 PCP. Made a short trip, ran back to bottom and circulated bottoms up. POOH to service core barrel. RIH to core. . . , • ) • December 10, 1979: RIH with core barrel. Circulated bottoms up and dropped 40 7151' ball. Cored 0 20' and POOH ( recovered @ 14'). Laid down core barrel. Picked up drilling assembly and RIH. Circulated and conditioned mud at the casing shoe. RIH and reamed out 71/2" rathole. Drilled to @ 7151' @ midnight. December 11, 1979: Drilled to @ 7234', circulated bottoms up and POOH. Picked 7151' up core barrel, RIH, circulated and dropped ball. Cut @ 20' core and POOH to recover. December 12, 1979: Laid down core barrel and picked up drilling assembly. 7290' RIM and reamed out rathole. Drilled to @ 7290', circulated @ 30 minutes and POOH for logs. Logged from 1300 -2400 hrs. December 13, 1979: Completed logging. Disposed of drilling mud and cleaned pits. 7290' Ran pilot tests for various viscosified Calcium Chloride Brines. December 14, 1979: Cleaned pits and mixed Calcium Chloride Brine. 7290' December 15, 1979: Completed mixing Brine to @ 80 PCF. Thawed kelly after RIH. 7290'. Displaced mud system with Brine. December 16, 1979: Completed displacement and POOH. Ran caliper logs. RIH with 7290' 15" underreamer on two runs. POOH. RIH to ream again at midnight. December 17, 1979: Reamed hole to 15 ". POOH. Ran 51/2" liner and screen. 7290' December 18, 1979: - Remainder of time spent in testing well. Magcobar engineer January 4, 1980: replaced on January 5, 1980 by Union Oil mud consultant to complete remainder of operations. MARATHON OIL COMPANY 3201 C Street, Suite 800 P.O. Box 196168 Anchorage, Alaska 99519-6168 Telephone: (907) 561-5311 Fax: (907) 564-6489 Letter of Transmittal March 12, 1996 TO: Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 FROM' Chick Underwood Exploitation Department WELL LOGS Description Kenai Gas ,Field ~C~ ~ /¢"~----'~ KDU-4RD COMPLETION RECORD 2.5" HSD KBU 41-7 COMPLETION RECORD Beaver Creek Field DC-6 COMPLETION RECORD 2/6/96 2/8/96 2/4/96 Print 1 TOTAL 3 Film 1 This data is considered confidential until the normal release date. (Marathon Oil) (Date) (Date) Letter of Transmittal MARATHON OIL COMPANY 3201 C Street, Suite 800 P.O. Box 1961 68 Anchorage, Alaska 99519-6168 Telephone: (907) 561-5311 Fax: (907) 564-6489 February 27, 1996 TO' Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 FROM: Chick Underwood Exploitation Department Description Print Film Ultrasonic Imager/GR Corrosion Log 12/12/95 1 " " Cement Bond 12/12/95 1 TOTAL 2 1 DIGITAL DATA UIT/CBT Waveforms I Tape The data is considered confidential until the normal release date. (Marathon Oil) (Date) (Date) Please Return I Copy by Either FAX or Mail to Marathon Alaska 0/I & Gas Cons, Commi~ion Anchorage MARATHON OIL COMPANY 3201 C Street, Suite 800 P.O. Box 196168 Anchorage, Alaska 99519-6168 Telephone: (907) 561-5311 Fax: (907) 564-6489 Letter of Transmittal January 25, 1996 TO- Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 FROM- Chick Underwood Exploitation Department WELL LOGS Description Kenai Gas Field KBU 41-7 KDU-2 !1 PERFORATING RECORD PERFORATING RECORD GAMMA RAY/CCL Print 1 1 TOTAL 3 Film 1 1 3 This data is considered confidential .until the normal release date. (~Ma~rr~t~ho~nn Oil)~~ ~(/~~ate) ~ ..{ReCeived ~ MARATHON OIL COMPANY 3201 C Street, Suite 800 P.O. Box 196168 Anchorage, Alaska 99519-61 68 Telephone: (907) 561-5311 Fax: (907 564-6435 Letter of Transmittal January 2, 1996 TO: Howard Okland Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 FROM' Chick Underwood Exploitation Department Description /,t I '~KDU-4RD PERFORATING RECORD _~/~ PERFORATING RECORD ~J3.1-7RD PERFORATING RECORD i~/"PERFORATING RECORD k, / ~" MULTIPLE ISOTOPE SPECTROSCOPY KBU 4.1-7 SQUEEZE GUN /,~~ / ~j~ " CEMENT RETAINER Print Film 11/11/95 I 1 11/25/95 I 1 1.0/26/95 I. 1 11/O6/95 I 1 11/26/95 1 I 12/1 2/95 1 1 12/12/95 I I TOTAL 7 7 The data is considered confidential until the normal release date. (Marathon Oil) (Date) (Date) Please Return I Copy by Either FAX or Mail to Marathon .uc vED 02 1996 Alaska 011 & Gas Cons. Commission 90?-564-6389 MOC ANC OPERAT IONS 241 P01 ALASKA REGION DAILY DRILLING REPORT December 6, 1995 AKR/Kenai Peninsula/Kenai Gas Fietd/KBU 41-7 W/0 Development/Operator MARATHON W.I. 100.00% Objective' Recomplete Well in ~he Middle and Lower Beluga DEC 06 '95 11:01 Dry Hole (Days) Total COSt (Days) Depth (MD) 24-hr Ftg APE (9201395) $1,810,000 (31) $1,810,000 (31) Actual $ 388,109 (13) $ 388,109 (13) 6,705' LAST CSG: LINER: SHOE TEST: NA MUD WT: 10.3 06 Dec: POOH. No recovery. RIH with spear and attempted to catch rotary shoe pushed down hole to 6704'. POOH, no recovery. M/U 8.5" tapered string mill and RIH. Milled from 6500' to 6510°. RIH to 6775' and started milling with string mill. NaSa Oil & ~ Coas. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: DavidJoh o,~n, Chairm~:;~ Blair Wondzell, ~ P. I. Supervisor t~',, FROM: Lou Grimaidi, ~.o ~- SUBJECT: Petroleum Inspector DATE: FILE NO: November 30, 1995 AQ9JK4CD.DOC BOP test Pool rig #122 Marathon KBU 41-7 PTD #79-29 Sundry #95-089 Thursday, Noyember 30,t995: I witnessed the initial/weekly BOP test on Pool rig #122 which is presently working over Marathons well ~41-7 in the Kenai Gas Field. I originally witnessed the initial test on Saturday November 25, 1995. The rig was rigging up to pull the dual string completion when I arrived. The initial test could not be completed due to a severely poor seal at the dual tubing hangers. The best that could be accomplished was a "Running" test, that is the test pump continuously ran while we ran from and to different parts of the rig to look for visible leakage. There was a tree hand on location who I discussed possible options with and indicated that this style of hanger had no feature that allowed energizing. I wiil do some investigation on this style head for future problem jobs like this. The choke manifold, upper pipe rams (dual), HCR valves and manual stack valves were tested with no leaks observed and although this was not a complete test I allowed for them to pull the tubing and retest the BOPE at that time. I returned on Thursday and retested the BOPE. The testing went fine until we started to test the Choke Manifold, this equipment had tested good bef°re but we had numerous failures this time. The entire choke manifold required greasing and after cycling the valves was retested "OK". SUMMARY: I witnessed the Initial/weekly BOP test on Pool rig #122 working over Marathons well KBU 41-7 Two tests, Test time 5/10 hours. 3 failures. Attachments: AQ9JK4CD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X Drlg Contractor: Pool Arctic Alaska Operator: Marathon Well Name: KBU 41-7 Casing Size: 5 1/2 Set @ Test: Initial X Weekly X Rig No. '/22 PTD # Rep.: Rig Rep.: 7,240 Location: Sec. Other 79-29 DATE: '/1/30/95 Rig Ph.# 227-042'/ Pete VergaYLance Lamons Gary Goerlich/Holly Waldron 7 T. 4N R. 11W Meridian Seward MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gert) PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec. P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F '/ 250/5, 000 P 250/5,000 P 250/5,000 P 250/5,000 P BOP STACK: Quan. Annular Preventer '/ Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves 2 Kill Line Valves Check Valve Test Press. P/F 25O/3500 P '/ 250/5,000 P '/ 250/5,000 P I 250/5,000 P '/ P 250/5,000 250/5,000 '/ 250/5,000 P N/A 250/5, 000 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes '/5 Test Pressure P/F 250/5,000 F 36 250/5,000 P 2 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3,000 I P 1,750 I P minutes 28 sec. minutes 45 sec. Remote: Psig. Number of Failures: 3 ,Test Time: 10.0 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Choke manifold had valves leaking, greased and cycled valves. Retested "OK". Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X' NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R, Grirnaldi FI-021L (Rev. 12/94) AQ9J K4CD.XLS Ala, . Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 May 10, 1995 Mr. Dave Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Reference: Kenai Gas Field Wells KDU-2, KDU-4RD and KBU 41-7 Beaver Creek Field Well BC-6 Dear Mr. Johnston' Please find attached Sundry Applications for the workover and recompletion of Wells KDU-2, KDU-4RD and KBU 41-7 in the Kenai Gas Field and BC-6 in the Beaver Creek Field. This workover program is scheduled to commence following the drilling at KBU 31-7RD and KTU 43-6XRD. Please advise if further information is required. Sincerely, M. F. Sinclair Drilling Superintendent /nrs H:\WP\DRILL95\MFS5101 Attachments RECEIVED MAY 1 5 1995 Oil & Gas Cons. Commission Anchora ~ A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging -X- Time extension __ Stimulate Change approved program __ Pull tubing -X-. Variance __ Pedorate ._X. O~er 2. Name of Operator ! 5. Type of Well: Marathon 0il Company ' i Development~._ Exploratory __ 9 - 61' Stratigraphic __ 3. Address P.O. Box 196168, Anchorage, AK 9951 8 Service__ 4. Location of well at surface 185' FNL, 4303' FWL, Sec. 7, T4N, R11W, S.M. At top of productive interval 186' FNL, 4268' FWL, Sec. 7, T4N, RllW, S.M. At effective depth ORIGINAL At total depth 179' FNL, 4268' FWL,. Sec. 7, T4N, R11W, S.M. 6. Datum elevation (DF or KB) 107 feet 7. Unit or Property name Kenai Beluga Unit 8. Well number KBU 41-7 9. Permit number 79-29 10. APl number 50-- 133-20327 11. Field/Pool Kenai Gas Field 12. Present well condition summary Total depth: measu red true vertical 7290 feet 7290 feet Plugs (measured) Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 134' 2425' 7025' 320' measured See true vertical 7240 feet 7240 feet Size 20" 13-3/8" 9-5/8" 5-1/2" Attached Tubing (size, grade, and measured depth) LS SS Packers and SSSV (type and measured depth) 13. Attachments - 2-7/8", 6.4#, 3-1/2" 9 2# 1. Baker Model 2 Baker Model Baker Model Junk(measured) Plug set @ 6928' Fill 6615' Cemented Measured depth True vertical depth Driven 134' 134' 692 SX 2425' 2425' 1800 SX 7025' 7025' Gravel Packed 7240' 7240' Description summary of ~r'oposal __ N-80 to 6930' N-80 to 5298' , SIN "A-5" Dual Packer ¢ 5250 , ""~'~!~a~e~ ~4~'20' ~~'~I~*' Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 9-7-95 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas _,~ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY IApprOval N°' c?~.._ ~_.~ Conditions of approval: Notify.Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ~O ~' Approved by order of the Commission Original Signed By David W, Johnston Form 10-403 Rev 06/15/88 ~:~'n' ~"'""'ed Copy ~_~e~urned Com~ Date .:~ ///~ ~:~4¢ SUBMIT iN TRipLICATE F~rm 3160-5 ('May 1989) UNI''~-''') STATES (Other Instruction8 'e- DEPARTMEN1 OF THE INTERIOR verse-'de~ BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~e this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) WELL WELL OTHER 2. NAME OF OPERATOR Marathon Oil Company 3. ADDS]EBB OF OPERATOR P.O. Box 196168, Anchorage, AK 99519-6168 OMB NO. ~0044)135 Fxpires: September 30. 1990 5. LgA~I DRBION&TION AND ~mal~ NO. A-028142 6. IF INDIAN, ALLOTTEE OR TIIBR NAM~z 7, UNIT &OREEMmNT NAM~ Kenai Beluga Unit 9. WBLL NO. KBU 41-7 4. LOCATION OF %VKLL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface 185' FNL, 4303' FWL, Sec. 7, T4N, R11W, S.M. 10, FIELD AND POOL, OR WILDCAT Kenai Gas Field 14. PERMIT NO. J 15. E{L,EVATION!S IShow whether DF, aT, GR, 79-29 { 107' KB ~e. Chec~c Appropriate Box To [ndicale Nature of Notice, Report, or Other Data 11. -qBe2., T., R., M., OI BLK. AND 8UIVBY o~ ABrA Sec.7, T4N, RllW, S.M. 12. ~OUNTY OR PARIAH'[ 13. STATE Kenai{ AK NOTICE OF INTENTION FRACTURE TREAT MLL~_IPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLAN~ (Other) SUBSEQUENT RBPOUT 0r: WATER SHUT~rr ~ R~PAIR!NG WmLL ~ FRACTURt TReATMeNT ALTERING CABINO SHOOTING OR ACIDIZING ABAN~NMgNT* (Other) /NOTE: Report resul~ of multiple completion on Well Completion or Reco~npletion Report and Log form.) 17, D~;S('RIBE PROPOSED OR COMPLETED OPERATIONF- (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionaJly drilled, give subsurface loc~tiuns and measured and true vertical depths for all markers and m~on~ peril- neat to this work.) * See attached addendum. RECEIVED ~A¥ 1 5 1995 Alaska Oil & Gas Cons. Commission Anchora i e 18. I hereby certify that the foregoing is true and correct TITLE (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL. LF AN~: TITLE DATE *See Inmuctions on Reverse Side Title I$ U.S.C. Section !001, makes it a crime for any person knowrngly and willfully to make to any' department or agency of the r~_:...x c .... ~ ~,,,. f~'..~e, fictitious cr fraudulen~ statements or representations as. to any matter w~thin its jurisdiction. KBU 41-7 PERFORATIONS 5334'- 5353' 19' 5641' - 5655' 14' 5761'- 5775' 14' 5905'- 5909' 4' 6128' - 6138' 10' 6494' - 6504' 10' 6668' - 6680' 12' 7200'- 7240' 40' Middle Beluga Middle Beluga Middle Beluga Squeezed w/450 SX Cmt Middle Beluga Lower Beluga Lower Beluga Upper Tyonek S.S. S.S. S.S. S.S. L.S. Abandoned All depths are measured and TVD (straight hole) Note Static BHP 1200 PSI - 6/94 /nrs G:\OMN\DRLG\417PERF ~/kY 1 5 1995 Gas Cons. Commission Anchora ¢' = 4 Middle ! _ 5 Beluga i Lower Beluga V 17 VIII Upper Tyonek IX~ REV. CATE 'WE'LL KBU 41-7 CASING & ABANDONMENT DETAIL I. Kelly Bushing at 0.0' II. Dual tubing Hanger at 22.6' III. 20°, 94~,, H-40 Plain-End Casing at 133.70' IV. 13-3/8°, 61~,, K-55 Casing at 2,425.27' V. Top of 5-1/2', 20*, N-80 Liner at 6,920.26' VI. 5-1/2' F.J. x 7" Cross-over at 6,933.14' VII. 9-5/8', 47~, N-80 Casing at 7,025.00' VIII. Top 5-1/2", 15.5~, 8RD W/.012' Screen at 7,198.65' IX. Bottom of 5-1/2" Bull Plug at 7,240' TUBING DETAIL LONG STRING: 2-778", 6.4~, N-80 TUBING 1. Otis 'XA' Sleeve at 5,214.55' 2. Baker Model 'A-5" Dual Packer at 5,249.47' 3. Otis "XA" Sleeve at 5,291.97' 4. Blast Joints From 6,326.22' to 5,364.94' 5. Blast Joints From 5,628.06' to 5,666.40' 6. Blast Joints From 5,749.26' to 5,788.10' 7. Blast Joints From 6,117.24' to 6,146.77' 8. Otis 'XA' Sleeve at 6,365.67' 9. Baker Model 'FH" Single Packer at 6,401.56' 10. Otis "XA" Sleeve at 6,445.64' 11. Blast Joints From 6,480.33' to 6,509.14' 12. Blast Joints From 6,665.01' to 6,694.27' 13. Otis 'XA' Sleeve at 6,881.57' 14. 2-7/8' x 3-1/2" x-over at 6,915.18', Followed by 3-1/2" x 4-1/2" x-over at 6,916.11' 15. Baker Model G-22 Locator at 6,917.18' 16. 7.8' Baker Seal Assembly W/top at 6,918.07' 17. Baker Model 'FB-I° Packer W/6' Bore at 6,920.26' 18. 2 x-overs From 4-1/2" to 2-7/8' W/top at 6,925.87' 19. Otis 'XN" Nipple at 6,927.84' 20. Bottom of Mule Shoe at 6,930.07' SHORT STRING: 3-1/2'; 9,2#, N-80 TUBING A. Camco Gas lift Mandrel at 2,312.76' B. Camco Gas lift Mandrel at 3,572.17' C. Camco Gas lift Mandrel at 4,741.99' D. Otis 'XA" Sleeve at 5,215.16' E. Baker Model 'A-5" Dual Packer at 5,254.50' F. Otis 'XN" Nipple at 5,296.64' G. Bottom of Tubing Collar at 5,297.97' PERFORATION RECORD DA TE IN TER VA L 7,200'-7,233' 12/28/79 6,494'-6,504' 12/29/79 6,668~-6,680' 1/02/80 6,128~-6,13 O' 1104180 6,128'-6,138' 1/11/80 5,905'-5,909' 1/15/80 5,761 '-5,765' 5,651'-5,655' 5,765'-5,775' 5,641'-5,651' 1/17/80 5,334'-5,338' 1/18/80 5,338'-5,353' CONDITION Upper Tyonek, Abandonded DST ~, lA L. Beluga, Open DST ~,IB L. Beluga, Open WSO, M. Beluga, Open DST ~2, M. Beluga, Open Csg. Leak, Sqz'd, Perfs Open WSO, M. Beluga, Open WSO, M. Beluga, Open DST ~3A, M. Beluga, Open DST ~3B, M. Beluga, Open WSO, M. Beluga, Open DST ~4, M. Beluga, Open RECEIVED MAY 15 1995 Alaska Ull & Gas Cons. Commission W E l L K b U 4 1- ~nchora ir, ~,.~,.~..,o. a.^.w. ~o. SCALE NONE DATE 3/31/86 WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA WORKOVER PROCEDURE' FOR KBU 41-7 . . R/U slickline. Opep sliding sleeves at 6445' and 5292', in long string. Fill long string with ~ Open sliding sleeve at 5215' on short string. Fill short string and annulus with KWM. 3. Set BPV in both strings. . . Move in and R/U workover rig. N/D tree, N/U BOP's and test to 250/3000 psi. . . . Clean out wellbore to 7200'. H ~,[~ -r~3' Perforate 5-1/2" liner at 717..___5'. Set retainer at 7150' and s.quee_ze perfs with 10_0 SX cement. Perforate Lower Beluga Lll-L15 6744 - 6940'. Frac same. Flow for evaluation. Sand back. 9. Perforate Lower Beluga L3-L8 6192 - 6415'. Frac. 10. Set production packer 5300'. 11. 12. 13. 14. Run 3-1/2" production TBG. Set BPV. N/D BOP's N/U tree and test same. R/D workover rig. R/U CTU for cleanup and flow tests. 15. 16. Perforate Lower Beluga L16-L18 6990' - 7136'. Commingle production L. Beluga L3-L18 plus existing Middle Beluga perforations. /nrs G:\CMN\DRLG\417~NOP RECEIVED MAY 15 1995 Oil & Gas Cons. Commission Anchor~ ~, KF-NAI OAS ?; LD KBU 4t PRO?OSF'D WELL_BORE SCHEMA-I- C ].% 5/8" @ 2,425' 5 1/2" tubing Packer set approximately 5,300' MD Current per ts: M. Beluga: 5,554' - 5,553' M. Beluga: 5,641' - 5,655' ~ M. Beluga: 5.761' - 5,775' M. Beluga: 5,905' - 5,909' M. Beluga: 6,128' - 6,1,38' L. Beluga: 6,494.' - 6,504' L. Beluga: 6,668' - 6,680' Tyonek: 7,200' - -,233' Abdn OHGP An initial L. Beluga L5-18 (6,192' - 7,136' MD)commingled completion is envisioned. Portions of this interval, the L Beluga Ll1-15 (6,744' - 6,940' MD will most likely be fracture stimulated as Stage 1 and the L. Beluga L5-8 (6,192' - 6,415' MD) will most likely be fracture stimulated as Stage 2. {F'rac String Fracs due to open perforations) J pre-existina Lwr & Mdl Beluga peris will be camm,naiad w,t.h the compleUon. ............Additional Lwr. M~II. & Upr Beluga ~s available for later recompletlon ~f needed. ~ B<~ker FB-1 pecker at 6,920: 5 1/2" liner top ~. 9 5/8" @ 7,025' Set plug @ approximately 7,150' Sqz liner below plug ~ 5 1/2" liner @ 7,240' MD CAM 5/05/95 RECEIVED Gas Cons. Commission Anchora, ? ,~Hi~rr ,~ i~Ec'r]ON i PI~OPOSED BOP STACK, CONFIGURATION h'Y&,a. ~3 $/a'-s,oooPs~ CHOKE ~ 11'-s, oooPsl ~.o. BLOW-OUT PREVENTER STACK P,M WORKOVEE RiG RECEIVED MAY ] 5 1995 Alaska 0il & (]as Cons. Commission Anchora., · "' ~ Doc.ument Transmittal . ':.' i " " ' .... Uni< -'"~ Company of Californi "'i:' ::": , ' : NO. COMM · ' "'." . TO William Van Alen Alaska 0&G Cons. Comm. ^T 3001 Porcupine Drive Anchorage, AK 99504 TRANSMITTING THE FOLLOWING: ii /~~~T T ED Jan. 2lJ 1981 ~ Warthen Union 0il Company GE©L ~) BOX 6247 ~ I 3"C~EOL Anchorage, AK 99502 ..... TELEPHONE NO. I STAT TE~ K~nai Rp!,!ga Unit 4!-7 Set of Core Chips from Core t RES :ER: aekmowiedge reeeip~ By s:'gning an DATE: FORM 1-2M02 (REV. 11-72) PRINTED IN U.5.A. R. C. V~-'-"RTHEN ANCHORAGE. ALASKA ALASKA OIL AND GAS CONSERVATION (',OMMISSION lAY $. HAMMONO, ~OVERNOR ~ 3001 PORCUPINE D RI VE-ANCHORA GE, ALASKA 99501 January 14, 1981 Mr. R. C. Warthen Union Oil Company of California P.O. Box 6247 Anchorage, Alaska 99502 Re: Union Kenai Beluga Unit #41-7 Permit No. 79-29 Dear Bob: Although the subject well was completed January 20, 1980, the Commission has not yet received the core chips specified in the drilling permit. Please send the chips at your earliest convenience. Very truly yours, . William Van Alert Petroleum Geologist Form No. G-! REV 10-69 STATE OF ALASKA SUBMIT IN DUPLICATE OIL AND GAS CONSERVATION COMMII-[EE GAS WELL OPEN FLOW POTENTIAL TEST REPORT Multi-POINT TEST Test Initial. F~l Annual F'~ Special ~ Reservoir [ Test Date Field Kenai Gas Fi eld Middle Beluga ~ 7/2/80 Operator Lease [ V,'ell .~o. Union 0il Company A-028142 I 41-7S "°umY Kenai I L°c~""" 185' S & 4304' E of NW C°rner °f Sec'7 Ic°~pI:"°~,',T4N, R11W; S ]q . ' !/30/80 { T/)t.1 Del)~h7240 { T/~aY t ~°~"~"~5334 5~]~L6138 Pr°ducin~ Thru ~ ~e~e~'°ir [ Wellhead i CSG' SlzeTBG. T~mp~:,ure Temperature %Vt/Ft. [ I.D. I Set* X Icsa' lla'~ 66o;F 9 5/8 47 8.535 7025' 3 1/2 9.2 3.5 2.922 5296 ,s~3,. ~h~, 2939 ~'*°"c~ ~B~b" '3~'~ Pipeline Connection I Type Taps Nikiski I Flange ~Iultiple Completion (Dual or Triple) Dual Type production from each zone Gas OBSERVED DATA Flow Data Time (Prover) I (Choke) Press. Diff. Tubing Casing Flowing No. of Flow (Line)[ (Orifice) h Press. Press. Temp. Hours Size Size psig w psig psig *F · s, t 1 3.826 2.2'5 [ 3.24 '1461 Pa~k'er 66 ~.' '! 1 ...... { 3.826 ....... 2~25 .... ! "7.56 .... 1415 PaCker ' "6'7 ' ' '1" j 3.826 2.25 I 20.70 1245 Packer ' 67' 1 ........... J 3 826 } 2[25 46.92 988 Pa~er 66 FLO~V CALCULATIONS ,Coefft- Flow Temp. Gravity Compress. ~o. cient ---~/h p Pressure Factor Factor Factor ]Rate of Fl'ow (24 Hr.)Vw m psla F F F Q I~[CF/D t g pv ~'. ....26.659 t 69.154. "' '1476 ......99z~3 ] '1.3423" ~.0592- '2606 ~. I 26.659 103.97 1430'- .9943 1'342'3 '].0578 3909 ~. t 26.659 l'6J.50 .... 1'260 .99~3 ' i.34.23 i 0529 6044 4.'1, 26':65..9. ...."216.93 I' "!,P03 ' :9943 '.., 1.3423 " 1.'044'2 8060. PRESSURE CALCULATIONS P P w p: p~ _ p~ , Cal. w '1; (Psla) P" F Q (F Q); (F Q)= X 1-e-~ p :t C C C 1V C W W P t ' e 1. 2. .~. 4. Absolute Pot,entiai I n 12395 MCF/D{ .6336 CERTIFICATE: I, the undersigned, state that I am theEnaineer- o~ me Union 0i'l :Company (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are true, correct and complete to the best of my knowledge. Signature Steve A. Lambert GAS WELL OPEN FLOW POTENTIAL TEST REPORT PRESSURE CALCULAT I OHS (Supplement to Alaska'O & GCC Form No. G-I) Reservoir Tesl Date FieldKenai Gas Field Middl~ Bel,uga 7/2/80 Lease We l I ~o. Opera~qon Oil Company A-028142 41-7S , , · , Test (I ) (2) (3) (4) - Ps Pf (Ps2- pt2) Q No. . ~.~s i a ,, .. :~$ i ~ X . 104 ~,.:CF/D 1 1 573 .... 1476 ,. 29.58 2_606 2 1 582 1430 45.78 3909 ' 3 1 588 1260 93.41 6044 ,,, , .... 4 1 588 1003 1 51.57 80'60 Sub-Surface Test Data Subsurface pressu.Pes measured. [----l Subsurface pressures computed. Cullender-Smith k:ethod of IOCC. (!) (2) (3) (4) Test Pws 0 ' (Pws2-pw~2) Q No. psia psia X 10-4 !,ICF/O ..... · . ......... Nomenclature: Ps = Static surface pressure ~P-f~.= Flowing surface pressure Pws ='Static bottom-hole pressure (mid-point of perforations) Pwf = Flowing bottom-hole pressure (mid-point of perforations) Q = Flow rate, Mcr per day at 60°F and 14.65 psia 1-70 .. · KENAI GAS FIELD Back Prer-~'~re Tests Well: Pool: Survey Date: 1.0 .................................................................... :. L .................... ,// ......................................... ........... ..: ............. : ~ .. .... __:...-: -._ ::::-_.:_. ....... / .................... ::_.:-- - · 5o .__-_:: ............. :.. ............... . ................... :--..: ...... -~ ......... ::.?-::..:--.::y:--.::-.~ .... :.:..:..- -:-~ ...... : .... ::: ..... :-.. .......... :.--..--_: ..... :.-: ............ :.'::- i' ..... : ....... ::-:'--:: :::i:_.".' : -: -- :!_'- ':M-:'::->'-'?:':::::-:'-':.-:~ ..... :: .... ::"'::': ........... .-.-:N:: ....... . - _ - - :-::- . ...... :_--..-_ .... >-ik::'--:h.================================================================ iX ...... ' - o5 .... :.:: ..... L:_ ..... ._:..: .......... --. ..... :7_ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :. . ..... - - ...... -:.,.... :'"_-:- ..... :/:::-:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ':''.'-'-:::':': i:-::' ======================= -- .: e-l:::. ..... ::::::::::::::::::::::::::::::::::::::::::::: ..... .._:.-. :. -:: ................. . ........ -' _- -- --""-' / :::::::__:_. _?:::::::::::::::::::::::::::::::::::::::::::::::::::__:-...-. _:._: ......... :.!:_ :..._:: ~::-::...- ~.: ':_ 2':' : _:::::': · ...... ....... -// :--:-::~ : :-:::.:-_- ::.. :. ================================= - ~ ..: - :.__-:..: :._:::: ........ ...... . ":::-:.' :"' :_. ::__:'-:::: '-::-R:__-:::--i:::! -- -- -':: :-:::': '- " ........ ':-':" '"" _ - . - .................. ; ................................... · 01 ......................... : .... il ....--l__./.'.... ........... ' - __. ' ' li0 2 5 10 20 50 100 GAS FLOW 'RATE MMCF/D Well: Pool: Survey Date: Y/Z/gO 1 O. x -- ;3~ . _2,¥ o ;~iO. 2 1. o 2 lO 2o GAS FLOW RATE MMCF/D 5O 100 GAS WELL OPEN FLOW POTENTIAL TEST REPORT PRESSURE CALCULAT I OHS (Supplement to Alaska'O & GCC Form No. G-I) Field, R~servot. r Tesl Date Kenai Gas. Field ..... Upper Tvon.ek . Ol~erator Lease - '~','61 F' ~. ,U,nion Oil ...Company ,,. A-028142 41-7L. Test ( I ) (2 ) "('3) (4 ) Ps pf (ps2_ pt2) 0 No. ~sia .bsi~ X 104 F. CF/D " -'; , , , ,, ; "-- ' I ' · '" , ,'~ ~, 2542 1652 373.27 2510 , ............ 2585 ...... 1538 ......4.3].68,, . 27¢7 2590 1416 470.30 2907 ..... .2595 978 57.5.1 6 , 3461 ,,, ......... .Sub-Surface Test Data Subsurface pressu-¢es measured. Subsurface pressures computed. Cullender-Smith ~.",ethod of IOCC. (I') ' (2 i (3') .... ('4') Test Pws 0 ( Pws 2-Pw ~2 ) Q No. psia psia ' X I0-4 f, ICF/O , , -, ,, , ' .' ' " , .... ~ ~' · · , ' ' . · · . .............. . Nomenclature: Ps = Static surface pressure ~t~f~.= Flowing surface pressure Pws ='Static bottom-hole pressure. (mid-point of perforations) Pwf = Flowing bottom-hole pressure (mid-point of perforations) Q = Flow rate, MCF per day at 60~F and 14.65 psia 1-70 .. . · Form No. G-1 REV t0-69 STATE OF ALASKA SUBMIT IN DUPLICATE OIL AND GAS CONSERVATION COMMITTEE GAS WELL OPEN FLOW POTENTIAL TEST REPORT MulL~-POINT TEST Test Initial ~] Annual ["'] Special Field Kenai Gas .Fi eld Ol)er;ttor Onion 0il Company Reservoir Test Date UDDer Tvnnpk I 7/3 A-028142 141 -TL County {Location 185' S & 4303' enai T4 , R11W, S.M. 72O] ff 1-7230 'Producing' Thru Resen'otr t Wellhead { CSG. Size Te r ute Te~p~ratur~ T~.F wu oF 5 1/2 E. of NW Corner of Sec.~,c0mpletl°nmte { TotalDepth / 1/30/80I 7240 2O 4. 778 724O TBG. Size I ~,Vt/Ft.[ O.D. I.D. { Set ~ { flasGra,tt, {Avg. Pr0d. [ GL Gas-LiquidHydrocarbon Graritvof Liquid 2 7/8 6.40 2.875 2.441 6930 's?o~Z' ~tJ~d"' 3846 """°"'c~"ebm' Pipeline Connection I Type Taps ~,Ni'~k~i s k i . { F1 ange 3Iultlple Completion (Dual or Triple) { Type production front each zone Dual { Gas OBSERVED DA.TA Flow Data Time (Prover) (Choke) Press. Diff. Tubing Casing Flowing No. of Flow (Line) (Orifice) h Press. Press. Temp. Hours Size Size psig w pslg psig *F is: ] 3.438.. ],50.. i5 2] ..1637.. packer 66 :.. . ] .3. 438 1.50i 19.36 .. 1523 Packe...r. 66... '" 1 i3.438 1.50 '" t 24.01 1401 .... Packer , ,66, ~:. ' ' "l'1!3'438 '1.50 I 50.41 ' '.. 963 Packer .66 FLOIA' CALCULATIONS Coefft--- . . . Flow Temp. Gravity Compress. 1~10. clent ~--~/h p Pressure Factor Factor Factor Rate of Flow (24 }tr.)Vw m psfa F F F q I%ICF/D t g pv ,. 11.255' 't158~'5~ '1652 ' .9943 .... 1" 32123 .1'.052~2 ' 2510 ~. 11.255 1172.56 153~3 .9943 " 1.3423 1.0521" ' 2727 9: 'Il .225 tl .84,39 1416 .9943 t.3423 1.0495 2907 4., 11.~25 .... 12.22.:0_.4'" ..97.8 '§943 1.3423 1.0377 ~461.. PRESSURE CALCULATIONS P P w Cal. w 'r~_ (psla) P~:t Pc Q (F cQ); (Fc Q)'" X 1-e-s p-"w P~e -- paw ' p W P t c 1. 2. 4. , ...... :.____~.~ ......... ' '. ' i, ,. Absolute Potential { n 'a745 .~CF/D,.,} .87~" l CERTIFICATE: I, the undersigned, state that I am th, Engineer of me Union 0il Company (company), and ~at I am author~ed by said comply to make this report; and that ~ls report was pre- pared ~der my supervision and direction and that the facts stated there~ are true, correct ~d complete to ~e best of my ~owledge. St~ature Steve A. kambert KENAI GAS FIELD Back Press -'-e Tests Well: 4] -, ,. Pool: Upper lyonek Survey Date: 7/3/80 10 - L-2Z2_.%" L _.7: ._L-ZT£Z; Z: LZ 7;'_._ %Z ---LL/X...Li. -.'L_~Z.'-~---~Z*_i;T ;TZ_L;r'.7£'--_ ............ ,_C~Z~._-Z/T~__-"ZL__--ZT_;Z-..---ZL:~.%---~7 ...... L27Z_--2-%ZS;-2_-.ZZTZL:;.~--ZZ-7-ZL27! LY'~TZ2Z'-Z=z"--'.2LTL-Z-~-?ZtZZZ%ZZ-ZL--ZZ-- - _ ;_--CZ:- '-Z-: '_-_ZZ-7_. Z - L_ - Z.: 7;'"._; i_:i.; ......... £ ./Z-.--_'~_-_:L~-_;'ZZL:'; ._;-.; Z':=;:-"-'] ........ 7:;~ZT~ZZ'L-;'_%7_-:TLAL2_~_Z~----_~-_T_-- ZZLZ2L."ZZL;'X2--277_2i2:;7:L2'i'-C'---Z-.'iZ.7 ..; X'_- 7i;'".".:.'-';Z.'22L'T2 ........ -.L'- _ . {¢, 1.0 2 5 10 20 50 100 GAS FLOW RATE MMCF/D SUBMIT IN D.JPLICATE* STATE OF ALASKA (Se~othertn- st ructions on reverse side) Oil. &ND GAS CONSERVATION COMMITTEE i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* TYPE OF WELL: ,V~:LL WELL [] l>aV [~ Other b. TYPE OF COMPLETION: W ELL OVER EN BACK P~ESVR. Other __ 9. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR P.O. BOX 6247, ANCHORAGE, ALASKA 99502 ,~. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* ,at,urface 185'S & 4303'E of the N.W, car., Sec. 7, T4N, RllW, SM At top prod. lnter,~l'reVortea he~ow 186'S & 4268'E of the N.W. Car. , Sec. T4N, RllW, S.M. At total depth 179'S & 4268'E of .the N.W. Car., Sec. 7, T4N, RllW, S.M. 5. API NUIV,._FRtICAL CODE 50-133-20327 e. L~-tSE DESlGNX~IO'~' A_ND A-028142 ~ 7. IF INDIA. N, ,A-L~O'I"f'EE OR TRIBE NA.~ 8. UNIT FA3'{.M OR LEASE NAME ;~ Kenai Beluga Unit 9. WELL NO. KBU 41-7 10. FLELfD A_ND POOL, OR WILDCAT Kenai Gas Field 11. SEC., T., R., M., (BO~I~OM HoLE OBJECTIVE) Sec. 7, T4N, RllW, S.M. 12. PEHAVIIT NO. 79-29 13. D.A. TE SPUDDED 14. DAT~i T.D. R.F_.ACHF. iD 15. DATE COM. P SUSP OR ABAND. 16.' 11/22/79 12/11/79 1/20/80 101'KB above MSL INTERYALS DRILLEDBY 729077q0, Mw~.rD.D [/ [~ 2 aO~AS~ ~oors ' '[ c^s~. TooLs ~.. P~.6DUCI~ INTERVAL(S), OF THIS COMPLETION--TOP, BOTTOM, NAME (MD AND TV'D)* 23. WAS D!RECTIONAJ-, SURVEY MADE Beluga 5330' M.D. ;- 6139' M.D. 5330' TVD - 6139' TVD i NO 24. TYPE EI-~CTRIC AND OTI-I~tt Leos I~uN DIL-SP-GR, BHC-SONIC, CNL-FDC-GR-CAL ~5. CASING RECORD (Report aH strings set in well) CASLNG SIZE WEIGHT, LB/FT. DEPTH SET (NLD) HOLE SIZE 20" )4# 134' - 13 3 2425 ' 9 5/8" 47# 7025' C~hiLNTING RECOIID Driven to Refusal 692 Sx 1800 Sx ANIOUNT PULLED 26. LINER i:LEC O 1R.D SIZI] '[ TOP(MD) [ BOTTOM (MD) [ SACKS CE2~ENT' [ 5½" [ 6920' } 7240' [ Gravel '- [ t [Packed ~8. pEP. FORATION$ OP~-~1 TO PI~ODUC-'TIOBI (interval, size and number) SEE ATTACHED $CT~EEN (MD) SIZE Dhgm SBT (MD) ~ PACKER SET (MD) 7200~ 5297' >249~ 7260' ACID, SHOT, FX~CI URE, C~E.NT SQUEEZE, ETC. See Attache 30. PP. ODUCTION 8 [~' .. DATE FIRST P~ODUCTION [ P~ODUCT1ON ME1HOD (Flowh*g, gas lif~, pumping--size and type of pump) ~'~t'}Op~' - :~[[ViELL~,~h%.i~)/.STATUS (Producing or 2 / 5 / 8 0 } Flowing .... '.'~req~ ."'""~s,,;~o d. [HO~'Eg~ '[~tOKE SiZE ]PROD'N FO~ oI~BDL. GA~ZCF. WA'I~R--BBL. [ O~S--~iL I~.%TIO I" 1- t ! i :,000" i 1000 PSI - > - 15~000 I - - , ..... . 31. DISPOSITION OF GAS (80ld, used lop eI, vented, etc.) [TEST WITNESSED BY SOLD 3.0. LIST OF ATTACHMENTS 33. I hereb~r certify that the foregoing and attached information is complete and correct as determined from all-available records Dist. DELE. Supt. PATE 2/20/80 SIGNED TITLE Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct ,,,,,,,eli completion report and log on all types of lanJs and leases in Alaska. Item: 16: indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in c, Ther spaces on this form and in ar~y Items 20, and 22:: If This well is completed for separate prcduction from more than one interval zone (multiple completion), so state ~n item 20, and in item 22 show the top(s), bottom(s) and name (s) (if any) for only the interv,~l reported i~ ~len~ ~0 S,,~t',mit ,~ scl.:...'~rate report (page) on this form, adequately identified, for each actditior~ol i,Te~val To be seperately produce:l, show- ing the ackiitional data pertinent to such intervc~l. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately producsd. (See instruction for items 20 and 22 above). WA'I'I:3! AND MUD , , u, ,, ,,, ,, ,,, SEE ATTACEED T/s~eriing 359~' 359~ ' gas sands T/Beluga FH 4680~ 4680' T/Tyoaek FH 720~' 720~' AND I)ETECTEI)'SII(')WS O~ OIb, GAS O1~ _ , ............. ,,, , , , , , , , , , , ,, ,,, ~,, ,, ,, ~ ,, uga 7~31' 7~5~' Dk. gray s~l~y-clayey sandstone ~/~n~er- e ~ laminated carbonaceous debris ~ m~nor coal. nek 7234~ 7254' L~.-Hed. gray s~l~y sandstone, laminated e ~2 carbonaceous silty mudstone & massive mudstone and minor coal. ,- ~elu ]ore ]ore F,)rm P--? SUBMIT IN DJFLICATE' STATE OF ALASKA ', Se~ other in- st ructions on reverse side) OILAND GAS CONSERVATION COMMITTEE i ! ii WELL COMPLETION OR RECOMPLETION REPORT AND LOG* WELL WELL DRY Other b. TYPE OF COMPLETION: WELL 2. N&ME OF OPERATOR UNION 0IL CO. OF CALIFORNIA, 3. ADDRESS OF OPERATOR P.O. BOx 6247, ANCHORAGE, AK. 99502 LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface At top prod. Interval reported below 179'S & 4268'E of the N.W. Cot., T4N, RllW, S.M. At total depth , ~.PRODUCING INTERVAL(S), OFT HI$ COMPLETIOn--TOP, BOTTOM, NAME (MI) ANDTVD)* Tyonek 7201' ~'~D.- ~7233' M.D. 7201' ~V,D - '7233' TVD 5. API NLFMF_A~CAL CODE 50-133-20327 6. LEASE DESIGNATION AND SER/AL NO. A-028142 7.IF INDIA2/, AJ-J.~TTEEOR TRIBE '8.UNIT,FARM OR LEASE NAME Kenai Beluga Unit 9. WELL NO. KBU 41-7 ;10. FIELD AND POOL, OR WILDCAT i Kenai Gas Field ~n.SEC., ~'., R., M., mOTTOM ~o~.~. · 7i om~,crzvr~ Sec Sec. 7, T4N, RllW, S.M. 12. PEqRgViIT 1~O. 79-29 · [ / I-IOW1V~Y* ROTARY TOOLS [ CABLE TOOLS 23. %VAS DIRECTIONAL , SURVEY MADE i 24. TYPE ELECTRIC A~ND OTHEI:~ LOGS RUN CASLNG SIZE ~VEIGHT, CASING RECORD (Report all strings set in well) DEPTH SET. (M_D) HOLE SIZE 26. LINEit RECOll. D 28. PERFORATIONS OPF_ZN TO PRODUCTIOI~ (Interval, size and number) ; CEa%IY~.NTING RECOi:~D ] AMOUNT PULLED I 27. TUBING RECOPJ) [ S~ (MD) SIZE DE~ SET (MD) [ PACI~ER SET (MD) 2 7/8" 6930' 6920' ' 29. ACID, Si!OT, F~ACI'URE, C~E:NT SQUEEZe, ~C. D~I I~V~ (MD) I AMOUN r 2e~I~ ~ ~TEP~ US~ 77r 2 0 30. PRODUCTION !:~S~ ~.Q{ & ,. . DATE CIEST PRODUCTION [ FRODUCTION ME1HOD (Fiowh3g, gas li,~, pumping-size and type of pump) ~¥i~L STATUS. ~Prg~ucing or 2/7/80 [ Flowing '~': · ~a~2/~]80 ]°r ~s~.~la°~s TZSr~ 24 ' IO~OXZ[i SXZZ ]l~'r I~°~'N ~-v~°~ ~o~ ~ o~. "~[A~mn' 1 4fi0 [ W~~U._ 1[ ~as-om _ ~.xTio ~O¥'; ~BiNG ' , CASLNG r~S~ ICAL~~ OI~BBL ~r,, 470 ]w ~Bnn. l ~_E~ I . 12~.-HOUR ~ I ' ~ OIL GRAVITY-~I (CO~.) I :l'-I - --" 31. DISPOSITION OF OAS (Sold, used for fuel, yen e~,, e:le.) ]TEST WITNESSED B~ Sold t 32. LI~T OF ATTACHMENTS 33. I hereby certify that the foregoing and attached i~f~}.rmatlon Is complete and correct as determined from all-available records /~ Dist. Drlg. Supt. *(See Instructions and Spaces ~o~ Addi*iona~ D~ta on Reverse Side) 2/20/80 INSTRUCTIONS .. General: This form is designed for submitting a complete ar'~d correct ,,,,,,ell completion report end log or'~ all types of lanJs and leases in Alaska. item: 16: Indicate which elevation is used as reference (whe, e r~ot o~herwise shown) for depth me,'~sure- merits given in ether spaces on this form and in any att,'~ch:T~ents Items 20, and 22:: If this well is completed for separate, l')rc.d~ctior~ from more th,'~n or-~e ir~terval zone (multiple completion), so state ~n item 20, and ir'~ ite,~ 22 .~how the top(s), bottom(s) and name (s) (if any) for only the interv,~l ret)orled ir~ ite~ 30 ,Submit a separate report (paoe) on this form, adequately identified, for each additio~'~l i~terval to be seperately produce:'l, show- ing the ackJitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). :34. SUMMAItY ()~,' F't)~I. MATIO'/'~ T]:~S'Ii.% INC'LUI~IN(; INTS]ItVAL TFlX'rED ~,~E~%"iJ'I'~E I}A~'& ~ ~COV~]I~IF~ ()~' OIL GAS. 35 G~GIC MA~K~q WAT~I AND MUD NAM~ 26. ('OI,~E DA~'A. A~'FACII BRIEF D~R~PI~O~S OF LITIIOLOGY. PO.RO%ITY. FIIAC~RFS. APP~NT DIPS ~ND 'DE'I~EC'I'EI) SIIOWS O~' OlD. G~S Oft XVAq'~I. II II I I, I , , , II, , ,,,I, , ,, , ,, ,, l.l,,, ,,,,, , ,, ,, , .. . ................. . .... , .., ., , , ........ DST # iA & lB 2 3A & 3B ZONE Upper Tyonek Lower Beluga Middle Beluga Middle Beluga Middle Beluga KBU 41-7 TESTING SUMMARY INTERVAL FLOW TIME 7200' - 7240' 116 Hrs. 6494' - 6504' 33 Hrs. 6668' - 6680' 6128' - 6138' 37 Hrs. 5761' - 5775' ) 5641' - 5655' ) 25 Hrs. 5905' - 5909' ) -- sqz. w/450 sx. 5334' - 5353' 19 Hrs. RESULTS 4.42 MMCF/D @ 300 psi 3.81 MMCF/D @ 550 psi 1.28 b~CF/D @ 110 psi 11.63 MMCF/D @ 1080. ps 10.48 MMCF/D @ 1140 ps GEAsE_Kenai ~luRa Unit j'ICLD Kenai Gas Field U i',! ] 0 N ~I_ CO. 0;' C,'-:,_.li":O'-'~'~' :A ¥¥ELL '~ PAGE NO. ,-,ZCORD WELLNO._ 41-~ SPUD DATE_ 11/22/79 _COMP. DATE~~ CONTRACTOR Bri~~~g RIG NO. i~OCAilOiX~ ..... 185'S & 4303'E of the N.W. cor. Sec. TYPE UNiT___Oil '7, T4N, RllW, S M. D~!!..L PiPE D~o,_,'~I~ ~ # ' ELEVATIONS: WATER DEI~'iI R.T. 'FO OCEAN FLOOR_ oo~ ~.~r,, 79-29 . g-028142 101' T.D.----7.2 9 0 ' T.V.D ..... . ,~ ~ . ' R.T. TO DK[I,L DE CASING & TUBING P~ECORD SIZE [ V/EIG}fT THREAD _2DJ' [. 94# ~lain E~d _9 5/8" ,.h47# GRADE H-40 , N-80 N-80 ' DEPTH 13.4' 2425' 7025' RE~4ARi<S Driven to refusal w./268 BPF Cmt'd_thru shoe w/442 sx, C1 '___J'G" w12½% pre-__hyd. __gal & 2% CaC%_2_fol!owed by 250 sx. C1 "G" w/2% Cmt'd thru_~hoe w/l'8Jl0 sx, C.1 "G" w/.5% CFR-2,__ · 3% ]ta~d_2~, and,3% KCL. ~ Gravel-packed in ±~' open no±e w/65 sx:-of 20=40 PERFORATING RECORD i2/28/7fl i2/29/8q 1/02/80~ i/o4/so/ i/os/so i/n/so !I{J%E~Z~ 6494' - 6504 6668' - 6--~ 6128' - 6i32 6762' II II DST#iA DST#lB Lower Beluga Open Lower Beluga Open 6209 ' WSO Middle Beluga Open " " DST #2 Middle Beluga Open II II Il -II II II 59417 !1 II !! II II Csg. Leak 5905' - 5909' 1/15/80 5761' - 5765' 1/15/80 5651' - 5655' 1/15/80 5765' - 5775~ 1/15/80 5641' - 5651" 1/17/80 5334' - 5338' 1/18/80 5338' - 5353' Reperforate Sqz'd w/450 sx. cmt. Perfs still Open WS0 Middle Beluga Open Open WSO DST~3A !! I1 5423' DsT#3B Middle Beluga Middle Beluga Open Middle Beluga Open Middle Beluga Open WSO " " DST#4 Middle Beluga Open INITIAL PZODUCT_IO__N ; .. W E L L_ ~LExlJO_A_S~JEPl~ TYPE:. 0 CASING HEAD:O'C'IT' 13 5/8" SOW Xll3 5/8" 5M Casing Head 'CASING HANGER: 9 5/8" slips CA~ING SPOOL: TUBING HEAD:= O.C.T. 13 5/8" 5M x 10, 5M Spool. ' Dual 3½" hanger TUBING HANGER:. TUBING tREAD TOP' Dual 3½", 10" 5000# tree ~'?ASTER VALVES: . MAS 'FR~.~E TOP CONN.: Sh'EET PAGE LEASE KENAI BELUGA UNIT UNIOrl OIL CCt £tVN OF CALIFOPC'IIA ' ELL i ECORD .. 41-7 I' LL 1'I0, FIELD KENAI GAS FIELD DATE A 11/18/7! B 11/19/7! C 11/20/7! D 11/21/7~ i .11/22/7c. 2 . 11/23/7c. 3 11/24/7c~ 4 11/25/7c~ 5 11/26/7c. 6 11/27/79 7 11/28/79 8 11/29/79 20" D. 134' 20" D. 134' 1584'/1584' 20" D. 134' 25141/930' 20" D. 134' 2514'/0' 20" D. 134' 2514'/0' 20" D. 134' 2514'/0' 20" D. 134' 2514'/0' 20" D. 134' 2585'/71' 20" D. 134' 13 3/8" C. 2 4200'/1615' 20" D. 134' 13 3/8" C. 2 25' ~25' DETAILS OF OPEPATIONS, DESCR!PTIOIIS g RESULTS Commence operation 00:01 hrs. 11/18/79. Skid~rig f/ KTU #43-6X to KBU #41-7 location. Rigging up. Drove 20" to refusal w/268 BPF @ 134' while rigging up. Welded on 20" starting flange. Flange cracked by weld. Removed flange & install new flange. Installed & functior tested 20" hydril. Spud well @ 00:20 hrs. 11/22/79. Drilled 17½" hole to 1584' w/BHA #1 & bit #1. Drilled 17½" hole from 1584' to 2514'. Circ. clean. Pooh. RIH w/BHA #2 bit #1. Circ. high vis. sweep around. Pooh. Attempted to run 13 3/8" csg. - stopped @ 156'. Pooh w/ 13 3/8" csg. RIH w/bit #2 on BHA #3. Reamed hole f/134' to 250', f/1360' to 1380'. Reamed hole from 2333' to 2354'. Plugged bit. Pooh. Removed jets. RIH & reamed f/2354' to 2514'. Circ. high vis. pill around. Pooh. RIH w/13 3/8" csg. Csg. stopped @ 2425' .... RIH w/stab in tool. Mixed & pumped 900 sxs. & cmt. unit broke down. Circ. out cmt. w/rig pump. Tear out B.J. unit. Rig up HOWCO cmt unit Cemented 13 3/8" casing thru · ' shoe w/442 sxs. C1 "G" w/2½% pre-hydrated Gel & 2% CaC12 followed by 250 Sxs. C1 "G" w/2% CaC12. Pumped 120 bbls. water ahead. Started pumping tail in slurry when received lead water @ sUrface. C.I.P. @ 01:30, 11/27/79. Cut off 20" & 13 3/8". Installed O.C.T. 13 5/8"5000 psi x 13 3/8" S.O.W. csg. head. Attempt to run Gyro while nippling up BOPE - stopped @ 1700'. (NOTE: Had cmt. returns to surface). Installed and teSted.13 5/8" 5000 psi BOP stack. RIH w/8½" bit & tagged cmt. @ 2352'. C.O. cmt. f/2352' to F.C. @ 2411'. Pressure tested 13 3/8" csg. to 2500 psi. Drilled out F.C. & retested 13 3/8" csg. Drilled out shoe & C.O. 10' to 2435'. Pressured test csg. seat to 95 PCF equiv. C.O. cmt. f/2435' to 2514' & drilled 12¼" hole to 2585'. Dir. drilled 12¼" hole f/2585' to 286~'. Circ. clean. Pooh. Ran SDC Gyro Survey f/2820'~to surface. RIH w/bit #4 on BHA #5. Directionally drilled 12¼" hole f/2865' to 4200'. SRFFF D PAGE "' LEASE KENAI BELUGA UNIT UHIO~I OIL C~-~?/~,iY OF CALIFOP~.IIA · I~,IEI.L IICQID I'i~LL I"lO, 4~-~ FIELD KENAI GAS FIELD ~TE 9 11/30/ 5016'/816' 20" D. 134 13 3/8" C. 2425' DETA,_o OF QPEP~TIONS, DESCRIPTIOilS g RESULTS Drilled 12¼" hole f/4200' to 4520'. Circ. clean. Short trip. Pooh. Ran Schlum. RFT in sterling "B-5" sand° Set @ 4228 - 1582 psi @ 4240' - 1578 psi. RIH w/bit #5 on BHA #6. Drilled 12¼" hole f/4520' to 5016'. S Ff7 PAGE LE) SE KENAI BELUGA UNIT Ur'lIOrl OIL OF CALtFOPCiIA 41-7 WELL FIELD Kenai Gas Field ~TE 10 1.2/1/7 11 12/2/7 12 12/3/7' 13 12/4/7! 14 12/5/7! 15 12/6/7! 5840'/824T 20" D. 134 13 3/8" C. 6289'/449' 20" D. 134 13 3/8" C. 7010'/721' 20" D. 134 13 3/8" c. 7025 '/15 ' 20" D. 134 13 3/8" C. 7025'/0' 13 3/8" C. 9 5/8" C~ 7025'/0' 13 3/8" c. 9 5/8" C. DETAILS OF OPEPATIONS, DESCRIPTIOilS g RESULTS 2425' 2425' 2425' 2425' 2425' 025' Drilled 12¼" hole f/5016' to 5042'. Drift @ 5042' - 3/4( Drilled 12¼" hole f/5042' to 5604'. Pooh. Drift @ 5604' _ ½o. RIH w/bit #6 on BHA #7. Drilled 12¼" hole f/5604 to 5840'. Drilled 12¼"'hole f/5840' to 6099'. Drift @ 6099' - 3/8°. Drilled 12¼" hole f/6099' to 6130'. Pooh. RIH w/bit #7 on BHA #8. Drilled 12¼" hole f/6130' to 6160' & lost 600 psi on pumps. Pooh. Found washout in 29th stand. Ran back to .btm. Drilled 12¼" hole f/6160' to 6289'. Drilled 12¼" hole f/6289' to 6492' & pumps broke down. Repaired pumps (1 hr. lost time). Drift @ 6592' - 1°. Drilled 12¼" hole f/6592' to 7010'. Drift @ 7010' - 7/8°. Made 10 std. short trip. Circ. & cond. for logS. Ran Dil-SP-BHC-SONIC-GR log f/7010' to 2425'. Ran FDC-CNL-GR f/7010' to 2425'. RIH w/RR bit #8 on BHA #9. Drilled 12¼" hole f/7010' to 7025'. Circ. & cond. mud & hole for 9 5/8" csg. Pooh. Ran 173 jts of 9 5/8" 47# N-80 butt csg. Circ. & cond. mud @ 100 FPM while reciprocating csg. Cemented 9 5/8" csg. w/1800 sxs. C1 "G" w/.5% CFR-2, .3% Halad 22-A & 3% KCL. While reciprocating csg. landed csg. when noted increase in hole drag (1200 CF of cmt. in annulus) w/shoe @ 7025' & F.C. @ 6980'. Bumped plug w/3000 psi C.I.P. @ 21:55 hrs. 2425' 7025' Removed BOPE. Cut off 9 5/8" csg. Installed OCT 13 5/8" 5000 psi x 10" 5000 psi tbg. head spool. Installed & tested BOPE. 16 12/7/7~. 17 12/8/7~. 18 12/9/7 19 12/10/ 20 12/11/7 7030'/5' ~ 13 3/8" C. 2425' 9 5/8" C. ]025' 7129'/99' 13 3/8" C. 2425' 9'5/8" C. 7 125' 7129'/0' 13 3/8" C. 9 5/8" C. 7 9 7151'/22' 13 3/8" C. 9 5/8" C. 7 2425' 025 ' 2425' 025' 7254'/103' 13 3/8" C. :~425' 9 5/8" C. 7t25' / RIH w/bit #9 on BHA #10. Tag F.C. @ 6978' DPM. Pressure test 9 5/8" to 3500 psi. .Drilled out F.C., Shoe & 5' of new hole. Tested 9 5/8" shoe to .65 psi/ft. Pooh. Ran Gyro survey & CBL fog. RIH w/BHA #11 & bit #10. Dir. drill 8~" hole f/7035' to 7129' (Tyonek core pt). Pooh. RIH w/rubber sleeve core bbl. Well started flowing on trip in @ 4980' (SICP 180 psi, SIDP 100 psi, 28 bbls). Circ. holding back pressure & increasing MW to 78 PCF. Pulled 3 stds & wait 1 hr. Run back to btm & circ. btms up. - No gas. ~ RIH w/rubber sleeve core bbl. Cored f/7131' to 7151'. Rec. 14.83' of core. (Correlation Questionable). RIH w/Bit #12 on BHA #13. Reamed cored interval. Drilled f/7151'. Had drilling break + 7214'.. Pooh. RIH w/rubber sleeve core bbl. Cored f/7234' to 7254'. SHELl' D P^ E LF SE KENAI BELUGA UNIT UNIO I OIL OF CALIFOPCIIA ',ELL ICORD ElD KENAI GAS FIELD DATE 21 12/12 79 7290'/36' 13 3/8" C. 9 5/8" C. 22 12/13 79 7290' TD 13 3/8" C. 9 5/8" C. 23 12/14/79 7290' TD 13 3/8" C. 9 5/8" C. 24 12/15/ 9 7290' TD 13 3/8" C. 9 5/8" C. 25 12/16/ '9 7290' TD 13 3/8" c. 9 5/8" C. 26 12/I7/79 7290' TD 13 3/8" c. 9 5/8" C. 27 ' '1.2/18/ 9 7290' TD 13 3/8" c. 9 5/8" c. - 5N" H 6920" 28 '1.2/19/ 9 7290' TD 13 3/8" C. 9 5/8" C. 29 ].2/20/' 9 7290' TD 13 3/8" C. 9 5/8" C. 2425' 025 ' 2425' 7025' 2425' 7025' 2425' 7025' 2425' 7025' 2425' 7025' 2425' 025' - 7240' 2425, 025 ' 2425' 025' DETAILS OF OPEP&TIONS, DESCRIPTIOHS g RESULTS Finish laying down core barrel. RIH w/bit ~15. Reamed cored interval f/7234' - 7254'. Drilled f/7254' to 7290'. Circ. & Pooh. Rigged up Schlumberger and ran DIL/GR, BHC-Sonic/GR/CAL., & CNL/FDC/GR/CAL logs f/7022' to 7281'. ' Finish running CNL/FDC/GR. RIH & shot 24 SWS f/7200' tc 7233' - recovered'20 SWS. Rigged down Schlumberger. w/Servco 15" underreamer - broke circulation @ 3000' & 5000~.Circ. @ shoe of 9 5/8" csg. Clean mud tanks. Finished cleaning mud tanks & changing over to polymer - CaC12 fluid w/underreamer @ 6970'. Finished cleaning mud tanks & changing over to polymer - CaC12 fluid w/underreamer @ 6970'. RIH to 7190' & attempted to underream to 15" hole size f/7190' to 7268'. Pulled into 9 5/8" csg. & circ. clean Pooh. Ran Schlumberger 4 arm caliper log f/7260' to .7000'. It showed that no hole was opened. RIH w/ underreamer. Underreamed f/7190' - 7211' - discovered error in pipe tally. Pooh. (Found ~c~ual depth under- reamed f/7097' to 7118'). Redressed underreamer & strapped in hole. Underreamed 8½" hole to 15" f/7190' to 7250' DPM. Circ. & Pooh. RIH w/Schlumberger 4 arm caliper & log f/7250' to 7000'. Log showed hole opened to 15" f/7094' to '7114' WLM & f/7186' to 7246' WLM. Rigged up to run 5½" liner. Ran 5 1/2" liner on 9 5/8" x 6" bore Baker Model "F-i" packer and hung @ 7240', top @ 6920'. Set pkr @ 6920' and POOH w/ D.P. RIH w/ seal assembly and stabbed into pkr @ 6920'. Tested pkr to 2000 psi- ok. POOH. RIH w/ Lynes gravel packing tool on 5" D.P. w/ 40' of 2 3/8" tubing tail. Set and tried to test Lynes external packers @ 7154' and 7163'. Pkrs. would not test. Located and closed port collar'@ 7150' 'andotested to 1000 psi - ok. Located port collar @ 7189'. Gravel pack the Tyonek sand through a port collar @ 7189' w/ 20-40 sand. A total of 65 sx. of sanR was used (105% of theoretical) with a packing concentration of 1/4 to 1/2 ppg and a final pressure of 1800 psi. The fluid used was 1PPB Hec, 2 PPB Dextrid, 145 PPB CaC1 and 1/2% L--5~ (Clay Acid). Reversed out and pulled up to 6900'. Circ. and condo mud. Mud is gas cut to 75 pcf on bottoms up. POOH. RIH w/ open-ended drill pipe to 7220' and circ. POOH laying down 5"drill. pipe. Install 3 1/2" rams in BOPEo Pick up and RIH w/ 69 jts of 2 7/8" buttress tubing, 9 5/8" HOWCO RTTS pkr w/ stimulation valve and RIH on 3 1/2,' D.P. Packer set @ 2740'. Could not release pkr. - POOH. RIH w/ new test tools.- with a 500' water cushion. SRFF7 D P^ E !.,:o, LEASE KENAI BELUGA UNIT OIL CCt?ANY OF CALIFORHIA I:,ELL i',ECQ · · 41-7 FIELD KENAI GAS FIELD ~TE 30 31 32 33 34 35 36 37 38 12/21/' 12/22/ 1.2/23/ 12/24/ 12/25/ 12/26/ 1.2/27/ 1.2/28/ 1,2/29/ '9 7290 ' TD 13 3/8" C. 9 5/8" C. '9 7290'-TD 13 3/8" C. 9 5/8" C. 9 7290' TD 13 3/8" C. 9 5/8" C. 9 7290 ' TD 13 3/8" C. 9 5/8" C. 9 7290' TD. 13 3/8" C. 9 5/8" C. 9 7290 ' TD 13 3/8" C. 9 5/8" C. 9 7290 ' TD 13 3/8" C. 9 5/8" C. 9 7290 ' TD !3 3/8" C. 9 5/8" C. 9 7290 ' TD 13 3/8" C. 9 5/8" C. 2425' '025' 2425' 025' 2425' 025' 2425' 025' 2425' 025' 2425' 025' 2425' 025' 2425' 025' 2425' 025' DETAILS OF OPEPATiONS, DESCRIPTIO[IS g RESULTS Complete RIH w/ test tools on 3 1/2" D.P. Set RTTS PKR @ 6888', 2 7/8" tbg. tail @ 7200'. Rigged up and tested HOWCO test head and surface lines to 3500 psi w/ diesel. Precharged drill pipe to 1250 psi w/ field gas. Opened stimulation valve @ 9:45 A.M. 12/21/79. Pressure increased to 1330 psi. Opened well to flare @ 10:00 A.M. on 1/4" choke. Pressure fell to 0 psi in 20 minutes. Pressure gradually increased. Opened to 3/4" choke @ 12:'40 P.M. Had fluid to surface @1:30 P.M. Well making 1.7 MMCF/D rate w/ 1 BPH water and some sand @9:30 P.M. Opened well to 1/2" and 3/4" choke and well began to make 3.1 MMCF/D w/ 970 psi surface pressure. Continued testing Tyonek Zone with the flowrate gradually increasing, the water rate decreasing to 0, and the sand rate down to a trace. Continued testing Tyonek Zone. Continued testing Tyonek Zone. Completed testing on Tyonek Zone. Had final rate of 4.42 MMCF/D with 300 psi on drill pipe. The well was making no water and trace of sand. Shut well in. Opened bypass to dump fluid across perfs. Bled off drill pipe pressure and filled drill pipe w/ Cacl2 fluid. Bullheaded 10 Bbls of CaC1 fluid across perfs. Closed bypass. Released RTTS and circ. around tbg. tail @ 7200' to kill well. Pumped pill and POOH w/ test tools. RIH w/ RBP and set @ 6799' DPM. Spotted 15 sx sand on top of RBP. Waited 1 hr. to tag sand @ 6793'. Re-tag top of sand @ 6777'. POOH. Rigged up Go Int. and ran CBL-Signature-Neutron-GR log f/ 6735' to 5900'. Log would not correlate and had CBL tool failure. Ran Signature-Neutron-GR log f/ 6735' to 3400' for correlation. Ran bit and csg. scraper to tag top of sand @ 6762'. Circ. and POOH. Pnm'J w/ bit and csg. scraper RIH w/ RTTS and stimulation valve and set'RTTS @ 6413' tail @ 6450' Precharge D.P. to 1300 psi and Open stimulation valve. RIH w/ 2 1/8" perf gun and perforate lower Beluga f/ 6494' to 6504' DIL for DST #lA. POOH w/ perf gun. Open well to flare. Well initially made:250 MCF/D rate w/ no fluid. Continued testing well until had a rate of 1.9 MMCF/D w/ 500 psi back pressure and no water. RIH w/ 2 1/8" guns and perforate f/ 6668' to 6680' DIL for DST #lB. Opened well to test. PAGE LDSE UNIOrl OIL CALIFORNIA KENAI BELUGA UNIT l';~LL [I0, 41-7 FIELD KENAI GAS FIELD DATE 39 i2/30/ 40 12/31/ 41 01/01/ 42 01/02/ 43 113/80 44 1./4/89 45. 1/5/80 46 1/6/80 9 7290' TD 13 3/8" C. 9 5/8" C. 9 7290 ' TD 13 3/8" C. 9 5/8" C. ;0 7290 ' TD 13 3/8" C. 9 5/8" C. ;0 7290 ' TD 13 3/8" C. 9 5/8" C. 7290 ' TD 13 3/8" C. 9 5/8" C. 7290 ' TD 13 3/8" C. 9 5/8 C. 7 7290' TD 13 3/8" C. 9 5/8" C. 7290 ' TD 13 3/8" C. 9 5/8" C. 2425' 025' 2425' 025' 2425' '025 ' 2425' '025' 2425' O25 2425' 25' 2425' 025' 2425' 025' DETAILS OF OPEPAT!ONS, DESCRIPTIO~IS & RESULTS Well made 3.86 MMC~/D @ 500 psi w/ no fluid. RIH w/ HP pressure recorder to 6500' and shut well in for 8 1/2 hrs. HP showed BHP = 2915 psi. Opened well to flare and made 3.81 MMCF/D @ 550 psi w/ no fluid. CWI. Opened bypass and killed well w/ 15 Bbls of fluid bullheaded across perfs. Circ and dropped mud wt. to 74 pcf. POOH and lay down test tools. RIH w/ 9 5/8" RBP and set @6230'. Spotted 16 sx. 20-40 sand on top of RBP and wait 2 hrs. Tagged sand @ 6209'. POOH. Installed 3 1/2" rams in lowest preventer and tested BOPE. RIH w/ test tools and set RTTS @ 6040', tail @ 6077'. Precharged drill pipe w/ 1320 psi field gas. Opened stimulation valve. Rigged up Go Int. to perforate w/ 2 1/8" bi-wire guns f/ 6128' to 6132' DIL. Opened well to test and received 35 Bbls of CaC12 fluid and some 20-40 sand. Killed well. RIH w/ tools to tag RBP @ 6230' - no sand on top. Pressured up drill pipe to 1300 psi and reset RTTS @ 6183' tail @ 6220'. Opened well to test RBP and received 1~ Bbls CaC12 fluid and then dry gas. RBP is leaking. Killed well and POOH.wi test tools. RIH and latched onto RBP @ 6230' - unable to work RBP down hole. - Finally work RBP down to 6485'. Circ thru choke. Getting gas cut mud. Complete circ. btms. up. Pick up on RBP and bullhead 15 bbls. CaC12 fluid down annulus to kill well. Pooh 10 stds. Circ. btms. up - no gas. Pooh w/RBP. RIH w/ OEDP to 6753' and circ. Pooh. RIH w/ 9 5/8" Baker RBP on Howco RTTS and set @ 6230'. Pressured up D.P. to 1300 psi w/field gas. Set RTTS @ 6200' and opened well to test RBP - no entry. Load up D.P. w/CaC12 fluid ~nd pressure tested RBP w/1500 psi - OK. Spotted 15 sx. of 20-40 sand on RBP. Tag Sand @ 6209'. Pooh. RIH w/test tools & set RTTS @ 6042', tail @ 6079'. Precharged D.P. to 1300 psi field gas and opened well to test WSO perfs, f/6128' to 6132' DIL. Had mediUm blow in bubble bucket. Perforate w/Go. Int. 2 1/8" bi-wire gun f/6128' to 6138' DIL to increase rate. Open well to test - still had medium blow in bubbl Reperforate DST #2 f/6128' to 6138' DIL w/Dresser - Atlas 2 1/16" link-jet guns. Opened well to test. Rate increased from small blow. Rate increased from small blow to 1.:21 MMCF/D and mane + 6.5 bbls. fluid. Rate was still increasing. Killed w--ell and Pooh w/test tools. RIH w/RBP retrieving tool and tagged sand @ 6205'. Wash to RBP @ 6230' and circ. SHEET D PAGE !'~0, LEASE KENAI BELUGA UNIT I';~LL 1..lO, 4~-~ FIELD KENAI GAS FIELD DATE 47 48 49 5O 1/7/30 1/8/8o 1/9/8o 1/lO/8O 7290 ' TD 13 3/8" C. 9 5/8" C. 7290 ' TD 13 3/8" C. 9 5/8" C. 7 7290 ' TD 13 3/8" C. 9 5/8" C. 7 7290' TD 13 3/8" C. ~ 9 5/8" C. 7 2425' '025' 425' '25' 1425' )25' 425' 25' DETAILS OF OPEP~TiONS, DESCRIPTIO~IS g RESULTS Retrieve RBP @ 6230' and reset @ 5914'. Positive test RBP to 2000 psi - OK. Spot 15 sx. sand on top - tagged sand @ 5899'. Retest to 2000 psi - OK. Pooh. RIH w/ Howco test tools and set RTTS @ 5551', tail @ 5588'. Rigged up and tested surface manifold and lines to 3000 psi. Precharged D.P. to 1250 psi. Opened stimulation valve. Rigged up and tested Dresser-Atlas lubricator to 5000 psi. RIH w/4' of 2 1/16" rigid jet perf. gun - had to pull out to change CCL. Had pressure increase to 1600 .psi in D.P. while running gun. Bled pressure back to 1250 psi - it increased back up to 1600 psi @ 25 psi per 5 minutes. Killed well. Released RTTS and RIH to reset RTTS @ 5859', tail @ 5896'. Closed rams and tested csg. above RTTS to 4000 psi and RBP below RTTS to 5000 psi - Held OK. Pooh w/test tools. Pooh w/test tools. RIH w/retrieving tool and tag sand @ 5899'. Wash down to RBP @ 5914' and latch onto RBP. Pooh. Dropped RBP @ 270' - parted retrieving neck. RIH w/overshot and bowl and retrieve RBP w/25,000# pull. (Note: Found pieces of perf. gun bi-wire and bottom bull plug). RIH w/bit and scraper and tag sand @ 6705' above RBP @ 6799'. P.u. one std. and circ. hole clean w/HEC sweep. Pooh. RIH w/Baker RBP and set @ 5900'. Set RTTS and tested RBP to 5000 psi - OK. Spotted 15 sx. sand.- tagged @ 5884'. Pooh RIH w/test tools and set RTTS @ 5551' tail @ 5588 Tested surface equip, to 3000 psi. Opened stimulation valve - had slight blow. Rigged up Dresser-Atlas. Drill pipe pressure built to 100 psi in 1 hour: Bled off D.P. Pressure built to 200 psi in 20 min. Bled off D.P. Pressure built to 800 psi while rigging down D.A. Killed well. RIH and tagged RBP @ 5918' (18' iow) with no sand. Circ. and Pooh. RIH w/retrieving tool. Latched onto Baker RBP @ 5920' and RIH to 6,510'. Circ. btms. up - no gas. Pooh. RIH w/Howco RBP and set @ 5980'. Tested RBP to 3000 psi - OK. Spotted 15 sx. sd. (sand bridged off while displacing and parted mud line in 4 places). Tagged sand @ 5941'. Pooh. RIH w/RTTS pkr. and stimulation value and set pkr. @ 5553', tail @ 5586'. Opened tool to bubble line. Pressure built to 20 psi in 1 hour. Opened to flare line. Well made rate of 600 MCF/D @ 80 psi with a fluid rate of 50 BPD CaCi~. SHEET PAGE LEASE KENAI BELUGA UNIT FIE KENAI GAS FIELD ~TE 51 52 53 54 55 1/11/~ 1/12/~ 0 1/13/~0 1/14/8 1/15/8 7290 ' TD 13 3/8"c 9 5/8" c. 7290 ' TD 13 3/8"c 9 5/8" C. 7290 ' TD 13 3/8"C 9 5/8" c. 7290 ' TD 13 3/8" C. 9 5/8" C.' 7290 ' TD 1.3 3/8" c. 9 5/8" C. DETAILS OF OPEP. ATiONS, DESCRIPTIOilS g RESULTS 2425' ?025' 2425' 7025' 2425' 7025' Well has rate of 830 MCF/D @ 120 psi and 2Z BPD CaC12 fluid. Rigged up Go. Int. and RIH w/Spinner - temper- ature survey. Logs showed wellbore entry @ 5907' (csg. collar). Pooh w/W.L. Killed well. Reset RTTS @ 5681' tail @ 5711'. Test annulus to 2000 psi. RIH w/4' of tornado link jet gun w/4 HPF and perforated f/5905' to 5909'. Pooh. Tested surface lines to 5000 psi. Broke down perfs. @ 2900 psi. Pumped in @ 10 CFM @ 2600 psi. Pumped 42 bbls. water ahead and squeezed w/300 sx. cl, "G" w/.3% Halad 22-A and 3% KC1. Displaced w/water. Had final pressure of 2600 psi @ 1.5 BPM. CIP @ 6:45PM 1/11/80. WOC for 3½ hrs. Released pkr. and Pooh. Test BOPE. RIH w/8½" bit and 9 5/8" csg. scraper. Cir~ and cond. CaC12 fluid. C.O. cmt. f/5809' to 5963' (firm cmt. to 5908' and stringers to 5963'). Pooh. RIH OE and spotted 7 sx. sand @ 5963'. Tagged @ 5941', Pooh. RIH w/HOWCO test tools. Set RTTS @ 5553', tail @ 5586'. Precharged D.P. to 1300 psi and open Stimu- lation valve. Bled cushion off of pipe. Pressure increased to 400 psi in 20 min. Well made up to 2.25 b~CF/D rate and then appeared to kill itself. Killed well. Reset RTTS @ 5645', tail 5676'. Test surface lin~s,.to 5000 psi. Broke perfs, down @ 5500 psi. Pumped in @ 2900 psi @ 10 CFM. Pumped 42 bbls. water ahead and squeezed w/150 sx. Cl. "G" w/.3% Halad 22-A and 3% KC1. Displaced w/52 bbls. water. Had final pressure of 4000 psi @ .25 BPM. CIP @ 12:45 PM 1/13/80. Held 2300 psi on squeeze for 3 hours. Pooh. RIH w/8½" bit and 9 5/8" csg. scraper to 5626' and circ. and cond. mud. 2425' '025' C.O. firm cmt. f/5794' to 5941'. Circ. and cond. CaC12 fluid. Pooh. RIH w/Howco~test tools and set RTTS @ 5551', tail @ 5588'. Test lines to 5000 psi. Precharge D.P. to 1250 psi. Opened stimulation valve and pressure increased to 1500 psi immediately. Opened well to flare thru ½" choke to blow down precharge pressure. Opened to ~" and 3/4" choke. Produced 25 bbls. of rat-hole fluid and well making 3.0 MMCF/D. Rigged up Go. Int. to run Spinner - t~mp. survey. RIH w/survey tool - could not get thru'test tools. Pooh w/survey. 2425' 025' RIH w/spinner - temp. survey w/o centralizer. Confirmed all entry thru perfs f/5905' to 5909' Dil. Pooh. RIH w/perf, gun and perf. upper 4' of DST #3A f/5761' to 5765' for WSO. Open well to test. Well made 7°52 MMCF/D @ 400 psi w/no water or sand.: Reran spinner ~ temp. log - showed 90% of entry from 5761' to 5765'. RIH w/perf, gun and perf. lower 4' of DST #3B f/5651' to 5655' for WSO. Open well to test. Well made 8.33 MMCF/D @ 650 psi w/no water or sand. RIH w/ perf. gun and perf. remainder of DST #3A f/5765' to 5775' and DST #3B f/5641' to 5651'. Open well to flare So clean up. Put well into system. LEASE KENAI BELUGA UNIT UNIO['I OIL CC - ?/V,IY OF CALIFOPC-IIA 1 ICO,L FIE KENAT CAn FTELD DATE 56 ]./16/8 57 1/17/ 58 :L/18/8 59 :L/19/8 60 :L/20/8 7290' TD 13 3/8" C. 9 5/8" C. 7290 ' TD 13 3/8" C 9 5/8" C. 2425' 025' 2425' 7025' 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' 5½" L.f/72~0' to 6920' . 2425' 7290' TD 13 3/8" C 9 5/8" C. Z025' ~0' to 76920' 5½" L. f/72 .DETAILS OF OPEP~TIONS, DESCRIPTIO~IS g RESULTS 7290 ' TD · 13 3/8" C. 2425' . 9 5/8" C. '025' ~ 5½" L.f/72~0' to 6920' Well stabilized flow from DST #3A and #3B @ 11.63 MMCF/D into the system w/no water and no sand. Shut in and killed well. RIH to 5915' and circ. clean. Pooh w/test tools. RIH w/RBP retrieving tool and tag sand @ 5953'. Mix high vis. pill and C.O. sand and debris to RBP @ 5980'. P.U. RBP and reset @ 5450'. RBP would not pressure test. Retrieve RBP and well started to flow. Circ. bottoms up - getting gas cut fluid. Attempt to RIH - RBP stopped @ 5515'. Bullhead 20 bbls. kill fluid below RBP. Circ. above RBP - well dead. Pooh w/RBP. Finish Pooh w/RBP. RIH w/Baker RBP and set @ 5450'. Test RBP to 4000 psi - OK. Spot 18 sx. sand on RBP. Tag sand @ 5423'. Pooh. RIH w/Howco test tools and set RTTS @ 5258', 2 7/8" tail @ 5295'. Test manifold and lines to 3000 psi. Precharge D.P. to 1250 psi field gas and open stimulation valve to test WSO - OK. Rigged up Go. Int. and test lubricator to 3000 psi. RIH w/4' perf. gun and perforate upper 4' of DST #4 f/5334' to 5338' Dil. Had pressure increase to 1780 psi. Pooh w/perf, gun. Open well to flare. Had fluid to surface in 9 minutes. Had rate of 6.23 MMCF/D @ 540 psi. Unloaded rat hole fluid. Put well into system Had rate of 8.56 MMCF/D @ 1100 psi w/no water and no sand. Rigged up Go. Int. to perf. remainder of DST #4. Opened surface valve but could not g~ in hole w/gun. Removed lubricator and found a cap had fallen off one of the charges and was alongside gun. Replaced charge and rigged up lubricator. Opened surface valve but still could not go in hole w/gun. Removed lubricator and added 1 sinker bar. Rigged up lubricator and still -could not get gun down the hole. While working gun in lubricator, parted W.L. below grease head. Gun fell down into safety valve - could not close valve. Closed master valve and removed lubricator and gun. Rehead Go. Int. W.L. and rigged up lubricator. RIH w/15' of 2 1/16" link jet perf. gun and perforate remainder of DST #4 f/5338' to 5353'. Pooh and rigged down Dresser-Atlas. Flowed well to clean up, then put into system. Well tested 10.48 MMCF/D @ 1140 psi w/no sand and no water. Killed well, Circ. and cond. CaC12 fluid-and Pooh'w/test tools. RIH w/Baker retrieving tools to tag sand @ 5413'. Could not wash thru sand. Pump viscous pill - still'could not wash sand. Pooh. Down 3½ hours to repair blocks. RIH w/bit and scraper and wash sand f/5413' to 5450'. Circ. and Pooh. RIH w/retrieving tool to RBP @ 5450' and circ. viscous pill. Retrieve RBP and Pooh. RIH w/bit a~d scraper to tag top of sand @ 6662'. Circ. and raise mud weight to 80 PCF. Pump viscous pill while"washing down f/6662' to 6799'. Pooh. RIH w/Howco retrieving tool and latch onto RBP @ 6799'. Release plug and wait 4 hours - had-no fluid loss or gain. Pooh - plug stopped @ 6459'. Could not go down or come up. Released from tool. PAGE LEASE KENAI BELUGA UNIT OIL CCFPS G OILIFOSIIA I,ELL 41-7 FIE KENAI GAS FIELD DATE 61 62 63 64 1/21/8, 1/22/8( 1/23/8c 1/24/8( 1/25/8 7290 ' TD 13 3/8" C. 9 5/8" C. 5½"L.f/724 7290' TD 13 3/8" C. 9 5/8" C. 5½" L.f/72 7290 ' TD 13 3/8" C. 9 5/8" C. 7 5½" L. f/72 7290 ' TD 13 3/8" C. 9 5/8" C. ~ 5½" L.f/72a 7290 ' TD 13 3/8" c. 9 5/8" C. 7 51~"L.f/7240 DETAILS OF OPEP~TiONS, DESCRIPTtC~iS g RESULTS 2425' '025' ' to 6920' RIH w/HOWCO retrieving tool on bumper sub and oil jars. Found pipe meas. error. Tagged RBP @ 6495' - in DST la perfs. Bumped RBP down. Tried to work plug up - could not get past 6495'. RIH and set RBP @ 6588' and Pooh. RIH w/8~" tapered mill, junk sub, 9 5/8" csg. scraper, bUmper sub, and jars. Reamed tight spot f/6495' to 6503'. Circ. btms. up and Pooh. RIH w/retrieving tool and latch onto RBP @ 6588'. Pumped viscous pill around system and Pooh w/RBP. 2425' 025' 0' to 6920' Pooh and recover RBP (top cup on RBP was mashed down around body of tool). Rigged up Dresser-Atlas and ran CCi to tie-in top of liner to existing perfs. Rigged down Dresser-Atlas. RIH w/12 jts of 2 7/8" tbg. stinger on 3½" D.P. and C.O. sand f/7214' to 7240'. Circ. clean w/viscous pill and Pooh laying down D.P. and tbg. Installed 2 7/8" x 3~" rams and rigged up to run tubing. Finish RIH w/dual 2 7/8" x 3 1/2" tbg. strings. Stabbed 2425' into FB-1 pkr. @ 6920' and tested sea~s"to 500 psi - OK. }25' P.U. and spaced out tubing strings and installed tbg. ~0' to 6920' hanger. Displaced tubing annulus by pumping inhibited CaC12 fluid down L.S. Landed tbg. w/Baker "FH" pkr. @ 6400' and Baker "A-5" dual pkr. @ 5248'. Locked down hanger and rigged up Otis lubricator. R%H w/ 2 7/8" "XN" Plug in L.S. to set "FH" pkr. 2425' 025' 0' to 6920' Set "XN"'plug in nipple @ 6926'. Pressure up L.S. to set "FH" pkr. @ 6400'. Open "XA" sleeve in L.S. @ 6430' and test pkr. w/500 psi - OK. Close "XA" sleeve. Set "XN" plug in S.S. @ 5280' and pressure up to set "A-5" pkr. @ 5248'. Pull "XN" plug from S.S. and test pkr. w/500 psi - OK. Install BPV's, remove BOPE, install and test tree. Open "XA" sleeve in L.S. @ 6370' and displace fresh water down L.S. and up S.S. 425' 025' to 6920' Finish. displacing t~bing strings w/fresh water. RIH w/ Otis in L.S. and close "XA~' sleeve @ 6365'. Attempt' to retrieve equalizing choke from "XN" in L.S. @ 6928'.. Could not latch onto retrieving prong. Tool came out egg-shaped -'appears to be going alongside prong. Made 2 trips to retrieve choke - could not. Gas lift fluid from S.S. to clean up Middle Beluga. RIH in LoS. w/ centralized overshot and retrieved choke. Retrieved mandrel from L.S. and open for flow.: Tyonek Zone would not flow. Middle Beluga Zone now making 10/MMCF/D w/no water. Open "XA" sleeve in L.S. ;@ 5214' to drop fluid level in L.S. Tyonek still would not come on. Close sleeve @ 5214' and open sleeve @ 5291' in L.S. Lost weight on W.L. when opened sleeve. Pooh. Left all tools and 23' of W.L. in hole. RIH w/I.B. & found fish in "XA" sleeve @ 5214'. S E FT PAGE LEASE KENAI BELUGA UNIT OIL CCI'-?/ Cff= CALIFCB'IIA I'i~LL ~I0, 41-7 FIELD KENAI GAS FIELD DATE 66 67 68 69 70 i :L/26/80 :L/27/83 1/28/8( 1/29/81 1/30/80 7290 ' TD 13 3/8" C. 9 5/8" C. 5½" L.f/72 7290 ' TD 13 3/8" C. 9 5/8" C. 5½" L. f/72 7290 ' TD 13 3/8" c. 9 5/8" C. 7 5½" L.f/724 7290' TD 13 3/8" C. 9 5/8" C. 5½" L. f/7. 7290' TD 13 3/8" C. 9 5/8" C. 7 5½" L. f/72 DETAILS OF OPEP2~TiONS, DESCR!PTIGilS g RESULTS 2425' 025' .0' to 6920' 2425' 025' .0' to 6920' 2425' D25' 3' to6920' RIH w/W.L, spear. Worked on fish for 4 hours. Pooh. Recovered 12' of wire - no tools. RIH w/I.B. - Had rope socket up. RIH w/latching tool. Latched onto rope socket @ 5214' & tried to jar loose - could not. Sheare pin in latch tool. Pooh. Repaired tool and RIH. Latched onto ro.pe socket and knocked fish down. Could not relatch onto fish. Pooh. Found pin sheared. RIH w/latch tool and pushed fish down to "XA" @ 6365'. Could not latch"Onto fish. Pooh. RIH w/different latch tool - could not latch onto fish. Pooh. RIH w/I.B. - have wire on top of fish. RIH w/wire grab. Pooh. - recovered bundle of wire. RIH w/latch tool & pushed fish to "XN" nipple @ 6928'. Latched onto fish & Pooh. Had total recovery. Open L.S. to produce Middle Beluga thru "XA" sleeve @ 5291' to clean up. Close sleeve & flow Tyonek thru L.S. until clean. Had rate of 2.5 MMCF/D w/no water. Open "XA" in L.S. @ 6882' to dump~fluid across Lower Beluga into L.S. Did not produce any fluid. Close "XA" @ 6882' and set plug @ 6882'. Open "XA" @ 6446' and opened Lower Beluga to L.S. to clean up. Had a rate of 4.21 MMCF/D from Lower Beluga w/no water. Closed "XA" @ 6446' and retrieved plug from "XA" @ 6882'. Retrieved plug from "XN" nipple in L.~...@ 6882'. Rigged down Otis. Open L.S. to produce Tyonek Zone - making 1.8 $'~CF/D w/no water. Shut-in well. Begin rig down. 425' 025' 40' to 6920' Rigging Down. 2425' )25' ~0' to 6920' Rigging down. Released rig @ 1600 hrs, 1/30/80. HUGHES TOOl COM- PANY has available the following bulletins to assist you in getting your hole down in the shortest time and with th( ~,.~.~,'est bits: ' '~!i":" ,:: i:?i'' "H~ulics for Jet Bits" "New Hughes Simpli- fied Hydraulics" "Rotary Drilling Bits" "How to get the most from Hughes Journal Bearing Bits" "Hughes General Cata-~ log" Contact your Hughes Representative. He will welcome the opportun- ity to work with you and will furnish you with the latest information on rock bits and drill- in~ .~hniques for yog~ a r ~:: Compliments of HUGHES TOOL COMPANY HOUSTON, TEXAS U. S. A. ......... BIT RECORD I PUMP S P M MUD DULL. COND. WT. JEt SERIAL DePth FEET HOURS Ft/hR ACCUMiDRLG. 1000 R P M VERT PUMP OPER- formAtl~ NO. SIZE MAKE TYPE 32ND IN OUT HRS. lbS. DEV. PRESS ATION 1 2 WT. VIS.I W.L. T B g OTHER REMARK ~-/~ ~ ~ , hTC 55-~ D ?.;':1 .. SF, T PAGE LEASE UHIO!'I OIL OF CALIFOPCIIA I,ELL · KENAI BELUGA UNIT I'E~L Il0, KBU ~'~41-7 FIELD. KENAI GAS FIELD D~TE JTS 2 JTS 59 JTS 109 DETAILS OF OPEPATIONS, DESCRIPTIOilS g RESULTS KENAI BELUGA UNIT #41-7 CASING DETAIL 20" 94# H-40 Plain-End Casing Description 20" 94# H-40 Plain-End csg. 20" cut-off Landed below RKB Total soil penetration - 112.50' Length 96.42' 16.08' 21.20' 13 3/8" 61# K-55 Buttress Casin8 Description 13 3/8" Float Shoe 13 3/8" K-55 Pup 13 3/8" Float Collar 13 3/8" K-55 Casing 13 3/8" cut-off 13 3/8" SOW x 13 5/8" 5M head R.T. to casing head Len~tb 1.55' 10.47' 2.18' 2374.66' 13.01' 1.50' 21.90' 9 5/8" 47# N-80 Buttress Casin8 Description 9 5/8" Float Shoe 9 5/8" 47# N-80 Casing 9 5/8" Float Collar 9 5/8" 47# N-80 casing 9 5/8" pup (marker) 9 5/8" 47# N-80 casing 9 5/8" cut-off R.T. to 9 5/8" csg. stub Length 1.70' 43.38' 1.40' 127.64' 16.50' 6805.83' 6.75' 21.80' Bottom 133.70' 37.28' 21.20 Bottom 2425 27' 2423.72' 2413.25' 2411.07' 36.41' 23.40' 21.90' Bottom 7q325.00' 7023.30' 6979.92' 6978.52' 6850.88' 6834.38' 28.55' '21.80' 37.2~ 21.2( --0-- Top 2423.72 2413o2f 2411.07 36,4] 23.4£ 21.9£ --0-- Top 7023.3£ 6979.92 6978.52 6850.8E 6834.3~ 28.5~ 21.8C --0-- OIL CAm O LIFCPCIIA I,ELL ,LLU?'JJ I<]~NAI BELUGA UNIT I'ZLL IIO, .. KBU #41-7' FIEf! KENAI GAS FIELD _ JTS DETAILS OF OPEPZ, TIONS, DESCRi?TIOiIS ~ RESULTS KENAI BELUGA UNIT #41-7 CASINGDETAIL 5 1/2" Liner Description 5½" Bull Plug 5½" 15.5# 8RD w/.012" Screen 5½" 20# N-80 pup 5½" Lynes port collar 5½" 20# N-80 pup 5½" Lynes E.C.P. 5½" Lynes E.C.P. 5½" 20# N-80 pup 5½" Lynes port collar 5½" 20# N-80 pup 5~" EUE x 5½" Hydril F.J. x-over 5½".20# N-80 F.J.P. csg. 5½" F.J. x 7" buttress x-over 7" 29# N280 buttress pup 9 5/8" x 6" Baker "F-I" packer Top of Liner - 6920.26' Length 1.00' 40.35' 10.00' 1.95' 15.35' 8.37' 8.35' 5.00' 1.95' 9.10' .88' 203.72' .84' 8.94' 3.94' Bottom 7240.00' 7239.00' 7198.65' 7188.65' 7186.70' 7171.35' 7162.98' 7154.63' 7149.63' 7147.68' 7138.58' 7137.70' 6933.98' 6933.14' 6924.20' Top 7239.00' 7198.65' 7188.65' 7186.70' 7171.35' 7162o98' 7154.63' 7149.63' 7147.68' 7138.58' 7137.70' 6933.98' 6933.14' 6924.20' 6920.26' PAGE OIL CALIFO? 'tIA ,ELL LE SE KENAI BELUGA UNIT I'~LL IlO, KB~ #41-7 FIF. LD KENAI GAS FIELD ~,~TE IE-ri') " JTS _ 10 165 .n..ETA~' ~ OF nDc~'~'-rIONS DESCRIPTIO[IS ~, RESULTS KENAI BELUGA UNIT #41-7 TUBING DETAIL - LONG STRING Descriptio~ 2 7/8" mule shoe 2 7/8" Otis "XN" nipple 2 7/8" Butt, x 3~" Butt, x-over 3~" Butt. x 4~" Butt. x-over ...... 6" OD Baker seal assembly 9 5/8" Baker "FB-I" pkr, @ 6920,26' Baker "G-22" locator 4½" Butt, x 3~" Butt, x-over .3~" Butt, x 2 7/8" Butt, x-over 2 7/8" 6,4# N-80 Butt, tbg, 2 7/8" Otis "XA" sleeve 2 7/8" 6,4# N-80 Butt, tbg, 2 7/8" blast joints 2 7/8" 6,4# N-80 Butt, tbg, 2 7/8" blast joints 2 7/8" 6.4# N-80 Butt, tbg, 2 7/8" Otis "XA" sleeve 2 7/8" 6,4# N-80 Butt, tbg, 2 7/8" Butt, pups (2) 2 7/8" Butt, x 2 7/8" 8RD x-over 2 7/8" 8RD x 3~" 10RD x-over 9 5/8" Baker "FH" packer 3½" 10RD x 2 7/8" 8RD x-over 2 7/8" 8RD x 2 7/8" Butt, x-over 2 7/8" 6,4# N-80 Butt, tbg, 2 7/8" Otis "XA" sleeve 2 7/8" 6,4# N-80 Butt, tbg, 2 7/8" blast'jts (2) 2 7/8" 6,4# N-80 Butt, tbg, 2 7/8" Butt, pups (2} 2 7/8" blast joints 2 7/8" 6,4# N-80 Butt, tbg, 2 7/8" Butt, pups (2) 2 7/8" blast joints 2 7/8" 6,4# N-80 Butt, tbg, 2'7/8" Butt, pups (2) 2 7/8" blast joints 2 7/8" 6,4# N-80 Butt, tbg, 2 7/8" Otis "XA" sleeve 2 7/8" 6,4# N-80 Butt, tbg, 2 7/8"'Butt,-x 2 7/8" 8RD x-over 2 7/8" 8RD x 3½" Butt, x-over 3~" Butt, x 3~' 10RD x-over 9 5/8" Baker A-5 dual packer 3½" 10RD x 2 7/8" Butt, x-over 2 7/8" 6,4# N-80 Butt, tbg, 2 7/8" Otis "XA" sleeve 2 7/8" 6,4# N-80 Butt, tbg, Hanger R,T, to dual hanger Length Bottom ~ ,71' 6930,07' 6929,36' 1,52' 6929,36' 6927,84' ,82' 6927.84' 6927,02' 1,15' 6927.02' 6925.87' 7,80' 6925,87' 6918,07' ,89' 6918,07' 6917,18' 1,07' 6917,18' 6916,11' ,93 6916,11' 6915,18' 29,99' 6915.18' 6885,19' 3,62' 6885,19' 6881,57' 187,30' 6881,57' 6694,27' 29.26' 6694,27' 6665,01' 155,87' 6665,01' 6509,14' 28,81' 6509,14' 6480,33' 31,47' 6480,33' 6448,86' 3,22 6448.86' 6445,64' 29,73' 6445,64' 6415,91' 6,35' 6415,91' 6409,56' ,50' 6409,56' 6409,06' ,50' 6409,06' 6408,56' 7,00' 6408~56' 6401,56' ,95' 6401,56' 6400,61' ,57' 6400,61' 6400,04' 31,87' 6400,04' 6368,17' 2,50' 6368,17' 6365,67' 218,90' 6365,67' 6146,77' 29,53' 6146,77' 6117,24' 313.14' 6117,24' 5804,10' 16,00' 5804,10' 5788,10' 38.84' 5788,10' 5749,26' 62,86' 5749,26' 5686,40' 20,00' 5686,40' 5666,40' 38,34' 5666,40' 5628,06' 249,12' 5628,06' 5378.94' 14,00' 5378,94' 5364,94' 38,72' 5364,94' 5326,22' 31,75' 5326,22' 5294,47' 2,50' 5294,47' 5291,97' 28,70' 5291.97' 5263,27' . ,95' 5263,27' 5262,32' ,50' 5262,32' 5261,82' ',75' 5261,82' 5261,07' 11,60' 5261.07' 5249,47' ,75' 5249,47' 5248,72' 31,67' 5248,72' 5217,05' 2,50' 5217,05' 5214,554 5190,95' 5214,55' 23,60' 1,00' ~23,60' 22.60' 22,60' 22,60' -0- NOTE: Caution should be used when running "~" plug to nipple @ 6928' as there is no 2 7/8" alignment bore above it, It is therefore neceSsary to centralize the plug pulling tool, Otis W,L. used a kickover tool to accomplish this, This nipple should 6nly be used as a last resort. SF,~ PAGE OIL CC~-P~-~ G~ CAL!FO~'IIA ' ~ r"'F'F',L~T'I ~'ASE D.~TE KENAI BE~UOA~UNIT l,faLL IlO, ~, ~u #~]_-F .... FIELD KENAI GAS ELET,D ' ':'° ©P?AT DESCRI?TIG~IS ~ RESULTS Da~Lo OF iONS, KENAI BELUGA UNIT #41-7 JTS ,. 15 37 40 73 TUBING DETAIL - SHORT STRING pescrip~ion 3½" 8RD collar 3~" Otis "XN" nipple 3½" 8RD x 3~" Butt. x-over 3½" 9.2# N-80 Butt. tbg. ' ..... 3~" Butt. x 3~" 10RD x-over 9 5/8" Baker A-5 dual pkr. Left-hand safety connector 3~" Butt. pup 3~" 9.2# N-80 Butt. tbg. 3~" Otis ,,XA,, sleeve 3~" 9.2# N-80 Butt. tbg. 3~" Camco GLM 3~" 9.2# N-80 Butt. tbg. 3~" Camco GLM 3½" 9.2# N-80 Butt. tbg. 3½" Camco GLM 3~" 9.2# N-80 Butt. tbg. 3~" Butt. pup Tbg. Hanger R.T. to Hanger .61' .72' .69 31.00' .45' 10.00' .25' 4.15' 31.6 9' 3.25' 466.97' 6.20' 1163.62' 6.20' 1253.21' 6.20' .2287.11' 2.05' 1.00' 22.60' Bottom Top ~297.97' 5297.36' 5297.36' 5296.64' 5296.64' 5295.95' 5295.95' 5264.95' 5264.95' 5264.50' 5264.50' 5254.50' 5254.50' 5254.25' 5254.25' 5250.10' 5250.10' 5218.41' 5218.41' 5215.16' 5215.16' 4748.19' 4748.19' 4741.99' 4741.99' 3578.37' 3578.37' 3572.17' 3572.17' 2318.96' 2318.96' 2312.76' 2312.76' 25.65' 25.65' 23.60' 23.60' 22.60' 22.60' -0- [[i i i TUBING DETAIL Long String ! [ 1. 2 7/8" "XA" sleeve - 5215' 2. Baker A-5 packer - 5249' 3. 2 7/8" "X~'sleeve - 5292' 4. 2 7/8" blast joints 5326'-5365' 5. 2 7/8" blast joints 5628'-5666' 6. 2 7/8" blast joints 5749'-5788' 7. 2 7/8" blast joints 6117'-6147' '8. 2 7/8" "XA" sleeve - 6366' 9. Baker "FH" packer - 6402' 10. 2'7/8" "MA" sleeve - 6446' 11. 2 7/8" blast joints 6480'-6509' 12. 2 7/8" blast joints 6665'-6694' 13. 2' 7/8" "XA" sleeve - 6882' 14. Baker "G-22" locator - 6917' 15. Baker "FB-i" packer - 6920' w/6" bore 16. 6" seal assembly 6918'-6926' 2 17. 2 7/8" "XN" nipple - 6928' 18. 2 7/8" mule shoe - 6930' Short Strin~ A. 3½" Camco GLM - 2313' B. 3½" Camco GLM - 3572' C. 3½" Camco GLM - 4742' D. 3½" "XA" sleeve - 5215' E. 3½" "XN" nipple.- 5297' F. 3½" collar - 5298' NOTE: See tubing detail for caution 9 in using "XN" nipple in L.S. @ 6928'. '13 3/8" C.2425' 15 9 5/8" C. 7025' 5½" L. 7240' KENAI BELUGA UNIT #41-7 SPUD: 11/22/79 COMPLETED: 1/30/80 SHEETS SCIENTIFIC DRILLING CONTROLS TOO tJEST qlST ANCHORAGE AK. .. GYROSCOPIC DIRECTIONAL SURVEY FOR NUMBER ~795 UNION OIL CO.. LL NAME KBU ~1-7 'CATION I<ENAI GAS FIELD ~RVEY DATE 12/7/79 IRVEY ENGINE[R dim RIGGS ,GNETIC DECLINATION 25.00 E 'PO REFERENCE BEARING S 10- O ~ 'THOD OF CALCULATION BY THE RADIUS OF' CURVATURE )MMENTS NO NO NO NO *THIS SURVEY IS CORRECT TO THE · *BEST OF fqY KNOWLEDGE AND IS . .SUPPORTED ~Y ACTUAL FIELD DATA.* .. . * ~.VE * ****************** *************** '~B NUMBER 3795 TIME 3- 0 13- 0 20- O 29- 38- 0 qO- 0 ql- 0 .2- 0 A3- 0 45- 0 qG- 0 A7- 0 AS- O qg- 0 54- 0 DEPTH 500 1000 1500 2000 2100 2200 2300 2z~OO 2500 2600 2700 2800 2900 300O 3000 SCIENTIFIC DRILLING CONTROLS 700 MEST ~iST ANCHORAGE AK, COMPUTER INFUT DATUM INC BEARING O- 0 N O- 0 E O-A5 N 70- 0 E 0-30 N 77- 0 E. O-A5 N 80- O E O- 0 N O- 0 E 0-15 N 80- 0 E 0-15 S 0- 0 E 0-1,5 S 68.- 0 E 0-30 N 81- 0 U 0-30 S 89,,- 0 E 0-45 $ 84- 0 E O-A5 S 79- 0 E 0-45 N 0-.0 E O-q 5 N 65- 0 E 0-~+5 N 45- 0 E 0-45 N ~+5- 0 E DATE 12/7/79 DRIFT CiiE CK COOE C 0 MF,'.EN T S N 10.00 E 0 ORIENI'ATION N 77.0fl W 0 DRIFT N 77.00 W D DR IrT PAGE 1 56- 0 3100 0-45 N 38- 0 E OB NUMBER 3795 TIME 5'/- 0 58- D 59- O 61- I1 62- 0 63- 6,4- O 65- 66-. 67- 0 6~- O 69- 0 70-0 71- 0 72- O 73- 0 7q- 0 DEPTH 3200 3qO0 3500 3600 3700 3800 390'0 qOOO 4100 A2OO A500 q600 4700 SCIENTIFIC DRILLING CONTROLS 700 'NEST 41ST ANCHORAGE AK, COMPUTER INPUT DATUM INC BEARING 0-30 N 6- 0 E O-Z~5 N 4- 0 E 0-15 N O- O E 0-15 N O- O E DATE 12/7/79 DRIFT CHECK CODE COMHENIS 0-15 0-30 N ~O- 0 E O-Z~5 N 2- 0 E 0-15 N O- 0 E 0-30 N 86- O E 0-30 N 85- 0 E O-q. 5 N 88- 9 E 0-15 N O- O E 0-'~5 N O- 0 E 0-~5 N 10- 0 W O-q5 N O- 0 E 0-15 S 88- 0 E 0-30 S 82- 0 E PAGE 2 75- O 5000 0-30 S 82- 0 E S 42.50 E O DRIFT TIME 81- O 82- 0 85- 0 84- 0 85- O 86- 0 87- O 88- 0 89- 0 90- 0 91- 0 92= 0 93- 0 94- 0 95- 0 96- 0 97- 0 98- 0 DEPTH 5000 5100 520O 5500 5qO0 5500 5600 570O 5800 5900 6000 6100 6200 6300 6400 6500 6600 6700 SCIENTIFIC DRILLING CONTROLS 700 WEST 41ST ANCHORAGE AK, COMPUTER INPUT DATUM DATE 12/7/79 INC B EAR ING 0-30 S 82- O E 0-15 S 85- 0 W 0-15 S 89- 0 E DRIFT CHECK CODE COMI,IE NTS S 45.25 E O DRIFT · -. 0-30 N 86- O E 0.15 N 55- 0 E 0-45 N 45- 0 E 0-15 N 72- 0 E O- 0 S69-0 W 0-15 S 63- 0 W 0-15 S 70- 0 E 0-30 S 73- 0 W 0-15 S 75- 0 E 0-30 S 85-. 0 E 0-15 S 89- O E 0-15 S 40- 0 E 0-45 S 20- O E 0-30 S 3- 0 E 0-15 S 45- 0 N PAGE 3 NUMBER 3795 TIME 99- 0 100- 101- O 103- O 111- D 117- 0 12l- 0 126" 0 131- 0 136- 0 lqO- D lqq- O 1~+8- D lqg- 0 15q- 0 157- 0 1Gq- D DEPTH 6900 6950 7010 6500, 6000 5500 5000 5000 q500 qOOO 3500 3000 2900 2900 2500 2000 SCIENTIFIC DRILLING COh,~TROLS 700 WEST z+IST ANCHORAGE AK, DATE 12/7/79 COMPUTER INPUT DATU~I INC BEARING DRIFT CHECK CODE COMIqENTS 0-15 S 70-0 E 0-15 S qO- 0 E 0-15 N 40- 0 E 0-I5 N ~*O- ~ E 0-30 N 72- O E D-15 N Gq- D E 0-30 N qq-. 9 E 0-30 0-30 0-15 N 74- 0 E S 31.50 E D DRIFT N 7z+- 0 E N 56- 0 E S 30.50 E D DRtFT 0-15 N O- 0 E 0-15 N O- 0 E 0-~5 N 52- 0 E 0-30 N 54- 0 E N 54,25 E D DRIFT 0-30 N 54- 0 E N 55,25 E O DRIFT 0-30 S 25- 0 E O- O N O- 0 E PAGE 169- O 1500 0-~5 N q5- 0 E NUMBER 3795 TIME 169- 179- 183- 0 198- 0 gEPTH 1000 500 500 SCI.[NTIFIC GRILLING CONTROLS 700 WEST ~IST ANCHORAGE AK. DATE 12/7/79 COMPUTER INPUT DATUM INC BEARING DRIFT CHECK CODE COMF~ENTS 0-30 N ~6- 0 E O- 0 N 29- 0 U O- 0 N 29- 0 ;J O-OW S 6q.75 E D DRIFT S 64°25 E D ORIFT N 20.00 W 0 ORIENTATION '~, PAGE 5 ]B NUMBER 3795 GYRO TIME SCI.ENTIFIC DRILLING CONTROLS 700 WEST ~+iST ANCHORAGE AK, DATE INTERCARDINAL CORRECTION APPLICATION FOR SPIN AXIS PARALLEL TO THE NORTH-SOUTH AXIS 12/7/79 DEPTH CORRECTION INCREMENTS ~ MINUS) BEARING DRIFT CHECK PAGE *THE LARGEST ABSOLUTE VALUE GIVEN* *FOR THE INTERCARDI~AL CORRECTION* *IS LESS THAN 0,01 DEGREES, HENCE* *THE OUTPUT DISPLAY IS SUPPRESSED* . · DB NUMBER .3795 SCIENTIFIC DRILLING CONTROLS 700 WEST 41ST ANCHORAGE AK,, DATE 12/7/79 PAGE DRIFT CURVE ANALYSIS NO, ADd TI,NE DEPTH DRIFT CHECK R AT E/HR · q&,O0 3000 2A5.00 51,00 3000 2~3.00 · O1 DEGREES (EAST DRIFT) 72,~0 78,00 5.DOO 137,50 5000 134,75 27.50 DEGREES (EAST DRIFT) 123,00 5000 1.48,50 !28,00 5000 ' 149.50 -12,00 DEGREES (WEST DRIFT> I~6.00 2900 54.25 151.00 2900 55.25 -12.01 DEGREES (W"ES T DRIFT) 176.00 5O 180.OD 50 ,. TOTAL ELASPED TINE TOTAL OBSERVED TOTAL CALCULATED DR DRIFT CURVE CLOSU THE HAXIMUM EAST DR AND OCCURRED AT THE THE MAXIMUM WEST DR AND OCCURRED AT THE 0 115.25 O 115.75 EOUALS 195,00 MINUTES FT EC~UALS 30,00 EAST IFT EQUALS 1,34 EAST RE EQUALS 2~.G6 LOW IFT POINT EQUALS 32.65 TI~'tE OF 100.50 MINUTES IFT POINT E~UALS 0.00 TIME OF O,OO MINUTES -7,51 DEGREES (~EST DRIFT) ~B NUMBER 3795 SCIENTIFIC DRILLING CONTROLS 700 NEST 41ST A~.~CHORAGE AK, DRIFT CURVE ANALYSIS INCREMENTAL DRIFT APPLICATIO~.~ DATE' 12/7/79 ADJ, T 10, 17, 26, 35. 37, 38. 39. 40° 42, ,3. 45. 53. 55. 56. 58. 59. 6,3. 61. 62. 63, 64, 65, 66, IME DEPTH DRIFT APPLIED O0 5~.0 1.47 DEGREES EAST OD lOOO 2.5,9 DEGREES EAST 00 15OD 3,82 DEGREES EAST O0 2000 5,1z~ DEGREES EAST O0 2100 5,44 DEGREES EAST O0 2200 5.59 DEGREES EAST O0 230U 5,73 DEGREES EAST O0 2~0D 5,88 DEGREES EAST O0 2500 6'03 DEGREES EAST OD 2600 6,17 DEGREES EAST O0 2700 6,32 DEGREES EAST O0 2600 6.~+7 DEGREES EAST 00 2900 6.61 DEGREES EAST OB 3600 6°76 DEGREES EAST 00 310O 7.79 DEGREES EAST O0 3200 7,9q DEGREES EAST 00 3qO0 8.OR DEGREES EAST OD 3500 8.23 DEGREES EAST O0 3600 8.53 DEGREES EAST O0 3700 ,0,.67 DEGREES EAST O0 3850 g.82 DEGREES EAST O0 39,90 8.97 DEGREES EAST O0 qOOO 9.34 DEGREES EAST O0 qlO0 9.95 DEGREES EAST OD 4200 10.55 DESREES EAST O0 43fi0 11.16 DEGREES EAST O0 4400 11.76 DEGREES EAST PAGE DB NUMBER SCI.ENTIFIC DRILLING CONTROLS 700 WEST 41ST ANCHORAGE AK, DRIFT CURVE ANALYSIS INCREMENTAL DRIFT APPLICATION DATE TIME DEPTH DRIFT APPLIED 67,00 4500 12.37 DEGREES EAST 68,00 4GOO 12,97 DEGREES EAST 69,00 Z~Ti'JO i3.5~ DEGREES EAST 7O.gO z~80D 14.18':'" DEGREES EAST 71,00 A~O0 1A,79 DEGREES EAST 72,00 5'000 15,qO DEGREES EAST 79.,00 5100 19,63 DEGREES EAST SD,OD 5200 20,24 DEGREES EAST 81,00 5300 20,84 DEGREES EAST 82.00 5400 21"45 DEGREES EAST 83,00 5500 22.05 DEGREES EAST 84.00 5600 22,66 DEGREES EAST 85.00 5700 23.26 DEGREES EAST 86,00 5800 23,87 DEGREES EAST 87.00 5900 2~,A8 DEGREES EAST 88,00 60OO 25,08 DEGREES EAST 89,00 6100 25,69 DEGREES EAST 90,00 6200 26,29 DEGREES EAST 91,00 ~.300 26,90 DEGREES EAST 92,00 6400 27,50 DEGREES EAST 93,00 65S'0 28.11 DEGREES EAST 94,00 6600 28,71 DEGREES EAST 95.00 6700 29.32 DEGREES EAST 96.00 68'90 29.92 DEGREES EAST 97.00 6'::)00 30.53 DEGREES EAST 98°00 6950 31.I3 DEGREES EAST 100.00 7010 32.3A DEGREES EAST 12/7/79 PAGE ,,~B NUMBEP, 37'5'5 SCIENTIFIC DRILLING CONTPOLS 700 WEST 4IST ANCH.ORAGE AK. DRIFT INCREMENTAL CURVE ANALYSIS DRIFT APPLICATION DATE 1217179 ADJ. TIME DEPTH 108o00 !14°00 118,,00 123.D0 133o00 137.0 1A1.0 145,0 154o0 161.0 1A6.O 166.0 176.0 6500 5500 5000 3500 3O00 2900 2500 2000 I000 5O 0 DRIFT APPLIED 32.25 DEGREES EAST 31.93 DEGREES EAST 31.72 DEGREES EAST 31,~5 DEGREES EAST 30.92 DEGREES EAST 30.71 DEGREES EAST 30.50 DEGREES EAST 30,29 DEGREES EAST 30°24 DEGREES EAST 29°81 DEGREES EAST 29.44 DEGREES EAST 29.36 DEGREES EAST 29.36 DEGREES EAST 29,5~ DEGREES EAST PAGE NUMBER 3795 SCIENTIFIC DRILLING CONTROLS 700' WEST QIST ANCHORAGE AK, DATE 12/7/79 PAGE 1 INRUN SURVEY BY THE RADIUS OF CURVATURE aS, VERT, PTH DEPTH VERT, COURSE SECT. DEV. INC BEARING COORDINATES D-LEG STATION DISPLACEMENT LATITLtDE DEPARTURE DISTANCE BEARING =OD,., 499.99 '~', -3.27 @00 799.96 -8.68 500 1499.93 -13.99 DOD 1999.92 "-17.15 100 2099.92 -17,36 !2~1] 2199.91 -17.25 -'_- 3 O 0 2299.91 ~400 2599.9] -16.96 ~500 2q99.91 -17.33 !6~0 2599.90 -18.27 3.27 5.45 5.4,5 3.27 .22 ,88 t,09 8-q5 N 83-32 O-3O N 7.5-30 O-q5 N 71.-11 O- 0 S 30-9 0-15 N 69-34. o-1 N so-3. E 0-15 N 37-16 W 0-30 S 50- 7 E 0-30 N 57-58 ~ 0-45 N 52-50 W .37 N ,1.35 N 2.93 N 3.9~ N '+.OG N 4 ,~2 N ~ .84' N 4.53 N 5,0,} N 5,62 N 5,26 W 8,62 k} ,06 I~'~,,84 W .06 I6,9q W 0,00 .17,lq W 17.01 6 .39 17.04 ~ ,28 16.71 W .75 17.06 ~.~ 1,CO 17.95 W ,26 3.28' AT N 83-28 8.72' AT N ,31- 0 14.15' AT N 7~- 3 17.~0' AT N 76-q6 17,62~ AT N 76-41 17.5g' AT N 75-25 17.71~ AT N 74- 9 17,32~ AT kl 7A-50 17.77~ AT N 73-3'9 18.81' AT N 72-37 ~700 2699.89 -19.33 .~800 2799.88 -20.q, 6 !900 2899.88 -21.gi 5000 2999,87 -22.9'2 ~100 3099.R6 -24.1A !,209 3199.85 -24.98 5q~O 3399.84. -26.21 ~500 3499.8q -26.£7 .~6gO 3599.84. -26.89 ~:700 3699.83 -27.17 1.31 1,31 1.31 1.31 1.31 1.09 2.18 .87 .44 0-45 N ~7-~1 0-45 S 31-28 0-4.5 N 83-23 0-4,5 S 16-46 0-45 S 70-~7 0-30 S 38-56 O-Z~5 S 37-5 [,-15 S 33-14 0 -! 5 S 33-32 0-15 S 53-40 6,30 N 6.84 N 6,77 N 6.40 N 5.7,~ N 4.06 N 3.35 N 2.98 N 2.66 N I i~, · 96 W .07 20.10 W 1.16 21.22 W 22.53 W .26 23,79 W .08 24.67 ~: .42 26,01 W ,13 26.51 W .51 26.76 w ,~i 27,u£ ~ .09 20.03' AT N 71-11 21,07' AT f',! '72-36 22.30' AT b~ 72- g.~ 23.52' AT N 73-17 24,65' AT b; 74-56 25.3q' AT ~'i 76-49 t,~ 26.33' AT N ,~1- 7 W 26.72' AT ?,3 82-4,8 ~ 2~,92' AT N 83-39 'W 27.19" AT ~ 8q-23 '..~ 5800 37~g.83 -27.74. .65 0-30 S 73-49 W 2.37 N 27.~4 W .28 2'7.75~ AT F; 85- 5 ;,! NUMBER 3795 SCIENTIFIC DRILLING CONTROLS 700 WEST ~IST ANCHORAGE AK. DATE 12/7/79 PAGE 2 INRUN SURVEY THE RADIUS OF CURVATURE ;AS, VERT, ;PTH DEPTH VERT, COURSE SECT. DEV, INC BEARING .D M D M COORDINATES D-LEG STATION DISPLACEMENT LATITUDE DEF'ARTUR[ DISTANCE BEARING 5.900 3899.83 -28.57 ~060 399'9,82 -29,03 ~100 q099,82 -29,62 ~-200 ~.199,82 -30, q.O ~.300 q299,81 1.09 0-45 S 35-58 · 87 0-15 S 3g-21 ,65 0-30 N 59- 3 · 88 0-30 N 59-27 1.89 O-Z~5 N 55-51 1 .T& N 1 .05 N 1,17 N 1,62 N 2,2~ N 28,52 W 29,62 W ,51 29.60 W ,55 30,36 W ,01 31 ,28 W ,26 28,57~ AT N 25-28 29.04~ AT N 87-55 29,63' AT .H 87-44 38,qO '~ AT N ~-57 3:1,.36" AT N .85-5E. ~fl90 ~399,81 -32,12 ~500 ~q99,80 -32.61 ~600 ~599.79 -33.2q ~7~g 46'99,79 -33,89 ~F, O0 ~799.78 -34,67 ,87 ,87 1,31 1,31 0-15 S 36-q6 O-z~5 S 37-22 O-q5 S 27-53 0-45 S 38-~.5 0-15 N 48-q. 9 2,07 1,38 ,27 ,83 ,76 32,06 I~ ,78 32,58 'N ,51 33,29 ~.~ ,13 3q..Ol W ,!~.. 3q.79 W ,81 32,12" AT N 86-18 32.61' AT N 87-35 35,29' AT N 89-32' W 34.,02 ~ AT S 86 -36 3~+.80' AT S 8~-~5 ~-gP. 0 ~899,78 -35,17 .'.'. 0 O 0q999,77 -35,79 ;100 5'399,77 -35,47 5200 519~o77 -35.68 5300 5299.77 -36.18 5~00 5399,77 -36,78 ~500 5/499,76 -37,65 5600 5599.76 -38,~9 5700 5699,76 -38,69 ~800 5799,76 -38,q8 5900 5899.76 -38,74 ,65 ,88 ,65 ,65 .87 ,87 ,22 ,22 0-30 N ~2-13 W 0-30 N ~1-36 W 9-15 S 50-22 E 0-15 N q3-~6 W 0-30 N ~8- 9 U 0-15 N 78-33 W O-q5 N 87-57 W 0-15 N 69-20 W O- 0 S 62-q~ E 0-15 S 68- 8 E 0-15 N 20-31 .31 S · 36 N · O~ N · 26 .N · 71 N 1.00 N 1,10 N 1.3~ N 1,45 N I,~7 N 1.61 N 35.26 W 35.84 W .O1 35,54 W ,75 35.7~ U ,50 36,21 W ,26 36,79 W ,32 37,65 Ig ,51 38.A. 8 N ,55 3t'~.67 ¢ 0.00 38.~7 '~ 3~.72 W ,~6 35.26' AT S g9-30 35.8q' AT N 89-.26 '~5.5fi"~ AT N 89-56 35.7~' AT N 89-35 36.21' AT N ~B-53 36.89' AT N 88-27 W 37.67' AT *,! 88-19 Y 38.51' AT N 8LZ- I W 36.79~ AT N 87-52 W 38.~9' AT N 87-5& N 38.75' AT N ~7-37 W tB NU~BE~' 37t~5 SCIENTIFIC DRILLING CONTROLS 700 WEST qlST ANCHORAGE AK. DATE 12/7/79 PAGE 3 INRtJN SURVEY BY THE RADIUS OF CURVATURE :AS. VERT. ]PTH DEPTH VERT. COURSE SECT. DEV. INC BEARING D H D M COORDINATES D-LEG STATION DISPLACEMENT LATITUDE DEPARTURE DISTANCE BEARING ~OOO 5999.76, -38.3~ i:lO0 6099.75 -38.73 ~200 6199.75 -39.08 ~.~O0 6299.75 -39.zi9 ,:,.400 6399.75 -39.q~ .65 '.'i.',- 65 °65 0-30 S 56-55 E ?,', 1.30 0-15 N 2z+-1,9 W 1.62 0-30 N 33-43 W 2.19 0-15 N 37- 6 ~ 2.72 0-15 N 12-30 E 3.1q, 3 ~.. 33 d .72 3 8.7[I W .73 39.02 ~ -26 39.~,0 ~J .26 39.31 W .21 38.35' AT N 88- q, 38.7q* AT N 87-35 39.08' AT N 86-~7 39.~9' AT N 8f~,- 3 39.~3' &T N 85-26 ~500 6q99.7zi -39.14 ~600 6599.7,% -38.q5 ~700 6699.7,% -37.82 !, 8.,n O 6799,73 -38.88 ~900 6899.73 -38.11 · 87 O-q5 N 33- 7 E 3.9q, N 1.09 0-30 N 53-q3 E ~.73 N · 65 0-15 S 80-~I E ,%.58 N .4~ 0-15 N 15- 5 W ~.~6 N ,~4 0-15 N 15-32 E 5,29 N 38.97 ~ .53 38.23 ~ .5~ 37.61 W .38 37.86 W .~3 37.65 g .1~ 39.17' AT N 8~-:I. 4 W 3P~.52' AT I~ 82-57 W 37.8,S' AT N 83- 3 W 38.17 ~ AT N 82-~2 Y 38.22" aT N F.',2- 3 ~; S950 69q9.73 -38.23 /OlO 7009.73 --38.50 · 22 0-15 N 83-52 B 5.q5 N · 27 0-15 N 82-,59 W 5.q9 N 37.96 W .77 3~.23 W .01 38.35' AT N 81-50 W 38.62"' AT t,;. ~1-50 W THE HORIZONTAL DISPLACEMENT AT THE DEPTH OF 7010 FEET ECUALS 38.62 FEET AT N 81-50 W. :, ,. }~ NUMBER 3795 SCI.ENTIFIC ..DRILLING CONTROLS 700 WEST 41ST ANCHORAGE AK, DATE 1217179 PAGE 1 THE RADIUS OF CURVATURE INRUN VERUS OUTRUN COMPARISON DEPTH INC D M DIFFERENCE = -'":' "'" !" BEAR ING ,~'~D IFF ER ENCE DM DM DM 6500 0-45 O-30 0-15 N 33- 7 E N 50-45 W 83-52 6000 0-30 0-15 0-15 S 56-55 E N 59- 4 W 177-51 5500 5000 0-45 0-30 0'30 0-30 0-15 N 87-57 N 79-17 N 41-36 N 4 .q-33 7-57 4500 0-45 0-15 0-30 $ 37-22 N68- 5W 74 -33 4000 0-15 0-15 34-21 55-43 21 -22 3500 0-15 0-15 O- 0 S 33-14 S 55-30 22-16 3000 0-45 0 -45 O- 0 S 76=46 N 72-43 30 -31 2900 0-45 0-30 0-15 N 83-23 W N 70-A6 W 12 -37 2500 0-30 0-30 O- 0 N 57-58 N 29-49 ~7-47 OB NUMBER 37'35 DEPTH 2000 1500 1000 500 SCIENTIFIC DRILLING CONTROLS 700 WEST qlST ANCHORAGE AK. DATE 12/7/7~.~ THE RADIUS OF CURVATURE INRUN VERUS OUTRUN COMPARISON INC DIFFERENCE BEAR ING DIFF[RENCE DM D ~, DM DM O- 0 0-~5 0 -45 PAGE 2 0-30 0-30 O- 0 ,, O- 0 S 30- 9 W S 54-26 24-17 O- 0 N 71-11 N 80-3~ 9-27 O- 0 N 75-30 N 79-38 q- 8 0-45 N 83-32 S 25-35 70-53 NUMBER 37.95 7AS. VERT. VERT. ~PTH DEPTH SECT. 508 LO00 lO00.OC -2,15 [500 1499.97 -7.51 ?000 1999.95 -10.72 ~SOO 2~99.95 -10.37 ~900 2999.93 5000 2999.93 -13.q7 5500 3499.91 -17.16 ~,000 5999,90 -18,~1 %500 ~499.90 5000 4999.89 -23.65 .~500 5~+09.87.. -27.q=. ,~ ~,OOO 5999.86 -31.21 ~500 6q99.84 -3~.37 7010 7009.83 -37.66 SCIENTIFIC [DRILLING CONTROLS 700 WEST 41ST ANCHORAGE AK. PACE DATE 12/7/79 OUTRUN SURVEY BY THE RADIUS OF CURVATURE COURSE DEV. INC BEARING D M D M COORD INA TES D-LEG LATITUDE DEPARTURE · 01 O- O S 25-35 W 2.18 0-~0 N 79-3S W 5.~,5 0-~5 N 80-38 W 3.27 O- 0 S 54-26 W 2,18 0-30 N 29-49 E 3.50 0-30. N 70-A. 6 1.09 O-q5 N 72-A3 ~,.36 0-15 $ 55-50 2'19 0-15 S 55-~3 2'19 0-15 N 6-8- 5 · Ot N .01 E .40 N 2.15 k; O.OO 1.34 N 7.52 W 1,87 N 10,75 W 0.00 3.76 N 9.67 ~ O.O0 6.63 N ].O.7q W .20 6,97 N 11,78 W .26 6.3q .N 15.95 !,~ ,13 5.11 N 17.75 W .01 5.33 N 19.8z~ W .05 3.27 0-30 N 49-33 q.37 0-50 N 79-17 3.27 0-15 N 59- A 3.27 0-30 N 50-45 3,34 0-15 N 82-39 7.02 N 22.62 W 8,88 N 26,52 W lO.Oq N 29.56 N .06 11,92 N 32.24' W ,06 13-22 N 35.27 '~ .07 STA. TI ON BISTANCE .01' .,~ 10.91~ i2,62' 13 17.16' 18.z~7~ 23.69' 27.97~ 31.22' 3~+ .37'~ 37,66~ DISPLACEMENT GE AR I NG AT N 26-36 AT N 79-25 AT N 79-56 AT ,~,~ 80- 9 AT N 68.-~+5 AT N 58-19 AT N 59-22 AT N 6g-19 AT N 73-5'7 AT N '/~-57 AT ,~ 72-46 AT N 71-29 AT .~? 71-19 AT N 69-q3 AT N 6S-27 THE HORIZONTAL DISPLACEMENT AT THE DEPTH 7010 FEET EQUALS 37.66 FEET AT N 69-27 OF INRUN VERUS OUTRUN CLOSUF. E DIFFERENCE = 6,29 FEET, ! INDUSTRIES i. ~-~~i OILFIELD PRODUCTS GROUP, DRESSER INDUSTRIES, IMC. 721 WEST FIRST AVENUE, ANCHORAGE, ALASKA 99501 January 15, 1980 Union Oil Compsny P. O. Box 6247 Anchorage, Alaska Gentlemen: 99502 We would like to take this opportunity to express our ap~preciation to you for allowing Magcobar to participate in the drilling of your well, Kenai Beluga Unit 41-7, in.,the Kenai Gas. Field. Enclosed you will find the following: 1. Well' History Sheets 2.~ Daily Well Activity Notes and Comments 3. Material Usage Summary If there are any questions on the material enclosed, or on any other aspect · of the well we were involved, with, please do not hesitate to contact us at your convenience at our Anchorage office. Once again, thank you. Very truly yours, DRESSER OILFIELD PRODUCTS FF/ra Dick Bur~s Sales Engineer Jim Brown Sales Engineer Enclosure PAGE i OF, 4 ......... ~ UNION OIL COHPANYl l POLYMER 20" 113' --- M gcobO .... , K.B.U. 41-7 KENAI GAS FIELD NOVEHBER 22, 1.979 13-3/812425' ~17~" 6~+~56[ .... i3~-~'~2~i~q ~T ...................... ~'~:'~ ......................... ,,,~.,.~.o,~r~ ............. BRINKE~IOFF RIG #43 KENAI DECEMBER 13, 1979 ; , 9-5/8 7026' 12~" [::] t~ ...... ~t~ ,tu,o s~nv,c~s [::] BROWN/BURNS AI.AS~ [tow ......... ~[ts' --- ] ~ . DATE URED MUD VIS. TEMP PV. YP PH F U O FLU O ~ M~ CHLORIDE ~ ~ ~ SOL ~PTH WT. SEC. ,~ 0 / ,0 0 ~'~%~ 3- ~Z~ ........................................ ~ ....... L ......... / _ .......................................................... L ........ [n~Jnee~ o[i TOcaL~on/r~ggJng up, R~E~ng up. ~zZ~0.J ....... I l ...... J_ L ........ · .... ] .... L.__L .............. l .......... l ......... L ....... J ....... ,[ ........... I 1 _J .... 1.~.~ ..... 1.~_ ...... 1 ........ 1 ...... ] ...... ~ .... I .... l_._l .... J .... J ...... ] [ .... l~_.I R~znE up/drive 20" conductor/fiZZ p~rs/m~x~ng mud. Riggin~ up/mixing mud/ri~ up QUADCO solids control system. Spud well/drilled ahead. -- Drilled 0 2514'/circulate bottoms up/POOH--RIH fo~ wiper trip, reamed to bottom/POOH, f~r cas:i.n~. !.!/~J~_~J~_iSP_ J~ _lz~_[!~._ _l~..~.Jl~l/_~_J~.~l/_l%~=z_J-~_J0~__.l_0_,..]. J_~00 ......... 1.4o~_J--J~.:l[_i[ Casing stuck ~ 154'/POOH/Rill--ream/damaged bell nipple--repairs/wiper run--ream to bottom. %~ZP.J~P]~!.~._lPP ~ t69 [].~2 J~lY.8~O.S[~- JO.t ~0.] ~0 Jtr 12_J..__~3_,J Circulate bole clean/POOiI/ran casing to bottom. Problems with cementing--changed companies/circulate casing. Cemented/WOC/top cement job/pressure test casing head/nipple up. ~qipple up/test BOPE/RIU--drilling. . . ... Drilled ahead/survey every 500'. ~illeO ahead/short trip ~ 4500'--tight~--~O~~a~~~d., .... ' ..... Drilled ahead--trip for bit ~ 5604'/RIH--drilled ahead. POOIt 0 6,130'/RIH--hit braes, worked to bottom/drilled ~ 6290'--POOt~ %or ~t. . Drilled 0 7~OlO'/short trip/circulate bottoms up/PO0[l for lo~s. Logged/Rill--drilled ~ 7025'/circulate--POOH for casinK, -- tun, cement 9-5/8" casin[/lost ~ 75 bbls. of mud during displacement. ~ipple up--test BOPE/pick u~ new BHA--Rllt to shoe/level derrick. ~est casing/drill float collar~ shoe/pressure test formation/POOlt/logs. , Drilled ~ 7120'/CBU/POOH--RIH with core barrel. BELOW LINE FOR OFFICE USE ONLY }~TERIAL USAGE PAGE PRODUCT Hagcobar Nagcoge 1 Caustic Soda Ben-ex Soda Ash Calcium Chloride Lhmvis Sodium Bicarbonate Ammonium Nitrate Drispac Sperseae C~IC Engineering Se. trice (NOVEHBER 18 - DECEIqBER 8, 1979) AMOUNT USED UNIT COST 145 sx. 649 ~5 sx. 23 51 sx, 26 sx. 28 sx. ', ~ SX. 30 sx. 21 days $ 12.83 13.84 27.73 15.61 24..1i 23.00?'- 389.55 31.61 20.00 158.28 30.47 156.14 340.00 TOTAL COST PAGE ~1 TOTAL COST $ 1,860.35 8,982.16 998.28 858.55 568.33 1,173.00 10,128.30 885.08 160.00 1,266.24 914.10 780.70 7,140.00 $35,715.09 2 4 PAGE__ OF___ UNION OIL CObtPANY i20" ]J~3_!_ ---- rlEtD ~UO DAT£ i SUnFAC~ K.B.U. 41-7 _KE.NA!_._GAS FIELD__ CONTRACTOR COUNTY/PARISII T D. DATE INI EIIMEI~IA'I E I ~ '.zoz~__ ~~ ___B R! N KEg~Q FF_._g I G._~/+_3 _~EBAI . ~ '" ' 8~" U ~ . 5-~ 72~0' ~.~ o.,tt,~o ~u,o s~.wcts ~5~ BROWN/BURNS ALAS~ ~ _M .... ~ .---~ ........... ~-q . = __ ~ ........... ,= ........... DATE URED MUD VIS.TEMP PV. YP.O/10 PH FLUID FLUID ~ Mf CHLORIDE G ~ ~e~' O~ O~ ~ ~ I~ O ~ O~ ' I ~ I~ ~ ~t ~ I ~ ~ ~ P CosTMUD DEPTH WT. SEC. LOSS LOSS ~ ) ppm ~ ~ % ~ ~ ~ ~c ~Z5c~ ,, 200°; ~ ~ ~ 12/9' 7129 80 55 92 ~L ~_~_~._~____,Z~.~ 5 0.4 1.1 600 tr_..l~._8~Z=~__._' ................. RIH to core--well Elowed/ctrcula~e gas--~nc~ease weight ~ 80 PCF/POOH--serv~ce core bb~.--RIH ~o core. Co,ed ~ 20~--recovered 1.4~/~Ifl wiCh b~C--d~11~ng. Drilled ~ 7234~--POOH/RIH--core 20~/POOH, ~led B 72~0~6i~u~.~teZE~6~g~gin8. '--- ... ' ....... LOEging/diseard mud--clean pits. Nix~nE calcium chloride. Mixed brine/circulate and fltsplace mud ~ith brine. zF_~91z~n_ 17~ ...... I~_ .t z.9._t!~_~_~_l~_:_a_D. A._ I I___1 ..... I_2~0~E9.kA~E_L___] ...... [ ..... L~_&~g.I ...... i_L_J J ...... L .... 1 .... 1 ....... [ .... I .... 1.~_ .... I POOll/cal/per log/under reamed hole--IS'. ~nderrea~t. nE/POOll--riE up ~o run liner/ra~ 5~[" liaer. ~n liner, packer--hung liner ~ 6,290'--set ~ 7,240'/Eravel pack. ' Gravel pack/EOOB/cheek for [lo~--no~e. Test BO~E/~lll pickin~ up 3.~'' RII-I ~ith D.P./testinE. Test tn~/ensinee~ released. Engineer on location/kill welllRIH and set bridge pluE. _ LoggSn~/R~H ~th 8~i" b~t and cas~n~ sc~aper/cSrcu~ate--POOH .... ~es tin~-- f Jow~n~ ue~. 'resting/f~a~ng ~e~. rest~n~--[~a~in~ uell ..... ~esting/c~cu~atJng k~ we~/reduce ue~ht to ~ 74 PCF. ~OOtt/~iH ~ith RTTS/set b~dge p~ug ~ 6320~/test~n~. BELOW LINE FOB OFFICE USE ONLY MATERIAL USAGE PAGE ~2 PRODUCT Magcobar Magcogel Drispac Baravis Calcium Chloride Magcoflol Preservative Dextrid Aluminum Stearate ~tg[neering Service (DECEMBER 9 - JANUARY 1, 1980) AL~UNT USED UNIT COST 1,207 sx. 59 5 SE. 23 sx. 2,574 sx. 1 drum 2 sx. 57 sx. 1 .~I~days $ 12.83 13.86 158.28 203.90 23.00 864 70.98 72.08 74.93 340. O0 TOTAL PAGE ~2 TOTAL FROM PREVIOUS TOTAL COST TOTAL COST $15,485.81 816.56 791.40 4,689.70 59,202.00 864.61 141.96 4,108.56 74.93 7,140.00 $93,315.53 35,715.09 $129,030.62 PAGE, 3 0 F./~ __ MA~, 1 .,20 ...... _113 ' ~_~0_~__0~ .C...O.~.~._X ............................... RO~-,'~B~B ....................... " -- K.B.U. 41-7 _~_N..AI_'__G_._AS___F_.I.~_LI)_ ............._ .N_ .0. .V. E_ H!?, _I~ .R__ _2_2.. , 1979 !.3._-.3]~_"_.2=_4;Z5._ ..... _.t.~" CONTRACTOR COUNT¥/PAR$S,H TO. IDATE ,, ~ BRINKERIIOFF RIO tt43 KENAI ~=5_f8_'_! .... 7Cl2f.~_ ! r':_I--ll ! '7,7/.(11 ' 01~11 c:~ [~,t t,~; ~ U,D s~,v,c~ ~ r_~ B F, OWN/ B URN S AL_A_S_ ~ ................ L ~).~ ..... C4,-~- ,- ....... 'a fLOW ~ GELS [ ~ P-I ' [)ATE DRIED MUD VIS,1EMP PV. YP. PH FLUIDFLUID ~ M~ CHLORIDE S~/~OL ,'-~ I--4 MUD DEPTH WT. SEC. LOSS LOSS :~] ppm 1-4 ,%'- COST L~F I~, 0 10 [3 mg/I i ~ r~ c 110~ ~ .... ~,~ m !/_2. .... 6_4.5Q .... 7_4_ .... 3_1. ..... 7_.0__j _3_ .... .], ...... o__/1__._._ 7__.._2_._6___..._6 ....................... _l_~l_.,_Q0._O.u.8_.~k_ L_Z ........................ ............................ ---[ .; -~---~ Testing/kill ~ell/test bridge plug/POOIt ~tth packer--kill ~e11. -~O..__1~_~_~_o___..7~_ ....... 1~_ l. zo__L_~_._[t'__16_J_~__Lz_..~__l.6.,m_l .... I _.1 ....... [ 'l~q,oool ~l_.k-]_~___L___l ........ 1 .... 1 ........ [ ..... I .... l .... 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I 1. .1 _l [ ............. ~ELOW LINE FOR OFFICE USE ONLY MATERIAL USAGE PAGE #3 PROUUCT Engineering Service QIJ/kDCO UNIT (JANUARY 2 - 4, 1980) AMO b~T USED - 3 days I day 29 days UNIT COST $ 340.00 TOTAL PAGE ~3 TOTAL FROM PREVIOUS TOTAL COST 1,525.~ 1,625.00~ TOTAL COST $ 1~020.00 $ 1,020.00 $129,030.62 $130,050.62 1,525.00 47~125.00 $48,650.OO COST RECAPITULATION DRILLING OPERATIONS (NOVEMBER 18 - DECE~ER 13, 1979) PRODUCT UNIT COST ~gcobar $ 12.83 Ma§cogel 13.84 Caustic Soda 27.73 Ben-ex 15.61 Soda Ash 24.71 Calcium Chloride 23.00 Duovis 389.55 Sodium Bicarbonate 31.61 Nitrate 20.00 Drispac 158.28 Spersene 30.47 CMC 156.14 BaraviS 203.90 Magconol 864.61 Preservative 70.98 Dextrid 72.08 Aluminum Stearate 74.93 Engineering Service 340.00 AMOUNT 1,352 sx. 708 sx. 36 sx. 55 sx. 23 sx. 51 sx. 26 sx. 28 sx. 8 sx. 13 sx. 30 sx. 5 sx. ---- ---- ---- ---- __ 26 days TOTAL COST $17,346.18 9,798.72 998.28 858.55 568.33 1,173.00 10,128.30 885.08 160.00 2,057.64 914.10 780.70 ---- ---- ---- ---- __ 8,840.00 COMPLETION/TESTING (DECEMBER ].4 - J~UARY 4, 1980) AMOUNT TOTAL COST 2,574 sx. 59,202.00 __ 23 sx. 4,689.70 1 drum 864.61 2 sx. 141.96 57 sx. 4,108.56 1 sx. 74.93 19 days 6,460.00 PAGE 4 OF 4 $54,508.86 $75,541.76 COMPLETION REPORT UNION OIL CO 6YROSCOPIC SURVEY TANGENTIAL METHOD OF COMPUTATIONS COMPUTED FOR SDC BY F ~ LINDSEY G ASSOC 19 DEC 79 WELL KBU K B ELEV 101FT JOB { 3795 ) RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I 8 M ELECTRONIC CONPUTER Ai~ka Off & &.:s gons, ~'ommission TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D ~ SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES CLOSURES D I STANCE ANGLE DOG LEG SEVERITY DEG/IOOFT 0 0 0 0,00 -101,00 N O,OOE 500 0 45 499,95 D98,95 N83,54W 1000 0 30 999,93 898,93 N75,50W [500 0 ~5 1499,89 1398,89 NTJ,Jgw 2100 0 15 2099,89 1998,89 N69,58W 2200 0 [5 2199,89 2098.89 N30.DgE 2300 0 15 2299,89 2198.89 NBTe28W 2400 0 30 2399.88 2298,68 550,135 2600 O 45 2599,87 2498,87 2700 0 4~ 2699.86 2595-86 N47,69W 2800 0 ~5 2799.85 269S.85 2900 0 45 2899.85 2798.85 3000 0 ~5 2999.'8~ 2898,8~ $76,78W 3100 'O &5 3099e83 2998,8~ $70,79W 3400 0 a5 3399.8! 3298,81 537.09W 3500 0 15 3~99.81 3398,81 $3'3,24W ~600 0 15 3599.81 3498o8~ $33.5~W 3700 0 15 3699.80 3598,80 SS3.68W 3800 O 30 3799.80 ~698.80 $73-83W 3900 0 ~5 3899'79 3798.79 ~3~.98W 0. 5 0. N 1 N 3.9~ N ~.09 N 4.~6 N 4.25 N ~,71 N 5-50 N 6,38 N 5,27 m 5,~2 N 5,12 N ~,69 N 4,01 N 1,92 N 1,56 N 1-19 N 0,93 N 0,69 N 0,36 $ 0.00 W 6,50 W 10.72 W 16,92 W 16,92 W 17,37 W 16,70 W 18.48 W 19,49 W 20.13 w 21,43 W 22,71 w 23,94 W 24,49 W 26,07 W 26.31 W 26.59 W 26.90 W 27.7a W 28,51 W O.O0 5 0 0 0 w 6,54 N 83 3Z 23 w 10.88 N 80 19 30 W 17.37 N 76 5~ 48 w 17.37 N 76 53 ~8 W 17.80 N 76 43 4 ~ 17e68 N 75 22 5 ~ 18,02 N 7~ 30 ~5 ~ 17,2B N 75 ~2 36 W 18.07 N 7~ 52 3 W 19,29 N 73 24 33 ~ 20,47 N 71 49 10 w 20,8i N 7~ 19 40 w 22,11N 75 4B 12 W 23,28 N 77 17 12 w 24,40 N 78 54 43 w 2~o82 N 80 41 34 w 26,t4 N 85 46 29 w 26.~ N 86 ~6 1~ w 26,5~ N 87 25 2 w 26,92 N 88 0 2 w 27.75 N 88 33 44 w 28e51 $ 89 16 15 w 5ECTI~ DISTANCE 0.000 O.00 0.150 6*54 0,053 10,86 0,051 t7.25 0.150 17.25 0,2~0 17.67 0,~83 17,~9 0e279 17.79 0-746 17,06 0,998 17,85 0-256 18J97 OEO&7 20,0/ 1.156 0.807 21'90 0.2~8 2~.13 0,078 24,31 0.~19 2~,78 0,~01 0,001 0,0~7 0.279 27,65 0.469 20.D0 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY ! B M ELECTRONIC COMPUTER TRUE NEASe DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. 4000 0 15 3999,79 3898.79 4100 0 30 4099-79 3998.79 N59.06W 4200 0 30 4199,78 4098.78 4300 0 45 4299.78 4198.78 N55,B6W q400 0 15 4399.77 4290.77 $36,78W 4500 0 45 ~499.77 4398,77 $37.38w 4600 0 45 4599.76 4498.76 $27.99~ ~700 0 45 4699,75 ~598,75 $38.59w 4800 0 15 4799.75 4698,75 N48,83~ ~gO0 0 30 4899.74 4798.7~ N~2-2~W 5100 0 t5 5099.7% ~998,74 $50.$8E 5200 0 15 5199.74 5098,74 5300 0 ~0 5299.73 5198.7~ ~O0 0 15-.. 5399,73 5298.7~ N78.~6~ 5500 0 45 5~99.72 5398,72 NS'7,96W 5600 0 15 559'9.72 5498.72 N60,34W 5700 0 0 5699.72 5598,72 5800 0 15 5799.72 5698.72 5900 0 15 5899.72 5798.72 6000 0 ~0 5999,72 5898.72 556,93E 6~00 0 [5 ~099,72 5998,7~ 6200 0 30 6199,?~ 609~.7[ N33,73~ 6300 0 15 6299,71 6198,71 6400 0 15 6~99,71 6298,71 N12.SOE 6500 0 ~5 6499,70 6398,70 6600 0 30 6599.70 6498.70 6700 0 15 6699.70 6598.70 $80.69E 6800 0 15 6799,70 6698.70 TOTAL COORDINATES 0.72 0.27 0.16 0.90 0,55 0 1 2 2 ~.07 1.35 1,04 0,46 0,32 0,27 0,l~ O.~4 0,05 0.7S 2.65 C L O $ U R £ 5 DISTANCE ANGLE D M S DOG LEG SEVERITY SECTION DEG/IOOFT DISTANCE 28,76 W 28.77 $ 8~ 33 ~5 w 0-500 29.51W Z9.51S 89 28 2 ~ 0-546 30.26 W 30.26 N 89 40 47 W 0-003 30.10 31e34 W 31.35 N 88 20 55 ~ 0.253 31-25 31,60 W 31,61N 88 59 43 ~ 0.780 32,40 W 32e~0 $ 89 8 26 W 0.500 33,83 ~ ~3.9~ $ 85 29 ~b ~ 0-139 3~.16 W 34,2½ S 86 I 6 ~ 0,801 33.69 3~'~!~ii~ 34,79 $ 87 B ~9 ~ 0.253 3~32~W 35,34 $ 88 15 1 ~ 0-005 34.99 34.99 W 35.01 $ 87 ~6 42 ~ 0,7~8 ~4,63 35,29 W 35.30 $ 88 18 30 W 0.~99 ~7.b7 ~ 37,67 5 89 30 9 ~ 0.50~ 37,41 38,05 W 38.05 $ 8.9 49 57 ~ 0.54~ 38.05 ~ 3~,05 $ 89 ~9 57 ~ 0,250 ~7. 37,65 W ~7.65 $ 59 35 I ~ 0,250 37.~0 W 37,80 N 89 ~7 4~ ~ 0,~57 ~7.59 37,07 ~ 37,07 $ 89 28 22 ~ 0-717 36.81 37.25 ~ 37,25 N 89 5~ ~7 ~ 0.723 ~7,03 37.73 ~ 37.7~ N 8~ 48 a5 W 0-257 ~7.59 38.00 W 38,O1N 68 17 ~7 ~ 0.251 37.90 ~ 37.93 N 87 38 57 w 0,210 36e48 W 36,62 N 85 2 1~ W 0.3~2 ~b.61 36,17 W 36.34 N 54 26 ~4 W 0,'~20 RECORD OF SURVEY ALL CALCULATIONS PERFORNED BY ! B M ELECTRONIC COHPUTER TRUE MEASe DRIFT VERTICAL DEPTH ANGLE DEPTH O M SUB DRIFT SEA DiREC DEG, !0 0 15 6899070 6798070 N[5,5~E 950 0 15 6949,70 6848,70 N83088W 7010 0 I5 7009,69 6908069 N82,66~ TOTAL COORDINATES 3,93 N 36005 3,96 N 36027 3,99 N 36053 BOTTOH HOLE CLOSURE 36074 FEET AT N 83 ~5 24 W C L O S U R E S DISTANCE ANGLE DOG LEG SEVERITY DEG/[OOFT 00763 ~60A8 00009 36,7A INTERPOLATED TRUE VERTICAL DEPTHS. COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE CODE MEASURED VERTICAL TOTAL C~.RDINATE5 C L O $ U R E SUB NAME DEPTH DEPTH DISTANCE ANGLE SEA D M MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 201 201. 100. 301 301 · 200. 401 ~+01- 300. 501 501.. 400. 601 601 · 500. 701 701,, 600, 801 801 · 700, 901 901. 800,, 1001 1001',, 900. II01 110'1- i000, 1201 1201. llOO* 1301 1301. 1200. lZ+O1 1401 · 1300. 1501 150i . 1400. 1601 1601 * 1500. 1701 17'01 · 1600. 1801 1801. 1700. 1901 190'I. 1800. 20'01 2001. 1900. 2101 2101. 20:00,, 2201 2201- 2100, 2301 2301. 2200, 2~0'1 2401 * 2300- 2501 2501- 240'0* ,2601 2601, 2500, 2701 2701 * 260'0. 2801 2801. 270'0* 2901 290I. 2800. 3001 3001 · 2900. 3101 3101, 3000. 3201 ~201. 3100. 3301 3301e 320'0- 3401 3401, 330'0e 3501 3501 · 3~00, 360 1 360.1 · 350Oe 0*29 N 2.61 0.59 N 5.21 0.73 N 6.51 0.95 N 7,35 1.17 N 8,,20 1.39 N 9.0~ 1.61 N 9,,89 1.83 N 10.7~ 2.25 N 11,97 2,67 N 13.A1 3.09 N 1~.~5 3e52 N 15.69 3,93 N 16.92 3.93 N 16.92 3.93 a 16,92 3,93 N 16e92 3,93 N 16.92 3.9~ N 16.92 ~,17 N 17,11 ~.80 N 17.36 ~,25 N 16,71 ~.72 N 17,45 5.51N 18,49 5.37 N 19.~6 5",2? N 20.15 ~.~2 N 21,~5 5,11N 22.72 4,68 N 23,95 ~,00 N 2~,50 2.95 N 25,29 1.92 ~ 26,07 1,19 ~ 26,~6 NEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, .. TRUE ~EASURED VERTICAL SUB ND-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 3701 3701. 3600. 0 0 0.93 N 26.91 ],801 3801., 3700. 0 0 0.68 N 27,,T5 3901 :~g01 · ~800, 0 0 0,36 S 28,51 4001 400 ].. :~900e 0 0 0.71 S 28.77 4101 ~101. 4000, 0 0 0,~6 S 29.~ 4~0~ 4201, 4100, 0 0 0,17 N BO,2? 4~01 4301. 4200. 0 0 0,89 N Ml,~4 4401 4401. 4~00. 0 0 0.54 N ~1,6[ 4501 4501. 4400. 0 0 0.50 S ~2,40 4601 4601. 4500. 0 0 1.65 ~ ~*02 ~70~ 470~. 4600, 0 0 2.66 S ~e83 4801 ~801. 4700, 0 0 ~.~6 $ ~4,16 ~901 4901, 6800. 0 0 1.72 S 36,7D 5001 5001. ~900., 0 .~G 1.08 5 35,~2 5101 5101, 5000, 0 *~ 1.~5 $ 36,99 5201 5201. 5100, 0 ~ ?~ 1,0~ S 3~,30 5301 5301. 5200. 0 ~ 0..45 S 35.9~ 5501 5501, 5400. 0 0 0,32 $ ]7,68 5601 5601. 5500, 0 0 0,11 S ~8,05 5'701 5701. 5600. 0 0 O.li $ 38.05 5801 5801. 5700. 0 0 0,26 S 37,65 5~01 5901. 5800, 0 0 0,12 N ~7,79 6001 600~. 5900. 0 0 0,3~ 5 ~7,07 6101 6101- 6000. 0 0 0,06 N ]7,26 6201 6201. 6100. 0 0 0.7~ N 37,7~ 6301 6301. 6200. 0 0 1,13 N 38.00 6401 6401. 6300, 0 0 1.~7 N 37,89 650! 6501. 6400. o 0 2,65 N ~7,18 560] 6601. 6500. 0 0 3,16 N ~6,4~ 6701 6701. 6600. 0 0 3.10 N 36.05 6801 6801. 6700. 0 0 3.52 N 36-16 6901 ~901. 6800, 0 O ~,96 N ~6,06 INTERPOLATED VALUES FOR EVEN 10,00 FEET OF MEASURED DEPTH, TRUE ~4EASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL COORDINATES 1000 999, 898, 2000 1999, 1898, 3000 2999, 2898, ~000 3999~ ,3898. 5000 ~999t 4898. 6000 5999, 5898. 1.82 N 10.72 W 5,12 N 22.71 W 1,07 $ 35,32 W 0,3~ S 37,07 W COMPLETZON REPORT UNION OIL CO GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDC BY F H LINDSEY & ASSOC 19 DEC 79 WELL KBU 41-? K 0 ELEV 101FT JOB (3795} RECORD OF SURVEY ALL CALCULATIONS PERFORHED BY ! B N ELECTRONIC COMPUTER TRUE NEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH O M SUB DR I F T SEA DIREC DEG · TOTAL COORDINATES C L 0 $ U R E S DISTANCE ANGLE D DOG LEG SEVERITY SECT' DEG/IOOFT UISTANCE 0 0 0 0,00 -101,00 N O,OOE 500 0 4~ 499.98 398,98 N83,5~W 1000 0 30 999,95 898,9~ N75,SOW [500 0 45 1499e92 1398e92 N?[olgW 2000 0 0 1999,91 18.98,91 $30,16W 2100 0 15 2099,91 1998,91 N69e58W ~200 0 15 2~99,90 2098,90 N30,59E 2~00 0 ~5 2299e90 2198,90 N37,28W 2400 0 ~0 2~99,90 2298-90 $50,13E ~'~OO 0 ~0 2~99.,90 2398,90 N~?e98W ~600 0 45 2599,89 2~98,89 N52.8~ ~'700 0 4~ 2699,88 ~598,88 N½7e69~ 2800 0 45 2799e87 2698,87 $3[~48W 2900 0 4.5 ~899,87 2798,87 N8~,39~ ~000 0 45 2999,86 2898.86 $76,78~ 3100 0 45 3099.85 2998e85 &TO,79W 3200 0 30 3199.8~ ~098,8~ $38,9~W 3400 0 45 3399.83 3298,83 S~7,09~ ~700 0 15 3699,82 3598.82 $5~,68W 3800 0 ~0 379.9,82 3698,82 $,73,83W 4100 O ~0' 4099,81 3998,81 N59.06W 0 4.0! 4,42 4,88 5,72 5,56 5,01 4,57 2.2~ 1.~2 1.16 0,84 0.05 0,76 0.89 0.00 W 1.99 W 7.35 W 12,57 W 15.40 W 15.7~ 15,42 l~,T& 16-66 17,66 18.80 19,91 21.21 22.47 23,35 24,69 25,73 27*70 28,28 0.00 5 0 0 0 w 2.99 N 41 ~6 1l W 13,45 N 69 I0 11W 15,84 N 76 24 18 w 16.01N 76 ~7 57 w 16,22 N 7~ 39 42 w 16,~5 N 7~ 17 20 w 16,33 N 7~ §1 O ~ 1.7,3~ N 7~ ~9 8 ~ 18,57 N 72 2 58 w 19,60 N 7~ ~1 16 w 20-53 N 75 51 18 w 21.78 N 76 52 56 W 22.93 N 7~ 29 1W 23,b8 N 80 22 41 W 24,79 N 8~ ~8 59 W 25,2~ N S6 31 55 w 25,46 N 87 22 5~ W 25,75 N 88 6 ~2 W 27,20 S 89 53 1 w 27,71S 88 24 39 w 28,29 $ 88 1t 11 w O.000 0.O0 0.150 2,27 0.050 7,72 0,05'0 13.11 0.150 15.77 0,250 15,94 0,383 16,12 0,279 16,20 0,250 15,92 0,99~ 0.250 [7,17 0,067 0,807 20,4t 0,258 21,69 0,250 23.67 0,125 2~.77 0,500 25,~7 0,00! 0.250 0,250 26,93 0.500 27,33 0.250 27,~9 UNIQN KBU 41-7 GYROSCOPIC SURVEY 19 DEC 79 ,JOB{ 3795 RECORD OF SURVEY ALL CALCULATION5 PERFORMED BY I B M 6LECTRONIC COMPUTER TRUE NEAS, DRIFT VERTICAL. DEPTH ANGLE DEPTH D N SUB DRIFT SEA DIREC DEG. 4200 0 30 4199651 4098.81 N59,46W 4300 0 45 4299.80 4198,80 N55e86W 4400 0 15 4399,80 4298.80 4500 0 45 4499,79 4398,79 537,38w 4600 0 45 459.9,78 4498e78 4700 0 &5 4699.78 4598,78 538,59W 4800 0 15 4799,77 4698,77 4900 0 30' 4899.77' 4798,77 N~2,23W 5000 0 30 4999676 4898,76 5t00 0 15 5099e76 a998,76 $50,38E 5200 0 15 ~Z99,76 5098,?6 5300 0 30 5299.76 5198.76 5400 0 15 5399e76 529.8,76 N?Se56W 5500 0 45 5499e75 5398e75 57'00 0 0 5699,75 559~,T5 $62,74E 5800 0 15 579967~ 569867~ 5900 0 15 ~89967~ 5798e75 NZOe53W bO00 0 30 5999675 5898675 6LO0 0 ~5 6099,74 '5998e74 6200 0 30 6199,74 6098,74 6300 0 Z5 6299,7~ 6Z98,74 6400 0 ~5 6399,74 6298,74 6500 0 45 6~99.73 6398,73 6600 0 30 6~99,73 6498,73 N53,73E 6700 0 15 6699.73 6598,73 580*69E 6800 0 ~5 67'99672 6698.72 NIS.,ogw 6900 0 15 6899e72 6798e72 N~Se56E 6950 0 15 6949,72 68~8,7Z TOTAL COORDINATES 0,44 O. 13 0,00 0,69 1,79 1 1.5~ 1,32 0,86 0657 OeZ~ Oe ~0 0e03 0,3~ 1,23 2,18 2,98 3.76 3~9~ 4,62 ~677 CLOsuRES DISTANCE ANGLE D M $ DOG LEG sEvER I TY SECT ION DEG/iOOFT DISTANCE 29e03 W 29,03 5 89 6 ~6 W 0.003 28,~r' 29e95 W 29,95 N 89 4~ 37 w 0e250 29, 30,73 W 30.73 N 89 59 qO ~ 0.500 31,26 W 31,26 5 88 ~3 46 W 0.500 30eB6 31,96 W 32,01 5 86 ~7 18 W 06123 32.68 W 32.81S 84 57 11 ~ 0,139 31,97 33e46 W 33.59 $ 84 57 5 W 0,500 32,73 33,92 W 34,01S 85 ~7 22 w 0.250 33,26 34,51W 34.56 S 86 56 2 W 0,00~ 33,93 34e20 W 34e2~ 5 ~7 2~ 54 w 0,250 33.67 3~,0~ 34,03 $ 87 46 17 w 0,~99 33,50 34,48 W 34,49 $ 85 33 2~ W 0,250 3~e03 35.06 W 35e06 $ 8,9 3 ~5 W 0,250 35,9,2 W 35092 $ 89 14 24 W 0,500 35e5~ 36,?~ W 36,7~ $ 8.9 37 31 ~ 0,500 36,37 36,69 ~ 36,69 5 89 49 4 W 0,250 36,32 36e49 W 3,6e49 $ 89 ~0 28 W 0e2'50 35,8~ W 35e85 N 89 26 57 W 0,250 35,56 35,48 W 35,49 N 88 5~ 49 w 0,250 35,80 W 35.82 N 86 1 32 w 0-250 35.63 36,18 W 36,22 N 87 12 12 W 0,250 36,08 36e27 W 36,33 N 86 33 35 W 0,210 36.22 35,93 W 36,06 N B5 15 Jl w 0,500 35,19 W 35,39 N 63 53 15 w 0.250 36.57' W 34.79 N 83 32 8 W 0.250 ~4.7B 34,32 W 34,57 N 83 2 27 ~ 0-~20 3~657 34,32 W 34.63 N ~2 19 D? W 0,132 34,63 34,43 W 34,76 N 82 5 49 w 0,763 UNION KBU GYROSCOP!¢ SURVEY 19 DEC 79 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY ! B M ELECTRONIC COMPUTER TRUE NEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, 7010 0 15 7009,72 6908,72 'TOTAL COORDINATES ~,81 N ~.69 W BOTTOM HOLE CLOSURE 35,02 FEET AT N 82 6 20 W C L 0 S U R E $ DISTANCE ANGLE D M S DOG LEG SEVERITY DEG/IOOFT ~5,02 N 8,2 (~ 20 W 0,009 DISTANCE UNION KBU .~1"'7 GYROSCOPIC SURVEY INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVE~ DEPTHS TRUE CODE MEASURED VERTICAL TOTAL COORDINATES C L 0 5 U R E SUB NAME DEPTH DEPTH DISTANCE ANGLE SEA D ~ $ UNION KBU 41-7 GYROSCOP!C SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, 19 DEC 79 TRUE MEASURED vERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 201 201. 100 0 0 0,~9 N O,lq 301 301. 200 0 0 1.04 a 0,48 401 401. 300 0 0 1.66 N 1,09 501 501* kO0 0 0 2,23 N 2.00 601 601, 500 0 0 2.40 a 3.25 701 701. 600 0 0 2.59 N ~,~1 8.01 80~. 700 0 0 2.80 N 5,48 90~ 901e 800 0 0 3~03 N 6,46 1001 ~001- 900 0 0 3~22 N 7,~5 1i01 ll01, 1000 0 0 3.~6 N 8~2k 1201 1201. llO0 0 0 ~°?~ ~ g.20 l~O1 1~01. 1200 0 ~ ~.06 N 10,25 1401 1401, l~O0 0 ~ "o~2 N ll,~? -- 1DO1 1501, 1400 0 ~ ..... 4,78 N 12,58 160~ 1601. 1500 0 ~ 5cO1N 13e73 1701 1701. 1600 0 e ~,89 N 14.6~ 1801 18'01. 1700 0 O ~.~6 N 15,2~ 1901 19OIJ 18OO 0 0 ~.12 N 15,48 2001 2001~ 190'0 0 0 3.72 a 1~40 2101 ~101. 2000 O 0 3.6~ N 1~.~9 2201 2201. 2100 .0 0 ~.02 N 1~.71 2301 2301, 2200. 0 0 ~.43 a 15.7~ 2401 240.1. 23.00 0 0 ~,7) ~ 15.~1 2501 2501. 2400 0 0 ~27 N 15.77 2601 2601. 2500 0 0 ~.89 N 16.67 2701 2701e 2600 0 0 5~7~ N 17.67 2801 2801. 2700 0 0 5,55 N 18e80 2901 2901. 2800 0 0 5,02 a 19,92 3001 3001. 2900 0 0 ~.g4 N 21,22 3101 3101. 3000 0 0 ~,~7 N 22,~8 ~201 3201. 3100 0 0 3.~95 ~ 23~35' W 3301 3301- 3200 0 0 3,17 N 23,9& 3401 3&01, 3300 0 0 2,23 N 2~,?0 3501 3501- 3400 0 0 1-52 N 25e20 3601 3601e 3500 O' O 1-15 N 25o~ UNiQN KBU 4.1-7 GYROSCOPIC SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES ].9 DEC 79 JOB{ 3795) 3701 3701, 3600 3801 3801, 3700 3901 3901, 3800 4001 4001, 3900 4101 4101, 4000 4201 420!, 4100 4301 4301, 4200 4401 440 ! · 4300 4501 4501. 4400 4601 4601, 4500 4701 4701, 4600 4801 4801. 4700 4901 4901. 4800 5001 5001 · 4900 5101 5101. 50'00 5201 5201. 510.0 5301 5301. 5200 5401 .5401 · 5300 5501 5501. 540'0 5601 5601. 5500 5701 5701. 5600 5801 5801. 5700 5901 5901, 5800 6001 6001 · 5900 6101 6101. 6000 62:01 6201 · -6100 6301 6301, 6200 6401 6401. 6300 6501 6501. 6400 6601 6601. 6500 6701 6701, 6600 6801 6801, 6700 6901 6901. 6800 7001 7001- 6900 0,84 N 25,74 W 0.55 N 26,33 W 0,06 5 27,20 W 0.77 $ 27.70 W 0,89 5 28.29 W 0e44 S 29e04 W 0,14 N 29e96 W 0.00 $ 30,73 W 0.70 $ 31,26 W 1,80 $ 31.97 W 2.89 $ 32,69 W 2,95 $ 33,46 W 2,49 5 33,93 W 1,84 $ 34,51W 1.53 5 34,20 W 1.32 $ 34,01 W 0,86 5 34.48 W 0,57 $ 35e06 W 0.47 $ 35e93 W 0.23 $ 36-76 W 0,11 $ 36.69 W 0.20 $ 36.48 W 0.03 N 36,24 W 0.33 N 35.85 W 0.66 N 35,48 W 1.24 N 35.80 W 1,77 N 36.18 W 2.18 N 36,27 W 2.99 N 35.92 W 3,77 N 35.18 W 3.91 N 34,56 W 4.62 N 34.32 W 4.80 N 34.65 W UNION GYROSCOPIC SURVEY DEC 79 JOB13795! INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH, TRUE MEASURED VER T ! (AL SUB DEPTH DEPTH SEA TOTAL COORDINATES 1000 999, 898~ 3~27 N 7,34 W 2000 1999, I898, 3,7~ N 15,40 W 3000 2999~ 2898, 4.93 N 21,21 W 4000 3999. 3898. 0.77 $ 27.69 W 5000 4999, 4898, 1,84 S 34,~0 W 6000 5999. 5898, 0,33 N 3B,8~ W ¸ 'IOFtlZO NTAI, UNION OIL COMPA RADIUS i OF CURVATU GYROSCOPIC SURVEYi" SCALE,-i~"= ~0 I-' DEC'; , i i · . 8O0 1200 _.:. VERTICAL SECTION NION OIL ._.KBU 41-7 .R~DIU$ OF' CURVATURE GYROSCOPIC --SCALE j--I"=' I00,0 DEC._:Ig, 11979 (~'"ii Document Transmitta~ ' ' ' Union Oil Company of Calif'.. ,~'~- COMM + ~, ~. 11, 1980 ~as~ O&G Co~. ~. U~on Oil ~~~2 G[~I ~00~ Po~~ D~w '~ ~ 6~7 / !' '['3 ~oL~ ~c~rage~ ~ 99504 ~orage, ~ 99~02I STAT TF~... · ~,~,~ ~ ~o~o~,~= i I ! & 1 set Bluelines 11 511 5" Run 1, Run 2 5" BHC Sonic 2" 5" Sandstone of Curvature Survey & return FORM 1-2M02 (REV. 11-72) PRINTED IN U.S.A. Form No. 10-404 REV. SUBMIT lN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING OPERATIONS AND W RKOVER ,. , $. APl NUMERICAL CODE 50-133-20327 6. LEASE DESIGNATION AND SERIAL NO. A-028142 7. IF INDIAN'ALOTTEE OR TRIBE NAME O,L GAS [g WELL WELL OTttER 2. NAME OF OPERATOR UNION OIL COMPANY OF CAT_.IFORNIA A1c$~2 ~,,)!~ cs ,..:~ L;otl& b0rflff ADDRESS OF OPERATOR P.O. Box 6247, Anchorage, Alaska 99502 AllCJl0ra~ 4. LOCATION OF WELL 185'S & 4303'E of the N.W. cur. Sec. 7, T4N, RllW, S.M. S. UNIT FARM OR LEASE NAME Kenai Beluga Unit ~iOV~ L L NO. KBU 41-7 10. FIELD AND POOL, OR WILl)CAT Kenai Gas Field 11. SEC. T. R. M. (BOTTOM IIOLE OBJECTIVE) Sec. 7, T4N, RllW, S.M. 12. PERMIT NO. 13.REPORT TOTAL DEPTH AT END OF MONTH, CtlANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEIYFlt SET AND VOLUMES USED, PERFORATIONS. TESTS AND RESULTS FISHING JOBS JUNK 1N HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CttANGES IN HOLE CONDITIONS. 41 01/01/80 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' POOH and lay down test tools. RIH w/ 9 5/8" RBP and set @6230'. Spotted 16 sx. 20-40 sand on top of RBP and wait 2 hrs. Tagged sand @ 6209'. POOH. Installed 3 1/2" rams in lowest preventer and tested BOPE. RIH w/ test tools and set RTTS @ 6040', tail @ 6077'. Precharged drill pipe w/ 1320 psi field gas. Opened stimulation valve. 42 01/02/80 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' Rigged up Go Int. to perforate w/ 2 1/8" bi-wire guns f/ 6128' to 6132' DIL. Opened well to test and received 35 Bbls of CaC12 fluid and some 20-40 sand. Killed well. RIH w/ tools to tag RBP @ 6230' - no sand on top. Pressured up drill pipe to 1300 psi and reset RTTS @ 6183' tail @ 6220'. Opened well to test RBP and received 1~ Bbls CaC12 fluid and then dry gas. RBP is leaking. Killed well and POOH w/ test tools. RIH and latched onto RBP @ 6230' - unable to work RBP down hole. - Finally work RBP down to 6485'. Circ thru choke. Getting gas cut mud. 43 1/3/80 7290' TD 13 3/8" C 2425' 9 5/8" C. 7025 Complete circ. btms. up. Pick up on RBP and bullhead 15 bbls. CaC12 fluid down annulus to kill well. Pooh 10 stds. Circ. btms. up - no gas. Pooh w/RBP. RIH w/ OEDP to 6753' and circ. Pooh. RIH w/ 9 5/8" Baker RBP on Howco RTTS and set @ 6230'. Pressured up D.P. to 1300 psi w/field gas. Set RTTS @ 6200' and opened well to test RBP - no entry. Load up D.P. w/CaC12 fluid and pressure tested RBP w/1500 psi - OK. Spotted 15 sx. of 20-40 sand on RBP. ~ ',~--/~~~ Dist. Drlg. Supt. Feb 1, 1980 SiGNEc~ '~' TITLE ......... DATE ' NOTE~--fiepOrt on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Form No. 10404 ~REV. 3-1-70 ' SUBMIT 1N DUPLICATE STAT E O F A LAS KA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1o O,L GAS [] WELL WELL OTIIER 2. NAME OF OPERATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN.ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME 9. '~ ELL NO. KBU 41-7 10. FIELD AND POOL, OR WILDCAT 11. SEC. T. R. M. (BOTTOM ItOLE OBJECTIVE) 12. PERMIT NO. 44 13.REPORT TOTAL DE~H AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DE~'il SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED ItOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 1/4/89 7290' TD Tag sand @ 6209'. Pooh. Rig w/test tools & set RTTS @ 13 3/8" C. 2425' 6042', tail @ 6079'. Precharged D.P. to 1300 psi field 9 5/8 C. 7025' gas and opened well to test WSO perfs, f/6128' to 6132' DIL. Had medium blow in bubble bucket. Perforate w/Go. Int. 2 1/8" bi-wire gun f/6128' to 6138' DIL to increase rate. Open well to test - still had medium blow in bubble 45 1/5/80 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' Reperforate DST #2 f/6128' to 6138' DIL w/Dresser - Atlas 2 1/16" link-jet guns. Opened well to test. Rate increased from small blow. 46 _1../6/80 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' Rate increased from small blow to 1.21 MMCF/D and made + 6.5 bbls. fluid. Rate was still increasing. Killed well and Pooh w/test tools. RIH w/RBP retrieving tool and tagged sand @ 6205'. Wash to RBP @ 6230' and circ. 47 1/7/80 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' Retrieve RBP @ 6230' and reset @ 5914'. Positive test RBP to 2000 psi - OK. Spot 15 sx. sand on top - tagged sand @ 5899'. Retest to 2000 psi - OK. Pooh. RIH w/ Howco test tools and set RTTS @ 5551', tail @ 5588' Rigged up and tested surface manifold and.lines to ~000 psi. Precharged D.P. to 1250 psi. Opened stimulation valve. Rigged up and tested Dresser-Atlas lubricator to 5000 psi. RIH w/4' of 2 1/16" rigid jet perf. gun - had to pull out to change CCL. Had pressure increase to 1600 psi in D.P. while running gun. Bled pressure back to 1250 psi - it increased back up to 1600 psi @ 25 psi per 5 minutes. Killed well. Released RTTS and RIH to reset RTTS @ 5859', tail @ 5896'. Closed rams and tested csg. above RTTS to 4000 psi and RBP below RTTS to 5000 psi - Held OK. Pooh w/test tools. 14. I hereby certify that the foregoing is true and correct SIGNED TITLE DATE 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. ,Form No. 10404 REV. 3-1-70 ' SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL OTitER WELL 2. NAbtE OF OPERATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME 9. WELL NO. KBU 41-7 10. FIELD AND POOL, OR WILDCAT 11. SEC. T. R. M. (BOTTOM ttOLE OBJECTIVE) 12. PERMIT NO. 48 13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTtt SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED ItOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' 1/8/8o Pooh w/test tools. RIH w/retrieving tool and tag sand @ 5899'. Wash down to RBP @ 5914' and latch onto RBP. Pooh. Dropped RBP @ 270' - parted retrieving neck. RIH w/overshot and bowl and retrieve RBP w/25,000# pull. (Note: Found pieces of perf. gun bi-wire and bottom bull plug). RIH w/bit and scraper and tag sand @ 6705' above RBP @ 6799'. P.u. one std. and circ. hole clean w/HEC sweep. Pooh. 49 1/9/8o 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' RIH w/Baker RBP and set @ 5900'. Set RTTS and tested RBP to 5000 psi - OK. Spotted 15 sx. sand - tagged @ 5884'. Pooh. RIH w/test tools and set RTTS @ 5551' tail @ 5588'. Tested surface equip, to 3000 psi. Opened stimulation valve - had slight blow. Rigged up Dresser-Atlas. Drill pipe pressure built to 100 psi in 1 hour. Bled off D.P. Pressure built to 200 psi in 20 min. Bled off D.P. Pressure built to 800 psi while rigging down D.A. Killed well. RIH and tagged RBP @ 5918' (18' low) with no sand. Circ. and Pooh. RIH w/retrieving tool. 14. I hereby certify that the foregoing is true and correct SIGNED TITLE DATE 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. ,Form No. 10404 REV. 3-1-70 ' SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME OIL GAS WELL WELL OTltER 2.NAME OF OPERATOR $. UNIT FARM OR LEASE NAME 3. ADDRESS OF OPERATOR 9. ~Vl..LL NO. KBU 41-7 10. FIELD AND POOL, OR WILDCAT 4. LOCATION OF WELL 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. 13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS F1SH1NG JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 50 1/10/80 51 1/11/80 7290 ' TD 13 3/8" C. 2425' 9 5/8" C. 7025' Latched onto Baker RBP @ 5920' and RIH to 6,510'. Circ. btms. up - no gas. Pooh. RIH w/Howco RBP and set @ 5980'. Tested RBP to 3000 psi - OK. Spotted 15 sx. sd. (sand bridged off while displacing and parted mud line i: 4 places). Tagged sand @ 5941'. Pooh. RIH w/RTTS pkr. and stimulation valve and set pkr. @ 5553', tail @ 5586' Opened tool to bubble line. Pressure built to 20 psi in 1 hour. Opened to flare line. Well made rate of 600 MCF/D @ 80 psi with a fluid rate of 50 BPD CaC12. 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' Well has rate of 830 MCF/D @ 120 psi and 22 BPD CaC12 fluid. Rigged up Go. Int. and RIH w/Spinner - temper- ature survey. Logs showed wellbore entry @ 5907' (csg. collar) Pooh w/W.L. Killed well Reset RTTS @ 5681' tail @ 5711'. Test annulus to 2000 psi. RIH w/4' of tornado link jet gun w/4 HPF and perforated f/5905' to 5909'. Pooh Tested surface lines to 5000 psi. Broke down perfs. @ 2900 psi. Pumped in @ 10 CFM @ 2600 psi. Pumped 42 bbls. water ahead and squeezed, w/300 sx. cl. "G" w/ 3% Halad 22-A and 3% KC1. Displaced w/water Had final pressure of 2600 psi @ 1 5 BPM CIP @ 6:45PM 1/11/80, WOC for 3½ hrs, Released pkr, and Pooh· 14. I hereby certify that the foregoing is true and correct SIGNED TITLE. DATE 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. ,Form No. 10404 REV. 3-1-70' ' SUBMIT IN DUPLICATE sTATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING .,&.ND WORKOVER OPERATIONS WELL WELL 2. NAME OF OPERATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME 9. WELL NO. KBU 41-7 10. FIELD AND POOL, OR WILDCAT 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 52 1/12/80 7290' TD Test BOPE. RIH w/8~" bit and 9 5/8" csg. scraper. Circ 13 3/8" C. 2425' and cond. CaC12 fluid. C.O. cmt. f/5809.' to 5963' 9 5/8" C. 7025' (form cmt. to 5908' and stringers to 5963'). Pooh. RIH OE and spotted 7 sx. sand @ 5963'. Tagged @ 5941'. Pooh. RIH w/HOWCO test tools. Set RTTS @ 5553', tail @ 5586'. Precharged D.P. to 1300 psi and open Stimu- lation valve. 53 1/13/8o 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' Bled cushion off of pipe. Pressure increased to 400 psi in 20 min. Well made up to 2.25 MMCF/D rate and then appeared to kill itself. Killed well. Reset RTTS @ 5645', tail 5676'. Test surface lines to 5000 psi. Broke perfs, down @ 5500 psi. Pumped in @ 2900 psi @ 10 CFM. Pumped 42 bbls. water ahead and squeezed w/150 sx. Cl. "G" w/.3% Halad 22-A and 3% KC1. Displaced w/52 bbls. water. Had f'inal pressure of 4000 psi @ .25 BPM. CIP @ 12:45 PM 1/13/80. Held 2300 psi on squeeze for 3 hours. Pooh. RIH w/8½" bit and 9 5/8" csg. scraper to 5626' and circ. and cond. mud. 54 1/14/80 7290 ' TD 13 3/8" C. 2425' C,O. firm cmt. f/5794' to 5941'. Circ. and cond. CaC12 fluid. Pooh. RIH w/Howco test tools and set RTTS @ 5551', tail @ 5588'. Test lines to 5000 psi. Precharge D.P. to 1250 psi. Opened stimulation valve and pressure increased to 1500 psi immediately. Opened well to flare thru ~" choke to blow down precharge pressure. Opened to ½" and 3/4" choke. Produced 25 bbls. of rat-hole fluid and well making 3.0 MMCF/D. Rigged up Go. Int. to run Spinner - temp survey. RIH w/survey tool - could not get thru test tools. Pooh w/survey. 14. I hereby certify that the foregoing is true and correct SIGNED TITLE DATE 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. SUBMIT IN DUPLICATE ,Form No. 10~404 REV. 3-1-70 ' STAT E O F A LAS KA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME OIL GAS 2. NAME Of OPERATOR 8. UNIT fARM OR I EASE NAME KBU 41-7 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT 11. SEC. T. R. bt. (BOTTOM ttOLE OBJECTIVE) 12. PERMIT NO. 13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTlt SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE A~NI) ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 55 1/15/80 7290' TD 13 3/8" C. 2425' RIH w/spinner - temp. survey w/o centralizer. Confirmed all entry thru perfs f/5905' to 5909' Dil. Pooh. RIH w/perf, gun and perf. upper 4' of DST #3A f/5761' to 5765' for WSO. Open well to test. Well made 7.52 MMCF/D @ 400 psi w/no water or sand. Reran spinner - temp. log - showed 90% of entry from 5761' to 5765'. RIH w/perf, gun and perf. lower 4' of DST #3B f/5651' to 5655' for WSO. Open well to test. Well made 8.33 MMCF/D @ 650 psi w/no water or sand. RIH w/ perf. gun and perf. remainder of DST #3A f/5765' to 5775' and DST #3B f/5641' to 5651'. Open well to flare to clean up. Put well into system. 56 1/16/80 7290' TD 13 3/8" C. 2425' Well stabilized flow from DST #3A and #3B @ 11.63 MMCF/D into the system w/no water and no sand. Shut in and killed well. RIH to 5915' and circ. clean. Pooh w/test tools. RIH w/RBP retrieving tool and tag sand @ 5953'. Mix high vis. pill and C.O. sand and debris to RBP @ 5980'. P.U. RBP and reset @ 5450'. RBP would not pressure test. Retrieve RBP and well started to flow. Circ. bottoms up - getting gas cut fluid.' Attempt to RIH - RBP stopped @ 5515'. Bullhead 20 bbls. kill fluid below RBP. Circ. above RBP - well dead. Pooh w/RBP. 14. I hereby certify that the foregoing is true and correct SIGNED TITLE DATE 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. .Form No. 10~04 REV. 3-1-70 ' SUBMIT lN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. AP! NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 7.IF INDIAN'ALOTTEE OR TRIBE NAME 1. OiL GAS E3 WELL OTItER WELL 2.NAME OF OPERATOR 8.UNIT FARM OR LEASE NAME 3. ADDRESS OF OPERAIOR 9. WELL NO. KBU 41-7 10. FIELD AND POOL, OR W1LI)CA'I' 4. LOCATION OF WELL 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. 13. REPORT TOTAL DE~H AT END OF MONTH, "CHANGES 1N HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DE~H SET AND VOLUMES USED~ PERFORATIONS. TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ~NY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 57 1/17/80 7290' TD Finish Pooh w/RBP. RIH w/Baker RBP and set @ 5450'. 13 3/8" C. 2425' Test RBP to 4000 psi - OK. Spot 18 sx. sand on RBP. Tag sand @ 5423'. Pooh. RIH w/Howco test tools and set RTTS @ 5258' 2 7/8" tail @ 5295'. Test manifold and lines to 300~ psi. Precharge D.P. to 1250 psi field gas and open stimulation valve to test WSO - OK. Rigged up Go. Int. and test lubricator to 3000 psi. RIH w/4' perf. gun and perforate upper 4' of DST #4 f/5334' to 5338' Dil. Had pressure increase to 1780 psi. Pooh w/perf, gun. Open well to flare. Had fluid to surface in 9 minutes. Had rate of 6.23 MMCF/D @ 540 psi. Unl~aded rat hole fluid. Put well into system. Had rate of 8.56 MMCF/D @ 1100 psi w/no water and no sand. Rigged up Go. Int. to perf. remainder of DST #4. Opened surface valve but could not go in hole w/gun. Removed lubricator and found a cap had fallen off one of the charges and was alongside gun. Replaced charge and rigged up lubricator. Opened surface valve but still could not go in hole w/gun. Removed lubricator and added 1 sinker bar. Rigged up lubricator and still could not get gun down the hole. While working gun in lubricator, parted W.L. below grease head. Gun fell down into safety valve - could not close valve. Closed ~?~?!~ ~'~:~ ~ i: :~: ~ Go. Int. W.L. and rigged up lubricator. ~'~ .~.i,fi~! iji~f~ master valve and removed lubricator and gun. Rehead 14. I hereby certify that the foregoing is true and correct SIGNED TITLE DATE 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. ,Form No. 10~04 REV. 3-1-70 '. SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 1. 7.1F INDIAN'ALOTTEE OR TRIBE NAME WELL WELL OTllER 2.NAME OF OPERATOR 8.UNIT FARM OR LEASE NAME 3. ADDRESS OF OPERATOR 9. ~',ELL NO. KBU 41-7 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 58 :L/18/80 7290 ' TD 13 3/8" C. 2425' 9 5/8" C. 7025' 5~" L.f/7240' to 6920' RIH w/15' of 2 1/16" link jet perf. gun and perforate remainder of DST #4 f/5338' to 5353'. Pooh and rigged down Dresser-Atlas. Flowed well to clean up, then put into system. Well tested 10.48 MMCF/D @ 1140 psi w/no sand and no water. Killed well, Circ. and cond. CaC12 fluid and Pooh w/test tools. RIH w/Baker retrieving tools to tag sand @ 5413'. Could not wash thru sand. 59 60 1/19/80 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' 5½" L.f/7240' to 6920' :L/20/80 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' 5~" ' ' 2 L.f/7240 to 6920 Pump viscous pill - still could not wash sand. Pooh. Down 3½ hours to repair blocks. RIH w/bit and scraper and wash sand f/5413' to 5450'. Circ. and Pooh. RIH w/retrieving tool to RBP @ 5450' and circ. viscous pill. Retrieve RBP and Pooh. RIH w/bit and scraper to tag top of sand @ 6662'. Circ. and raise mud weight to 80 PCF. Pump viscous pill while washing down f/6662' to 6799'. Pooh. RIH w/Howco retrieving tool and latch onto RBP @ 6799'. Release plug and wait 4 hours - had no fluid loss or gain. Pooh - plug stopped @ 6459.'. Could not go down or come up. Released from tool. 14. I hereby certify that the foregoing is true and correct SIGN ED TITLE DATE 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed, Form No. 10-404 REV. 3-1-70s ~ SUBMIT !N DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING . _ND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. KBU 41-7 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT 11. SEC. T. R. 5,t. (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. 13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 61 1/21/80 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' 5½"L.f/7240' to 6920' RIH w/HOWCO retrieving tool on bumper sub and oil jars. Found pipe meas. error. Tagged RBP @ 6495' - in DST la perfs. ~umJ2~_~_RBPdown. Tried to work plug up - could ~pt.get past 6495'. RIH and set RBP '@ 6588' and Pooh. RIH w/8k" , , ~ tapered mill junk sub 9 5/8" csg. scraper, bumper sub, and jars. Reamed tight spot f/6495' to 6503'. Circ. btms. up and Pooh. RIH w/retrieving tool and latch onto RBP @ 6588'. Pumped viscous pill around system and Pooh w/RBP. 62 3_/22180 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' 5¼" L.f/7240' to 6920' Pooh and recover RBP (top cup on RBP was mashed down around body of tool). Rigged up Dresser-Atlas and ran CCi to tie-in top of liner to existing perfs. Rigged down Dresser-Atlas. RIH w/12 jts of 2 7/8" tbg. stinger on 3½" D.P. and C.O. sand f/7214' to 7240'. Circ. clean w/viscous pill and Pooh laying down D.P~. and tbg~ Installed 2 7/8" x 3~" rams and rigged up to run tubing. 14. I hereby certify that the foregoing is true and correct SIGNED TITLE DATE 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed, SUBMIT IN DUPLICATE Form No. 10-404 REV. 3-1-70~ ~, STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL OTItER WELL 2. NAME OF OPERATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN'ALOT'FEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME 9. ~'I..LL NO. KBU 41-7 10. FIELD AND POOL, OR WILDCAT 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. 13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTll SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 64 63 65 1/23/80 7290' TD Finish RIH w/dual 2 7/8" x 3 1/2" tbg. strings. Stabbed 13 3/8" C. 2425' into FB-1 pkr. @ 6920' and tested seals to 500 psi - OK. 9 5/8" C, 7025' P.U, and sp~ced out tubing st.~.- '"'xn~s', and installed tbg. 5½" L. f/7240' to 6920~ hanger. Displaced tubing annulus by pumping inhibited CaC12 fluid down L.S, Landed tbg~ w/Baker "FH" pkr. @ 6400~ and Baker "A-5" dual pkr. @ 5248'. Locked down hanger and rigged up Otis lubricator.9 R!H w/ 2 7/8~' "XN" plug in L~S. to set "FH' pkr~ 1/24/80 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' 5½" L.f/7240' to 6920' Set "XN" plug in nipple @ 6926'. Pressure up L.S. to set "FH" pkr. @ 6400'. Open "XA" sleeve in L.S. @ 6430' and test pkr. w/500 psi - OK. Close "XA" sleeve. Set "XN" plug in S.S. @ 5280' and pressure up to set "A-5" pkr. @ 5248'. Pull "XN" plug from S.S. and test pkr. w/500 psi - OK. Install BPV's, remove BOPE, install and test tree. Open "XA" sleeve in L.S. @ 6370' and displace fresh water down L.S. and up S.S. 1/25/8o 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' 5½"L.f/7240' to 6920' Finish dispt~acing tubing strings w/fresh water. RIH w/ Otis in L.S. and close "XA" sleeve @ 6365". Attempt to retrieve equalizing choke from "XN" in L.S. @ 6928'. Could not latch onto retrieving prong. Tool came out egg-shaped - appears to be going alongside prong. Made 2 trips to retrieve choke - could not. Gas lift fluid from S.S. to clean up Middle Beluga. RIH in L.S. w/ centralized overshot and retrieved choke. Retrieved "XN" mandrel from L.S. and open for flow. Tyonek Zone would not flow. Middle Beluga Zone now making 10/MMCF/D w/no water. Open "XA" sleeve in L.S. @ 5214' to drop fluid level in L.S. Tyonek still would not come on. Close 14. I hereby certify that the foregoing is true and correct SIGNED TITLE DATE 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Form No. 10404 REV. 3-1-70~ · SUBMIT IN DUPLICATE STAT E O F A LAS KA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING .ND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 1. 7. IF INDIAN'ALOTFEE OR TRIBE NAME OiL GAS [] WELL WELL OTHER 2.NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME 3. ADDRESS OF OPERATOR 9. WELL NO. KBU 41-7 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILl)CAT 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. 13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEFFH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND AaNY OTHER SIGNIFICANT CHANGES 1N HOLE CONDITIONS. sleeve @ 5214' and open sleeve @ 5291' in L.S. Lost weight on W,L. when opened sleeve. Pooh.. Left all tools and 23' of W.L. in hole. RIH w/I.B. & found fish in "XA" sleeve @ 5214'. 66 1/26/80 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' 5½" L.f/7240' to 6920' RIH w/W.L, spear. Worked on fish for 4 hours. Pooh. Recovered 12' of wire - no tools. RIH w/I.B. - Had rope socket up. RIH w/latching tool. Latched onto rope socket @ 5214' & tried to jar loose - could not. Sheared pin in latch tool. Pooh. Repaired tool and RIH. Latched onto rope socket and knocked fish down. Could not relatch onto fish. Pooh. Found pin sheared. RIH w/latch tool and pushed fish down to "XA" @ 6365'. Could not latch onto fish. Pooh. RIH w/different latch tool - could not latch onto fish. Pooh. RIH w/I.B. - have wire on top of fish. RIH w/wire grab. Pooh. - recovered bundle of wire. RIH w/latch tool & pushed fish to "XN" nipple @ 6928'. Latched onto fish & Pooh. Had total recovery. 67 1/27/80 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' 5½" L.f/7240' to 6920' Open L.S. to produce Middle Beluga thru "XA" sleeve @ 5291' to clean up. Close sleeve & flow Tyonek thru L.S. until clean. Had rate of 2.5 MMCF/D w/no water. Open "XA" in L.S. @ 6882' to dump fluid across Lower Beluga into L.S. Did not produce any fluid. Close "XA" @ 6882' and set plug @ 6882'. Open "XA" @ 6446' and opened Lower Beluga to L.S. to clean up. Had a rate of 4.21 MMCF/D from Lower Beluga w/no water. Closed "XA" @ 6446' and retrieved plug from "XA" @ 6882'. 14. I hereby certify that the foregoing is true and correct SIGNED, TITLE DATE 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. SUBMIT IN DUPLICATE .Form No. 10404 REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTItER 2. NAME OF OPERATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME 9. WELL NO. KBU 41-7 10. FIELD AND POOL, OR WILDCAT 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. 68 13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS. TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. z/28/8o 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' 5~" L.f/7240' to 6920' Retrieved plug from "XN" nipple in L.S. @ 6882'. Rigged down Otis. Open L.S. to produce Tyonek Zone - making 1.8 MMCF/D w/no water. Shut-in well. Begin rig down. 69 70 1./29/80 1/30/80 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' 5~" L. f/7240' to 6920' 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' 5½" L. f/7240' to 6920' Rigging Down. Rigging down. Released rig @ 1600 hrs, 1/30/80. 14. I hereby certify that the foregoing is true and correct SIGNED TITLE DATE 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Form No. 10404 REV. 3.1,70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL 2. NAME OF OPERATOR 5. APl NUMERICAL CODE 50-133-20327 6. LEASE DESIGNATION AND SERIAL NO. A-028142 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR P.O. BOX 6247, ANCHORAGE, ALASKA 99502 4. LOCATION OF WELL 185'S & 4303'E of the N.W. cor. Sec. 7, TbN, RllW, S.M. Kenai Beluga Unit 9. WELL NO. KBU 41-7 10. FIELD AND POOL, OR WILl)CAT Kenai Gas Field 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 7, T4N, RllW, S.M. 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES INSOLE sIzE~ CASING' AND CEMENTING JOBS INCLUDING DEPTtt SET AND VOLUMES USED, PERFORATIONS. TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED ItOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. i ~ ~'' ~ ' 10 11 12 13 14 12/1/79 12/2/79 12/3/79 12/4/79 12/5/79 5840'/824' 20" D. 134' 13 3/8" C. 2425' 6289'/449' 20" D. 134' 13 3/8" C. 2425' 7010'/721' 20" D. 134' 13 3/8" C. 2425' 7025'/15' 20" D. 134' 13 3/8" C. 2425' 7025'/0' 13 3/8" C. 2425' 9 5/8" C. 7025' Drilled 12¼" hole f/5016' to 5042'. Drift @ 5042' - 3/4©. Drilled 12¼" hole f/5042' to 5604'. Pooh. Drift @ 5604' _ ½o. RIH w/bit #6 on BHA #7. Drilled 12¼" hole f/5604' to 5840'. Drilled 12¼" hole f/5840' to 6099'. Drift @ 6099' - 3/8©. Drilled 12¼" hole f/6099' to 6130'. Pooh. RIH w/bit #7 on BHA #8. Drilled 12¼" hole f/6130' to 6160' & lost 600 psi on pumps. Pooh. Found washout in 29th stand. Ran back to btm. Drilled 12¼" hole f/6160' to 6289'. Drilled 12¼" hole f/6289' to 6492' & pumps broke down. Repaired pumps (1 hr. lost time). Drift @ 6592' - 1©. Drilled 12¼" hole f/6592' to 7010'. Drift @ 7010' - 7/8©. Made 10 std. short trip. Circ. & cond. for logs. Ran Dil-SP-BHC-SONIC-GR log f/7010' to 2425'. Ran FDC-CNL-GR f/7010' to 2425'. RIH w/RR bit #8 on BHA #9. Drilled 12¼" hole f/7010' to 7025'. Circ. & cond. mud & hole for 9 5/8" csg. Pooh. Ran 173 its of 9 5/8" 47# N-80 butt csg. Circ. & cond. mud & 100 FPM while reciprocating csg. Cemented 9 5/8" csg. w/1800 sxs. C1 "G" w/.5% CFR-2, .3% Halad 22-A & 3% KCL. While reciprocating csg. landed csg. when noted increase in hole drag (1200 CF of cmt. in annulus) w/shoe @ 7025' & F.C. @ 6980'. Bumped plug w/3000 psi C.I.P. @ 21:55 hrs. 14. I hereby cy/rtit~ that the for.gg~/n~gzg'y true and c .... ct Dist. Drlg. Supt. DATE 1/9/80 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Form No. 10-404 REV. 3-1-70 SUBMIT IN DUPLICATE STAT E O F A LAS KA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-133-20327 6. LEASE DESIGNATION AND SERIAL NO. A-028142 1. 7.IF INDIAN'ALOTTEE OR TRIBE NAME OIL ~'] GAS [] WELL WELL OTItER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME UNION OIL COMPANY OF CALIFORNIA Kenai Beluga Unit 3. ADDRESS OF' OPERATOR 9. '.~ ELL NO. KBU 41-7 10. FIELD AND POOL. OR WILl)CAT 4. LOCATION OF WELL 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. 13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK 1N HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 15 12/6/79 7025'/0' 13 3/8" C. 2425' 9 5/8" C. 7025' Removed BOPE. Cut off 9 5/8" csg. Installed OCT 13 5/g' 5000 psi x 10" 5000 psi tbg. head spool. Installed & tested BOPE. 16 12/7/79 2030'/5' 13 3/8" C, 2425' 9 5/8" C. 7025' RIH w/bit #9 on BHA #10. Tag F.C. @ 6978' DPM. Pressure test 9 5/8" to 3500 psi. Drilled out F.C., Shoe & 5' of new hole. Tested 9 5/8" shoe to .65 psi/ft. Pooh. Ran Gyro survey & CBL log. 17 12/8/79 7129'.99' 13 3/8" C. 2425' 9 5/8" C. 7025' RIH w/BRA #11 & bit #10. Dir. drill 8½" hole f/7035' to 7129' (Tyonek core pt). Pooh. RIH w/rubber sleeve core bbl. Well started flowing on trip in @ 4980' (SICP 180 psi, SIDP 100 psi, 28 bbls). 18 12/9/79 7129'/0' 13 3/8" C. 2425' 9 5/8" C. 7025' Circ. holding back pressure & increasing MW to 78 PCF. Pulled 3 stds & wait 1 hr. Run back to btm & circ. btms up. - No gas. 19 12/10/79 '7151'/22' .13 3/8" C. 2425' 9 5/8" C. 7025' RIH w/rubber sleeve core bbl. Cored f/7131' to 7151'. Rec. 14.83' of core. (Correlation Questionable). RIH w/Bit #12 on BRA #13. 2O 12/11/79 7254'/103' 13 3/8" C. 2425' 9 5/8" C. 7025' Reamed cored interval. Drilled f/7151'. Had drilling break + 7214'. Pooh. RIH w/rubber.,~l~ve core bbl. Cored f/7234' to 7254' 14. I hereby certify that the foregoing is true and correct SIGNED, TITLE DATE 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Form No. 10-404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. AP! NUMERICAL CODE 6. LEASE DESIGNATIDN AND SERIAL NO. 1. 7. IF INDIAN.ALOTTEE OR TRIBE NAME WELL WELL OTItER 2. NAME OF OPERATOR 8. [_iNIT FARM OR LEASE NAME UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL 9. ',',t'LL NO. KBU 41-7 10. FIELD AND POOL, OR WILl)CAT 11. SEC. T. R. M. (BOTTOM ItOLE OBJECTIVE) 12. PERMIT NO. 13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTlt SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CttANGES IN HOLE CONDITIONS. 21 12/12/79 7290'/36' 13 3/8" C. 2425' 9 5/8" C. 7025' Finish laying down core barrel. RIH w/bit #15. Reamed cored interval f/7234' - 7254'. Drilled f/7254' to 7290'. Circ. & Pooh. Rigged up Schlumberger and ran DIL/GR, BHC-Sonic/GR/CAL., & CNL/FDC/GR/CAL logs f/7022' to 7281'. 22 12/13/79 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' Finish running CNL/FDC/GR. RIH & shot 24 SWS f/7200' to 7233' - recovered 20 SWS. Rigged down Schlumberger. RIH w/Servco 15" underreamer - broke circulation @ 3000' & 500'. Circ. @ shoe of 9 5/8" csg. Clean mud tanks. 23 12/14/79 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' Finished cleaning mud tanks & changing over to polymer - CaC12 fluid w/underreamer @ 6970'. 24 12/15/79 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' Finished cleaning mud tanks & changing over to polymer - CaC12 fluid w/underreamer @ 6970'. 25 12/16/79 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' error in pipe tally. Pooh. reamed f/7097' to 7118'). strapped in hole. 14. 1 hereby certify that the foregoing is true and correct RIH to 7190' & attempted to underream to 15" hole size f/7190' to 7268'. Pulled into 9 5/8" csg'. & circ. clean. Pooh. Ran Schlumberger 4 arm caliper log f/7260' to 7000'. It showed that no hole was opened. RIH w/ underreamer. Underreamed f/7190' - 7211' - discovered (Found actual depth under- Redre~'~ ~rreamer & SIGNED TITLE DATE 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. SUBMIT IN DUPLICATE Form No. 10-404 REV. 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTItER 2. NAME OF OPERATOR UNION OIL COMPANY OF 'CALIFORNIA 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME 9. WELL NO. KBU 41-7 10. FIELD AND POOL, OR WILl)CAT 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK 1N HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 26 12/17/79 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' Underreamed 8½" hole to 15" f/7190' to 7250' DPM. Circ. & Pooh. RIH w/Schlumberger 4 arm caliper & log f/7250' to 7000'. Log showed hole opened to 15" f/7094' to 7114' WLM & f/7186' to 7246' WLM. Rigged up to run 5½" liner. 27 12/18/79 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' Ran 5 1/2" liner on 9 5/8" x 6" bore Baker Model "F-i" packer and hung @ 7240', top @ 6920'. Set pkr @ 6920' and POOH w/ D.P. RIH w/ seal assembly and stabbed into pkr @ 6920'. Tested pkr to 2000 psi- ok. POOH. RIH w/ Lynes gravel packing tool on 5" D.P. w/ 40' of 2 3/8" tubing tail. Set and tried to test Lynes external packers @ 7154' and 7163'. Pkrs. would not test. Located and closed port collar @ 7150' and tested to 1000 psi - ok. Located port collar @ 7189'. 28 12/19/79 7290' TD Gravel pack the Tyonek sand through a port collar 13 3/8" C. 2425' @ 7189' w/ 20-40 sand. A total of 65 sx. of sand 9 5/8" C. 7025' was used (105% of theoretical) with a packing concentration of 1/4 to 1/2 ppg and a final pressure of 1800 psi. The fluid used was 1 PPG Hec, 2 PPB ~:'~ ........ ~ ........ Dextrid, 145 PPB CaC1 and 1/2% L-53 (Clay Acid). ' Reversed out and pulled up to 6900'. Circ. and cond. .... ~ ~- :i~i mud. Mud is gas cut to 75 pcf on bottoms up. POOH. RIH w/ open-ended drill pipe to 7220' and circ. POOH la%~ng down 5" dirll pipe. 14. I hereby certify that the foregoing is true and correct S I GN ED TITLE DATE 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Form No. 10-404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL OTttER WELL 2.NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN-ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME KBU 41-7 9. WELL NO. 10. FIELD AND POOL, OR WILl)CAT 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) ~i~?~PERMIT NO. 13.REPORT TOTAL DEPTH AT END OF MONTIt, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AN[) ANY OTHER SIGNIFICANT CHANGES 1N HOLE CONDITIONS. 29 12/20/79 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' Install 3 1/2" rams in BOPE. Pick up and RIH w/ 69 jts of 2 7/8" buttress tubing, 9 5/8" HOWCO RTTS pkr w/ stimulation valve and RIH on 3 1/2" D.P. Packer set @ 2740'. Could not release pkr. - POOH. RIH w/ new test tools - with a 500' water cushion. 3O 31 32 33 12/21/79 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' 12/22/79 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' 12/23/79 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' 12/24/79 7290' TD 13 3/8" C. 2425' Complete RIH w/ test tools on 3 1/2" D.P. Set RTTS PKR @ 6888', 2 7/8" tbg. tail @ 7200'. Rigged up and tested HOWCO test head and surface lines to 3500 psi w/ diesel. Precharged drill pipe to 1250 psi w/ field gas. Opened stimulation valve @ 9:45 A.M. 12/21/79. Pressure increased to 1330 psi. Opened well to flare @ 10:00 A.M. on 1/4" choke. Pressure fell to 0 psi in 20 minutes. Pressure gradually increased. Opened to 3/4" choke @ 12:40 P.M. Had fluid to surface @1:30 P.M. Well making 1.7 MMCF/D rate w/ 1 BPH water and some sand @9:30 P.M. Opened well to 1/2" and 3/4" choke and well began to make 3.1 MMCF/D w/ 970 psi surface pressure. Continued testing Tyonek Zone with the flowrate gradually increasing, the water rate decreasing to 0, and the sand rate down to a trace. Continued testing Tyonek Zone. 14. I hereby certify that the foregoing is true and-correct , SIGNED TITLE. DATE 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Form No. 10404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. AP! NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 7.IF INDIAN'ALOTTEE OR TRIBE NAME !. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR 9.WELL NO. KBU 41-7 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILl)CAT 11. SEC. T. R. M. (BOTTOM ItOLE OBJECTIVE) 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CA~I~;G~'~'5~EMENTING JOBS INCLUDING DEPTtt SET AND VOLUMES USED, PERFORATIONS. TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 9 5/8" C. 7025' 34 12/25/79 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' Continued testing Tyonek Zone. 35 12/26/79 7290' TD 13 3/8" C. 2425', 9 5/8" C. 7025' Completed testing on Tyonek Zone. Had final rate of 4.42 MMCF/D with 300 psi on drill pipe. The well was making no water and trace of sand. Shut well in. Opened bypass to dump fluid across perfs. Bled off drill pipe pressure and filled drill pipe w/ Cacl2 fluid. Bullheaded 10 Bbls of CaC1 fluid across perfs. Closed bypass. Released RTTS and circ. around tbg. tail @ 7200' to kill well. Pumped pill and POOH w/ test tools. RIH w/ RBP and set @ 6799' DPM. Spotted 15 sx sand on top of RBP. Waited 1 hr. to tag sand @ 6793'. 36 12/27/79 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' Re-tag top of sand @ 6777'. POOH. Rigged up Go Int. and ran CBL-Signature-Neutron-GR log f/ 6735' to 5900'. Log would not correlate and had CBL tool failure. Ran Signature-Neutron-GR log f/ 6735' to 3400' for correlation. Ran bit and csg. scraper to tag top of sand @ 6762'. Circ. and POOH. 37 12/28/79 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' POOH w/ bit and csg. scraper. RIH w/ RTTS and stimulation valve and set RTTS @ 6413', tail @ 6450'. Precharge D.P. to 1300 psi and Open stimulation valve. RIH w/ 2 1/8" perf gun and perforate lower Beluga f/ 6494' to 6504' DIL for DST #lA. POOH w/ perf gun. Open well to flare. Well initially made 250 MCF/D rate w/ no fluid. 14. I hereby certify that the foreg~)ing is true and correct SIGNED TITLE DATE 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Form No. 10-404 REV. 3-1-70 SUBMIT 1N DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOYER OPERATIONS 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 1. 7. IF INDIAN.ALOTI'EE OR TRIBE NAME OIL r--] GAS WELLl I WELL OTItER 2.NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME UNION OIL COMPANY OF CALIFORNIA 3.ADDRESS OF OPERATOR 9. WF. LL NO. KBU 41-7 4. LOCATION OF WELL 10.FIELD AND POOL, OR WILl)CAT 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. 13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISH1NG JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 38 39 4O 1.2/29/79 1.2130179 1.2131/79 7290 ' TD 13 3/8" C. 2425' 9 5/8" C. 7025' 7290' TD 13 3/8" C. 2425' 9 5/8" C. 7025' 7290 ' TD 13 3/8" C. 2425' 9 5/8" C. 7025' Continued testing well until had a rate of 1.9 MMCF/D w/ 500 psi back pressure and no water. RIH w/ 2 1/8" guns and perforate f/ 6668' to 6680' DIL for DST #lB. Opened well to test. Well made 3.86 MMCF/D @ 500 psi w/ no fluid. RIH w/ HP pressure recorder to 6500' and shut well in for 8 1/2 hrs. HP showed BHP = 2915 psi. Opened well to flare and made 3.81 MMCF/D @ 550 psi w/ no fluid. CWI. Opened bypass and killed well w/ 15 Bbls of fluid bullheaded across perfs. Circ and dropped mud wt. to 74 pcf. 14. I hereby certify that the foregoing is true and correct SIGNED TITLE DATE 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Form 9-331 Dec. 197:~ UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use Form 9-331-C for such proposals.~ 1. oil gas well [] well [] other 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR P oO. BOX 6247, ANCHORAGE, AK. 99502 4, LOCATION OF WELL (REPORT LOCATION CLEARLY. See space 17 below.) AT SURFACE: 185'S & 4303'E of the N.W. Cor., AT TOP PROD. INTERVAL: Sec. 7, T4N, RllW, S.M. AT TOTAL DEPTH: 16. CHECK APPROPRIATE BOX TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA REQUEST FOR APPROVAL TO: TEST WATER SHUT-OFF [] FRACTURE TREAT SHOOT OR AClDIZE [] REPAIR WELL 'E~ PULL OR ALTER CASING [] MULTIPLE COMPLETE [] CHANGE ZONES [] ABANDON~ [] (other) see below Form Approved. Budget Bureau No. 42-R1424 5. LEASE "f.~" .t...:. A-0-814 :-22, ':' "':. 6. IF INDIAN, ALLOTTEE OR TRIBE .NAME .. -' ~ ..... :' 7. UNIT AGREEMENT NAME ' KENAI BELUGA UNIT' 8. FARM OR LEASE NAME . ,. . ' . . 9. WELL NO. - ;''' , .- .'L' KBU 41-7 '~.~ 10. FIELD OR WILDCAT'NAME " KENAI .GAS FIELD · 1!, SEC., T., R., M,, OR BL K. AND SURVEY AREA ':i." "' .'~, · SEC. 7, T4N, RliW,':S.M':' 12. COUNTY OR PARISH 13. STATE KENAI :.L.:-I " .AK. 14. APl NO. : .:.' : i-, 7: .~: 50-133-20327 "-' :. 15. ELEVATIONS (SHOW DF, KDB,'AND WD) 101' ~'Above MSL :, - SUBSEQUENT REPORT OF: . [] ,. .,. · : ,; ,~ , ..;, 'L i': L' ": .' ,::' '~,_~..~ · · ri . .... :: ~:. [] (NOTE: Report res"Its ~f multiple com'Pletion"or zone [] change on Fc~rm 9-330.) .. ~ '' ':' -' '-' '- " " ' . 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, ' including estimated date of starting any proposed work· if well is directionally drilled, give .subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.) It is Proposed to amend the plan of procedure approved 11/29/79 'for KBu ~1.-.7",; · _ Kenai Gas Field as follows: ** (SEE ATTACHED) "., ,.,-~ ..... . .::.-.., .. .:'-RE,qEiVFD-- .: ..'-,_ __ *¥erbal approval =ece±ved from Barry Boudreau, USGS, 12/7/79 'i .' ONSFIORE J)IST: OFFIC~- .. - .-:CO,-,o....,. .... ~ f,~]q .D VIS ON · " ,'. U. Si" GEOL':,C.'ICAL SURVEY ,'~. , .' . . . .. .' ANC;-:O;L,\GE, 'ALASKA Subsurface Safety Valve: Manu. and Type ' ':- ': Set @ - Ft. 18. I hereby certify that the foregoing is true and correct ..; _:.'" ~ ' ' APPROVED BY CONDITIONS (This space for Federal or State office use) DI~T,P~ICT SUPERVISOR DATE *See Instructions on Reverse Side Anl~hu~a,~ PLAN OF PROCEDURE: 2. 3. 4. 5. 6. 7. 8. . Move in rig up Brinkerhoff Rig #43. · Drive 20" to refusal @ + 100'. Drill 12 1/4" vertical hole to + 2500' MD. Run & cement 13 3/8" csg. @ + 2500'. Drill 12 1/4" vertical hole to + 7000' ~-~. Run logs Run & cement 9 5/!~' csg. @ + 7000' MD. Drill 8 1/2" to Tyonek core point & core 20' of Tyonek with a rubber sleeved core barrel. Drill 8 1/2" vertical hole to +7675" TD. 10. Run logs. 11. Plug back to base of.Tyonek sand. 12. Under ream Tyonek sand f/8~"'to 15" f/~ 7260' to 7300'. 13. Run 5~" liner from + 6975' - + 7300' w/wire-wrapped screen across Tyonek sand ~/~ 7260' t--o ~ 7300' and gravel pack the Tyonek sand. (15.50#, N-80, 5 1/2" Liner) 14. Test and evaluate middle and lower Beluga and Tyonek sands. 15. Complete well as justified by tests. EMERGENCY ORDER December 14, 1979 Union Oil Company of California Attn~ Mr. Robert T. Anderson P. O. Box 6247 Anchorage, Alaska 99502 Dear Mr. Anderson: Union Oil Company of California, operator of the Kenai Unit, by letter dated December 13, 1979, has requested an emergency order to perforate, production test and dually complete the Kenai Unit KBU No. 41-7 well in the Kenai Gas Field. The request has been submitted in order to prevent economic waste and hardship because of rig stand-by time and other related costs to the operator and unit participants. The Alaska Oil and Gas Conservation Commission hereby issues the requested emergency order but cautions the operator that he will proceed at his own risk since the requested operations are exceptions to the regulations and subject to a notice and possible public hearing followed by a conservation order to be subsequently issued. This emergency order expires on December 29, 1979. ~oyl~H. Himil t6n Chairman/Commi ss loner 1,'~ - ~.,~ ..... ~ ../\ .... ~onnie C, ~th Commissioner Form No.'10404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE oF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-133~20327 6. LEASE DESIGNATION AND SERIAL NO. A-028142 WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME UNION OIL COMPANY OF CALIFORNIA KENAI BELUGA UNIT 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. BOX 6247, ANCHORAGE, ALASKA 99502 KBU 41-7 4. LOCATION OF WELL 185'S & 4303'E of the N.W. cor. Sec. 7, ~T~4N~, ~RllW, S.M. 10. FIELD AND POOL, OR WILDCAT KENAI GAS FIELD 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 7, T4N, RllW, S.M. 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING_A~ND CEI~EN~I~I~OIIlt~t~ii~I~LUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS F1SHING JO//gg~Oli~jg~!~N~ HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 11/18/79 Commence operation 00:01 hrs. 11/18/79. Skid rig f/ KTU #43-6X to KBU #41-7 location. B 11/19/79 Rigging up. 11/20/79 20" D. 134' Drove 20" to refusal w/268 BPF @ 134' while rigging up. 11/21/79 20" D. 134' Welded on 20" starting flange. Flange cracked by weld. Removed flange & install new flange. Installed & function tested 20" hydril. 11/22/79 1584'/1584' 20" D. 134' Spud well @ 00:20 hrs. 11/22/79 Drilled 1vu'' · .~ hole to 1584' w/BHA #1 & bit #1. 11/23/79 2514'/930' 20" D. 134' Drilled 17~" . Circ. clean. 2 hole from 1584' to 2514' Pooh. RIH w/BHA #2 bit #1. Circ. high vis. sweep around. Pooh. 11/24/79 2514'/0' 20" D. 134' Attempted to run 13 3/8" csg. - stopped @ 156'. Pooh w/ 13 3/8" csg. RIH w/bit #2 on BHA #3. Reamed hole f/134' to 250', f/1360' to 1380'. 11/25/79 2514'/0' 20" D. 134' Reamed hole from 2333' to 2354'. Plugged bit. Pooh. Removed jets. RIH & reamed f/2354' to 2514'. Circ. high vis. pill around. Pooh. RIH w/13 3/8" csg. Csg. stopped @ 2425'. 11./26/79 2514'/0' 20" D. 134' RIH w/stab in tool. Mixed & pumped 900 sxs. & cmt. unit broke down. Circ. out cmt. w/rig pump. Tear out B.J. unit. 14. I hereby c~t~ that ?e fox~loin~l~ trtce and correct ..... SIGNED~~ ..~f_~_~_~-~~ TITLE ~lSE: prig_. .... Supt. DATE 12/10/79 NOTL~eport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Form No[]0-404 ~REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS $. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME 3. ADDRESS OF OPERATOR 9. WELL NO. KBU 41-7 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING J~i~l~j~ HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 11/27/79 2514'/0' 20" D. 134' Rig up HOWCO cmt. unit. Cemented 13 3/8" casing thru shoe w/442 sxs. C1 "G" w/2½% pre-hydrated Gel & 2% CaC12 foll'owed by 250 sxs. C1 "G" w/2% CaC12. Pumped 120 bbls. water ahead. Started pumping tail in slurry when received lead water @ surface. C.I.P. @ 01:30, 11/26/79. Cut off 20" & 13 3/8". Installed O.C.T. 13 5/8" 500 psi x 13 3/8" S.O.W. csg. head. Attempt to run Gyro while nippling up BOPE - stopped @ 1700'. (NOTE: Had cmt. returns to surface). 11/28/79 2585'/71' 20" D. 134' 13 3/8" C. 2425' Installed and tested 13 5/8" 5000 psi BOP stack. RIH w/8½" bit & tagged cmt. @ 2352'. C.O. cmt. f/2352' to F.C. @ 2411'. Pressure tested 13 3/8" csg. to 2500 psi. Drilled out F.C. & retested 13 3/8" csg. Drilled out shoe & C.O. 10' to 2435'. Pressured test csg. seat to 95 PCF equiv. C.O. cmt. f/2435' to 2514' & drilled 12¼" hole to 2585'. 11/29/79 4200'/1615' 20" D. 134' 13 3/8" C 2425' Dir. drilled 12¼" hole f/2585' to 2865'. Circ. clean. Pooh. Ran SDC Gyro Survey f/2820' to surface. RIH w/bit #4 on BHA #5. Directionally drilled 12¼" hole f/2865' to 4200'. 11/30/79 5016'/816' 20" D. 134' 13 3/8" C. 2425' Drilled 12¼" hole f/4200' to 4520'. Circ. clean. Short trip. Pooh. Ran Schlum. RFT in sterling "B-5" sand. Set @ 4228 - 1582 psi @ 4240' - 1578 psi. RIH w/bit #5 on BHA #6. Drilled 12¼" hole f/4520' to 5016'. 14. I hereby certify that the foregoing is true and correct SIGNED. TITLE DATE 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. December 11, i979 Re: Kenai Beluga Unit KBU 41-7 Union Oil Company of California Permit No. 79-29 Sur. Loc.: 185'S, 4303'E of the ~'~ cr, Sec 7, T4N, RllW SM. Bottomhole Loc.: Same as above Mr. Robert T. Anderson District Land ~anager Union Oil Company of California ~. O. Bo~ 6247 Anchorage, Alaska 99502 Dear ~r. Anderson EnClosed is the approved application for permit to drill the above referenced well which replaces the permit issued for the Kenai Beluga Unit No. 31-7 well. Since a conservation order (COO. No. 157) was issued for the Kenai Beluga Unit No. 31-7 well, the change of plans to drill the Kenai Beluga Unit No. 41-7 well instead requires the Commission to declare Conservation Order No. 157 null and void. This well may be d. rilled at the operator's risk but the perforation and/or completion is subject to the consideration of the Commission and the issuance of a conservation order. The reason for this is that our records indicate that if the KBU No. 41-7 well is completed in the Beluga sands there will be an interval of less than 3000' from the Kenai Beluga Unit No. 13-8 well. In addition, if the well is completed in the Tyonek sands, it will be less than 3000' from both the Kenai Deep Unit No. 1 well and the Kenai Deep Unit No. 2 well. Core chips are required. A directional survey is not required. If available, a tape containing the digitized log information on all logs shall ~ submitted for copying except experimental logs, velocity surveys and dipmeter surveys. Mr. Robert T. Anderson Kenai Beluga Unit KBU 41-7 -2- December i1, 1979 Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska AdminiStrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited, by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may ~ contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. ~e would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is dril led. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Ve~ truly yours, · }~oyi'e H. Hamil ton Chairman of S~ ~OSD~,q O~ TH~ CO~S~©M Alaska Oil & Gas Conservation Commission Enc lo sure . CC: Depar%~ent of Fish & G~e, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of Labor; Supervisor, LaSer Law Compliance Division w/o encl. REVISED Form 10-401 ~ SUBMIT IN TRII FE REV, 1-1-71 (Other instructio, reverse side) la. TYPE OF WORK STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN DRILL [~ b. TYPE OF WELL OIL GAS ~ SINGLE MULTIPLE WELL [3 WELL OTHER ZONE [5] ZONE [] 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR P.O. BOX 6247, ANCHORAGE, ALASKA 99502 DEEPEN [] 4' LOCATION OF WELL185 'O (~At surface 4303E of the N.W. cor., Sec. 7, T4N, RllW, s.M. At proposed prod. zone 185'~ & 4303E of the N.W. cor., Sec. 7, T4N, RllW 13.' DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICB* 3 miles south of Kenai AP1 #50-133-20327 !5. A-028142 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN, ALLOTTEE OR TRiBE NAME 8. UNIT FARM OR LEASE NAME Kenai Beluga Unit 9. WELL NO. * KBU 41-7 10. FIELD AND POOL, OR WILDCAT 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 7, T4N, RllW, S.M. 12. 14. BOND INFORMATION: TY~Estate widesuretyand/orNo' United Pacific Ins. Co. B-55372 Amount $100,000 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest dtig, unit, ff any) 3,650' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 2,200' 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 101' KB above MSL 16. No. OF ACRES IN LEASE 2,560' 19. PROPOSEDDE~H 7,730'** 23. PROPOSED CASING AND CEMENTING PROGRAM 17. NO,ACRES ASSIGNED TO THIS WELL 640 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START 11/18/79 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement - 20" 94~/ g-40 +100' Driven to refusal 17~,, -- a 13 3/8" 61~/ K-55 +2500' 1750 12¼" 9 5/8" 47~/ N-SO T7000' 1800 ~qx. 8½" 5~" -- 2 Liner 15.50~/ N-80 +6975' Not rom~nv~rt - +7300' o- .... SEE ATTACHED Formerly KBU 31-7 150' deeper than submitted on Sundry Notice dated 11/28/79. , IN ABOVE SPACE DESCRIBE~E~PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed /. new productive zone. If prOpo~l~is to drill or deepen directionally, give pertinent data on subs'arface locations and measured and true ~-~/~" /-,~ vertical depths. Give bl~,o~t pre)enter progxam. 24. I herg;ff, eff~Y tl~t th~ Foregoing i~True and Correc'~ I / ~ .... ~ . . ,~ego~..~.. _ C. or~e~ ("~f~/ 12/10/79 DisC SIGNED.':~,~_ ~. L/[~'~3~ ,:;~%ATE TITLE . Land Mgr. (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: SAMPLES AND CORE CHIPS REQUIRED MUD LOG []'~s Rr NO [] YES Zl NO DIRECTIONAL SURVEY REQUIRED [] YES J~ NO OTHER REQUIREMENTS: SUBMIT OQRE CHIPS A.P.I. NUMERICAL CODE 50-133-20327 PERMIT NO. APPOVED BY 7 9-2 9 APPROVAL DATE *See Instruction On Reverse Side July 2, !979 DATE ~TMD 4-420 u-m ~ TMD 5680 TMD 10~502 KDU-3 (21 3 MD !1,510 U-M -'T' TM D 4390 U- M KDU-4 RD ' iMD 10,810 Or,g. ho e . -~ KDU-4 -~'~ TMD 5540 / (J & 0 ..... 500 I000 U-M KU-43-6 TMD 5?00 , KU~43-6A '~T MD 5300 KBU-4-1-7 7580 TV D ' . ~F~ U-M ~-- - ~ -~-" &--~---Z .~. K D U- 2 (2 i-8) .// ~, TARGET A - T/BELUGA T M D 10~620 · 4670' MD 4670' VD TARGET B- T/TYONEK 7 2~o0:. 'v D 3 KB U- 13-8 TMD 8770' sU-M . KU-43-7 · PROPOSED WELL LOCATION ..... KBU-~I-T, The bottom hole location and zones of interest for KBU 31-7, Kenai Gas field have been altered from the approved permit to drill nec- essitating a well number change from KBU 31-7 to KBU 41-7. Also, the plan of procedure has been revised as follows: PLAN OF PROCEDURE: 1. Move in & rig up Brinkerhoff Rig #43. 2. Drive 20" to refusal @ + 100'. 3. Drill 12 1/4" vertical h--ole to + 2500' MD. 4. Run & cement 13 3/8" csg. @ + 2~00'. 5. Drill 12 1/4!' vertical hole t--o + 7000' MD. 6. Run logs. -- 7. Run & cement 9 5/8" csg. @ + 7000' MD. 8. Drill 8 1/2" to Tyonek core point'& core 20' of Tyonek with a rubber sleeved core barrel. - 9. Drill 8 1/2" vertical hole to ~7675'~. TD. 10. Run logs. 11. Plug back to base of Tyonek sand. 12. Under ream Tyonek sand f/8~" to 15" f/+ 7260' to 7300'. 13. Run 5½" liner from + 6975' - + 7300' w/--wire-wrapped screen across Tyonek sand f/+ 7260' to + 7300' and gravel pack the Tyonek sand. -- -- 14. Test and evaluate middle and lower B~u.8a and Tyonek sands. 15. COmplete well as justified by tests. CO.fEY CASING AND TUBING DESIGN _ ~ ~.WfJD ~.~. I ~PcF-~j~.. HYD GR, i ,Sg) psi/ft_~. Mb"D %,T, II ._~ ..... j_ - ........... ~,, _ ~. - _. ,, , DESC~P~0N ~IGHT ~NSION ~E h~o2,~ ~F COLLAPSE COLL~SE W/ BP -top of ST~NG~ P~SS. O PZSIST. W/O BF~ section TE!~SION bott~ tension lbs lbs !000 lbs .~ psi_ _ ~s~ DESIGN BY .... ~'~_,~/~ psi/ft~ M.S.P._ ...... CDF PRESSURE YIELD p.si,,, _ psi BDF P?-vCE C$Si PER PT. ! - Yield Strength ~.~ I~,.~:~ ~ i,.~,..~. ~'° ;/.,I,..11t,*.1 ;:1".~ ..11 ;.~ ;~;~ i' ,.,, .... ...,...i.I ,l':. ., :": ": '4.:!1 ,,~-...~ .... Formulae: Collapse resistance in tension = X (Collapse pressure ratlr~) ~z? + De.~th ( Hya. Gr. IZ -.~) BF (Bouyancy Fac'tot) = ~.oo- (o.o~ x ~u~ w~. ~) Calculations: Total Co~t 17 1/£" hole drilled to · 2500' o o /qSP' · o ~. ' t ' , ......'.9 4 PP..S ?£,'2 9 5/8'; casin_q._r~n~ c.e.:o.~nted._, thru this assy. . ' .-'~'-: ~ ,"~~ l. /,/ .. - . ' ' ' · -- ", ' /Z ~ c,,,,',', ,~' ' ' . ' '- .. ~. ,_.,-.,w~ ~z, ~:. ' ' . , . . , ' -------' H'.r,9,-71L _. ..... ~ . . . . .~..'. ...... ~ '~ .' . . ' _ . ~;:.. ,!', iJ/q- '~,,,,o ,?,,- -._T,.-~, ! s-., ' . .:' ~' :--- - ,,.o '-------__ .-- ' - ~aska Ol ~ ,,:. '. .. - . .:. . ... . ... % ' -~ '~'~fi'~ / ' - "' .... ~, ~ .. ...... :. ~ ..~ ....... - ~:. :..-., ...... ~ I I ' ' ~ eF~N< . . .... .L~ .~_ J. .. :~. ~. ~.~.~ ......... ,_,1. . -~. ~ . ~~.. ~ ~ ..... ~ ~_ ~.-~ .~ ~_ ~. ~ .. . -... . · · .. ' ~. ~ ~ - 6~,~ I,.LVE A'~O~/,,-~c~ -. ,, ~x z ~ . . . . ' ~-"~'~ ~J'-'>L ' I ~' ..... ~---~ '~ ~- DR~LL~;G ~ . _ · Z.R VXLV£ - ' LP VXLVES ~ e. o _ .4DJL/S YX BL F . e, ALL C}~,'G[S I','..usT I!&VE V.~ITTEH /,d',;,ROVAL BY'THE DISTRICT 13?GLLI}~G SU pE U,;:~TE ~;D£.N'F. . Form 10-4e~ REV., 1-10~7~3 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) OIL I'--I GAS I--;I WELL t I WELLI..Z~ OTHER 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR P.O. BOX 6247, ANCHORAGE, ALASKA 99502 4. LOCATION OF WELL At surface 185'S & 4303'E of the N.W. Cor. Sec. RllW, S.M. 7, T4N, (corrected) 13- ELEVATIONS (Show whether DF, RT, GR, et~) 101' 'KB above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. AP, .UMER,CAL CODE 50-133-20327 6. LEASE DESIGNATION AND SERI$'L Np.~-~-- A-028142 7. IF INDIAN. ALLOTTEE OR TRIBE' NA~AI~ GEO-~'-- [e~ai ~eluga U~i~ s. UN~T, FARM OR LEASE NAME ~TAT TEC~ 9. WELL NO. ~O 31-7 '.~ 10. FIELD AND ~OL, OR WlLDCA' [e~ai Cas 71eld 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 7, T4N, RllW, S.M. 12. PERMIT NO. 79-.29 )orr, or Other Data NOTICE OF INTENTION TO-' TEST WATER SHUT-OFF ~ FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) see below PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERII~IG CASING SNOOTING OR AC ID IZI NG ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimatecl date of starting any proposed Work. (SEE ATTACHED) RECEIVED h V3.9 1979 16. I hereby/~t~fy~hat the foregoing is true and correct / / ~) //~ _// ,~- __ Dist. Drlg, Supt. (T~,,,~. for Bt.t. of.=. ~.) ' ' ~/ .... AP~OVED By .... TIT LE CONDITIONS OF APPROVAL, IF ANY= DATE DATE 11/28/79 See Instructions On Reverse Side The bottom hole location and zones of interest for KBU 31-7, Kenai Gas field have been altered from the approved permit to drill nec- essitating a well number change from KBU 31-7 to KBU 41-7. Also, the plan of procedure has been revised as follows: PLAN OF PROCEDURE: . 2. 3. 4. 5. 6. 7. 8. Move in & rig up Brinkerhoff Rig #43. Drive 20" to refusal @ + 100'. Drill 17 1/2" vertical-- hole to + 2500' MD. Run & cement 13 3/8" csg. @ + 2500T. Drill 12 1/4" vertical hole to + 7000' MD. Run logs. Run & cement 9 5/8" csg. @ 7000' MD. Drill 8 1/2" to Tyonek core point & core 20' of Tyonek with a rubber sleeved core barrel. ~-- 9. Drill 8 1/2" vertical hole to 7580' TD. 10. Run logs. 11. .Plug back to 9 5/8" csg. point. 12..i~stand evaluate '~ddle and lower Beluga sands. 13. Complete well as justified by tests. Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Conservation File No. 157 Re: The application of Union Oil Company of California, dated June 22, 1979, for an order granting an exception to the minumum distance requirement of Title 11, Alaska Administra- tive Code, Section 22.055(a)(3) for the Kenai Unit KBU No. 31-7 well which is to be drilled in the Kenai Gas Field in Section 7, T4N, RllW, S.M. Notice i~ hereby given that Union Oil Company of California has requested the Alaska Oil and Gas Conservation Commission to issue an order granting an exception for the minimum distance of 3~000 feet between completions requirement of the referenced regulation. The operator states that the Kenai Unit KU No. 14-6 well is completed in the Beluga reservoir and will be 2,200 feet from the Upper and Middle Beluga sands which are proposed to be completed in the referenced well. The operator further states that the referenced well will be located at the apex of the Beluga structure in the Kenai Gas Field and will have the poten- tial for developing additional reserves. Parties who may be aggrieved if the referenced order is issued are allowed 10 days from the date of this publication in which to file a protest and a request for a hearing. The place of filing is the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501. If such a protest is timely filed, a hearing on the matter will be held at the above address at 10:00 AM on July 12, 1979 at which time protestants and others may be heard. If no such protest is timely filed, the Commission will consider the issuance of the order without a hearing. Harry W. Kugler Commis s ioner Alaska Oil & Gas Conservation Commission I.~nion Oil and Gas F~(ision: Western Region ., , ~ Union Oil Company alifornia P.O. Box 6247, Anchurage, Alaska 99502 Telephone: (907) 276-7600 Telex: 90-25188 Robert T. Anderson District Land Manager .November 21, 1979 Mr. Hoyle Hamilton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 995'04 KENAI GAS FIELD Kenai Unit Conservation Order 157 Dear Mr. Hamilton: On July 13, 1979 Union Oil Company of California's request for a spacing exception for KBU No. 31-7 well was approved. The drilling program for this well has been altered. A Sundry Notice will be submitted changing the well number from KBU No. 31-7 to KBU No. 41-7 and it will be drilled as a straight hole. We, therefore, request that Conservation Order 157' be voided. The KBU No. 41-7 drilling program will allow optimum formation coring and reduced well cost. We aplogize for the inconvenience caused you. Very truly yours, xc: USGS, Rodney Smith, Supervisor Marathon Oil Company, Morrie Lowman Arco Oil and Gas Company, John Kavanagh Chevron U.S.A., Jack Bertino July 2, 1979 Re: Kenai Beluga Unit KBU %31-7 Union Oil Company of California Permit. No. 79-29 Sur. Loc.: 285'S & 830'W of the NE corner of Sec 7, T4N, RllW, SM Bottomhole Loc.: 300'S & 1630'W of the NE corner, Sec 7, T4N, RllW, SM Mr.. Robert T. Anderson ~District Land Manager P.O. Box 6247 Anchorage, Alaska 99502 Dear Mr. Anderson: .Enc.losed is the approved application for permit to drill the above referenced well, This well may he drilled at the operators risk but the perfora- tion and/or completion is subject to the consideration of the commission and the issuanlce of a conservation order.. Well samPles, core chips and. a mud log are not required. A directional survey is required.. If available, a tape containing the digitized log information on all logs shall be submitted for copying except experimental, logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important .for the spawning or migration of anadromous fish. Operations in these areas are subject 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska .Administrative Code). Prior to commencing operations you may be contacted by the I{abitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibit.ed by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and. by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equip~ment before surface casing shoe is drilled. In the event of suspension or ~andonment, please give this office adequate advance nctification so that we may have a witness present. Very truly yours, .h ~rman of ~laska~Oil & Cas Conservation Commission ~nc losur e ~.c: Department of Fish & Game, }~abitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of Labor; Supervisor, Labor Law Compliance Division w/o encl. Robert T. Anderson District Land Manager Union Oil and Ga?"hvison: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union June 18, 1979 Mr. Hoyle Hamilton Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 KENAI SOLDOTNA AREA State of Alaska Kenai Tyonek Unit #43-6X Kenai Beluga Unit #31-7 A-028142 (8-86-71-5390-600972) Kenai Gas Field Dear Mr. Hamilton: Enclosed for your approval are three (3) copies each ~of~the Permits to Drill or Deepen (Form 10-401) wells KTU #43-6X andi,,~'KBU #31-7 .... '~ Also en- closed are our checks, #18931 for KTU #43-6X and #I8932for'KBU #31-7, each in the amount of $100.00 to cover the filing fees. Upon approval, we would appreciate an executed copy for our files. Very truly yours, Robe~rt T. Anderson / / sk Enclosures Form 10-401 ~ SUBMIT IN TRh ,ATE REV. 1-1-71 (Other instructions on reverse side) la. TYPE OF WORK STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN DEEPEN [] DRILL b. TYPE OF WELL OILI-'-! GAS r77'I SINGLE ir---~ MULTIPLE WELL L_] WELL 2. NAME OF OPERATOR Union 0il Company of California 3. ADDRESS OF OPERATOR P.O. Box 6247, Anchorage, Alaska 99502 4. LOCATION OF WELL At surface 285'8 & 830'W of the NE corner, Sec 7, T4N, RllW, SM At proposed prod. zone 300'S & 1630'W of the NE corner, Sec 7, T4N, Ri1W, SM API# 50-133-20327 6. LEASE DESIGNATION AND SERIAL NO. A-028142 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Kenai Beluga Unit 9. WELL NO. KBU #31-7 10. FIELD AND POOL, OR WILDCAT Kenai Gas Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 7, T4N, RllW, SM 13. DISTANCEINMILESANDDIRE~IONFROMNEARESTTOWNORPOST OFFICE* 12. 3 Miles South of Kenai 14. BOND INFORMATION: TYPEStatewide Suretyand/orNo. United Pacific Ins. Co. B-55372 Amount $100,000 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT.' (Also to nearest drig, unit, if any) 3,650' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 2,200' 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 101' KB above MSL 16. No. OF ACRES IN LEASE 2,560' 19. PROPOSED DEPTH 8200' 17. NO,ACRES ASSIGNED TO THIS WELL 640 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL STARS[' 7 /15/79 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH ~antity of cement 20" 94# g-40 +100' Driven to refusal 17~" 13 3/8" 61# K-55 +_2500' 1750 sx 12¼" 9 5/8" 47# N-8n +7700' 2375 Sx SEE ATTACHED IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on. present productive zone and proposed new productive zone. If proposal is to dxill or deepen directionally, give pertinent data on subs~face locations and measured and true vertical depths. Give blowout preventer program. 24. I hereby certi£y~fl)~a~.~oi~ue an~ .... t _ff, (This space for State office use) / SAMPLES AND CORE CHIPS REQUIRED /[ MUD LOG [] ~s 115 NO [] YES DIRECTIONAL SURVEY REQUIRED ~YES [] NO DATE June 18, 1979 CONDITIONS OF APPROVAL, IF ANY: OTHER REQUIREMENTS: ]qO A.P.I. NUMERICAL CODE 5'0 '- 11.3 - ~ TITLE Dist. Land Mgr. API# 50-133-20327 PERMIT NO. 7 q - 2. ~? 79-29 APPROVAL DATE APPOVEDBY ~~~'~/~/~~~~ TITLE COMMISSIONER .J~ ~g ~ i:~;~ tO~J~]:Sg~ON *See Instruction On Reverse Side duly 2, 1979 DATE July 2, 1979 PLAN OF PROCEDURE KBU #31-7 1. Move in & rig up Brinkerhoff Rig #43. 2. Drive 20" to refusal @ +100'. 3. Drill 17½" directional hole to +2500' MD. 4. Run & cement 13 3/8" csg @ +2500'. 5. Drill 12¼" directional hole to +7700' MD. 6. Run logs. 7. Run & cmt 9 5/8" csg @ 7700' MD. 8. Test and evaluate middle and lower Beluga sands. 9. Complete well as justified by tests. ~ KU-II-~ ~ U-M -'"'~' U-M TMD 5680 T5N T4N TM.D 10,502 ~.' u-MKDu_3 (21-5 .TMD 11,510 . . U-M KU-43-6 6 ~ TM DiT5700 U~jM. 43.6A -:, MD 5300 · .U-M , KDU-I KU-14-6 "' ' . ---- / %~KU-21-7 KBU ~17 ~' ' / ~TM~ ~9o :~'~"' T/BELUgA .~ ·j . , ~---o ........ ~ [ ~D: ~ TMD 4800'MD / ~ / 7370' TVD 4670' VD~ I Orig. hole KDU=4, ~~ - TMD 5540 / u-u ~ 7 KDU-4RD MD( 10,810 0 500 I000 P=--=~ FFFT ~TM U-M KU-43-7 I": I000' 5 U-M ~---~ K D U-2 (21-8) T M D 10,620 U-M KBU-13-8 TM D 8770 i ii L i ~ un= n Alaska District KENAI GAS FIELD PROPOSED WELL LOCATION KBU-31-7, MAY 14.79 'cs! INT~tVAL LENGTH.. DESCRIPTION %~IGHT TENSION Top Wt. Grade ~nread w/W/oBP of STRENGTH Bottom ~-7-- section TENSION lbs lbs 1000 lbs MMoo o ]]oo ~n~ ~-~ ~o~ss Z~t~0o 3~oo · TDF COLLAPSE C0LL~PSE CDF BUP£T IET£Ri~%L BDF PRESS. @ PESIST. PRESSURE ~.~,.'5.?.~1E~. bottom tension YIELD psi ~si ~sl. psi 73~0 ' ,~,0 3~7~-- ~f~ 7~ 1,2_c) ~ So~-~ ' ~*?'?O > '. ~_ pp_v~ PER , C,9,~ Formulae: Collapse resistance in tension = X (Collapse pressure ratify) Burst Pressure = ~P + Depth ( Hyd. Gr. II --.~) BF (Bouyancy Factor) = ~.o0 - (o.o~s x ~u~ w~. ~) Calculations: 17 1/2" hole drilled to 2500' ~ ~ S_TtV d L '20" 8~II 20" /qSP 2000 ?~. ., ,~ . 12 1/4" hole dffille~ to 770o' 9 5/8" casing.run_ & cemented thru this assy. · · · G~:,~' ~,. I,O-TO:?,-%C · o o P,'PE RAMS V/LYE ............ 'r.,.~:~ / ' . - - , . ~~ / LO-,V,,~Y~ .. ,~,~"- ~'""'"~-~~-' PiPE ..~,;,'S · i Z/," · -~(~.,-~- '~. ' ' _---. · /.~ ~-s~,x~ ~q~2' .'""r ~ ~ ,. - ~iT'"; : ' ~_..?~ ....L '- ,, . c/ · . ~---~'~t'-'~. ' I .'-'"-~ .... ? .. · . . ~k~. i ~.~ ~ ALL CHANGES W. UST HAVE WRITTEN ~ J t~~B' J ' APPRSVAL BY TH~ DISTRICT . · o · e · · · . e. o *. · · .0. . ' · · · · ''e ,. o · · L R VA L V£S ~ · e, POSI,vV£ CHOKE /. ADJUS T,4 £L F · CHOKE · o '° · i, · · · · · · · · ALL CHANGES MuST HAVE V,"RITTEN APPROVAL BY'THE DISTRICT DRILLING SUPER;~,tT-E HDENT. · 8 ' .! /414'1~!U/,! ST,4A'flA,RD ~//,9/:£ /,!,4/,'/FOLD ,4$$E/,!£LY · · · -,, . CHECK LIST FOR NEW VELL PEP&[ITS Is the permit fee attached ..................... Is well to be located Jn a defined pool ............. Is a registered survey plat: attached . . . .; Cm~pa nv ~, ?~x~ Yes Xo Remarks I~ well located proper distance from property line ........ · Is well located' proper distance from other wells .......... ~i'~-"!~sufficient undedicated acreage available in this p0ol Is well to be deviated ................. 9f / Is operator the only a,~ected party ................ / Can permit be approved before ten-day wait ............. Does operator have a bond ~n force . . . · ............. ~__~ Is a conservation order needed ................... 4.~ / is administrative approval needed ................. Is conductor string provided ................... " Item Approve is e. nough ce. me~t use¢] to circulate on conductor and surface ~ i~'i~ll ceu~ent t~e in surface and intermediate or production strSn!7_.s . ~____ Will cement cover all. known productive horizons ........ Will surface casing protect fresh water zones ......... t-;ill all. casing give adequate safety in collapse, tension & burst Does iV)PE have su[f'icient pressure rating -T¢~;t to ~oO(D psi? (3) Admin.~ Ge ol_o_g_ZV: i~'.:K /,,~,,% WVA 165/ I ~'~ -~/ CHECK LIST FOR NEW ~LL PER~TS O3~pany Yes No Remarks 1..Is the permit fee attached .......................................... ~--&~ 2 Is v.~ll to be located in a defined pool ; ............................ Is a registered survey plat attachsd 4. Is ~11 located proper distance from property line 5. Is well located proper distance from other wells 6. Is sufficient underdicated acreage available in this pool ........... ~ 7r~J'~ls~ . ~11 to be deviated . - .' , eeeeeeeeeeeeeeeeeeeeeeeeee~eeeee.ee ee ee eeee cee .. 8. Is operator the only affected party ' 9. Can peri,nit be approve~ before ten-day ~ait · / 10. Does .o~erator have a kond in force .................................. · Is a conservation order needed ......................... , ............ ii / 12. Is administrative approval needed ............... -.. ....... , ........... 13. Is conductor string provided ........................................ ~ 14. Is enough cament used to circulate on condUCtor and surface ......... f¢6) !5.~ ~'~ill cement tie in surface and intermediate or production strings ... Lease & '~ii ~. /¢. /f. &f. ~ It6m ~pprove Date (]_) Fee LQ~ /~-/¢'7 / 16. Will cement cover all kn~vn productive horizons ..................... f_~ (3) .A~. ~~ / (4) 17. Will surface casing protect fresh w~ter zones ........ ' ............... 18. Will all casing give a~ecA]ate safety in collapse, tension and barst.. .19. Does BOPE have sufficient pressure rating - Test to 3~oO psig .. ~_~ Approval Recommended: ;'~dditionai ' '"' Re _qu~rements: Geology: Engineering: LCS ~_-~-BEW . RAD rev: 06/21/7 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. , 'I~ADULAt~ 5 A H A ~ A N I) CUNPANi{ UNIUN IL}lb COMPANY Ut CALIi"UHNIA ~L,L ANU 41-? S~.ATE ALAGAA D:A~E 13-DC-79 L L B T 1 ,N G 8 A R A B A N D A SANDSTONE ANAb¥~I5 CONPAN'~ UN ION O ~Lh t<,BU 41-7 i~I.gLD i~5NAI GAS F lgblJ CUUNI~ KENAI ,STATE ALA,SKA DATE 1 J-DC- 79 ~P BA,SE LINE 6HiFT NONE L.GR LC'A.'L. 19 18 C~ISP At, I{ A X' 55. 45. 45. 35. ~<~:"'"?,'.':,:'"~/~:'~",~Y:'~;':":,":..'?.:O;;:::'3~O'O".'::,".?O o 3:00 0"'6.'0:0 '3 "000 AT D~P<I'H 7000. 5870. 4b 7,5. 3580. TUP D~PTH 58'70. 4675. 3580. 24J0. O. O. O. O. O..Oo.O:"':'>:O:°..O0:O 0.~:0.0'0' O"O.'O0. O. O. O. O. :0:~ O!',';-/...J.,:,'../,.,:'~ O. O. O. DTNA A~.~Y 55.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 ~N~A!'::'!~4BA~'::?'~>?.{O~.~OOO'j':'."':::O-O0.O 0'00'0 ,O;O'O:O 0o00.0.:",'...:.0"000 0.':0~'0 0.0.00 TOP DLPTIi O. O. O. O. Oo O. O. O. ¢ ( 2 .~ 4 5 ~, 7 8,9 I0 I1 12 13 14 15 lb 17 18 {9 20 21 22 02010100 0 0 0 0 0 0 0 0 I O O 0 0 INPUT PARAMETE~ FHOM 3580,,, 3;,0 2430. WMIJD XLI, T ,BIT'.;gZ BHT BH'TDEP ,SUFT i~MF I~MFT ROMFS PH:IMF~ DAb, IL 9,,6 0.50 12.25 lib. 7000. '50. 2.70 75. 0.998 0.~96 U.850 O- 98 0.20 7000. 24~O. O.000 1.00~ 0.O00 4.00 b.OO · NH:].,: :~P~H'I,,LEV B;~ 8~I~' AK P~' S~ ~'OPIN* ' P~IHAX' ' ' PHINCL P,HiDC~ .200 0.000 .10 0.30 b2500, b.0 2.0 2~,J0. 0.3bO 0.5UO 0 lb0 PHIN~U AB PUN DAX DALI~ DAGA [~A~'i D'f~D ~TSH CP PfiS,H 0.280' ,0..~ .0',20 ~0. 48. J.2.'. 76. 150. 1'50. 1.00 .JO.'O :ED.~{'A~R. '~P:N~=~I M ~P'.D.'I:~:~{.:N R.LI M G.R,L:.I..~' 0... O0 0 ,...48 0.45 5.0 1000.0 0.07 O. ~.].'{ 0.70 0.20 O.O'b S:P 5TATISTI..CS .OVEH ENTI'RE IN'TE~VAL DEPTH PkHN. · 1 T ¥ FEET ~D % HATkR % G~/CC VUbUME % FI:;ET CUN. fI¥,CARB t"'E E T 2431.0 300 2432.0 300 31.4 243,:1.0 1000 24'.'14.0 700 34. i 2435.0 2000 38.4 2436,0 800 34 24j9.0 1000 {6.J 24,40:~0,700 33-g 2441.0 200U 2442.0 200'0 3'8.b 2443.0 100.0 3b.4 2.4.44~'0 i.O.O0 3'5.2 2.4.4.5.0 I000 36.1 · 2'44b~..0 10o0 2447...0 1000 36.9 2449.0 0.0 0.0 24.5..1....0 ....... 2.000 ~8:,5 ~453.,0 2000 38.6 :.';::.:::... · 2455.0 1000 37.8 2457.0 3000 40.4 :2~4:58~0:~::>.: :.:~'::~0:0.~::'.':'''..''''::'.''.'''-'38':~4 2459.0 2000 37.9 ~i~JO 2010:0 2461.0 4000 41.9 2463,0 1000 JT. 1 2465.0 2000 38.7 2467.0 900 j4.9 ~'..' :' · -.~. '.' ..~....-'s ...~ ".:.'. . ................................. 2~9.0 1000 37.2 2471.0 3000 41.0 247~3o0 I000 36.4 · :2~,71~:. 0'.i'.:.!i.i:::7'?'?:i 2475.0 1000 35.4 2477.0 I000 36.3 bO 79 95 99 95 98 100 91 U5 95 97 99 78 91 99 0 0 100 100 9:8, 82 8:2: 79 ·9.'2. 8::5, 93 8··8· 99 89 91 100 88 97 77 95 '9~ 94 99 93{ 12 21 15 14 lO 13 12 13 10 15 12 12 0 767.50 767.21 7o0.89 766.54 766.19 765.80 765.45 765 ,, i 2 7~4 763.2b 762.90 lbl .~2 lU.l.81 lOl.lb 1,61.75 101.74 lbl. 71 Ibl. Tu 101-69 1 .05 .~0 161.38 16'1. :17 7O2.55 Ibl.3b 762.'. 18 101.2 7 761.81 101.25 0.00 0.00 0 0. O0 O. oo 9 701.4'4 1bl,25 lJ 761.07 1:7 .7'6::0' 70 19 760.J4 I...5 75,9:' 9.5 17 759.54 1 ,t:..'::'l 5::9:.::~.:.:I 8. 8 758.~J0 ~'::3:'. :: ,::..':'::.' '::.:::"'::".::!7 5:8_ 11 758.02 1.".1 4 757.23 1::4: ,:...'::::'.' .:'": ..'..:...'..:7:5 6':*~:.'2 13 750.45 I 5. '7:5.:b'.~. 0.8 8 755.72 16 754.97 1:0 =================================== :.:..:.....":......::.:.:::~:&t~.... I I '754.29 lbO.b2 · '~'2:::::.:.:':.".'.::...:::'.:.:."::7~::}:~':90 1:':~'0:~:"5::8 lei .25 16.1 .'2'5 lbl,24 lb1:* 1.8 lo1.11 1~i.02 1~0.9~ 1. 6:.0...90 lb0.87 1:'.o.0:~.: 8.4 I bO. 77 l:"b 0'. 73 160.69 · l,'b.'O '69 lbO.b4 14 753.47 160.48 13 '752.68 160.39 i3 7.5:2":~.:'32 1'b..0.:-..3.7 14 751.96 IbO.J4 1.':.1::: 75.i.:;.'.6f::.'".:.'...'.'..:'..".'"l..e:O. 32 I4 751.25 100.30 FEET HD % ~ATER H¥CARB CbA ' CUM. CUN. ,SAT, o D,EN,5 o VOLUt4E PORUSIT¥ H¥CAI~B % G~4/CC % FEET FEET 2478°0 2479.0 2480°0 24B1.0 2482°0 o0 ,0 2489.0 2.490. '0 2000 1000 1000 2000 900 bOO soo 8OO 38.3 :16.5 36.8 34.9 34°5 3b,,2 ~I 0 3.4. b 98 95 89 84 99 100 100 U4 99 I00 100 10 13 15 15 14 11 12 t2 1 I o 11 750.8U '750.50 750.14 74g.77 749.41 7~.07 748.72 748.30 747.99 °34 7..4.bo.9.4 1b0.27 100.20 leO.2] lbO.lb lO0.1] lt:,O, i~ lbO. 13 lbO.il leO .07 lo0.07 1~ 0.07 0.00 16 0.0 7 .:::.?:... :. 2.49.1...0... 70.0.. 34.0 100 It) .. 74b...D9 . .100.07. :~::~,:.~..:...':'.. '~14'9.~:'...'.0'."~i"" ' .... ....1'0'.'0:.. i." .. '. " .'..%.-4 .... lOO... '..' ... · ".. '............:~.~..........~.4'.~..~.:~..... · · ." l...e..o-.o."~ · · ............. 2.493.0 · .2..00 . 29.8 100. 21 745.9e lbO.O. 7 ....... 2495.0 .0.0 .... 0.0 0 . . 0 .0.00 . 0.00 .~::~:,:~¥~. 2.~,.~:~......0 900 35.0 I00 . . 17 7.45.17. . .lbO.07 .................. 249.9.0 ..... 500 . 33.2 ~ 100 22 7.~4.4b lbO'.07 .......... 25.0i -0 1000 '&5.9 81 23 743.7B 160.00 ~?:~?~'~?~::~?~{~'~''~?:~''''''':::'::''''''':~'~:~;?~''''':'{'''~?{:~:::~:~3'':''::~j''~'~''''''''''''''''''':] :)"::.'""...;9'.~:::'"'".'"'":"~.". "."~'.'""'.'jJ..':"..' .'""."]"'" "~'"' ]]''':''''''''''':~:':''~'''19:'':~''''''''':''''''/~''~i'~/~'~i~'':'''~'''' .."""~. ': i5'9. 9.~. 2503.0 100 28.1 O0 ..... ' ..:...&....:..~ ........... ...:.j:,....:.}:,:,,~.: ,::~.~.:.. .......................... . .............................. . ........................... ~ ..... ~b 743~. O~ 159.94 2505,0 600 34.1 93 26 742.44 159-92 ~/~.?{:.:/~a~.;~{;~.?.??./~6~:.~?j.~/~::6?..~...;.............~''''''':''''''.'~':.'''~.:'''' ~]~.8..'?..."':""'":':"~:"":':~'~":..':'.'''.''''''...' ' ~"] ' '.~ ']'" i~ ". ':" """ ~:~":i' i2:. ".]'""" "'". t s a' a'.l ]' "..'.' · ~.~ .... 2500.0 1000 3~.S 81 19 741.0~ asl!.o ~oo ~.s ~oo iv 74o.~s ~9.~9' ' . .2513.0 ~00 J4.j 87 19 739.~8 159.~8 ' 25i7.0 600 33..3 93 . 21 738.~1 t59.72 2521.0 400 31.8 9b 20 737.10 159.b8 ... 2 2,~.0 ~00 33.5 100 13 736°40 159.07 ' 2525.0 700 34.1 99 I4 7 ~5.7'7 i59.66 ;~::.:::~ ~:~' ?~.~ ~.:'??:~?~???? ?.'?~.??~?~ ~:~?j:'.:?::?': ?:???:'~';.~ :. /......./...: %. ~......,.........?... :?.~.::.......? ....... :...:.~. :~..::...:~:.....~....:.:.../:.:..<.~,. ~.~...~ ..?~:..::...?.~:.. ?.~:.'.~:~ :..? .......:... :.:..':..~..'.....:..~ ...:......... ~ ...~.~ ...:.?:~.?..~?'./-..'?..'...'.~.~...' '.? :~...: ::. '..j..~.: ~'.~'.~j.~. ~ ~ .... ~...:: :.~. ....'..;'~..' :.~:.... ~.":. ~ ~.."~.::~ :.:?:~..:.j.'..:::~/.: ':?.'~. ~.'.~. ~.'~:. ~. ,. :..'.././. '.. ?.~ ':...~ .'.... ~......~: ~ :?~.'~ ~?:~.:..~. %?:(.:??.~?.'?.~.j?~..??.~.~::.~::?:.." :..?.&.~'.:'../. :L:..:.:.':...../<?~.,. ~ :.?.,.....::......'.. ~......~. ?'..:......'.:...~..: ...:?~....:...'.... ~.:.: ?:..:.%.~..":.~,?../<...:/..".:'...'::'.'.) :~.. ?~?/....'. ,.. ~:...........: ...., :~. '....:.:.... ':/:...:,.~..~ ..::.~/.?....'.,.:... ~:'....:....'::.:.:...: :.~.'.:..' .'..'.:'~ '.~ .:~ :.......... .... .... .?.......... "..~........ FE~T PO~ITY ~ATER SAT,. % H¥CAR~ G~/CC CbA/ VOLUME % CU~. CU~. PORU~I~¥ H¥CARO F'~LT FEET 2526.0 2527.O 2528.0 2529.0 253O°O 6O0 33.4 4OO 32.1 70O 34.0 8OO 34.3 600 33.3 500 32.8 3 O0 31.0 300 30.1 300 30.7 30O 30.5 o8 25J7o0 500 32.5 25'3.8.. :0 50.0 32.3 .. 9.o 400 ..~:,~i~o 2..o.o2~:..~. 2541.0 200 30.1 2'5~2::,0 400:..:.~:..':'...'.':.': :'". ?."32:<~2 2543~0 100 27.6 25:'~4::- 0 2 00.:':. '"'"" "',.'". :'28 .. :7 2~4~.o ~oo ~4:.~ 2547.0 500 J2.5 2549,0 500 33.0 ~S~a..?,:::.......:. :..:<.: :/.~0~, 99 100 97 97 100 100 1 O0 I00 100 100 100 .I O0 9...5 I00 100 93 99 95 I'..00: 15 735.43 159.05 17 735.10 15g.b5 14 734.78 159.65 lO 734.q4 lbg,b4 17 734.10 159.b3 15 733./7 159.63 15 733.45 159.63 lb 7.{3.14 ib9.03 15 732.84 159.63 lb '732,53 Ibg.b3 14' 732'23 159.63 10 731.92 159.b3 12 731.59 159.b3 11 731.27 159.b3 16 7:30'. 9b 159.63 19 730.bb 159.63 20 7'30. ~b 159.62 21 730.04 1§9.60 19 729.7.7 1'1 72q.4~ 159.5-9 1'4 7.2.9.12 1§9.'57 15 728.78 159.56 17 72'8.14 16 7:27~'::8.'1 159.~.5:4 100 . . . 2553.0 200 29.3 I 3 720.92 159o54 ' ' 2555.0 400 31.I 100 12 726.30 159.54 2557-0 200 28.8 lO0 15 725,09 159.54 :~:~;?.,~(?~~8:~;~<~J?~'.':?.::~j.;:.;:j..'~:::.~ ;;:::~:~j~:O~'?J~)::.:~()~; ?.2'~'9;~ 0)).) );..".(..) ."~;; .>':.';:..?(':!::00(~' ).)J ):. ': .:.:'J :'. ",::' '.'" :':'>' ;... > ,: .' :(' :". :::!..2j~j:: :<.'.:.:'?/,..~7~2~57~:.~0'~;.'.::('. '..(...:: .'..¥I.;.59:.'.,5.4)....'. :...: .' ,..,....; :.:...:' .'... :.:. ':.,: 2559.0 200 29.0 lO0 15 725,tl 159.54 25b1-0 '300 '30.3 .I00 17 724,51 lb9.54 2563.0 ~00 33-0 99 2i 723,83 2505.0 50 2'4.4 100 25 723,22 159.51 25b.7.0 200 28.8 100 31 722.72 ~?:.: ~.:..': ~'~:.::~.~ ~::..::~..~:~.~:~:.~..::.::.~..~...~.:~....::..::..~:~.:::~:~..~....~.~ 0.:::?:: >".'.:.~" ?'!:~.:~,~;i:<.'.'::".......': . :< . '." '..:.. i"O0 ::. '. ... :.. <:::".'.':~::. < :>.:"..'.:.".'.~..~../..'.~"':":. '..'....:~>.:./.~: ..'...'.'.: :.:::':':...':.~:2:i'.'..~..z:"..>..:..:..i..~.'~:.':~.'.l. · · ....... · ~:~:~::~?~?~:~:.~?~2~:?.:.:..:...~:::.~?.:~..<:~..~..:.:~:?~:~:~:.:.:/:<::.~.::.~::>:.::.::.~:..:~:~.:~ :~ '..~' "<~':.<.':':'..": :.'..:"'~':i::.~O".""..::~ .':':'.:..<':'..::.'.'.::.::..<' '~".:..':.:'.:'.:' .. '.:". ~'.::'."::<..:':.":?:.':~:.'~.::::~:~..~: :' ::'.::'.:::'.":'/'.:'":~'~.:2~.~::':~:5:~i.::':.''' <..::::':.:l/5..g~5.~:::":''' ," :.' .: ": :.'"":" ".':""..' 2573.0 40 23.5 100 37 721.28 159.50 £ WATEI~ H¥CA~B CbA CUM. CUN. SAT. DENS. VUbUME PURU&IT¥ H¥CAAB % G~/CC % F~ FEET 2574,0 2575.0 2576,.0 2577.0 25711.0 oo 10 300 40 300 400 I00 I9.9 23- 6 30.7 31.9 27.1 4 16.7 100 100 82 100 100 100 lO0 33 721 .Ob 25 720.U! 46 720.49 25 720.22 30 719.91 3.{ 719.5t~ 48 719.30 lb9.50 159o50 159.50 I59.48 159.48 159.48 159.48 2,583.0 2586.0 2587.0 2.5.88,. 0 259..0..0 2.59.2 2:,5 ./9...,.~ , O 2.5.9,6O ,300 -31-4 500 600 -{,0.0 31':00 800 2.0..00 1 32,9 3.3..4 31.5 31.,..4 34.7 O. O: 3~7'. 1 I_0 2 0 .. 1 1.0 2.0.. 1 I O0 100 lO0 1,00 100 100 1'00 100 0 100 · 1 O0 100 100 1';'00 I00 2602...0 i 0 20,3 10.0 ::i~!..:.~.~:~..!".i~i':i.~:::~i'.;:."i!'~.~::!::.i :'?:i...':::?"::::';i~. :":.:? !.· ' .260.4,0 $00 30.b '10.0 2bO0,.O 300 ~0.9 100 2608.0 200 29.~ 100 ~6~ '":~ 0~ ~:??,~.~.:::~,: /': ?': ::?~:~0~&:? ?"?',72~67~' 3 99 25 :718-84 24 19 717.90 lb 7.1.7.57 2 2 717.2.4 2 ,~{ 71, ~. '93 2 0 716. b.O 0 0 o00 § 7 l.b:o~t3 1'0 71.6'08 24 715...~1 48 7 I5. 48 715.J~ 40 49 714.82 159.48 15q.48 48 159.48 15.9.48 15.9.48 1~59o:48 159.4.8 0:-'0'0 15.9.~8 1-59.48 1'59.48 lbg.48 159.48 159..48 27 713.59 159.46 27:"':.:"."::.:.."::.;'.::'.:7'i3.28.: 24 712.97 159.48 22 712.41 159.47 2~t0,0 300 30'.7 100 . 23 711.84 159.47 2~14,0 40 23.8 98 34 710.78 159.41 o16,o 2i..6 ioo 3o vlo. l Isg. l .... 2020,0 500 32.7 100 I~ 709.43 159-35 .: 2o .o o.o o.o o o o.oo o.oo . . . ..:::: ] j:] .', :'....'....: .,.: .... "..'....:: ~.....: .... . . ..... .' :. . . ;; ~J . . ~ .... .~,:.~.:~ ~....:~. ~..:....:..:...:..:....::.:..,:.:~:......:..............:..:,......................: .....:.....,........................, ..~:.. ,.:........ ..... .......... :.. .... ...... ..... ........... .....,....: .... .... . ... ..... . .....: ....... ... ...... . .... FEET WATER ~ATo % H¥CARB DEN~ o GN/CC CLAY( % CUM. PORU& 1 T ¥ CUM. H~CARB 2623'0 300 2024.0 40 2625.0 50 2626.0 80 2627.0 30 30.7 24.2 25.9 22.0 92 80 85 95 78 ]0 709.08 qO '708.81 J9 708.58 35 708.3z 49 708.07 159.35 159.$1 159.29 159.27 159.25 2629-0 40 ~o0 50 00 · 2,3.8 2.5 100 100 I00 45 707.08 40 107.44 49 707.22 i59.21 159.21 159.21 20.'2 2034.,0 1000 30.1 2 (:, 35',:. 0 400 32..0 2b30.0 200 28.7 2..63.7 o0 O..0 O. 0 2.6.3.8...00 . 0 0 . 0 ~:~::.~i~..~ 'o. :o. o.... o 2040.0 300 :11.3 !~, ~:'~;,:~:i.'~!:.:O .~.o'o':~:::~ .. o ;~o4,z..o soo ~..~ ~.i~ ~!i;~.!Oi: .~:i0.'~. .;~:~ ...~ 100 100 O 0 0 1OO 10'0 100 I00 .2644.0 0,0 0o0 0 !i~!:.;L:.,..:.:i~.i~~.:.i:'::,,.......i.':ii~,:..ii.?:i~;~ ~.;...:.:?,.:.?:.:::.......::.:...,.~.:;.:o.~.~:.o o 204:6,0 0,0 0., 0 0 26,48,.0 2000 39 . I 1 O0 2650.0 400 32.2 100 ~6~t:~!O:.::i::....;i::<.:::'i..'.:.:::....:'.:~O0. .i:.':.3~.0.~.,~ .10'0. 2052.0 '100 27.1 I00 !.'?/'"!:::2615~3~'0 4;:'"'.':...:'.:':"/::...'::"'i~:1:'6 .~':9 i'.00. 2054,0 10 20.1 100 ;~:6~0i:: 2-00' 29:',6 1 0:0, 2050.0 300 30,9 1 O0 2658.0 500 32.7 ~100 ~::!':::: /.."::':::'::.:::'!? ~0:0 7. :::' "'. :?.:."::::i!31i:~ '~ ;:.. ~ .i O0 2060.0 200 28.5 91 50 706,83 23 700,58 2.0 706,24 34 705.95 o 0.00 0 o.00 0 '0.00 24 705.53 24 705.24 21 704,92 25 7.04.5'9 0 0.00 0 0..,00 0 o.00 O' 0.,:'00 lb 704.44 20 703.75 159.21 159.21 0..00 0.00 0.. 0'0 159.2i 1..5'9. :21 159.21 15'9.2'1 0.00 O. 0"0 0.00 0.., 0.0 159.21 159..21 39 703.12 159.21 t:a::'":...:.:':' ':'::'.'.,:'/:.i'.::TO,;.2~:':89'.:,".:-:.:i...':h.';:'i,59'..:, 2l 't9 702.72 159.21 31 702.10 159.21 23 .70'I';{'~'.'86 l'5'g' 2 :. I 21 701.54 159.21 2.37::'-';/::':'.. :.".' .:~0t>:"2 2'.'T/...: '..'/'.. 1 59.~J21 40 700.91 15g.21 2602.0 30 22.:{ 100 qO 700.35 159.1'9 2065.0 200 29.1 98 Ji bgq.63 159.17 ~:~'~?:j?':??~,;~:8~) ~:"::,~ ?j,)~?,~',' ~', ~:O~b:,':::j"'J'~,"J· ~t ~:"~,:,,'2~'~,{,:, "'~?;/,"/':",, ::',: ,,~" ':?"'"!,:')O0:]:,,';~' ,' '~,':' ",/~',, ', '",,,','/':,,"/::,:,:'~ :;:, ~,,'~:",,t,~:,~::;'~,: ~,]",,~,'], ,,J2 4,,'j:/' ?~,j,,,L,~98'~::,',]~9/,,~,,:j:: :' ':,,':,,!':59',i,'6 ,,:, ,,'" 2669.0 300 30.3 100 22 698.00 159, 16 2071-0 200 29'8 100 24 698.02 i59.12 . .: . . · ~??~:'~:~:'.:.:~: :?.~??.~?~?:"..?:~??:::?'?~ ???..?.~::::~:.::~?.'....?.?':.~ {:..? ..:.....: ......... ?.......::..:.: .... ."~: ..: ........:.:......~ .....'; ;.?:..:....: ~....; .....~ .'..........::....:. j...~. :....: .:... :.~: .../:/..........:....; ~.....:.: .... :... :...:.. ~. :.:'....:....:....... . . t~E.F'TH MD PO ~,.,~ 1 T¥ WAT~I~ ,SAT,, % H¥CA~B GM/CC VULUME % CUM. 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VOLUME PORU5 l'fY H:¥~C AR~ J214.0 O.O 0.0 J21~.0 0.0 0.0 3,216-0 0.0 0.0 J217.O 1000 36.7 3218:.0 400 32.0 J219.0 30 22.9 3220o0 322 0 500 32.7 9 9 5 0 0 o 80 94 100 94 100 I00 100 I O0 322?:*0 60 2'4.7 J2.3.0....0 JOO .JO. 1 3232.0 10 lg.b 323~.,0 20 21.4 3236.0 0.0 0.0 3238.0 200 28.8 3240.0 400 32.2 !:i:i?!.'?i': :::i::'i'-~.~!~i!~ O?::?'::?i.:...:.:"...!:3~:OOi?:':'-':::': :'.;i :3!l'::;:j 3244.0 20 21.3 ~,~:.45~ 0 li,O~O 27 ;:2 3246.0 100 26.4 3248.0 50 24.3 ~250..0 ~0 22.8 J252,0 200 100 lO0 0 100 1 O0 100 I'00 100 10.0 0 1.'0'0 100 9,8 100 !,OjO 100 100 100 1.00 100 i 100 t'O0 100 ".i'0:0 I00 3254.0 200 JO.l 1 O0 J25b..O 200 29-5 100 3~58.0 50 23.9 I00 ??J::~::.:~j: 2;0~07:::?':.'?~~ I00 ]2bO.O lO00 36.0 100 3262.0 0.0 O.O 0 0.00 0.00 0 0.00 0.00 0 0.00 0.00 20 56J.47 15b.05 25 563.11 155.98 35 562.80 155.97 30 562.54 155.97 30 502.2~ 155.90 40 561.95 1:55.90 33 5bleb~ 155.90 30: 56i. ~t4 155.96 29 5bO..B5 41 560.b0 · 0 O. 00 I0 560,,20 26 55:9.8'9 39 559.b2 44 5'59.42 48 559.25 4:2. 559.05 0 0.00 3:7 55'8'.'9:2 24 558.b5 31 22 558.07 16 557.44 I::9 34 55b.Sq 21 2O 2~ 2:5' 42 lbS.gb 0.00 155.9b 155.9.b 155.9b 0.00 .15'5..9b 155.96 1:55.95 155.95 .:.:'~:1:..5.5~:.9:5: 155o95 556.30 155.95 555.77 t55.95 §55:~:5~ i:'55..9"5 555.~2 155.95 42"?:'.'.' j': :'55':'4.!g':98 t55'95. 26 554.75 155.95 · <:'"""':: ...... : S"-'"' "" ': ' "'"': ' "' :" '" ' ':" ........ 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' 155.79 155.79 155.79 155.79 155.79 155.79 155.79 155.79 1 §5-79 155.79 155.79 155..79 1.55.79 155.79 15.5'.7g 155.79 1'55.7'9 155.79 155 ..79 155.79 1:55.79 155.79 .'t.55.79 155.79 '::: 3541,* 0 400 :29:. 5 100 , 2 487.56 ~543'0 000 ~s4'5.o 700 ~'~.:~::::~4~?::?~.?:.??.:?::J:~O~O.~:~:~:. ~ 35 47,0 500 ~?:.~.:::::??.~::: ::~::?."':?~:~::::j:?:?. :.:..::~:i;?~::.::'..':::.::.:..... ::: :::..: :':":' ::?i".o:O:.'.'. ':.:::':..':::.'::'::::'.':'.".'..':.:::.:.::?:: :'j.:.: :::':' :.::'~.:'~:::'::. ::."::':':: :"::'j,::j:~:~.".:. :...::::..:..:.:: :j:~:~:.~:~'~::. ?..::.:::":::::.:::~..::':i::~9:.%.:'.?'9'. ::...:'.': ".".'.'"."...".".:'.' :.:.: .:.:' 3551.0 1000 35.3 100 3 484.41 155.:79 ~::~:J::::?~i~S~{~O~:??,:~:;:~::~.:~;~;~O:~: ::::.?.::.??~:~::0::.'~.:::':::.?:.:::':.':.: ::" :..:.:':':::.?':'/..~.:0'::· .'?'.":::.:::':::.:'::.'/:::.' :::.% ?::'".:":::.':': ..":":'..::::':."?.::0:':::".?': :: ::': ."::::': ::?..':.'::~o:;:00:::".:?/'.:. ::".'...: .:'.o'...o..o.' "..: .' .'"" '. 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VOLU~E ORO~I ~ ~ H gCAR~ ~ GN/CC ~ F~T ~ 4586,0 100 25.2 4587,0 80 28,3 4588,0 200 4589,0 300 J4,9 4'590,0 300 34-0 4591,0 300 34,2 4592.0 300 34.! 4593,0 200 J2.9 4594.-0 200 32,5 459b.0 '200 il. 7 4597,0 100 25.2 4598,0 1'00 31.2 4599.0 400 29.J 4'6'.00.0 3.00 28.1 4601.0 100 30.1 '46:02~.0 200 3:2.9 4603..0 lO0 460~:~'0 1.00 4~o~:.o ~oo 4.60:7.0 200 28.3 4608.0'!>':::~'":!"?.:..'.::0.0'6~0 72 9 228.93 59.95 bO 7 228.01 59.~7 59 4 228o3e~ 59.7b 55 O,tJ, 4 228,04 59,02 56 0.8, 4 227..70 59.47 54 0.8, 4 227.3b 59.31 54 4 227.01 59.16 55 59.00 55 0.8, 58.85 56 O,U'* 58.70 68 58.58 ,0 75 58.34 '7.6 58.2'7 b5 58.19 bi 5'8.06 t:,4 0.8, 57.94 b4 0..8~ 5'7.83 73 57.74 86 57.b8 71 57.63 0 0,00 5 22b.u~ 6 226.35 10 2 ,02 11 225.a; 7 225.21 2 224.9O 0 2.2'4.bi ~ 224.32 0 224'°01 5 2.23.08 9 22'3..-38 10 22~.09 1'"1 222.82 12 222.56 O. 0,0.0 40,30,.0 I 14.2 I00 33 721.36 57.48 463~o0 6 17.8 10.0 30 220,e9 57-48 · 46 ~ 8:. 0 40 2 1 73 0 · 5 20 2:20 ' 57 · ] 7 4 40,0 30 2 .2 Ob 0.8. 24 219-83 57.24 4642.0 50 24.6 62 2i 219.:J5 57.07 4644.0 50 25.4 64 0.7, 17 218.85 56.89 .~.~: ~?'>">""'"';Y;.' <'~."~S>.."> '"% '<":J.':.>'. ':'"~:"'<'J"J> :"' ".>'.' '~'"'.T' ."' ~'~' ".':': "./'"~'" .... .' .< "" :';' '<;' '. ": .... "'."' "'" :~,' ""./" .'<'.' .~": ':" "'"'"Y.' ,'.<'<'.' ".'"~"'..' , "... ".'.. "/.":"' .~:'.'"j."""..~ ~' .'"' '" .>.'y'<"".':';/.""." ~' 'j.. "" .'. '.' '.' )'~..' '.'" .' ~;~'~ ~:'~;~:'".,~':"~{'~ ~.~:~ ~0:~'~::~'::":~:~''.'< :'"::::?'t~'~O::~:':~<<.'.:':::" <:'~2:'8~:~:2.:' :"'..' :"..' :';' ?..'.,'.'. ': ..' 5.'8 .:':".': :'::: ~:''''' .'::'"':..':..'~. 0 :~.:8'~ :. ::". :"'"":'~:':?i:: 7': '?' :' ::':"'.": "2' 1' 8; '~0'~'.'~."' :':': <': "':' 5~ :~'80" ":; "'" .":': ":" '." .'."' 4e46.0 70 26.4 59 0.8* i7 218.32 5~.68 :.~.~??:~::~/.~' ~:~:.~~~::?. ~;~.'~:'~.<:'<;~:i~?~/;:~:~ ~.:.?..~:J~ ~; ~?i~9;'.~:~J''~ "<: ..'?'> Z..'...: ..'!~9.~...'.<; .".;~::.'.>...:~; .;' ./L'.".':..".'? ~'". '.> :'.':'. :~..."r~:.'::../. ~... :'....:, .~'~ ~ s,..o.~. ;;..... :~.;'~. :......>:~:~. ~S;9'..' .: ': .:'.~ :.'....:.' <.. >": '.... >..'"..'"' ?~??~:<~,~:~~0.?:?::~'~ ?:;'~': ~??.::: ':~{ :j:.: ~:~0;:'~:~ :~:::::::::::::::::::::: ~:'~8" '. '. .. :'.::.~ .~'.: <>:<":./':":<':' ?:)b::9'<:'":'>:.. "...'. ':: '.:':..: '. ':0' ~.b~....~.'. '.:<.. :.':~:..:: :.~; :..:~ :2;.?: ">'.'. '"' '<':'2:1'7':~.'.b'6: ? .>~,~ '.:.'..:'"~..'..~ ', ::':'5~'6J'~::5~2' .::~:'>.':'.. ::" :': :': ~.'.":'."~" ':~":";'..';: ::: .: ? .": 4650.0 90 25-2 68 0.8* 14 217.41 56'44 ~?~'???.;??.~<~?:?<...<~...'.~ :'./...:. ~..~.'..~;:~.~;.:<>??:.~:.~?~:.....<..?..~ ??..j..:j.>?>...?<. ?....:..,.. ::....>.. :..<:....<<:.,.y.<..,.....:... ~; ....... :..:..........:..:~....~.~........ %: <.'..'...?>/<??:?~ ~.:.'..: ..'j~ ..' .:...:'.... · ...........: ,...:./..:........ >'<:.'/...Q..~. .......?. .. . ...:.:.. :.~. ... . .. .. ;........,. DE[3TH PEHM. MD P t3~,~ I T ¥ % . tt¥CARB CLAY CUM. DENS. VOLUME GM/CC % CUM. HICARb FEET 4651.O 4052.0 4653.0 4054.0 4655.0 465 .0 'o .0 .O 4062.0 4653.0 4~4.0 4068.0 466:9 4570.0 30 21.7 100 25.b I00 2b.2 200 27.8 10'0 27.0 90 25.2 90 24.9 10~0 2 u. 9 200 2.7.4 I0 28.°2 28.6 3OO 28.9 300 29 'b 3O0 28.7 200 28:' 3 I00 25.5 60 2'.,3 ..'7 I00 25.? 90 JO 22.j 85 72 7O 70 '74 74 72 7 71 78 89 78 8'0 79 14 217.17 O.Bm 13 21o.95 0.7, 13 215.09 0.8, 12 215.4J 0.8* 13 216.15 0.8~ lJ 215.~9 12 215.6~ 12 215.38 i0 215-11 0.8* 8 214.84 O. 8, 7 214'55 0.8* 0,8'* 214.2b . 21.~.97 9 21]..07 10 2.13..J9 13 213.11 14 2.12.85 1.2 212.o2 15 21.2.~0 20 212.11 56.]7 5u.25 56.10 55.99 55.94 55.87 55.81 55' 73 55.47 55.39 5 55.13 la~ - 2 3 4 5 6 ? ~ 9 10 11 12 13 14 15 1o 17 1~ 19 2o 21 2'2 02010100 0 0 0 0 0 0 0 0 I 0 u 0 0 INPUT ,PA~AHET~RS F~O~ 5870. T,O 4675. 9.b 0.b0 12.25 11b. 7000. 50. 2.70 75. 0.99~ 0.~gb v. Sb0 0., O. 2. ,20 7000. 2430. 0.000 1.00 0.000 6.30 8.00 .200 0.000 ,10 0.30 62500. b.O 2.0 4675. 0.220 0.470 o.040 0.230 .0~ :.O40 bO. 44. 7b. 150.. 150. 1..OO .J0.O E.;D'..I.'.AH .PN~.i~H.:........'.:~PDb 1::~ Rb.l M GRLI.H V-A.;RH.C CON:ST R.IIP V.A~'b..I M .C~E 0.00 0.19 0.30 5.0 1000.0 0.07 0.333 0.70 O.2u 0.02 ~P ~ATI~TIC~ OVgH ENTIRg INTBRVAb GA.HNA - RA.¥ ~TATI:,STIC~ OVEN ENTIi~E INTERVAl., pLUM. HD % CLAY ¥OLUME % CUM. CUM. HYCA~ 4681.0 4681.0 4084.0 4685-0 461 ,0 0,2 10.7 5 15.5 ] 14.1 :10 19.b 40 20.5 50 19.B 50 19,,, 3 .8 .2 17,.9 19. i 18.5 1.7'... 9. 17.9 20.i 0.0 8.2 2 12.6 10o b4 5O 45 38 34 ~2 29 3..0 29 '30 ~4 '41 98 53 47 211.2Z 55.11 37 211.10 b5.09 25 210,96 55.05 21 210.81 54.99 17 210.bO 54.88 15 210.40 54.70 14 210.20 b4.b4 14 210.01 5~.52 16 209-82 54.]9 lb 54: lb 209.24 15 2.09.0.0 18 208.87 20 208. t~ 9 22 208.51 2.1' 20B.34 It, 208.i5 1. 5 2.07 .. 9.5 34 207./0 49 20:7-. 50 207.§4 24 20::?'4'~ 43 207.25 53.49 53.3.7 5J.24 53.11 Si.go 52.94 52.92 5.2. '89 52.80 63 45 29. 27 40 47 22 206.83 20 206.43 52.53 · I::0 ::">'.::20:!~:'::~.:24...i." '.':.": ::: :':'".">."'.':. ". 5:'2ij~ .4..2 11 205,97 52.23 i:3':.:"..: :..:'." .".: :...':...':::205':i:.~.::t 5.2.-'..0 18 205.54 5.1.95 4717.0 0.2 10.4 98 43 205.1b 4:{i:ii!8ii~ .], Ii3i':~:2 ~'.:~ 40 2'05".' 05. 4'~i~.o 0.0 o.o o o o.oo ~::;:??.?.~~07 ?.:':'::.?:.:' .~'.~'~.'0~..;::0':~??':?<'~~'' ~:'o :..<' ~..:....~.<'< ?'.:". '..'.::.>~' .:: 0'<.: ~:': ../':..:""'> <:<> ~:; :>../<<:(::. ><j: .>'~' :~<Oj:>: >/>: 4t21.0 0.0 0.0 0 0 0.00 ~::~':.<?:~::~?/a~i?~L:,'?..'. j:':Y'.~:~..::;~.~O.:: >'?<.: <?:~ :~. :..~:~':~:.;'.".:('::~ (": '<:.:..'..>. :::'.>. ::'>>:0~..~..:>...:'.:<< :.: :.:.~?:.: ...:::'..'.:><::.::?~:.:.: L;.:~?/.....::, >.~ ::::?.': :::.'...<~<::~,..: 4723.0 0.8 12.9 100 27 204.80 MD 1,~ATER H ~C Alqlj CIuAY( (.U ~ CUM % GM/CC ~ F"L~,'I' FEET 4732,0 47]3.0 4734.0 4735.0 473'6.0 4737.0 4738.0 4741,0 4'7:42.0 474.~.0 4744..0 4745,.0 4..7~4..6,. 0 4747.0 '4'74~8,0 4749,0 47 §0'. 0 4751,0 4?53,0 .4..~:.54:. 0 4755°O 310 15.5 8 12.0 2 9.1 5 6 ii ,5 30 15.2 5 ll.b 7 12.9 10' 13.9 5 4'79'7.0 0.0 5.7 4769.0 0.3 10.9 4771.,0 20 20.0 4773.0 10 1'1.5 4775.0 20 18.2 ~ ~i~::O.'i:'.::. :,'::.:.....::' :!'::::'::(:.":'...:-:::~JO 1:5 ~' ,.,..t'. ,t77'7.0 ~0 17.7 4779,. 0 50 19.. 9 29 30 35 3O 29 .35 3'7 37 35 32 .tl 41 4'0 44 .47 58 5'6 58 b'O 100 100 6.8 · I O0 71 8.0 74 77 -i'.'O0. 100 64 0 62 82' 4:6 .:19 31 20t.99 J5 203.84 39 203.72 42 203.05 36 203.52 30 203.3~ 41 203.24 39 20J.15 36 203.00 22 202.84 20 202, b5 22 202.0~ 28. 201.8.9 24 201.1~ i '9 '2:01.58 19 201.3~ 1'8 2.0'1 . 20 201.00 1.'9 2.00.84 22 200oUb 4'5 2'0i0.4"~ 45 200.34 51.49 b1.38 51.30 bl .24 51.1b bI.OU 50.96 50.89 50.81 50.71 50.59 50.17 50.00 49.98 490.87 49.75 4.9.b4 49.55 ,4.9.~'8 49.~0 4'9.32 49.29 48 4I 4:i: 19'9:,:'~5 4. 9:. 20. 2b 199..71 49.17 3,51 i'.~i~..'...:.5.3 4.9 ..'..i '2 37 199.41 49.10 2: ~. 199.2,4 ..~...9.0...~ 39 199.04 48.9B :4:2: .I 98',:*"9'3 4'8 '9'7 2':8 28 198,,b4 48.9.7 24 198.45 48.9,7 O 0 o 00 0:;?00 28 198.24 48.88 ~::2:,'?,?/'""J','/I, 98 g,'O!9'i":!'/i',,,:i':':',","/',',::',:~4~B~i:8 3~ 23 197.95 48.78 2:9 19:7:~80 '~.:*' 7:t 25 197.04 48.b2 :29 ':"l. gq'. 4'~ :4':~,:' ~""1 17 197.27 4B.38 (. .. WATEH HYCA}~ CLAY CUM. Cui~. 6AT:. DENS. VOLUMi;; PORO~ 1'1'¥ H%CAR0 ~ GN/CC ~g F tSl:; T FEkT 4780.0 4781.0 4 20 12.9 i7.8 50 34 197.0~ 48.2, 7 44 40 190.95 ~{B. 21 47t) 5.0 4786~, 0 3 0.0 8.3 O4 40 19b.47 4~.03 100 42 19b.33 47.99 4791.0 4796,0 4.7'97.0 479B...0 4799.0 0.0 b 0.5 1 0,.0 7:. 5 ;lO' 4 17.2 l:b. 5 1,5.2 12.1 13.7 100 34 195.93 47.98 100 50 195.~0 47.98 72 47 195.79 47.98 54 26 195.0b 47.93 57 23 195.~8 47.85 68 21 195.04 100 4.2 194.9.2 .480!2.0 '0. ~ :1 :I. 8 - 71 42 'I 94 ...b ~ 47.59 4803.0 0.1 9.2 100 35 194.~7 47.57 4:8.'0..~0 0,.~ 12 -6 72 27 194.. 48 47.57 4ao .o 4813.0 0.6 12.3 77 27 193.39 47.26 t"!8:! 4:~(.0 2 l.~:.~a:::2 7 b I::8' 19 '.3.'.'.: 26 47..'. 22 4815.0 6 15.~ 64 21 19:3.11 47.1B :~'iJJ'!:!.'.ii.:J'~i~;iii~:~!O: :0.:~'~'i! :!~:.~J.:5'..::.'' :....' :.:..i:...:.:,..'.',..::':I:00 3:2 I~2.i~.*i:9;63"i:.:ii:J 47.... 4819.0 0.1 8.9 100 39 192.63 47.0b 4821.0 0.0 5.b 100 47 19~.49 47.0u 4825.0 0.0 0.2 100 47 192.2~ 47.0b 4829.0 0.0 7.0 I00 45 191.93 47.00 4'040.0 0.0 7.1 100 36 i91.30 47.00 :~O:i~:~i~'iiO ;J I'::3:~/~ b2 3:0..':'!:i/'../V':":lg!t?i* 2:'! :4'7':00 4842.0 20 18.4 49 28 191.0o :.~:~'~O:.:'::"::.'.:/::~:'.::.J::.~",::?:~:i:O: 1:6::'::~. 5:.~ 2.6 1.9.0 .:8:8 484b.0 0,3 11,0 77 29 19~).b3 DEPTH % H¥CARB GM/CC % CUM. POROSITY CUN. H~CA~B F~ET 4847.0 484~.0 4849.0 4850.0 4851.0 48 4858- 0 48.59"o'0 4.8'6 4.862o..0 4864.0 6 15.6 30 19.0 20 18.1 50 19.5 60 19.9 19.7 bO 20.0 ?0 ,20.4 40 18.8 50 1:9.4 40 18.4 · 30 1.7:~.b 30 17,8 30 .1':,?:'" 7'" 10 .15.8 6 1":':~:.* 6 i 8.'0.8,.0 J 0 19., 4 ~:'~. 40 20.','4. 48:70'.. 30 19 ,I 487'2-0 0.4 11.0 4876.0' 0.0 4878.0 10 17.0 :'4:!i~i.~i0 ::::::::::::::::::::::::':..:.;.'...::.:~l::87.' 9 48,80.0 40 18,,8 :::! i~?~;.:i?!!.~::8~8~i~i ~:.O '2.9b !::.:?:-.'."~ :"?'~.' .:':..: I i6!'.;~ 9 48'82,0 30 .17.4 4884,0 JO 17.2 60 4b 43 37 35 37 4b.70 40.02 46.52 4bo41 46.29 4bolo 4boO4 45.91 45g79 45.0b 4.S'S2 19 18 18 20 19 17 19 17 18 1 1 1.7 19 18 19 19 1 '9 14 1..8 14 19 1.3 190.41 190.24 190oOb 189.87 18q .b8 189.48 189. 189.09 188.89 48 188,,28 188,,09 187.90 :1.87"- 7.1 187.54 I'8:?':- J'.~. 187.1~ 18. 7...* 03 1.86.8~ 1 181U..52 i':8..b .. 186.12 t".8'5.:...9::~ :15 45.14 J6 4.5.02 3b 44.91 3'9 4:4.7.9 49 44.09 51'3 44, bi 45 44.54 4.':~. 4.4. :4.4 47 44.3.~ 4'6 44 .'2'3 4'/ 44.t2 5::7 44. '02 100 12 185,77 42i.97 1":00 :~:8 L85'~!'5:4 4 ~.i' 9:7 100 40 185.49 43.97 6:6 2:2:.i.: ?.;:'; ........'.:...:::!..'8.'5.'i 4.0 45.9::7 5,4 24 185.25 43.90 4::I 22 '1:'85::., 05 37 23 184.8e 4~.70 3:8 2;6. 1.8':4:.:'*:0~8 ]7 25 184.50 4.{.47 ':~8 t;6' 1:8 4;.:.:3.3 37 27 I84,~9 4J.2U 40 12 la3.aO 43.04 38...::-.'"....".'~: 20 i~ 8 3,:*:'~0 40 15 183.41 42.80 40 '::.~0.?.'.:': 18.::t * 40 20 lO].O1 12.56 t2 }5:.:.b.'..;.;::..:: ..... ~..'I 82;";B:i..:.~.:...::;':.::::' 41 19 182.01 42.33 4i ;.18 I'82 ,::'4:2 42 13 182.22 .42.09 4895.0 489bo0 48'97°0 48! ~ 490 7. 49O8.0 490,9,- 491,2..0 4..~.14.... 40 19.7 10 15.1 3 10.9 5 8 I :'i .4 20 1},,7 .! 20 16.4 2O i6.4 10 i4.7 2:0 l..e. 7 2.0 16.. 8 1.5.. 9 .I3'..~6 .50 ............... 1..8.'.. 1 39 :10 42 42 37 3'7 38 34 38 ~2 20 182o02 41.98 35 1~1.85 41 181.72 27 18t.bl ql.73 24 181.49 41-b6 25 181.J4 41.57 34 181.19 41.47 23 181.Ob 41.3~ 180.90 41.29 .7u 41.21 .b4 25 180.49 17 18'0..32 20 180.lb 20 160.0! 22 179.84 2.I. 27- 179.51 31 .17.9'°3~ 25 179,23 2'4 1.79.05 41.12 40o8J 4'0.74 40. 40.2b 40. lb 4.920.0 ....... 3. . .14.0 b5 42 174.48 ........ 4922.0 0.0 b.O 100 47 i78.2e 4924.0 0.1 8.7 lO0 39 178.14 ~4926:,0 3 I~.4 ~4 28 177.95 4928.0 5 13.4 50 · 30 177.65 ~J:~=.~j~::~ =~:~???'~..:.<~?{=?~:~::~.~?~.~:./:j:".::. :~.~:.j' L../:.:..' :.=~:.~=~.".~.:/.:. ::. :/ .. .:.::. . : :.. ?~ .: .~ :'.:..=.. :..../:.~.'::.:::~'?'/'....'<'.i~:i.~;.S.~/~.: j..j ~:~~~/~:~?~:~?:~;~:~=~j~j<~? ~l?<?:/. ?.~j~ ..~.~ ~:==~..~...~=/.~.' b'o...:.~... ~................::..'~'.~.? 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I. 0::i{:::"':',""{: ,,9' I';~7':,:;,,', 25 103.b4 17.23 3~2i.;i<:.:'../.....'i.:.'./::':..:l'::O'.]>".Si:'...'.>.:...i:'.~J:.>:~/';:;~..J' 2b 103.38 17.07 {JS~:~:;:'?').':':'' '::"fJO".3:" 2:5':'"'::?:::~'.'~':~'..JJ':~':.::'J'.":~J~ ~::~'00 34 i03.~4 Ib.94 P FEET t4U % % G~/CC ( CLAY CU~. 5657.0 0 . 0 566 1.0 0.1 ~.662.o 0.0 5:66'3,~' ' 0.0 0:~ 7.5 1.3 .7 561,.8,,0 0.2 5.66.9.0 0.0 5 b 70.0 0.0 567 I:'.. 0 0.-4 5.672.0 0°5 .5..b. 7 4. ..... .b .2 I1 . 4 12.1 5.4 10.1 11.5 '1.f'9 0.8 12.6 9'682.0 .... 0. I I0.0 5684,0 0.0 6.0 5686.0 O. l 8.9 5'688.0 0..2 10.1 !. :.,::'i: .svol.o o.o o.4 5703.0 0.0 8.i 5705.0 0.0 7.3 5707.0 0.0 0.0 lO0 1 O0 100 I00 100 90 I00 70 100 I00 I 99 100 100 I00 99 95 9;5 I00 100 lO0 8,7 100 I00 100 100 iO.O 100 100 100 100 1 O0 I00 100 38 103.07 16.94 31 35 50 30 33 25 102.76 102.67 102.62 102.ol 102 102.45 102. ,37 10.94 16.94 16.94 16.94 16.94 16.9,1 27 10i.90 4'1 I01 '. 8O 30 101.75 33 10-1... 6.5 2,,2 10,l,. 43 21 101.31 35. ..1' 01.1 '~ 16.90 16.90 16.89 16.8.9 16.88 16.86 47 1'00.9.7 lo.8'0 30 100.89 16.80 1'9 1':0'0.",~8 t..b'79 $b 100.70 16.79 2'3 32 lO0..SJ 16.78 27 100.32 16.75 o 0o00 0.00 4:9. 9 8.75 16 . 7..4 DEPTH PEB~. PU~81T2 WATER ttXCARD CGAX CUM. SAT,. DENS. VOGOME POROSITY % GM/CC % F~T CU~o FEET ~? 5715:o0 0.0 6.6 5716.0 0.1 9.8 5717o0 0.7 11'.9 5718.0 0.2 IO.1 100 37 98.70 16.74 96 31 98.03 16.14 75 14 98.92 16.71 87 23 98.42 lu.70 5720.0 0.0 5.9 100 40 9~.~2 IO.09 57~t0.0 60 9.7 7 40 97.97 O0 § 7 '12.0 5.7'4 3° 0 0,2 10,4 7 0.0 98 38 16,54 ~8: 36 16-5] 97°48 97o~8 5'7.5'8,.0 0 ,I 9 . 5 l O0 4,4 96 , 5.3 I b.o 43 5759.,.0 .... 2 ......1..1.:, 5 5b 48 . 96,44 1.b,,43 ~:?.:!,.i?:::~'::.:'.'.~' .5J~i6:O~:.~!,'..:'~.:'J".':J'. :..::..:..% '.?:.~4.:':;....':."/"".'.'.i':.'2."8 '".' ::.' ..... ...4"7" .... · ' :'.. '. "' 4'2 '.."."" ' '.9.6..:, .3~'.' '...'."' ' ~.'. ............... 576t...0 ..' .2 . 11..0 45 .42 96.22 . 16.]4 ?~:~:~?~:~:~:~;~s~/~?~:~??:~?~:~?~;~::~::~/~:~?i~:;~i~?~:~~. ..'" ...' .",..'4.~.: ..".':" :." ".'..'... · · · ;'..:.".~;.~;." 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'/.'" ~..:'..'..'.,"4~.:~..':..":.:'.'. :.'./:...:..'.' L':.~:~:~....".s.l. ..... .....:.. ':?.~:.4......~..s..'..'" ..'.. "· DEPTH i:'ls~M. ~.ATER HtCARB CbA~ CUbt. CUN. ;5 a'[. DEN6 . VOLUME PORO~ JLTY 5826.0 0.0 7.3 b827.0 O.O 7.J 5~29.0 0.O 58J2.0 0.0 0 0.3 0 0 . I 5'8:39 · 0 584.0.0 12.9 11.3 11.4 5847.0 0.0 u.8 58.'48~0 .0.3 tl.2 5849.0 0.:0 8.4 585::'0:..0 .0o2 .10.3 100 47 91.44 14.73 100 49 91.30 14.7J 100 45 91.21 i00 41 91.0~ : lq.l] 76 24 90.94 14.73 9~ 29 90.81 14.b9 99 49 90.72 14.69 I00 28 90.43 14.69 100 28 90.jJ 14.69 lOg 35 89.98 100 2.b 89.8.8 100 ~.2 89.7't I"0'0 JO 8..9.68 5'8b:4:.~0 '.:: :'.':,,':..'..:'.'0...o' 0 '5 ...~ 1 O0 4b 8.~..! 3 14.6.8 5 8...6.b..,.0 0.0 6. 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'..'. .... .~.':.~,~ ~,,..~~ l~b - 2 3 4 5 b 7 ~ 9 10 11 12 13 14 15 1~ 17 18 19 20 21 22 0 2 01 0 I 0 0 0 O 0 O O 0 O O I O 0 O O INPUT PAR:AHgI~gRS FRON ~000. T,O 58?0. WMUD XbI~ 'B:ITSZ B:HT BHTDEP SUFT RHF RMF'I RU'MF$ PH, I~P~ DASIL 9.b 0.50 12,25 lib. 7000. 50. 2.70 75. 0.998 0.996 0.850 DSPCIt 1 0. ~LRGN &]fART 5IUPL ZSPNL BGN ZS,PDb t~EC HI~,SH CSS 0.20 7000. 2430,, 0.000 l.O0 0.000 .6.JO 8.00 O.b .200 0.000 ,10 O.JO b2500, b.O 2.0 5870. 0.180 0,,,~170 0.040 :PHI,N.SO A.R PUN DAX DAIalM DAGA DA,Sit DT.SD DTSH CP PS.SH · 0.'230 .04 .036 bO. 50, 4.0, 88., 15.0, 150'..1.00 .300 E.D'i.A'M :P::N:L,i::M 0o00 0.39. 0.,30 Ab. IN GRLI:M VARHC. .C'O~NS:T R. OP. VA-P,h'I.N CaF 5.0 1.000...0 0.07 0.J33 o.70 0o. 20 0.02 GAMMA -{~A.¥ 8'i~A~I',STIC,..'3 U:V'ER igN'ilRE INT~]R.VAL, D 5 P P~BM. PO ~X WATER % H ¥CABi::t CLAY CuM. VOLUME PORO611' ¥ CUM. 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'"4.:3. ~!':a.,~:."?!?:~i':::.'::'.i'~!f,i~.~'6;O'?;;, '. i! .'.i.j.;;.:.:.'...'.;~'!:':..'"'.'.!",..'.'... ~-o o.o 4~-o ,~oo ~o 4~.~ ~.~o . . ~?i?i!Jj:~i~~. !~?~,j i,.il.il i'.iiii'~i~.ii.ii:~;i i.!i?i'i!'ii!j~:;i~:i!.? i 'i.!'..',:/.i'.'.;i..i. iiij!~0,/i!'j.'i i:.i"';i ?i'iji..'i. !,ili:/il..: !:"!'::..:?. !~ i,'!!i.:i?ii!j:. !i"~ ~i.'" !..i?..'.'.": :,.'":.,:.4 3!~';~!~}, 6~81,0 I 13'-4 75 27 43.b5 ~ii~;i.~;~.~!:!:~~i~ii:ii~.~i:'i~!::..i.i ::i.??i~i~ ~:i!.ii~!i.i;!ii.~ !:?~:~i.~.:,ii?..:T~.,,. :'.?.!:'."!.~.iio~.??~ ;'.. ;.: ?.'?.. ::~,:;. !..: :" ;. ;i ?i ;.. ~. ii.' i!.. ;,..:'i:!; ;.~..,~ :'..;. :'~i: :i ~?i~i' ~;~ ~. ;. ~. :. ~i,! i;~'~ .':' ~'.:: ~/'.:....' ... ;;'~': ~.'.~ ~5...~,!i; 6383.0 0o0 7,6 100 2~ .43,.44 8.57 ~i!?i;!~i`ii~~i~!:!!?!:.!!~!:!.i~`!.~.?~!ii.!~?.C~:~i~i~..!.:.~;.!~..~..~.:.`....~!~`.:i.`;`i`.~.~:.~/.i!~...;;:~/`:/..;.::?:~`.~.?;:!...~.i.QR.:.?.;?.:..~i%~!~i~?:`~.;.~`~... ~..'..::' '..;..~.~"~.;.,~:i~!?!.?.!.~,i,'.:< D~PTH WATER SAT. % HYCARB CLAY VUbUHE CUM. b39t.0 0.! 9.2 6J92o0 0.0 8.4 b393.0 0.0 b.9 b~gt.o 1 ~t95'.0 0.3 10.9 6~ b402.0 6 '4 O' 3- 0 t, 4.04..0 e,.:405.,0 b 4 ob.:..O. 0.1 ,1 5 0"I 0.! 0'0 0.0 8.8 8.b 17.4 4 15.0 1-t. 3: 8.5 8.8 8.5 7- 9 641o.o. o.o e4!2.0 ...... 0.1 6418.0 0.0 5.2 6420.0 0.0 O. 7 6422.0 0.0 5.5 100 100 I00 78 92 100 77 58 bl 78 100 I00 100 1.o0 lO0 I00 100 1'00 1 O0 93 i O0 100 100 I O0 I00 I'.00 100 100 70 ?3 lO0 O7 i O0 100 I':'0;0 100 190 100 I00 29 30 32 19 23 29 49 3b 18 15 20 24 40 48 42.81 42.72 42.bb 42.50 42.43 42.32 42.24 42.13 41.95 ,il 80 4I: 41.]8 41.22 41.13 43 41.0.3 38 4'0.99 26 40.94 2a 4'0~85 8.57 8.57 8.57 8.55 8 8.48 8.39 28 8.25 8.25 8..25 8.25 8.2'5 a. 4 .4.0.a:'.7:.!3 8*2,5 40 40.b9 8.25 a8 ",.:':~:..:'::4~O'i~';b.:3 :~..,.:.:..":." :,~:."',:',.:..'.,'"'8 45 40.58 8.25 · ~:8 ~!~::;.~5:.2:. 8..~2:.:5. 39 40.45 8.25 42 40.33 8.25 25 40.18 ~.23 23 4:0., 0.~: 8 ' 1:9 3B 39.95 8.17 22 39.81 8,1.7 39 39. O0 8.13 3;7 3~9:,,55 8.'a~ t 3. 49 J9.51 · 48 :.:~.~9::.~.~8'. .~'-.~.:1.'3 44 3.9.46 8.13 41: 3.9.' ~':l 8 ...13 49 39.,37 8.13 31 39.28 ~.13 Ut, P'i'H Pis,BM. FEE;I' MI3 Pt % WATER ,.SAT. % H¥CAt{t~ DEN8. GM/CC VOLUME % CUM. CUM. R)RU6 l'f ¥ H ¥CAR8 .... b'439.0 0 '0 5.3 100 6442.0 0.0 b443!.0 4 5.0 I00 1].7 59 ,0 b4 .6 66 1.5 77 . 3 I O0 10.8 95 58 7.5 I00 i O0 100 i'.O0 76 100 70 63. bt) · 1 O0 100 7:2 75 1.:0.0 lO0 6475,0 0.0 b.4 I00 e477.0 0.0 8.2 100 6479.0 0.7 9!,6 bl ============================================ 648 i,..O . O,g 9.,5 52 6483:.0 O. ~. 9.4 76 : . 6485,°0 0.0 7.5 I00 ..... 6487.0 0.0 2.5 I00 39.23 8.13 50 39.15 8.1 ] 48 39.0{S 8.1~1 22 38,78 22 38.b0 23 38,4b 19 38.34 25 38,24 7.94 7.90 7.88 ..t5 37,97 19 3.7.78 32 37.b4 42 3.7 ,.b'5 39 37.49 29 3:7:. 4! 2 ! 3.7.,..3 ! 31 3'7 ,.2.i .... 28 37.1..3 2"3 3'7 ... 02 23 30.91 30 36,74 21 3:6:. 45 3b.bl 45 43 3b.35 '4::4 7.73 7,73 7.73 7.7.3 7.72 7 7.69 7.62 7.59 7.59 7.57 7.53 7.52 31 3b.02 7.49 33 35.87 7.49 :47. 35.' 8I:::'..'::: :. '".':.'" ::.'" '.::. :'.,. ".".'7:'-"4'9 35 35.76 7.49 2b 35,57 7,46 28 35.35 7.3,5 28 35.i4 7.26 21 '34.9b '7.24 :2 !~:~ :i:~:.:: 3::~::."8 9:.'::?::'..':.:'..:.':i::.:':.::..:>:~:,::2:..{ 27 34.85 7.24 2:b ~"~:~'.8::2 ?':.~!':~ ~'~ 40 34.74 7.24 DEPTH PERM. WATE~ SAT-. % H¥CASB DEN~. GM/CC ¢ CbA¥ % CUM, PORU6 IT FEL, T CUiq. H¥CARb 6490'0 0.0 (~491.0 0.0 6492.0 O. 0 U495.0 6496.0 3.4 5.1 11,0 12.2 12.2 12,8 12,5 14' 4 12,9 1].4 12.2 '9...,..5. 8.4 ~.~4 651..1..,0 ......... 0 . 8 9 , 9 6~'I~3.,.,0 ................. I. . . Ii'. 3 b515,0 10 15.2 6.517,0 0.0 5.2 65:19.0 0.2 10.0 ~52~0'. ~;:0 ~.:~:~;07:;:...'.:>;:'.'"<.:.::"':.~'.~ ~521.0 0.1 ~.I ~5~J.0 0.7 525,0 0.9 :~;~j':?:.:':. '?: ;?~:.~.:.?~:j.~.:.~'j~?~?~ ~527.0 '0.0 6529,0 30 U531.0 O. 1 ~533.0 0-0 b.l 12.5 12,7 0.0 18,9 9ol lO0 i00 100 51 58 53 49 55 5.4 6O 58 6.! 58 bi 50 1:.:00 100 69 ~7 70 0 4'2 1:00 100 42 34.71 40 34 .b 1 43 34.61 .{5 24 34.43 17 16 34..i9 15 34.07 14 33.95 12 ii 3:{. I1 33.55 11 ~3.,t2 1 } 33 ...2 B · 17 .3:3 o 1..'7 20 33°08 ! 5 J 3 o 0'0 19 32.92 23 3.2.8.4 20 32.7B 21 ]2.7.4. 16 J2,~4 % 1 '3:2"'. 5.5 lo 32.45 2;.:I: 3;2"a:...;~ 3 36 32.19 24 18 31.46 ~'...i1' 31.2O 0.00 30.79 7.24 7.24 7.24 7.18 7.13 7.08 7.02 6.96 6.91 6.84 6.77 6.71 6.64 6.59 6 6,49 6.43 6.43 6.39 6.36 6.33 "6::"2 8 6.21 .:b.::~ t'3 6.11 O.li '~'.' 1'"I. 6.11 .'6:::. 6.07 b".'03 5.99 5' 9 5 0,00 5.8 3 5";,:'.:72 5.6j 5.61 6537.0 2 14.6 88 lO 29.92 5.55 D~PTH F£,ET ~D P Ui{,.,~ I T ¥ ~ATER IiYCARI:½ CLAY CUM. CUM. · SAT . DEN,tS. ¥OI,,UME PllRli61'l' ~[ H ~CARB % GM/CC % FP, LT FEE r .0 b545,0 .. O. 2 I0.0 0.3 0.! 8.6 O0o 0.0 8.1 i00 21 29.79 5.54 I00 15 29.b9 5.54 100 22 29.b0 5.54 100 45 29.5J 5.54 98 $? 29.q7 5.54 100 39 29o~9 5.54 62 30 29.32 5.54 50 25 29.23 5.bO 63 30 29.12 5.45 95 3.3 29.03 5.41 6571 0 0.] 11.2 94 24 27.2, 5.11 .............. ...6.,5.75'. ......... O.1... . 9:.5 I00 20 27.07 5.11 ' ~:~:~.:~;: ~:~::~.~:~.~:.:~::;:.~..~.?:~?~??~:~.~:.::::<:~.~.: ~:.~:~::::..:.:..?:. ~::;~:i::~ ~'."~::::: ' ,1 13,0 '8:9 19 26.8b 5,10 ~::~:~'~ ~?~?~:::~:~??:~?~:~???~::::~::~?::::~:~:::?~:~:~?:::~:~::::~:~:::?~?:::~::~::~::~::~?:<?::<:~:: ~ ~. o . ...... o..,..o, ................. :...5 ..... l o.o ...... ~.~ ~:581.,0 0,0 100 48 :~:~:~ ~:~:~?~:~:~:~ ~i:~:~?;~ :.?.:~' ~'~i.::~::::..:..:':' ::::::::::::::::::::::::::::::::: ~::'~ ~.~:~ ~0 :~" · 658]-0 0.1 9.4 80 2 ~'~:~:~i.~:~'::.:~ :::.:.:::.: ::.."~'.?'::::.~:::'~..~ :::~:':?i':~:~'.:~:.::....':........:.:.~: :.'.~::~;.~:::'0~ ~'.::::.~:~ ?:~":~:::~::.:'~:~:~::.?.:~ ?'.:..:. ::::::::::::::::::::::::::::::::::::::::::::::: :~;~.~ ~;~':~ ~.. :. :.~ "::~/"i::":::~':¢":~:: ~: '~'.~;~;.~:~:.';:':~..::'.~.: ...~ ::.~":::' ..~:< :.:. '.':::~:.~.,.;~> ::~: ~:~ ~:' "<~.~:. ?<~.: ..:, .. ~,:.. ': '::~:?';.:?' ':.'~?::;::<';?:: ~':.? .:.. ~,...., :' .;.".:';.: :.." .'." ;'.:~..~:~ '.: ';:::'." :. ,~ ':. "' 2. ".: .". ~ ::::~?;::::: '; ;?~:::~8~8~:...: '~::'.??' ::::"~' ~::.: ::.~: ::~::' ::.: ~:~;,~:,~.:': ~ .. :'.:' ::'? :.. :l.:~.'...~': '....: :..: :'.." ..".... ':' .' '".'< .: :.. '... '? .5 5" .:' :'.. ,.':' :::: '..'::'..:':~ :.~ ':,:,'. :'. :':..' '::..:" :::,. ~.: .:' .: .'.:.: ...: ...:' .: :::?. '. ~: .:::: :.~4. :. ~.:~'::, .....:: :.... :. :.....:..:25: ~ "< '.2. :..:~ '. ': .:'.<: '?:' :..:~ .<':. ,'.~':'...~.-?8,:2'. '?.:: .":' ......: :..": ", .,..' .: :',' <...' ..'. ,': .: .'~. 658.9, 0 4 13~- 6 53 20 25.70 4..:7:7 ~?~??~?:~?~:?..?~:?~?.:~::??~:.:~:~>?.?.:~<:.??:::<?:;~ ~::?.?....:..........: .:. >.::: ::.?:<..>..:.:?:: ?.:.? ::...>..:.:.:....:.<..:::.:.:.: :.....::: : .:.:::::::::::::::::::::::::::: ?.?....:.. :... :~. :. :...:.... :.: . . ......,.. :......:...........:..:............:..?......:'.:..:.~......... .....:.......... ::...... :............:':. ::... :...'.:.:'..':.. ..:..: · . .. ...... ..... . . ..... .... .:. ,: ......... :...:,..~............:.> : . .... ........... ....,.. . ....... ... ... .... ....: .... ND SAT. G~4/CC CLAY CUH, CU~o H ¥CA~i"J 6590.0 ~59i.0 659{.0 6594.0 6595.g 6596' 5 14.1 O. I 0.1 B.9 0.8 O. { ' OoO 7.1 0-3 ,10.9 2 .4 O- .'0 0.0 8,5 55 02 71 67 bO 59 100 70 67 0 100 I00 bO 95 9.9 100 100 100 .I..0.0 100 1 O0 68 1 O0 ~2 72 'I 0.0 5'9 100 I00 0 O i00 5'8 55 6:4 2b 23 29 44 44 18 0 39 25.57 25.~ 25.30 25.20 25.08 24.97 24.87 24.7! 2 - 4.71 4.65 4,bO 4,57 4,52 4,48 4.44 4.41 4,38 0.00 '24,43 4,32 49 24.:tl 44 24.24 48 24,15 45 .24',0b 48 23,99 36 23,9.3 45 2].80 4b' 2.3.7'9 49 23,72 4.26 4'.2b 43 23,118 3'97!':<?i':":/<:::.:"'.!:::723.!~'I::1 :4:1:~,i'.:I~0 28 2],05 4.10 22' 22.:';'9;~ 4'0.4 27 22.83 4.00 28 :2:~2:."~:.:'0,. . 3~. 9'~ 29 22.52 3.91 2'2 22'"..::46. .3.;~..9'.1 b640,0 0.9 11,.0 71 23 21ob4 3.65 DkPTH PERM. FEET MD WATER % H~CARt} GM/CC CLAg VOLUME % P~ {I~ 0,5 IT ¥ CUM. H¥CARB 0641.0 0.1 rob42.0 0.0 bO.4{.O 0.0 U044.0 0.7 t, O4b.O 0.o 6647.o o'o 7.2 8.1 12.4 8.8 't,.9 4.9 bbS2,0 0.2 10.7 100 100 100 91 100 100 1 O0 100 99 58 70 30 21.52 46 21.45 38 21.39 20 21.29 25 21.1~ 27 21.09 29 21.01 43 20.9b 35 2-0.89 39 2.0.53 3.63 3.03 3.03 3.62 3.02 3.62 3.02 3.62 . 3.48 1,4.7. 15.2 40 4O 49 48 4:7 45 I00 lO0 46 20.34 -50 20.24 {.4.b 47 20.18 3.46 ~9 2.0.02 3.45 4.3 1..9,82 3.39 35 19.70 1.8 I:"9:. rio .3 o. 3 .V 22 1.9.47 3.33 2.3 i:9. ~:5. 3:. 29 .2..~ 19.20 ~..22 23 18.91 3.05 ..2:. 20 18.b4 2.89 2.4 t.,.'8.. -:'b:O 2 *8 i. 35 18.$7 2.73 3:6 1.~8::~.'.:~:0 2' 25 18.22 2.08 'S:'5 1',8.'::::1'2 2.':'6'.:.3 28 17.80 2.46 ~5 i:':7i.'~ 7:0 43 17.bi 2.39 21§ 42 17.4b 2.39 23 17.21 2.3'9 :J'.!4:''''' ........... ' ""'"' l.",:::':'"i'O2::i~:318 24 1b..98 2.3,5 % DEN8. GIq/CC % CUM. CUN. 6691.0 0.0 6.0 0092.0 0.0 4.9 6693.0 I 10.9 0094.0 5 14.0 6695.0 O.i 9.5 0696.0 0,0 5.3 6.700.0 6703.0 0.3 e70'4.0 0.'0 4.4 3 10.8 7.4 b708...,0 .......0.,.0 67.10,0 0.0 6'71.2.0 . 8.0 7,0 5.8 1.1.7 12.3 100 100 64 54 82 100 100 I00 I00 68 .1'.00 100 100 I00 8.8 94 100 9,4 78 100 53 lO0 10'0 e728,0 0'7 12.4 ~::. :'..":"%.~2::'~:~' "&": 'i.:...~..''.. ."Q.L.': i.: .:~.'.~':".:~:;i~:{'.':('.:."i~' ~'~....;?'~.Q..:':: ...'..."/':".' ... ~730.0 0.5 12.0 77 ~3~ ~0 ;0~?:.:~?~;..':~:'~:.:..:~.~:3~ 7.8 6732.0 0.0 4.9 100 b734.0 0.0 3.2 100 ?'.: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~:.0 6736.0 0.I 9.5 lO0 0738.0 0.4 I i .6 79 .... :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: b740.0 0.0 6.6 I00 21 2b 25 31 47 16.91 lo.ub 16.79 16.07 16.53 2.35 2.35 2.35 2.24 2.23 28 41 25 Ih. JO 1.0.22 lb.17 16'1o 2.23 2:' 23 31 15.7.4 30 15 3.2 15.5.7 34 15.50 24 15.4'4 18 15,33 2.5 15.,..21 38 15.13 3.5 1:5'.-:'05 31 14.97 34 I:.:~.i*.'91 28 14.83 14.u~ 2.17 2.1b 2.14 2.1'3 2.13 2.:o.,,I,,2 2.10 2:.'.~ ~ 2.05 44 14, ~0 3'9. 50 14.40 2.05 2'"~05 2.05 14.30 24 14.08 ::..:..':::3 ::::::::::::::::::::::::: 30 13.89 2:.':~ 44 13.78 2.00 1,,96 1 ;"9 6: 1.90 27 1].OS 1.95 ::2.4 1 ]:':':5'4. 24 13.44 1.95 3~57":;/''' :I:":3:'.~ '~::'$'t' ,. 9..'~ ,3b i3.2b 1.93 MD WATER % ~XCAR~ GM/CC CbAX VOL, UNE CUM. Pre{IR O~ t T ¥ CUM., H¥CARB Fis~ T ti 741'0 e742.o 67'4 t.0 0,0 0,O 0.0 674 4.2 4.7 4.8 9.5 5.2 8.9 10.$ 42 4O 39 2b 43 22 26 35 4O .1 9.3 1.0.6 8.8 6 ..0 1.2.. 0 7.7 100 100 I00 98 100 94 b8 53 55 b8 95 78 99 100 b8 100 1.00 13,20 13,15 13,11 Il,Ob 12.98 12,93 12,84 12,7q 12.6-3 12.. 1~ 1'2.,1'! 11.98 1.93 1.93 1 1.93 1 1 1 1,88 1,84 1.76 I"- 7.5 1 ,. 71, t:. :7'0 '..,: ...... ,b 7 b,5:.,O ............. 7 ..... 1.5- b. . 58. ~} 5 11 · 3t, 1. ~t. ............ 6767'0 0'2...:10-1 .. 100 ........... 24 11.12 1-5:7 Ill IIJI . ~Uil,l:-]l~ [:J .. PO~IT¥ H¥CAAB CLA/' DENS. VOLUME GM/CC % CUM. CUM. H ¥CAi. IB b~O0.O 0.0 6801.0 0-'0 0802.0 0.0 6803°0 0.0 0~.0 0.0 .O 0.2 0~0 .0 :~0 0'6 o810.0 0.1 0.3 100 49 7.0 100 38 b.5 100 0.0 0 0 0.0 0 0 10.4 b7 29 4.'t 100 40 7.3 98 3 9 9.2 60 39 9 · 5 5,5 34 8.8 :7 ! bSlO.O b 8.1.i17':. 0 0.0 U8 !..8.0 0.0 6 '820.0 0.0 12.0 5.1 4..7. 4.8 7.3 5' 2 6847.0 0.0 5.1 ~.01 8.94 0.00 O.OO 8.u.4 8.Jb l.lb 1-16 l.lb 0.00 0.00 1.0~ 1.0~ 1.08 0.~ 69 42 7.99 0.90 100 4.0 '7.90 0.88 100 38 7.85 0.88 100 40 7.81 0.88 99 45 7.70 100 48 7.:69 0.88 1'00 49 7.'50 42 4:7 7.3'4 0.. 85. 0 0 0.00 0.00 1'0'0' 4'9. 7 ':.2:1 0 -81 1" O0 46 :6:~.:9:4.. 1:0:0 4 3 -~:-:8,0 100 40 b.74 0.81 100 43 b.b4 0.81 1" O0 '4'~ 6 "b'O 0..' 81 100 49 b.57 0.~1 1.'00 .~ ~ 6..',lb 3 O..,.:8'.,i 100 3b b.4O 0.81 I00' .4'.{ ~ ~:::40: 0':' 8:1 100 ~1 6.33 0.81 i..00 ~.,7 ~.~0,~: 0-80 I00 38 5.94 0.79 9,9 3'8 5...8b '0'-78 60 40 5.7b 0.76 WATER % H¥CAHB OEN$o GM/CC VOLUME % P(iRO~IT¥ F~ET CUH. H I~CARB 6866,.0 0.0 7.9 100 bSbT.O 0.0 5.0 100 68:68.0 0-0 5.5 100 68~9.0 0.0 b.l 100 33 5.b5 4O 35 5.53 34 0.71 0.11 0.71 0.71 6 2.0 ,0 6877.0 1 b.8 .? :8.0 0.0 U879..0 0..0 6.b 7.4 8.7 .$ 10.2 6.3 3,,5 100 100 99 64 52 59 100 100 .t3 5..t4 35 5.28 .t8 5.Zl 44 5.1,2t ,:tl 5.05 2,4 ¢-95 .19 4.81 43 4.07 0.70 0.7(] 0.70 0.69 O.b6 0 0.53 10.0 1.00 100 i'O0 70 ?,I 8~ 1'00 100 6892.~0 0.0 6.0 100 :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 49 ~i.bO 0.5.:1 4'b :~ '"5:~b 0".,~5 3 45 4.. 5.2 0..53 28 4.'.~t6 0.53 l'B 4.~5 O. 53 24 4':20 O. 4g 28 ,t.09 0.45 4I 4::~'!0:'I 0.. 4.5 30 3.95 O. 45 :~::5 3.".~' b':i 0 ':' 4""~t 41 3.57 0.44 ,~..'a ~i"..':'~::2 o..,.4~ 44 ~J. 40 O..qq · ".3.:6 3.:':,:..4.0 0'-4 4 b902.0 0.0 ...... 3...8 tO0 46 3.30 0.44 ~':i!!i!::i':'i~!~ii:~!~ .................... . ................. ::::::::::::::::::::::::::::::::::::::: ::::.::;!:':.:!! :i!::::.::~::: ::!::::?::: !'?::..":':'. :?::' :?: :::::::::::::::::::::::::::::::::::::::::::: ::":!'":':: .:i:,i i:)i::?::/:!?::::' i:?? i:?: ?:: ::::!::: ~: ::j::. :/:::: :j?!~ :,:':. :::'j::: :~i:ii,::,,:. ::.::,' ? :':?::::' :: )? j:j: ~905,0 0.0 3.5 100 48 3.20 0.44 6907.0 0.0 3.4 I00 . 42 3. iJ 0..44 :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~'::,::.:::.::..:::' ::.'".::'.:.::...:...::.:'.::::~.:0~":::.':::'::: ::::::::::::::::::::: :::::::::::::::::::::::::: :.: i:': ?".."::::?~' :' i?:~ili:i::! :: :::'5::'.: Y:i: =================================== ?:::::::::::::::::::::::::::: b91!.O 0.0 5.4 100 t7 2.99 0.44 ~,~t:~.o o.o ~.o ioo 4~ 2.~ o.,~4 b915.0 0'0 6.0 I00 ]9 2.'/9 0.44 · MD WATEH H¥CAHB ¥ObUME % CUM. CUM. 6916.0 0.0 100 ~918.0 69 ,~ 0.0 0.0 0.'0 * 8.5 8.4 5.7 4.8 2.8 81 88 1 O0 100 I O0 6924-0 0'-0 4.0 e o.o 6 .o 0927.0 o.o o..o e, 928..o o.o o.o bg 2.9.,.0 5 14,8 69i3.:0!~*'0 0:, 1 9- 0 t~.gJ.t,...O 0 ,.1 9. I b.7 100 100 1 O0 58 9b 1'00. 100 I00 100 100 5b 0 '0: I00 1"00 47 2.73 0.44 30 2.bb 30 2.57 0.42 35 2.50 0.41 4g 2.44 0.41 47 2.~9 0.41 45 2.34 46 4'9 0 0.00 0 0.00 25 2.. l~, 4'0 2.03 38 1.93 4'4 1....8.5' 45 1.78 33 1.7.0 21 1.59 20 1.4'5 21 1 .J5 3'I 1!::* 3'0 38 1.241 0 O.UO -0: 39 0.99 0.41 0 41 0:41 0 0.]1 0,28 0.2.1 0.19 0.1'9 O. 19 0,,,19 0.00 0,:.0:0 0.I1 :0:'.:':.'t..'1, o o~:o0 0,-..oo O 0o00 0-00 0 .0...0:0 O.O.O 0 0.00 o.uo 0 0;"0'0 0-0"0 0 0.00 u.O0 49 0 0 0 0 0.00 o.oo 0 O~OiO o 0.00 0.00 ~':'":<":":':':::':::'?"<"7:.":"'.::.:::":0:.;?,0:0 0;*..~0."0' o 0.00 0,o0 0 .O.::.~:::!O0::::::::::::::::::::::: 3,::.:.'.:;.:.':::':'. 0.68 0.03 0.:::; 00. 0'-0'0 0.00 0.00 0.0:0 0.* 00 i"O'O 48 '0-58 PE~'TH P I:~H M · PO 6A~F. % Y C A R B t)~N6. GM/CC CLA~ % CU~. CUP. Pt}RU51T¥ F*~L'£ F ir,,ET b967.0 0.0 0.9 100 6969.0 0.0 0.0 6970.0 0.0 0.0 6971.0 0.0 0.0 697.]..0 O. 0 O. 0 0.0 0.0 b960.0 0.0 0.0 0982,0 0.0 0..0 6990 ,'0 0.,, 0 5,5 6991,0 0,0 69.92;;.90'~0 7°5 ~99a.o o.l $.~ ~':9..g"~:~.:o ..o.'o .o.'o .6.99.5 ,. 0 O... 0 .0 .,0 ~:.:~:~:.~"0 o::~...o o..-'~ ~97...o o.o o.o ~,~.9..8 .:.0. 0.0 0 09,99,0 0,0 0,0 '~:.O:iO:O:i~.o ..... . :........: ,o....~:.,'.o ~.."o lO0 100 9'7 0 0 0 0 0 0 98 43 0.52 0 0,00 0,00 0 0,00 0,00 0 0,00 0,00 0 o.00 o.00 0 0,00 o,00 0 0.00 Oo00 0,00 49 0. ,28 O' 03 44 0,23 O.O,:l t'8 0'. 16. 0.0] 29 0.08 0.01 0 O, O0 .0, O0 0 0,00 0,00 0 0..00 0.00 0 0,00 0,00 0 0~.00 0', 0.0 0 0,00 0,0o 3:4 0.'-.04 0,00 ***************************** SCHLUMBERGER ***************************** LIS/U physical record map o4 AKDVXISMUBO:[]LISA.DAT~ Using command LIST/FULL/OUTPUT=(SAMWVF,LST)/SUMMARY Company Name MARATHON OIL COMPANY Well Name KBU ~41-7 Field Name KENAI GAS FIELD County KENAI State ALASKA Service Order Number 499784 Date 27-DEC-95 Run Number ONE Job Number 95405 , Sch ~f-,mberger Page 2 LIST Command Listing KEY I LIST SUMMARY MNEMONICS Summary output is created by LIST/SUMMARY summaries written for Logical LIS structures: FILE (Abbrev: F) LIS logical file info TAPE (Abbrev: T) LIS logical tape info REEL (Abbrev: R) LIS logical reel info and for the entire LIS/A input logical unit: LU (Abbrev: L) LIS/A logical unit info The field labels appear on some or all of these summarles,'as indicated by the abbrev, on right, Summary Field Labels: REELS TAPES FILES #PR #LR #DR #ENC #FM PI PI UNITS MAXPI MINPI Number of logical reels on (L ) Number of logical tapes on (LR ) Number of logical files on (LRT) Number of physical records (LRTF) Number of logical records (LRTF) Number of data records ( F) Number of encrypted records ( F) Number of data frames ( F) Primary index channel name ( F) Primary index units mnemonic ( F) Maximum primary index value ( F) Minimum primary index value ( F) Schl~umberger LIST AKDVXISMUBO:[]LISA.DAT; Reel header 41 7 USI *~ REEL HEADER SERVICE NAME : USIT DATE : ORIGIN : DLIS REEL NAME : 41 ? USI CONTINUATION #: PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY Tape header 41 7 USI · ~ TAPE HEADER ,~ SERVICE NAME : FUSIT DATE : 95/12/12 ORIGIN : DLIS TAPE NAME : 41 7 USI CONTINUATION ~: 1 PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY (EOF) File header USIT .044 · ~ FILE HEADER ~, FILE NAME : USIT .044 SERVICE NAME : PLAYBA VERSION # : 7C~-427 DATE : 95/12/12 MAX, REC, LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Data format specification record Listing of set 1 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 2 0 66 3 19276 79 2 4 1 66 5 1 66 6 0 73 4 7 IN 65 2 8 60 73 4 9 .lIN 65 4 11 1 66 12 -999.25 68 4 13 1 66 14 .lIN 65 4 15 73 66 16 1 66 ~ 66 0 27-DEC-95 12:59:08 Page , Schlumberger LIST AKDVXISMUBO:E]LISA.DAT; 27-DEC-95 12:50:08 Page 4 End of set Listing of set 0 type CHAN NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) BS USIT IN 28 201 0 26 1 1 4 68 0000900000 CS USIT F/HR 63 621 0 26 ! 1 4 68 0090999999 CVEL USIT F/MN 63 609 0 26 1 1 4 68 9999909009 TENS USIT LBF 63 521 0 26 1 1 4 68 0900900099 ETIM USIT S 63 621 0 26 1 1 4 68 0000009090 MARK USIT F 15 091 9 26 1 ! 4 68 0000000990 STIA USIT F 0 26 1 1 4 68 0000090900 STIT USIT F 9 26 1 1 4 68 0009090009 CFVL USIT US/F 0 26 1 1 4 68 0900999000 CZMD USIT US/F 0 26 1 1 4 68 0000990909 UFRT USIT HZ 0 26 i ! 4 68 0900000000 UTDL USIT US 0 26 I 1 4 68 e000090090 RSAV USIT HZ 9 26 1 1 4 68 0000000909 FNOR USIT OER 63 191 0 26 1 1 4 68 9900900009 FINC USIT DEG 63 101 0 26 1 [ 4 68 0090090000 HAZI USIT DEG 63 901 0 26 [ ! 4 68 0099900000 P1AZ USIT DEG 63 001 0 26 1 1 4 68 0909009090 RB USIT DEG 63 191 9 26 [ 1 4 68 0099999999 SDEV USIT DEG . 62 99[ 9 26 1 1 4 68 9009909999 HV USIT V 9 26 1 1 4 68 0909090999 RGR USIT GAPI 9 26 1 1 4 68 0999000999 TIME USIT MS 63 621 0 26 1 1 4 68 0099090909 ANOR USIT F/S2 63 101 0 26 1 1 4 68 9090000999 GAT USIT DEGF 0 26 1 1 4 68 9909900999 GMT USIT DEGF 0 26 1 1 4 68 9090000000 CTEM USIT DEGF 0 26 1 1 4 68 9909900900 GR USIT GAPI 0 26 1 1 4 68 9090900990 lA USIT MS 63 621 0 26 1 2 8 68 9900000999 CCL! USIT 0 26 1 2 8 68 9909920990 CCL2 USIT 9 26 1 2 8 68 0990020990 CCL3 USIT 0 26 1 2 8 68 9009920009 CCL4 USIT 9 26 1 2 8 68 0000020999 PIPE USIT 9 26 I 2 8 68 0909029099 2A USIT 0 26 1 2 8 68 0000020999 3A USIT 0 26 1 2 8 68 9009920900 4A USIT 9 26 1 2 8 68 9999929990 5A USIT 0 26 1 2 8 68 0909929990 6A USIT 9 26 1 2 8 68 9990929999 AGMI USIT DB 0 26 1 2 8 68 9999999999 AGMA USIT DB 9 26 1 2 8 68 9990000990 GNMX USIT DB 9 26 I 2 8 68 9099909909 GNMN USIT DB 9 26 1 2 8 68 9999990900 IDQC USIT IN 0 26 1 2 8 68 9099900009 WDMX USIT US 9 26 1 2 8 68 9099009990 WDMN USIT US 0 26 I 2 $ 689990909000 WDMI USIT US 0 26 [ 2 8 68 9990909990 WDMA USIT US 9 26 [ 2 8 68 9000009900 AWAV USIT DB 0 26 1 2 8 68 0909000000 AWMN USIT DB 0 26 1 2 8 68 0000000900 Sch!~umberger LIST AKDVXILSMUBe:[]LISA.DAT; AWMX USIT DB 0 26 AIAV USIT MRAY 0 26 AIMN US~T MRAY 0 26 AIMX USIT MRAY 0 26 AZEC USIT DEG 0 26 DIAM USIT IN 0 26 CWEI USIT 0 26 ERAV USIT IN 0 26 ERMN USIT IN 0 26 ERMX USIT IN 0 26 ECCE USIT IN 0 26 IEAV USIT IN 0 26 IRMN USIT IN 0 26 IRMX USIT IN 0 26 THAV USIT IN 0 26 THMN USIT IN 0 26 THMX USIT IN ~ 26 USGI USIT 0 26 USBI USIT 0 26 AIBI USIT MRAY 0 26 UOOIL USIT 0 26 U002 USIT 0 26 U003 USIT 0 26 U004 USIT 0 26 U005 US!T 0 26 U006 USIT 0 26 U007 USIT 0 26 U008 USIT 0 26 U009 USIT 0 26 U0~0 USIT 0 26 UOll USIT 0 26 uel2 USIT 0 26 U013 USIT 0 26 U0~4 USIT 0 26 UO15 USIT 0 26 UO16 USIT 0 26 uel7 USIT 0 26 U0~8 USIT 0 26 U~19 USIT 0 26 U020 USIT 0 26 U021USIT 0 26 U022 USIT 0 26 U023 USIT 0 26 U024 USIT 0 26 U025 USIT 0 26 U026 USIT 0 26 U027 USIT 0 26 U028 USIT 0 26 U029 USIT 0 26 U030 USIT 0 26 U03~ USIT 0 26 U032 USIT 0 26 U033 USiT 0 26 U034 USIT 0 26 U035 USIT 0 26 U036 USZT 0 26 U037 USiT 0 26 IL IL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ! 72 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 576 144 144 144 144 144 144 ].44 144 144 144 144 144 ].44 144 144 144 144 144 144 144 144 ].44 144 144 144 144 144 144 144 144 144 144 144 ].44 144 '144 144 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 27-DEC-95 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 12:50:08 Page Schlumberger LIST AKDVXISMUBO:[]LISA.DAT; U035 USIT O uo3g USIT O U040 USIT O U041USIT O U042 USIT 0 U043 USIT 0 U044 USIT 0 U045 USIT O U046 USIT 0 U047 USIT O U048 USIT 0 U049 USIT O U050 USIT O U051USIT 0 U052 USIT 0 U053 USIT 0 U054 USIT 0 U055 USIT 0 U056 USIT 0 U057 USIT 0 U058 USIT 0 U059 USIT 0 U060 USIT 0 U06~ USIT 0 U062 USIT 0 U063 USIT 0 U064 USIT 0 U065 USIT 0 U066 USIT 0 U067 USIT 0 U068 USIT 0 U069 USIT 0 U070 USIT 0 U071USIT 0 U072 USIT 0 UTIM USIT 0 UPGA USIT DB 0 WFDL USIT US 0 WPKA USIT 0 WAGN USIT DB 0 AWBK USIT DB 0 AIBK USIT MRAY 0 T~BK USIT IN 0 T2BK USIT IN 0 ERBK USIT IN 0 IRBK USIT IN 0 TTBK USIT US 0 THBK USIT IN 0 UFLG USIT 0 CCLU USIT 0 AX USIT M/S2 61 AY USIT M/S2 61 AZ USIT M/S2 61 FX USIT OER 0 FY USIT OER 0 7A USIT MS 63 FZ USIT OER 0 502 0 503 0 501 0 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 , 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 26 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 72 72 72 72 72 72 72 72 72 72 72 72 72 72 1 1 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 4 4 4 4 4 4 4 144 144 144 3.44 144 144 144 144 144 144 144 144 144 144 144 144 144 144 144 144 3.44 144 144 144 144 144 144 144 144 144 144 3.44 144 144 144 576 576 576 288 576 576 576 576 5;76 576 576 576 576 576 8 16 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 68 68 68 79 68 68 68 68 68 68 68 68 68 68 68 68 68 68 65 68 27-DEC-95 0000000000 0000000000 0000000000 i2:50:05 Page , Sch~umberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page 7 End of set Data record type 0 DEPT 827940 .lIN 6899.5 FT 2102.9676 M BS 12.25 MARK 0. UFRT 122.7286 HAZI 232.4216 RGR 21.49254 CTEM 139.1 lA -999.25 0. CCL1 -999.25 CCL2 -999.25 0. CCL3 -999.25 0. CCL4 -999.25 0. PIPE -999.25 0. 2A -999.25 0.08333333 3A -999.25 1. 4A -999.25 0.08333333 5A -999.25 0.3611111 6A -999.25 0.3611111 AOMI -999.25 -4. AOMA -999.25 20. ONMX -999.25 15. ONMN -999.25 15. IDQC -999.25 8.489916 WDMX -999.25 65.11833 WDMN -999.25 56.61833 WDM[ -999.25 43.13274 WDMA -999.25 83.13275 AWAV -999.25 51.5573 AWMN CS 1093.56 CVEL -18.226 STIA 0. STIT 0. UTDL 77. RSAV 6.815703 PIAZ 257.2924 RB 24.96474 TIME 0. ANOR 32.31909 OR 27.70625 TENS 1375. ETIM 0. CFVL 198.9 CZMD 2.037658 FNOR 0.6151299 FZNC 33.49472 SDEV 0.3081146 HV 248.28 GAT 107.7623 OMT 148.96~1 , Schi, umberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 i2:50:08 Page 8 -999.25 49.58852 AWMX -999.25 52.85496 AZAV -999.25 5.327303 AIMN -999.25 -0.4256874 AIMX -999.25 12.94934 AZEC -999.25 353.4786 DIAM -999.25 9.625 CWEI -999.25 47. ERAV -999.25 4.803116 ERMN -999.25 4.769624 ERMX -999.25 4.85197 E¢¢E -999.25 0.1171676 IRAV -999.25 4.341163 IRMN -999.25 4.311472 IRMX -ggg.25 4.375102 THAV -999.25 0.4619526 THMN -999.25 0.4411939 THMX -999.25 0.4821673 USGI -999.25 0.08333333 USBI -999.25 0.6388888 AIBI -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999,25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999 25 -999 25 -999 25 -999 25 -999 25 -999 25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 11,89079 10.39203 10.11188 5.426498 3.164235 -4000. -2000. -2000. -2009. -2000. -2090. -2000. -2000. -2000. 2.684555 3.589842 5.255642 7.543544 9.662966 10.32455 19.01328 7.083595 5.214901 2.639006 -2090. -2009. -2000. 3.381628 Sch kumb~rger LIST AKDVX~$~UBO:E]LISA.DAT; 27-DEC-95 i2:50:08 Page 3.522057 -2000. -2000. -2000. 4.671262 5.939085 8.80924 8.694965 9.668335 8.68519 9.959983 6.649683 3.463322 -2999. -2999. -4999. -2999. -2999. -2999. -2999. -4999. -4999, -4099, -4999, 2,958977 4,332458 8,787617 9.34898 8.827987 8.27969 8.971918 8.962372 9.964756 8.855873 9.119948 8.895864 8.799282 7.994524 9.637764 19.21665 11.31085 11.61151 12.26691 12.94934 U991 -17 1S7 452 127 -89 51 -2 -27 -6 17 12 -3 -16 -8 9 3 -3 -5 -7 -192 39 229 27 -14 42 -2 -25 -13 19 12 4 -15 -7 4 2 U992 -17 -29 292 17 -2 141 2 -22 7 U003 -14 -39 15 272 21 -5; 152 8 0 28 8 498 23 -3 0 -4 423 26 -6 -6 -11 75 6 -4 42 -15 196 4 -1 44 -18 U904 -88 -19 -6 -11 -2 56 -15 -50 -27 5 -12 -1 139 -6 2 -85 -3.5 -7 -12 3 5;1 -16 -64 -30 19 -15 3 131 -6 0 Schl,umberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DE¢-95 12:50:08 Page U00~ -7 192 276 -66 -45 42 -41 -17 29 31 -10 -27 -14 23 20 -10 -16 0 -19 45 323 170 -55 37 22 -30 -27 15; 30 0 -30 -20 18 17 -6 -15; U006 -13 15;6 433 117 -75 5;9 -19 -43 11 50 16 -34 -42 10 49 12 -32 -23 -4 -59 150 298 42 1 56 -12 -51 -10 48 28 -25; -47 2 38 16 -24 U007 -18 -53 60 180 5;4 -32 144 9 14 -12 33 419 56 -43 -30 U008 -11 -5;0 63 280 59 -38 86 19 -32 62 -5;4 -70 -42 -6 -18 2 69 -5;1 -74 -61 48 -25 13 78 -13 23 461 57 -48 2 -38 158 15 8 53 31 -42 -47 -2 -20 8 5;8 -52 -90 -61 5;2 178 15; -28 61 -58 -26 18 79 -7 17 Schlumberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page U009 -13 160 450 132 -67 61 -27 -50 19 61 11 -51 -48 23 65 6 -51 -28 -4 -69 130 294 44 3 59 -22 -61 -4 62 28 -43 -58 13 57 15 -43 U010 -17 -54 63 194 -26 143 -11 29 39 48 U011 -14 -38 -24 -2 -34 -56 53 69 54 U012 -15 -30 5 -122 -13 29 -83 -60 44 32 43 473 53 -36 -20 -16 221 9 -59 147 0 25 -67 44 216 39 -41 68 -62 255 -41 42 -34 285 56 -24 32 -19 -35 -34 -9 -5 -17 -7 18 11 38 -61 26 44 -55 62 -64 -173 -65 46 24 -49 -201 -32 2 14 -32 -204 -22 -15 -4 -2 -98 -27 36 47 -52 -408 -61 49 -49 -461 -5;9 33 Schlumberger LIST AKDVXISMUBO:[]LISA.DAT; U013 27-DEC-95 12:50:08 U014 page 2 -154 -143 i73 69 -34 63 10 -57 -41 31 49 ? -48 -33 20 34 -2 14 -98 -452 -259 44 -53 -14 53 21 -44 -48 ii 53 21 -40 35 U015 -159 -14 -20 -53 -37 U016 13 49 -52 -332 -57 20 44 59 -42 -73 -48 -459 -60 28 3 23 -204 -7 -19 61 -46 6 9 -15 32 -26 -151 -23 29 -62 52 -240 -63 26 -4~ 19 -118 -23 5 -7 -2 16 35 -6 22 11 -26 70 40 2 20 16 -28 -13 -43 51 -7 -22 -11 -26 21 88 32 -14 -16 -13 -59 50 71 60 -39 -20 34 200 28 9 3 96 0 13 9 8 9 102 17 -16 21 -8 -146 8 -24 -51 48 412 64 -35 -33 23 257 28 -9 12 . Schl, umberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page -12 159 460 162 -67 59 -17 -49 11 55 24 -29 -45 0 38 ]*8 -].8 -25 -5 -76 ]*37 331 50 -ll 61 -18 -57 -10 49 35 -15 -42 -9 25 22 U018 -40 30 9 9 14 -36 23. 79 34 U019 4 13 -18 -280 -33 12 -222 -39 3 28 -2 U020 14 33 -17 -306 -28 1 -].62 -8 -7 -56 -13 350 21 4 -60 ]*8 -3]*8 -34 12 -29 24 -498 -34 21 10 36]* 43 -19 44 -20 81 11 3 -24 15 -217 -9 9 -54 20 5 7 9 27 -26 72 26 20 39 -12 57 17 6 8 3 23 -28 -173 -39 1 -49 12 -41 24 -14 -53 19 iii 36 -10 43 -23 -323 -43 3.8 44 -i9 -375 -24 -1 3 -3 -65 4 -8 . Schl,umberger LIST AKDVXISMUBO:E]LISA.DAT; 27-DEC-95 12:50:08 Page 14 U021 12 23 -277 -338 -12 -3 -39 24 28 -11 -27 -9 12 16 -3 -10 -7 1 -9 203 418 32 -90 52 -27 -24 22 31 -1 -19 -17 8 16 4 -3 -5 U022 8 82 -6 -130 -16 6 -25 6 19 5 -11 -10 -1 8 3 -2 -4 -2 -8 106 267 98 -23 25 -5 .17 0 15 9 -4 -12 -2 6 4 -1 -4 U023 -16 -41 17 250 21 4 168 -3 15 38 28 U024 -8 -25 4 113 2 7 77 -18 14 29 19 491 35 1 -15 8 270 13 6 -16 13 154 25 -12 53 -25 150 22 -9 32 -13 -80 -6 -5 -6 -17 -30 -111 -44 4 -7 -12 39 -20 13 -20 6 -4 7 -19 25 -17 -94 -24 -3 9 -16 -55 -22 10 . Schl,umberger LIST AKDVXZSMUBO:E]LISA.DAT; 27-DEC-95 12:50:08 Page 15 U025 -14 -28 290 380 21 9 73 -16 -72 -28 43 56 5 -50 -32 18 38 8 9 -222 -474 -80 63 -77 26 60 2 -6~ -48 15 59 15 -40 -37 3 36 Ue26 -15 -40 264 359 12 9 76 -20 -79 -35 44 66 11 -58 -44 16 48 16 8 -231 -491 -83 66 -78 29 67 7 -67 -59 15 69 25 -41 -48 -3 41 U027 1 -195 -223 155 64 -61 69 49 -35 -76 -25 49 65 -9 -60 -35 21 46 16 -106 -507 -318 41 -61 -51 51 70 -6 -70 -48 27 63 17 -39 -44 5 U028 1 -223 -294 119 71 -63 63 53 -23 -70 -33 38 67 6 -49 -40 8 43 16 -85 -503 -381 22 -46 -58 43 72 6 -57 -51 13 62 29 -27 -44 -7 , Schl,umberger LIST AKDVXISMUBO:[]LISA,DAT; 27-DEC-95 12:50:Q8 Page UQ29 6 -97 -273 -9Q 42 -37 Q 3Q 15 -21 -3Q -7 22 21 -3 -17 -11 $ 2' 42 -74 -178 -24 8 -4Q -4 3Q 25 -7 -27 -18 15 23 6 -13 -14 UQ3Q 5 -gQ -287 -135 29 -32 -lQ 28 23 -14 -31 -14 17 23 2 -16 -15 4 2 74 4 -144 -25 19 -36 -11 24 29 1 -25 -24 9 22 IQ -10 -17 UQ31 13 16 43 56 -27 2 73 -4 -81 -9 -326 33 -36 82 -63 UQ32 6 25 81 35 -12 -329 -38 -25 -29 -29 -63 -12 -65 26 -21 -18 218 -7 39 -76 49 438 61 13 -lQ1 26 -2Q 36 -29 4Q 38 3 -29 4 -15 -36 -5 -38 11 -1 -18 12Q -15 26 -185 -13 -18 -8 -18 -43 2Q 277 28 14 · Schlumberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page 17 U033 9 93 6 -129 -5 12 -41 -12 28 32 I -30 -24 11 23 11 -12 -18 -6 118 299 120 -17 40 8 -34 -27 16 34 15 -19 -24 -3 17 16 -5 U034 8 60 -56 -157 -10 8 -38 -8 24 24 -1 -23 -17 8 14 6 -7 -10 -6 123 287 87 -29 37 3 -30 -19 15 26 10 -16 -16 0 11 9 -3 U035 8 70 -35 -143 -9 5 -36 -6 21 21 1 -18 -15 7 10 3 -5 -7 -7 125 288 81 -30 36 0 -28 -18 21 11 -12 -14 -1 7 6 -2 U036 4 22 -138 -199 -14 2 -34 -1 20 15 -2 -14 -9 7 7 2 -3 -4 -B 121 267 B8 -37 36 -4 -24 -10 13 17 6 -11 -9 1 5 4 -1 . Schl.umberger LIST AKDVXISMUBO:[]LISA,DAT; 27-DEC-95 12:50:08 Page U037 10 -15 -386 -410 -10 -10 -65 8 45 26 -11 -28 -15 13 16 6 -8 -9 -9 213 425 10 -91 75 -19 -46 -11 30 33. 6 -22 -3.6 2 3.2 9 -2 U038 7 -92 -299 -153 28 -27 -14 3.8 18 -3 -14 -12 3 10 6 1 -4 -3 3 84 21 -142 -33. 23 -29 -3.2 11 3.9 $ -7 -13 -3 3 5 2 -3 U039 7 4 -3.46 8 -3. -98 -20 -7 U040 -3. 44 4 -411 0 -4 -266 -4 -26 -283. -2 -4 3.8 -3.3 -426 -24 -8 -21 -19 -92 -3.5 -4 -33. -3 4 -35 -4 -64 46 -14 3 -3.2 2 -37 60 4 -14 8 -27 3.9 3 54 -20 3.8 4 9 -79 13 -35 39 8 20 15 -441 31 1 , Schl,umberger LIST AKDVXiSMUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page 19 U041 1 -90 -$$ 98 33 -42 23 26 2 -19 -20 -7 2 -5 -6 -2 7 -56 -274 -19@ 16 -28 -36 -6 -18 -11 4 8 5 -2 -5 U042 -7 -32 119 186 -1 -12 40 16 -16 -32 -21 8 25 15 -3 -18 -15 1 3 -121 -269 -61 36 -48 -10 27 29 1 -24 -30 -6 16 20 -16 U043 -12 -24 306 371 -12 -7 90 28 -45 -74 -36 33 66 31 -18 -49 -30 13 11 -231 -482 -53 79 -104 -7 68 61 -9 -64 -66 -3 49 49 9 -36 -41 U044 -9 -29 89 -39 -7 71 -40 -21 14 -10 279 -24 7 -38 26 168 12 24 30 30 -21 39 -5 35 7 35 22 -116 4 -21 35 -12 -98 -34 -27 , Schlumberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page 20 U04S -8 88 272 122 -28 48 27 -28 -42 -10 26 37 8 -25 -28 -8 18 22 -4 -64 21 149 9 -27 44 33 -8 -40 -29 $ 34 20 -8 -27 -15 7 U046 -1 250 398 -13 -45 90 -31 -76 -35 47 79 40 -39 -66 -30 29 54 21 -[8 28 422 396 -16 33 87 -5 -72 -65 2 69 60 -6 -52 -49 3 45 U047 -4 -76 -22 305 3.1 46 235 -27 36 -52 73 328 53 54 44 56 U048 9 -22 3.4 124 32 22 -lOO 77 i6 83 -16 -65 31 -20 -12 -58 90 -47 61 -75 -46 -39 -65 437 -58 10 -30 40 14 46 1 77 17 29 -19 36 0 -17 -6 -32 -28 15 -37 112 -36 -1 -146 22 -14 14 -31 -43 -17 295 -1 24 SchLumberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page U049 11 51 -257 -376 1 4 -97 -23 57 74 17 -57 -67 -1 51 49 -3 -45 -7 222 494 128 -44 103 5 -74 -55 28 75 54 -25 -66 -32 28 54 25 U050 9 -65 -266 -165 18 -34 -33 20 42 18 -22 -44 -19 23 34 12 -20 -29 4 116 102 -82 -14 33 -34 -36 0 38 36 0 -36 -30 3 29 23 -6 U051 20 37 67 -154 71 -9 -126 82 25 -22 2 -501 37 -39 70 -69 U052 -285 -40 -57 -64 -59 41 -85 9 -70 6 -72 -37 235 0 58 -67 44 214 74 48 -92 -83 -34 -84 -9 -499 -36 -65 -7 -76 38 -58 i8 -9 55 2 74 43 -329 15 -51 -92 29 54 65 62 -270 -28 30 -65 8 76 -268 77 5 Sch[umberger LIST AKDVXISMUBO: [] LISA.DAT; U053 27-DEC-95 12:50:08 U054 Page 2 -235 -350 56 53 -88 34 78 35 -52 -85 -43 43 74 30 -39 -65 -25 18 -45 -430 -372 17 -40 -88 6 76 66 -5 -TS -66 9 62 55 -7 U055 -.10 23 -3 -'126 -19 -.18 U056 2 48 5 -288 -.18 -22 -88 -7 -213 24 -31 6 -32 -3.7 -413 -3.0 -3-24 -46 -24 -52 -28 3132 -34 4 -69 3-4 3-32 -25 .1 -23- .16 2138 -48 -2 -58 3.7 4'18 -5; 3 20 -3.55 2 -22 69 -49 -1 2 213 22 67 -13 17 23 33. 29 19 113 42 2 -113 2 -15 -117 -32 0 -23 26 -3.138 32 8 -71 36 -114 3.8 -2 213 -211 22 -113 -32 -38 -7 64 -213 33 18 -291 9 -3.2 45 34 -505 29 -11 65 -8 -471 -20 -9 22 . Schlumberger LIST AKDVXISMUBO:[]LISA.DAT; 2T-DEC-95 12:50:08 Page 23 U057 -9 -3 348 423 24 4 62 -3 -37 -25 6 23 13 -17 -14 -1 7 4 7 -198 -407 -49 76 -64 15 42 14 -25 -29 -11 18 12 -9 -12 -5 3 U058 -9 68 269 168 -16 25 20 -14 -20 -3 10 13 0 -11 -5 3 5 0 -4 -106 -84 88 19 -27 23 15 -6 -~8 -~0 3 12 0 -8 -6 0 3 U059 -18 125 489 279 -39 49 38 -27 -40 -7 21 27 2 -19 -12 0 11 7 -9 -222 -197 159 41 -53 44 31 -9 -36 -23 6 24 6 -8 -13 -5 6 U060 -3 -41 -1 331 5 7 258 -16 9 -6 27 483 26 8 7 16 105 32 -2 56 -13 -35 12 -21 -4 -15 68 -19 -51 -39 -7 -11 -17 263 -27 5 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 · SchLumberger LIST AKDVXISMUBO:[]LISA.DAT; 2T-DEC-95 12:50:05 Page 24 U061 -1 245 404 14 -50 66 -23 -40 -6 32 28 1 -24 -12 5 11 3 -6 -19 5 347 350 -3 15 54 -14 -43 -20 15 29 9 -~9 -15 -1 9 U062 9 90 15 -111 -T 11 -28 -6 12 14 2 -10 -10 3 6 2 -3 -3 -T 96 274 132 -16 3~ 7 -18 -14 6 13 8 -6 -10 -2 4 3 -2 U063 -5 9 133 28 -4 127 32 -55 12 -62 27 69 -13 U064 -251 -1 -3 6 -7 -20 -13 -36 2 18 -14 -20 7 -56 lo 485 19 4 6 -70 -263 -164 12 -25 -13 16 13 -6 -14 -9 5 9 0 -5 -3 3 3 86 45 -102 -21 18 -26 -8 12 15 3 -10 -11 4 8 2 -4 -4 Schlumberger LIST AKDVXISMUBO:E]LISA.DAT; 27-DEC-95 12:50:08 Page 25 U065 5 -82 -261 -132 21 -29 -7 18 11 -9 -16 -8 7 9 -1 -6 -3 3 2 57 -32 -160 -30 13 -30 -5 15 15 -1 -12 -12 5 8 1 -2 U066 0 -232 -376 -3 53 -56 31 33 -2 -31 -22 5 26 6 -13 -12 -3 7 16 -22 -390 -382 -2 -23 -51 19 41 13 -19 -26 -6 20 11 -2 -9 -4 U067 1 -217 -317 62 60 -58 34 30 -7 -33 -21 5 27 7 -12 -I1 -1 8 lS -45 -394 -332 5 -38 -53 18 38 9 -21 -26 -5 22 13 -3 -11 -6 U068 -8 -59 48 144 12 -6 26 0 -17 -13 1 11 7 -6 -6 -3 0 2 4 -103 -261 -109 19 -27 -1 17 8 -10 -13 -4 9 6 -2 -4 -4 -1 Schlumberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page 26 U069 -15 -141 39 259 26 -15 50 1 -32 -24 4 20 13 -10 -7 -1 I I 9 -199 -508 -203 37 -54 -3 34 16 -19 -24 -8 16 10 -4 -3 -2 -1 U070 -10 -51 230 358 30 0 49 -10 -32 -12 13 17 3 -15 -5 1 0 2 6 -198 -462 -147 47 -53 13 30 2 -24 -16 4 19 5 -8 -3 -2 U071 -11 -8 291 324 6 11 46 -13 -30 -9 13 13 0 -15 -4 I 0 1 9 -189 -378 -ll 83 -57 22 29 -4 -25 -13 4 17 2 -8 -2 -1 U072 -5 77 259 146 -17 24 6 -15 -5 9 7 -1 -8 -5 4 2 -1 -2 -2 -61 14 143 30 -13 25 1 -15 -9 5 6 3 -7 -5 1 Schl, umberger LIST AKDVX[$MUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page 27 UTIM -16 148 504 -28 -8 18 8 4 -1 260 57 -25 9 12 5 0 -999,25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999,25 -999.25 -999.25 -999.25 -999,25 -999.25 -999,25 -999.25 -999.25 -999,25 -999,25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 272 -44 38 6 14 -2 -16 -9 -3 -10 -142 -10 46 0 -26 -15 -14 -8 3 2 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 2.416106E+07 2.41608E+07 2.416133E+07 2.416133E+07 24161600 2.416106E+07 2,416106E+07 2,41608E+07 2,416133E+07 2.416133E+07 24161600 2.416106E+~7 2,416106E+~7 2,41608E+07 2,416~33E+07 2.416133E+07 24161600 2.416106E+07 2,416~2E+07 2,416093E+07 2.416146E+07 2,416146E+07 2.416173E+07 2,41612E+07 24161600 2.416106E+e7 2.4~608E+07 2.41608E+07 2.416133E+07 24161600 24161600 2.416106E+07 2.4~608E+07 2.41608E+07 2.416133E+07 2416~600 24161600 2.416106E+07 2.4~608E+07 2.41608E+07 2.416133E+07 2416~600 2,416173E+07 2,41612E+07 2.416093E+07 2,416~93E+07 2,416146E+07 2.416173E+07 2.41612E+07 2.416093E+07 2.416146E+07 2.416173E+07 2.416146E+07 2,416173E+07 2.4~6~2E+07 2.416093E+~7 2.4~612E+07 2,416093E+07 2.416~46E+07 2.416173E+07 2.416146E+07 2,416173E+07 2.416~2E+07 2.416093E+07 2.416~46E+07 2.416173E+07 2.41612E+07 2,416093E+07 2.41612E+07 2.416093E+07 2,416146E+07 2,416173E+~7 UPGA -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999,25 -999.25 -999,25 -999.25 -999.25 -999,25 -999.25 -999,25 -999.25 -999.25 -999.25 -999,25 -999,25 -999,25 -999,25 -999,25 -999.25 -999,25 -999,25 -999.25 -999,25 -999,25 -999.25 -999,25 -999.25 -999.25 -999,25 -999.25 -999.25 -999,25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 i5 i5 15 i5 i5 i5 15 i5 i5 i5 i5. 15 15 15 15 15 15 15 15 15 15 15. 15. 15. 15. 15 15 15 15 15 15 15 15 15 15 15 15 15 15. 15. 15. 15 15. 15 15. 15 15. 15 15. 15 15. 15 15. 15 15. 15 15. 15 15. 15 WFDL 15 15 15 15 i5 15 i5 15 Sch.:umberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DE¢-95 12:50:08 Page 28 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 WPKA -999.25 -999 25 -999 25 -999 25 -999 25 -999 25 -999 25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 WAGN 64.61835 64.61833 64.61833 65.11833 64.61833 64.61833 64.61833 64.61833 64.61833 64.11833 64.11833 63.61833 63.11833 62.61833 62.61833 61.61853 61.11833 60.61833 60.11833 59.61833 59.61835 58.61833 58.61833 58.11833 58.11853 57.61833 57.61833 57.11833 57.11833 56.61833 56.61833 56.61833 56.61833 56.61833 56.61833 56.61833 57.11833 57.11833 57.61833 57.61833 58.11833 58.11833 58.61833 58.61833 59.11833 59.11833 59.61833 59.61833 60.11833 60.11835 60.61833 60.61833 61.11833 60.61833 61.11833 61.11833 61.61833 61.61833 62.11833 62.11833 62.61833 62.61833 63.11833 63.11833 63.61833 63.61833 64.11833 64.11833 64.11833 64.11833 64.61833 64.61833 344 342 334 336 338 344 340 344 346 344 342 348 344 342 346 346 346 354 356 362 362 368 374 384 382 394 394 394 390 398 394 396 402 402 402 402 396 402 400 392 388 394 390 378 380 380 378 368 374 372 362 370 366 370 370 364 370 362 354 360 350 346 348 354 354 348 348 342 340 346 346 340 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999,25 -999,25 -999.25 -999,25 -999,25 -999,25. -999,25 -999,25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 Schl,umberger LIST AKDVXISMUBO: [] LISA. DAT; -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 AWBK 27-DEC-95 12:50:05 Page 29 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 2.96 2.96 2.96 2.96 2,96 2.96 2.96 2.96 2.96 2.96 2.96 2.96 2.96 2.96 -3.06 2.96 2.96 2,96 2,96 2,96 -3.06 2.96 -3.06 2,96 2,96 2,96 2,96 -3.06 -3.06 2,96 -3,136 -3.06 -3.136 -3.136 -3.06 2.96 -3,136 -3.136 2,96 -3,136 -3,06 2,96 -3.06 -3.136 2.96 2.96 -3.06 2.96 -3.06 2 . 96 2.96 2.96 -3.136 2.96 2.96 2.96 -3 . 06 2.96 2.96 2,96 -3.136 2,96 -3 . 136 -3.06 2.96 2.96 -3.136 2.96 2,96 2,96 -3,06 2,96 -999.25 -999,25 -999,25 -999.25 -999.25 -999,25 -999.25 -999.25 -999.25 -999,25 -999,25 -999,25 -999,25 -999.25 -999.25 -999,25 -999,25 -999,25 -999,25 -999,25 -999.25 -999.25 -999,25 -999,25 -999.25 -999.25 -999,25 -999.25 -999,25 -999,25 -999,25 -999.25 -999.25 -999.25 -999.25 -999,25 -999,25 -999,25 -999,25 -999,25 -999,25 -999.25 -999.25 -999,25 -999.25 -999,25 -999.25 -999,25 -999,25 -999.25 -999,25 -999,25 -999,25 -999,25 -999,25 -999,25 -999.25 -999.25 -999,25 -999,25 -999.25 -999,25 -999,25 -999,25 -999,25 -999,25 -999,25 -999,25 -999,25 -999.25 -999.25 -999,25 -2.671301 -3.1133439 -2.814247 -3.266434 -2.468666 -3.219425 -2.305138 -2.295132 -2.114418 -2.4713943 -2.1394536 -2.215927 -1.980404 -2.572128 -1,584011 -2,13137774 -2,1369866 -1,972797 -1.64254 -1.732159 -1,250534 -1.937321 -0,9365196 -13,8233337 -13.8296051 -0.8963585 -13.4256439 -0.6601944 -0.5427132 -1.026134 -13.3473587 -0.2725372 -13.4620781 -0.5408897 -0.157711 -0.4984016 -0,1848946 -0,7438049 0. -13.43741384 -13,3593864 -0,625164 -13.3577652 -0,9888992 -0.4702644 -1,1348119 -13,32631354 -0,7991447 -13.6885872 -1,089813 -0,7422829 -0,87134834 -0,4904137 -1,383141 -13.66813298 -1.014969 -13.7574043 -1.359791 -13.9947662 -1.248638 -1.012844 -2.1337476 -1.1771355 -1.210484 -1.056149 -1.685032 -1.262257 -1.645889 -1.404247 -2.150928 -1.312469 -1,619637 AIBK -999.25 -999,25 -999,25 -999.25 -999,25 -999,25 -999.25 -999.25 -999,25 -999.25 -999.25 -999.25 -999,25 -999,25 -999.25 -999,25 -999,25 -999,25 -999.25 -999,25 -999.25 -999.25 -999,25 -999,25 -999,25 -999,25 -999,25 -999.25 -999.25 -999,25 -999,25 -999.25 -999,25 -999,25 -999.25 -999.25 -999.25 -999,25 -999.25 -999,25 -999,25 -999.25 -999.25 -999,25 -999.25 -999,25 -999.25 -999.25 -999.25 -999.25 -999,25 -999.25 -999.25 -999.25 -999.25 -999.25 -999,25 -999,25 -999.25 -999.25 -999.25 -999.25 -999.25 -999,25 -999,25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 11.89079 10.39203 10.11185 5.426498 3.164235 1.032681 0.9752593 0.8050327 1.515318 2.171353 2.684555 3.589842 5.255642 7.543544 9.662966 7.083595 5.214901 2.6391306 1.324715 1.129645 -0.4256874 0.9250307 2.305239 1.1360317 10.32455 10.01328 2.297216 3.381628 Schlumberger LIST AKDVXISMUBO:[]LISA.DAT; 3.522057 1.776347 8.604965 9.668335 1.074611 0.2049215 -0.1999186 0.1157618 8.827087 8.27969 8.805864 8.799282 12.2669[ ~2.94934 T[BK -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 27-DEC-95 ~2:50:08 Page 30 [.782713 2.[52946 4.671262 5.939085 8.80924 8.685~9 9.050083 6.649683 3.463322 [.611953 0.9909706 0.57407 0.8967268 0.522346 0.~63063 0.~970819 2.958077 4.332458 8.787617 9.34808 8.071918 8.062372 9.064756 8.855873 9.~0048 7.994524 9.637764 10.21665 11.31085 11.6115~ -0.005970478 e.02270365 0.02776098 -0.00386858 -0.0123353 -0.01898623 0.005859852 0.02545404 0.02320576 0.00136[847 -0.0[890326-0.008353233 T2BK -999,25 -999.25 -999.25 -999,25 -999,25 -999.25 -999,25 -999,25 -999,25 -999,25 -999,25 -999.25 -999 25 -999 25 -999 25 -999 25 -999 25 -999 25 -999 25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -0.e047~4952 0.002741814 0.0[[23142 0.01204729 0.008535385 0.02853918 0.02988625 0.02148485 0.03260279 0.02863455 0.01~94913 0.02187061 0.01236629 0.007088661 -0.007183552 -0.01242208 -0.00774622 -0.02621794 -0.01426554 -0.01874781 -0.01988935 -0.0108366 -0.0~749134 -0.0~303339 -0.02608109 -0.02121592 -0.01647854 -0.0~700258 -0.008844852 -0.006787777 0.~009555817 0.0~5~4769 0.01797199 0.02283478 0.0~79696~ 0.02324677 0.02933025 0.0~755953 0.02625084 0.02163553 0.01096773 0.01663[[3 0.0[[[0077 0.01263618 -0.007693291 -0.007477283 -0.00991392[ -0.0231905 -0.01641941 -0.02379608 -0.02902794 -0.01328373 -0.01589775 -0.01216793 -0.01927948 -0.01433277 -0.01042032 -0.01562405 0.004014492 0.001080036 -0.004089832 0.01016733 0.005625218 0.00777477 -0.007923812 -0.01005933 -0.0180988 -0.026740~7 -0.02264792 -0.01982844 -0.01207793 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999 25 -999 25 -999 25 -999 25 -999 25 -999 25 -999.25 -999.25 -999.25 -999.25 -0.00131169 0.008612007 0.003466457 0.005525887 -0.01039636 -0.0[[94444 -0.02361667 -0.02714187 -0.02325812 -0.01707816 -0.01384804 0.005039573 0.00775668 0.~05274147 0.003295213 -0.01065266 -0.0144017 -0.02412498 -0.02417889 -0.02294466 -0.01747313 -0.009647042 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 0.002489567 0.004663736 0.004150391 0.006070763 0.00686723 0.004555076 0.004244804 0.006113857 0.00620392 -0.001465172 -0.004558057 -0.007405758 -0.01149118 -0.01151094 -0.01284254 -0.01432204 -0.0[598993 -e.01783779 -0.02729103 -0.03080606 -0.03043985 -0.026[[506 -0.02291453 -0,02285159 -0,02531382 -0.02739188 -0,02833387 -0,0~872018 -0.0~60~6[ -0,01454163 -e.01131499 -0.0[[25872 -0,0130643 , Schl,umberger LIST AKDVX~$MUBO:[]LISA.DAT; 27-DEC-95 12:5~:08 Page 31 -0.009722~54 -0.008418679 -0.005002022 -0.008554876 -0.002115965 -0.0002136827 ERBK -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 4.826221 4.82921 4.825186 4.84537 4.85197 4.845689 4.845886 4.826915 4.81152 4,816406 4.805603 4.808048 4.79224 4.782214 4.791011 4.783517 4.779339 4.781619 4.781175 4.787664 4.803522 4.803181 4.804528 4.80003 4.803945 4.815836 4.811284 4.813058 4.797744 4.776472 4.794033 4.787944 4.774162 4.781519 4.769624 4.789569 4.794424 4.789748 4.797077 4.788321 -999.25 -999.25 -999.25 -999.25 -999 25 -999 25 -999 25 -999 25 -999 25 -999 25 4.80244 4.806483 4,820281 4.84965 4.850142 4.840055 4.839644 4.829111 4.825702 4.784817 4.793676 4.786346 4.787955 4.773576 4.783454 4.787874 4.800261 4.789839 4.811213 4.808604 4.817651 4.800209 4.806186 4.798286 4.785112 4.770589 4.780065 4.785287 4.789073 4.780156 4.814398 4.813366 IRBK -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -0.006633759 -0.005368233 0.002078533 0.01056814 ~.02204037 0.0278759 e.02922297 0.02082157 0.0270977 0.01028585 0.02120733 0.01170301 -0.00453186 -0.01308537 -0.0084095 -0.02688122 -0.01299858 -0.02055264 -0.01149988 -0.01815462 -0.01964951 -0.0218792 -0.01714182 -0.01766586 0.005196571 0.0002923012 0.01448441 0.01730871 0.02479076 0.02258348 0.02866697 0.01689625 0.02254248 0.01030445 0.01596785 0.01043749 0.0006985664 -0.008140564 -0.e105772 -0.02385378 -0.01956654 -0.02969122 -0.01394701 -0.0[656103 -0.009016514 -0.01499605 -0,0110836 -0.01628733 TTBK -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999 25 -999 25 -999 25 -999 25 -999 25 -999 25 -999 25 -999 25 0.01138401 0.007872105 0.03193951 0.02797127 0.006425381 -0.007846832 -0.01492882 -0.01941109 -0.01369667 -0.02674437 -0.009508133 -0.007451057 0.0221715 0.01730633 0.02558756 0.02097225 0.0119729 -0.008356571 -0.01708269 -0.02445936 -0.01283121 -0.01994276 0.003351212 0.0004167557 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 ~ Schlumberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page 32 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 66.76207 66.75089 66.95515 66.76433 64.73134 64.08363 60,80701 60,89375 59,42924 58,82232 58.99326 59,43631 60.82341 60.96358 62.23353 62,74701 63.87691 63.75712 65.61464 65.93736 67.11104 67.01956 THBK -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 66.91565 67.08664 66.97575 66.69495 66.97504 66.23001 66.32436 65.90231 65.56876 64.69504 63.57168 62.75975 62.53165 61.91344 61.73969 60.44885 60.38058 59.86691 59.92335 59.48055 58.90908 58.71385 58.77764 58.69572 58.93085 59.32685 59.8794 60.08347 60.38261 60.38573 61.40073 61.26635 61.82865 61.96617 62.32283 62.89632 63.28424 62.9491 63.58729 63.62894 64.29109 64.34285 64.7859 64.71352 65.47908 65.87601 66.38664 66.30974 66.5327 66.42474 -999.25 -999 25 -999 25 -999 25 -999 25 -999 25 -999 25 -999 25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -0.001897067 -0.0135693 -0.01709449 -0.01321074 -0.007030785 -0.00380066 0.001628697 UFLG -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 0.005957544 0.008735687 0.01508695 0.01253694 0.01471111 0.01419777 0.02021471 0.01865938 0.01780406 0.01611814 0.01691461 0.01460245 0.01567259 0.01351383 0.01532152 0.01429218 0.01616123 0.0162513 0.01782215 0.01557326 0.01334259 0.008582205 0.00548932 0.002641618 0.002123564 -0.0003489852 -0.0006052852 -0.001443803 -0.001463562 -0.00279516 -1.195073E-05 -0.004354328 -0.004274666 -0.005942553 -0.007790416 -0.008051425 -0.0140776 -0.01724365 -0.02075869 -0.02039248 -0.0166927 -0.01413152 -0.01606768 -0.01286715 -0.01280421 -0.01260054 -0.01289728 -0.01526645 -0.0173445 -0.0182865 -0.009781063 -0.007425755 -0.008672804 -0.00596872 -0.00449425 -0.002030551 0.0004003346 -0.001267612 -0.001211345 -0.003016919 0.0003253222 0.005045354 0.0014925 0.007931411 0.009833694 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999,25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999 25 -999 25 -999 25 -999 25 -999 25 -999 25 ~ Schlumberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page 33 0. CCLU -999.25 AX -999.25 AY -999.25 AZ -999,25 FX -999.25 FY -999,25 7A -999.25 FZ -999.25 -0.1226604 -999.25 -999,25 -999.25 -999,25 -999.25 -999,25 -999.25 -999.25 -0.07170007 -999.25 0.~08844139 -999.25 9.85~634 -999,25 -0.3216071 -999.25 0.4392743 -999,25 0, -999,25 0,386568 File %railer USIT .044 ** FILE TRAILER *~ FILE NAME : USIT .044 SERVICE NAME : PLAYBA VERSION # : 7C0-427 DATE : 95/12/12 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SUMMARY ~LR #PR #ENC #DR #FM PI PI UNITS MAXPI 3835 11472 0 3816 3816 DEPT .lIN 827940 DEPT F 6899.5 DEPT M 2102.9676 (EOF) File header USIT .045 MINPI 599040 4992. 1521.5616 · SchFumberger LIST AKDVXiSMUBO:E]LISA.DAT; 27-DEC-95 12:50:08 Page 34 · * FILE HEADER -~ FILE NAME : USIT .045 SERVICE NAME : PLAYBA VERSION # : 7C0-427 DATE : 95/12/12 MAX. REC. LEN.: $192 FILE TYPE : DL PREVIOUS FILE : Data format specification record Listing o4 set $ type 64EB object 0 ENTRY VALUE REPCODE SIZE 2 0 66 3 9744 79 2 4 1 66 6 0 73 4 7 IN 65 2 $ 60 73 4 9 ,lIN 6S 4 12 -999.25 68 4 13 1 66 1 14 .lin 65 4 15 73 66 1 16 1 66 0 66 0 End o4 set Listing o4 set 0 type CHAN NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) BS USIT IN 28 201 0 27 I 1 4 68 0000000000 CS USIT F/HR 63 621 0 27 I 1 4 68 0000000000 CVEL USIT F/MN 63 6~0 0 27 1 1 4 68 0000000000 TENS USIT LBF 63 521 0 27 1 1 4 68 0000000000 ETIM USIT S 63 621 0 27 1 1 4 68 0000000000 MARK USIT F 15 001 0 27 1 1 4 68 0000000009 STIA USIT F 9 27 1 1 4 68 9999909900 STIT USIT F 0 27 1 1 4 68 9990000009 CFVL USIT US/F 0 27 1 1 4 68 0900000999 CZMD USIT US/F 9 27 1 1 4 68 9000000900 UFRT USIT HZ 0 27 1 1 4 68 9900099090 UTDL USIT US 9 27 1 1 4 68 0900009099 RSAV USIT HZ 9 27 ! ! 4 68 900000999~ FNOR USIT OER 63 101 9 27 1 1 4 68 0900909090 FINC USIT DEG 63 101 0 27 1 1 4 68 9990909900 HAZI USIT DEG 63 091 0 27 1 1 4 68 0900009000 P1AZ USIT DEG 63 091 0 27 1 1 4 68 9990909900 Schlumberger LIST AKDVXISMUBO:[]LISA.DAT; RB USIT DEG 63 101 0 SDEV USIT DEG 62 001 0 HV USIT V 0 CCL1 USIT 0 CCL2 USIT 0 CCL3 USIT 0 CCL4 USIT 0 PIPE USIT 0 lA US~T 0 2A USIT 0 3A USIT 0 4A USIT 0 5A USIT 0 AGMI USIT DB 0 AGMA USIT DB 0 GNMX USIT DB O ~NMN USIT DB 0 IDQ¢ USIT IN 0 WDMX USIT US 0 Wi)MN USIT US 0 WDMI USIT US 0 WDMA USIT US O AWAV USIT DB 0 AWMN USIT DB O AWMX USIT DB O AIAV USIT MRAY 0 AIMN USIT MRAY 0 AIMX USIT MRAY 0 AZEC USIT DEG 0 DIAM USIT IN 0 CWEI USIT 0 ERAV USIT IN 0 ERMN USIT IN 0 ERMX USIT IN 0 ECCE USIT IN 0 IRAV USIT IN 0 IRMN USIT IN 0 IRMX USIT IN 0 THAV USIT IN 0 THMN USIT IN 0 THMX USIT IN 0 USGI USIT 0 USBI USIT 0 CCLU USIT 0 RGR USIT GAPI 0 TIME USIT MS 63 621 0 ANOR USIT F/S2 63 101 0 GAT USIT DEGF 0 GMT USIT DEGF 0 CTEM USIT DEGF 0 AIBI USIT MRAY 0 UO~I USIT 0 U002 USIT 0 U0~3 USiT 0 U004 USiT 0 UO~ USIT 0 U006 US!T 0 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 27 1 1 1 1 1 1 3. 1 1 1 1 1 1 1 1 1 1 1 1 1 72 36 $6 36 36 36 36 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 288 72 72 72 72 72 72 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 79 79 79 79 79 79 27-DEC-95 0~00000000 12:50:08 Page 35 Schlumberger LIST AKDVXISMUBO : [] L'rSA.DAT; U007 USIT 0 27 U008 USIT 0 27 U009 USIT 0 27 UO10 USIT 0 27 UOll USIT 0 27 U012 USIT 0 27 U013 USIT 0 27 U0~4 USIT 0 27 U0~5 USIT 0 27 Ue16 USIT 0 27 U0~7 USIT 0 27 Ue18 USIT 0 27 UO19 USIT 0 27 UO2e USIT 0 27 Ue2~ USIT 0 27 U022 USIT 0 27 U023 USIT 0 27 U024 USIT 0 27 U025 USIT 0 27 U026 USIT 0 27 U027 USIT 0 27 Ue2$ USIT 0 27 Ue29 USIT 0 27 UO3e USIT 0 27 U03~ USIT e 27 U~32 USIT 0 27 U033 USIT 0 27 U034 USIT 0 27 U035 USIT 0 27 U036 USIT 0 27 U037 USIT 0 27 U038 USIT 0 27 U039 USIT 0 27 U040 USIT 0 27 U04~ USIT 0 27 U042 USIT 0 27 U043 USIT 0 27 U044 USIT 0 27 Ue45 USIT 0 27 U046 USIT 0 27 U047 USIT 0 27 U048 USIT 0 27 U049 USIT 0 27 U050 USIT 0 27 U05~ USIT 0 27 U052 USIT 0 27 U053 USIT 0 27 U054 USIT 0 27 U055 USIT 0 27 U056 USIT 0 27 U057 US~T 0 27 U058 USIT 0 27 U059 USIT 0 27 U060 USIT e 27 U06~ USIT 0 27 U062 USIT e 27 U063 USIT 0 27 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 1 '1 1 ! 1 1 1 1 1 1 1 1 1 1 1 1 ! ! 1 1 1 ! 1 1 1 1 1 1 1 1 ! 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ! 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 '79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 79 27-DEC-95 0000000000 0000000000 0000000000 0000000000 0000000000 12:50:08 Page 36 Schbumberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 12:5e:08 Page 37 U064 USIT e 27 36 I 72 79 U065 USIT 0 27 36 1 72 79 U066 USIT 0 27 36 i 72 79 U067 USIT 0 27 36 1 72 79 U068 USIT 0 27 36 I 72 79 U069 USIT 0 27 36 I 72 79 U070 USIT 0 27 36 1 72 79 U07! USIT 0 27 36 I 72 79 U072 US~T 0 27 36 I 72 79 UTIM USIT 0 27 72 1 288 68 UPGA USIT DB 0 27 72 I 288 68 WFDL USIT US 0 27 72 I 288 68 WPKA USIT 0 27 72 1 144 79 WAGN USIT DB 0 27 72 1 288 68 AWBK USIT DB 0 27 72 1 288 68 AIBK USIT MRAY 0 27 72 1 288 68 T1BK USIT IN 0 27 72 I 288 68 T2BK USIT IN ~ 27 72 I 288 68 ERBK USIT IN 0 27 72 1 288 68 IRBK USIT IN 0 27 72 1 288 68 TTBK USIT US 0 27 72 1 288 68 THBK USIT IN e 27 72 1 288 68 UFLO USIT 0 27 72 1 288 68 OR USIT GAPI 0 27 1 1 4 68 AX USIT M/S2 61 502 0 27 1 4 16 68 AY USIT M/S2 61 503 0 27 1 4 16 68 AZ USIT M/S2 61 501 0 27 I 4 16 68 FX USIT OER 0 27 1 4 16 68 FY USIT OER 0 27 1 4 16 68 6A USIT MS 63 621 0 27 1 4 16 68 FZ USIT OER 0 27 1 4 16 68 End of set Data record type 0 DEPT 827280 .liN 6894. FT 2101.2912 M BS 12.25 CS 1645.338 CVEL -27.42231 TENS MARK 0. STIA 0. STIT 0. CFVL UFRT 124.e273 UTDL 77. RSAV 6.88326 FNOR HAZI 74.36827 P1AZ 315.0016 RB 240.4353 SDEV CCLI 0. CCL2 0. CCL3 0. CCL4 lA 0. 2A 1. 3A 0. 4A AGMI -4. AGMA 20. GNMX 15. GNMN WDMX 62,61833 WDMN 58.61833 WDMI 43.10101 WDMA AWMN 53.04436 AWMX 57.48529 AIAV 10.06875 AIMN AZE¢ 61.06369 DIAM 9.625 CWEI 47. ERAV ERMX 4.817036 EdGE 0.05235295 IRAV 4.331377 IRMN THAV 0.4698595 THMN 0.4638923 THMX 0.4771267 USGI ¢¢LU -0.05006313 RGR 32.23881 TIME 0. ANOR GMT 144.1065 CTEM 139.1 AIBI 10.74873 10.46929 12.15973 12.06121 13.69895 13.64396 12.08163 13.15593 12.66269 12.31486 10.44992 19.59641 7.298392 5.664351 4.62638 3.546799 3.386595 2.615294 1475. ETIM 9. 198.9 CZMD 2.037658 0.6656895 FINC 26.69831 0.314735 HV 248.28 0. PIPE 0. 0. 5A 0. 10.9 IDQC 8.473717 83.19191 AWAV 55.58654 2.615294 AIMX 17.18092 4.801236 ERMN 4.78305 4.314514 IRMX 4.348888 o. USBI 1. 32.59249 GAT 192.5232 13.36179 7.716287 3.89922 , Schlumberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page 38 3.470613 4.993345 5.061123 6.608844 7.716125 11.24689 12.13626 13.67697 12.58956 13.19354 12.23262 13.38969 14.32647 14.70442 13.64949 1S.63933 13,85386 13.55647 12.47673 13.71684 13,71038 12.46666 12.20551 13.50569 14.39331 17.18092 14.98823 11.6453 10.59788 10.40129 8.701281 6.18187 6.305214 5.663189 4.991115 5.65121 7.53355 9.749199 9.675087 6.009329 6.278659 7.631966 7.808538 7.999213 8.611765 10.74711 11.48324 10.31845 9.324842 9.433645 9.450~03 U001 -8 -60 33 113 3 -3 19 -4 -14 -6 6 9 3 -10 -7 1 5 1 8 -98 -270 -104 19 -24 2 12 2 -11 -8 0 10 4 -6 -7 -2 4 U002 -14 -94 91 220 10 -6 34 -5 -25 -11 10 14 2 -18 -10 6 9 0 9 -162 -427 -173 28 -41 2 21 3 -19 -13 2 17 5 -14 -10 2 9 U003 -8 -11 290 321 4 8 36 -1~ -22 -4 12 10 -4 -14 1 9 5 -4 6 -156 -337 -66 42 -43 15 19 -5 -20 -7 6 13 -S -15 -4 5 5 U004 -12 86 381 250 -14 28 14 -19 -16 6 12 5 -10 -9 6 7 -1 -7 -7 -155 -135 96 26 -23 29 8 -15 -16 1 10 9 -10 -10 2 7 2 U00S -8 72 264 135 -21 20 2 -12 -4 7 6 0 -7 -3 3 2 0 -2 -3 -57 19 121 16 -9 19 -1 -12 -7 3 6 2 -7 -4 0 1 U006 -8 90 316 176 -20 26 4 -16 -6 10 8 0 -8 -4 3 1 1 0 -4 -82 9 153 23 -13 25 1 -15 -9 5 7 3 -7 -4 0 0 U007 -5 197 337 14 -40 38 -23 -15 10 20 4 -9 -13 4 6 -1 -3 -2 -20 21 365 304 -14 22 28 -16 -21 2 14 9 -6 -11 2 4 0 ~ Schlumberger LIST AKDVXISMUBO:[]LISA.DAT; 2T-DEC-g5 12:50:08 Page 39 U008 uoog UO10 U012 U013 uel4 uo15 -2 -Z 246 361 -32 -49 50 -40 -22 17 29 3 -14 -18 8 ii -1 -5 0 -18 49 508 441 -2 36 39 -25 -28 5 20 ii -11 -16 4 6 -1 8 59 -38 -113 -1 3 -20 0 10 6 -4 -7 -4 5 3 -2 -3 -2 -g 95 263 98 -20 25 -1 -11 -4 8 6 0 -7 -3 3 3 0 --2 10 6Q -123 -2Q5 -3 2 -3Q 2 16 8 -6 -9 -5 9 7 Q -7 -5 -8 137 353 125 -28 37 -3 -17 -6 8 Q -11 -6 5 7 2 -6 11 -8 -375 -382 -7 -17 -38 13 22 2 -15 -lQ 2 15 3 -11 -14 Q -9 163 35Q 42 -55 44 -25 -21 7 21 7 -7 -15 1 16 9 -5 -13 9 6Q -92 -185 -12 -1 -29 3 18 8 -9 -lQ -2 11 5 -5 -9 -2 -7 12Q 3Q2 113 -23 31 -5 -17 -4 13 9 -3 -13 -3 9 8 -1 -9 8 61 -32 -113 -3 2 -22 1 15 7 -7 -9 -2 8 3 -6 -7 Q -9 99 274 lQ4 -2Q 24 -3 -14 -4 8 -2 -iQ -2 7 4 -3 -7 -1 119 158 -42 -27 25 -28 -14 16 21 -i -15 -13 9 12 Q -g -4 -lQ 35 283 231 -6 22 2Q -19 -2Q 7 18 6 -14 -14 5 9 1 -8 -4 145 166 -103 -42 28 -41 -13 31 31 -8 -26 -14 2Q 17 -4 -11 -4 -14 73 453 326 -17 34 18 -31 -24 17 28 4 -26 -17 14 13 Schlumberger LIST AKDVXiSMUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page 40 U016 U017 U018 U019 U020 U021 U022 Uo23 -9 -2 262 397 -25 -49 58 -51 -31 33 50 -2 -41 -35 25 39 1 -27 -18 -22 39 511 435 -19 40 47 -38 -48 14 47 15 -36 -37 15 32 12 -19 -3 150 155 -134 -39 36 -54 -16 38 37 -15 -39 -19 32 35 -8 -32 -11 -16 85 511 355 -22 50 23 -39 -3~ 24 41 2 -40 -27 23 33 2 -27 -2 121 134 -89 -31 31 -40 -16 27 33 -7 -32 -20 23 32 -3 -28 -15 -10 51 352 262 -17 34 23 -30 -27 16 36 6 -31 -27 15 30 8 -22 9 77 3 -91 3 1 -28 I 23 12 -15 -21 -2 22 13 -12 -18 0 -10 91 265 106 -13 30 -2 -21 -7 20 17 -7 -25 -8 18 15 -6 -18 -1 1t8 154 -43 -22 27 -35 -17 23 31 -5 -30 -20 20 29 -2 -25 -13 -9 35 276 226 -5 27 22 -26 -28 12 32 7 -28 -25 13 26 7 -20 -5 201 321 -25 -34 44 -49 -26 33 47 -3 -42 -33 27 44 2 -36 -24 -19 57 467 353 -17 44 35 -37 -43 16 47 12 -39 -40 14 40 14 -27 -4 200 361 53 -23 44 -33 -32 14 43 12 -30 -38 40 15 -21 -26 -20 -11 295 279 -11 26 41 -24 -46 0 39 24 -22 -42 -5 29 22 -15 -8 247 470 73 -29 55 -34 -33 12 44 14 -30 -4t 6 38 17 -20 -27 -25 -11 336 304 -19 30 44 -26 -47 -2 39 27 -18 -41 -7 27 24 · SchlUmberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page 41 U024 U025 U026 U027 U028 U029 U030 U031 -11 -5 164 324 73 -20 37 -17 -25 2 30 16 -13 -27 -2 20 14 -6 -17 -18 -43 166 188 -15 11 31 -13 -34 -8 22 22 -5 -25 -10 12 17 -11 65 270 145 -20 25 8 -18 -15 9 17 5 -14 -13 4 10 5 -7 -3 -90 -71 70 8 -16 24 6 -17 -18 1 14 11 -1~ -13 -1 8 6 -9 -7 250 274 3 11 34 -11 -28 -7 18 17 -3 -19 -5 7 8 -3 6 -125 -274 -48 34 -41 16 21 -5 -26 -14 8 21 0 -16 -8 3 9 -14 -49 250 322 0 2 4~ -11 -30 -10 16 17 -1 -17 -2 9 5 -5 12 -191 -477 -134 52 -51 14 25 0 -24 -15 5 18 -3 -16 -4 6 6 -10 -47 138 214 7 -2 29 -2 -17 -6 8 8 -1 -12 0 9 4 -6 6 -125 -303 -97 33 -31 6 15 0 -9 2 10 -4 -13 -3 5 4 7 -210 -350 17 50 -39 33 12 -18 -20 2 10 lQ -10 -11 1 6 2 19 -44 -450 -354 19 -27 -23 22 17 -9 -15 -4 11 11 -7 -9 -1 6 5 -199 -391 -86 34 -33 18 16 -9 -19 -3 8 13 -4 -9 0 4 5 23 55 -202 -242 2 -12 -28 13 21 -1 -12 -8 6 12 -4 -7 -5 2 10 -67 -275 -150 18 -20 -4 11 3 -9 -6 0 8 2 -7 -5 1 4 2 89 68 -77 -18 11 -18 -1 11 6 -5 -7 -2 8 3 -4 ' Schlumberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page 42 U032 U033 U034 U035 U036 U037 U038 U039 11 -91 -359 -206 27 -23 -6 16 4 -12 -8 2 14 5 -11 -7 2 5 4 104 31 -143 -24 21 -23 0 18 9 -8 -11 -2 14 6 -6 -6 14 4 -366 -384 3 -10 -38 17 26 0 -16 -12 2 ~1 -1 -4 -5 0 -8 187 430 76 -61 52 -23 -24 ~0 24 5 -8 -15 0 9 3 -2 -6 9 2~ -230 -277 -9 -2 -29 8 18 3 -10 -9 -1 8 2 -~ -4 -3 -8 137 325 83 -40 36 -11 -16 4 15 5 -2 -~0 -2 5 4 1 -4 7 43 -83 -144 -2 1 -21 3 13 4 -6 -5 -1 3 0 ¢ -~ -3 -9 101 270 92 -24 26 -4 4 -1 -6 -1 2 7 39 -154 -226 -14 -5 -32 3 16 I -12 -9 -2 4 1 0 -1 -3 -5 124 297 90 -34 28 -lQ -16 3 15 5 -4 -9 -2 2 0 2 -3 78 81 -79 -32 17 -20 -4 11 9 -3 -5 -4 3 1 -1 -1 0 -9 47 279 193 -16 18 9 -13 -7 6 6 1 -5 -3 3 0 -1 -1 8 80 4 -103 -6 4 -19 2 12 4 -6 -5 2 7 0 -3 -1 1 -12 99 287 115 -21 22 -2 -12 -2 9 4 -3 -8 1 5 0 -2 -8 218 369 -14 -48 46 -32 -15 16 21 -2 -i4 -9 14 8 -8 -6 -1 -21 52 477 369 -22 29 28 -22 -21 6 15 3 -15 -8 12 7 -1 Schl'umberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page 43 U040 U041 U042 U043 U044 U045 U046 U047 -5 -2 129 177 -47 -35 29 -21 -10 12 16 0 -11 -$ 9 $ -3 -5 -3 -11 39 328 264 -11 16 15 -15 -15 4 ~1 3 -11 -8 6 6 0 -4 -9 245 461 SS -44 ~1 -23 -21 9 21 4 -11 -13 10 11 -1 -5 -4 -24 $ 387 337 -20 18 34 -16 -26 -1 12 6 -12 -13 5 6 2 -5 -9 240 438 28 -48 50 -27 -17 13 20 -1 -15 -13 11 9 -5 -4 2 -21 30 430 353 -23 21 31 -19 -23 4 1~ ~ -14 -12 $ 6 -3 -6 -$ 243 467 71 -41 46 -23 -19 ll 21 2 -13 -17 12 -3 -7 -3 -23 -8 340 311 -18 17 31 -19 -2~ 3 17 11 -9 -16 4 $ 0 -7 -! 140 226 3 -30 28 -17 -11 9 14 3 -8 -12 4 9 0 -5 -3 -12 16 270 243 -3 13 21 -12 -15 3 12 8 -7 -10 3 5 -5 -3 103 159 -31 -28 21 -18 -7 8 9 0 -6 -9 3 7 -1 -4 -2 -10 37 266 194 -15 15 12 -11 -9 3 8 5 -6 -9 2 4 0 -4 -3 87 109 -60 -30 19 -18 -4 8 7 -1 -6 -8 4 7 -1 -4 -2 -9 44 277 198 -14 16 10 -11 -7 3 7 4 -5 -8 3 4 0 -4 -4 104 16B -32 -29 21 -18 -4 9 9 2 -3 -8 3 6 1 -3 -4 -10 36 269 198 -15 15 11 -12 -8 3 7 6 -2 -7 2 5 2 , SchI~umberger LZST AKDVXISMUBO:[]LZSA,DAT; 27-DEC-95 12:50:¢8 Page 44 U048 U049 U050 U052 U053 U054 U055 -2 -2 138 199 -38 -38 27 -22 -9 10 12 3 -4 -11 1 7 3 -3 -5 -12 40 341 275 -9 17 !8 -13 -11 2 7 7 -3 -10 -1 4 5 -10 261 511 87 -43 49 -22 -22 7 24 16 -2 -22 14 9 -2 -13 -25 -21 321 396 -19 16 35 -16 -30 -7 11 18 2 -18 -8 7 13 -9 83 293 137 -28 26 1 -15 -3 12 11 2 -12 -6 6 6 0 -6 -3 -49 49 149 15 -10 24 -1 -16 -9 5 11 6 -9 -7 2 6 2 -9 74 279 144 -21 23 3 -15 -6 9 11 3 -10 -6 4 5 2 -4 -2 -67 -10 196 13 -12 21 0 -15 -11 2 11 7 -7 -7 0 5 3 -10 127 423 219 -29 39 0 -28 -6 20 20 1 -23 -12 11 13 2 -10 -4 -76 102 266 37 -11 43 -1 -30 -16 11 22 9 -18 -15 2 13 5 -8 247 442 19 -36 62 -42 -31 22 43 12 -29 -39 9 34 13 -17 -22 -22 43 468 371 -27 39 45 -32 · -44 5 40 26 -19 -36 -5 23 20 -11 -4 89 121 -48 -23 21 -26 -10 16 18 -3 -18 -15 8 17 4 -11 -lq -10 41 269 192 -13 23 15 -lg -16 8 20 7 -14 -16 2 13 8 -7 -4 101 153 -33 -21 24 -27 -11 16 22 0 -19 -18 8 19 5 -10 -11 -9 41 276 199 -13 25 18 -19 -19 7 22 8 -16 -19 ! 14 9 Schi'umberger LIST AKDVXISMUB~:[]LISA.DAT; 27-DEC-95 12:50:08 Page 45 U056 U057 U058 U059 U060 U061 U062 U063 -7 12 94 -53 -174 0 4 -41 1 31 20 -14 -31 -12 23 23 -3 -21 -11 -11 145 406 169 -22 46 0 -30 -12 24 28 -1 -30 -17 14 22 5 -17 7 21 -144 -178 1 -7 -31 6 25 10 -14 -21 -5 18 13 -6 -14 -5 -8 110 277 80 -24 33 -10 -21 -2 20 17 -5 -23 -8 12 13 0 -12 5 7 -180 -198 0 -8 -27 8 21 6 -14 -17 -1 16 8 -7 -11 -2 -8 105 258 6~ -29 31 -12 -17 2 19 12 -7 -19 -4 12 9 -3 -10 6 40 -88 -145 -2 -1 -23 4 17 7 -7 -12 -4 9 6 -3 -7 -2 -8 106 280 96 -22 27 -5 -15 -2 13 11 -1 -12 -5 7 6 -6 9 14 -295 -340 -10 -7 -38 13 27 4 -19 -18 4 21 7 -8 -11 -1 -6 163 364 83 -46 43 -18 -24 6 26 12 -10 -22 -1 16 9 -3 -9 9 -23 -448 -433 5 -32 -61 24 50 7 -38 -32 9 36 10 -18 -22 0 -11 190 426 46 -60 70 -35 -41 10 45 21 -23 -42 1 31 17 -8 -21 10 -67 -279 -154 19 -28 -13 17 18 -7 -20 -9 11 14 -1 -11 -8 4 1 102 -58 -8 18 -25 -10 15 20 2 -16 -15 7 14 4 -8 -9 10 -24 -444 -428 1 -26 -52 21 42 5 -31 -24 9 29 8 -14 -15 1 -10 177 386 31 -63 58 -32 -34 11 39 16 -19 -33 1 26 t4 -7 ' Schl~umberger LTST AKDVXISMUBO: []LISA.DAT; 27-DEC-95 12:50:08 Page 46 U064 U065 U066 U067 U068 U069 U070 U~71 -16 17 -118 -489 -282 31 -43 -18 30 26 -13 -28 -10 20 21 -2 -13 -7 5 7 164 113 -136 -21 24 -45 -14 24 29 -1 -25 -22 11 18 2 -10 -8 9 -84 -307 -154 23 -30 -8 17 12 -11 -17 -3 13 8 -7 -10 -3 6 2 72 13 -115 -12 13 -28 -6 17 16 -4 -15 -9 11 11 -1 -7 -4 9 -86 -295 -130 28 -34 -3 17 5 -15 -15 0 14 6 -8 -7 -2 4 3 46 -65 -159 -10 9 -29 0 19 12 -8 -14 -6 11 8 -3 -7 -2 7 -79 -280 -138 23 -29 -8 13 8 -9 -11 -1 10 -5 -4 0 4 2 53 -33 -133 -11 13 -24 -4 13 -4 -11 -6 8 6 -1 -3 -1 10 -144 -492 -246 40 -44 -5 27 11 -18 -18 -1 16 8 -6 -7 -5 2 4 83 -119 -290 -34 15 -45 -2 28 17 -9 -16 -9 11 10 1 -5 -6 5 -143 -275 -43 19 -31 13 12 -7 -16 -6 5 12 2 -6 -7 -3 3 11 5 -179 -166 9 -15 -21 11 17 0 -12 -12 -1 10 5 -1 -5 -3 6 -206 -327 39 44 -50 37 21 -18 -33 -8 17 26 -3 -18 -11 2 9 18 -67 -505 -377 23 -37 -36 24 32 -5 -29 -18 9 22 7 -10 -13 -1 6 -200 -309 47 42 -51 38 24 -17 -33 -7 18 23 -4 -17 -9 2 8 18 -71 -507 -376 23 -41 -40 22 31 -28 -17 9 19 3 -10 -11 ~ Schlbmberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page 47 U~72 2 -173 16 -20 -17 -8 -331 15 -23 -12 UTIM 1.742985E+07 1,743025E+07 1,742985E+07 1,743078E+07 1.743e25E+07 1,743052E+07 1.742985E+07 1.743078E+07 1,743025E+07 1,743052E+07 1,742998E+07 1.742972E+07 1.743038E+07 1,743065E+07 1,742998E+07 1,742972E+07 1.743038E+07 1.T43065E+07 1.742998E+07 1,742972E+07 1.743038E+07 1.743065E+07 UPGA 10.9 10.9 15. 10.9 10.9 15. 10.9 10.9 10.9 10.9 15. 10.9 10.9 15. 10.9 10.9 10.9 10.9 10.9 10.9 10.9 10.9 WFDL 61.11833 62.11833 62.11833 62.11833 60.61833 59.61833 59.11833 58.61833 59.61833 60.11833 60,61833 WPKA 362 286 380 354 336 390 298 386 380 286 404 396 386 4!2 406 386 420 426 326 414 -247 47 38 -39 32 -28 -3 16 20 -6 3 8 15 -54 -427 -31 -29 22 25 -7 lq 19 2 -10 -lq 1.743078E+07 1.743025E+07 1.743052E+07 1.742985E+~7 1.743025E+~7 1.742985E+~7 1.743025E+07 1.742985E+07 1.743038E+07 1.742998E+07 1.743~38E+07 1.742998E+07 1.743038E+07 1.742998E+~7 1.743052E+07 1.743078E+07 1.743052E+07 1.743e78E+07 1.743052E+07 1.743078E+07 1.743065E+07 1.742972E+07 1.743~65E+07 1.742972E+e7 1.742985E+07 1.743078E+07 1.743025E+07 1.743052E+07 1,742985E+~7 1,743078E+07 1,743025E+07 1,743052E+07 1,742985E+07 1.743078E+07 1,743025E+~7 1,743052E+07 1,742998E+07 1,742972E+07 1,743038E+07 1,743065E+07 1,742998E+07 1.742972E+~7 1.743038E+07 1.743065E+07 1.743e65E+07 1.74299SE+e7 1.742972E+07 1.742972E+07 1.743038E+07 1.743e65E+07 302 274 358 394 334 448 356 386 368 398 368 462 354 392 384 426 372 464 368 398 378 434 386 490 372 382 398 452 398 402 418 400 42~ 476 404 294 418 402 426 480 390 310 42~ 394 406 406 382 344 424 406 61.11833 61.11833 61.61833 61.61833 61.61833 62.11833 62.61833 62.61833 62.61833 62.61833 62.61833 62.11833 62.11833 62.11833 62.11833 62.61833 62.11833 62.11833 62.11833 62.11833 61.61833 61.11833 61.11833 61,11833 60.61833 60.11833 60.11833 59.61833 59.61833 59.61833 59.11833 59.61833 59.11833 59.11833 59.11833 59.11833 59.11833 59.11833 59.11833 59.11833 59.11833 59.11833 58.61833 58.61833 59.11833 59,11833 59.11833 59.61833 59.61833 59.61833 59.61833 59.61833 60.11833 59.61833 60.11833 60.11833 60.11833 60.11833 60.61833 60.61833 60.61833 10.9 10.9 10.9 15. 10.9 15. 10.9 15. 10.9 15. 10.9 15. 10.9 15. 10.9 15. 10.9 15. 10.9 15. 10.9 15. 10.9 15. 10.9 10.9 10.9 15. 10.9 10,9 10.9 10.9 10.9 15. 10.9 10.9 10.9 10.9 10.9 15. 10.9 10.9 10.9 10.9 10.9 10.9 10.9 10.9 10.9 10.9 ¢ Sch?umberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page 48 402 334 WAGN -7.16 -1.14 -1.14 -1.14 -7.16 -3.96 -1.14 2.96 -7.16 -3.96 -1.14 -3.96 -7.16 -3.96 -1.14 2.96 -1.14 -3.96 -7.16 -3.96 -1.14 -1.14 -1.14 -3.96 -7.16 -3.96 -1.14 -3.96 -1.14 -1.14 -7.16 -3.96 -1.14 -3.96 -7.16 -3.96 -7.16 -7.16 -1.14 -3.96 -1.14 -1.14 -1.14 -3.96 -7.16 -7.16 -7.16 -3.96 -1.14 -7.16 -7.16 -1.14 -1.14 -7.16 -7.16 -3.96 -7.16 -7.16 -7.16 -1.14 -1.14 -7.16 -1.14 -1.14 -7.16 -7.16 -7.16 -1.14 -7.16 -1.14 -1.14 -1.14 AWBK -1.612278 -3.503992 -3.22171 -4.157177 -1.765934 -4.278843 -2.385368 -4.449926 -1.838665 -2.9244 -1.945994 -4.375179 -1.519962 -4.97341 -2.527832 -4.145965 -1.642555 -2.745865 -1.854927 -4.291687 -1.218433 -2.941294 -1.198242 -3.194633 -1.379257 -2.859619 -1.642597 -3.889446 -1.1628 -3.461227 -1.245766 -3.184536 -1.174553 -2.261276 -1.269714 -3.899994 -9.8949814 -1.158154 -9.6772423 -2.86351 -0.7496944 -9.5697376 -1.193493 -3.394539 -9.4412842 -9,7293979 -9.3516922 -2,381693 -9.7298355 -9.7329557 -1,326744 -3.323727 -9,1449468 -9,8339269 -9,266777 -2.158794 -9,3665695 -9,2743934 -9,9425987 -2.751652 -9,3554396 -9,8777695 -9.7561951 -2.293823 -9,5972327 -9,5873694 -1.221325 -2,953566 9. -9.6895866 -9.7999837 -2.379326 AIBK 19.74873 19.46929 12.15973 12.96121 13.69895 13.64396 13.36179 12.08163 13.15593 12.66269 12.31486 19.44992 10.59641 7.716287 7.298392 5.664351 4.62638 3.546799 3.386596 2.615294 3.89922 3.479613 4.993345 5.961123 6.698844 7.716125 11.24689 12.13626 13.67697 12.58956 13.19354 12.23262 13.38969 14.32647 14.79442 13,64949 15.63933 13,85386 13.55647 12.47673 13,71684 13.71938 12,46666 12,29551 13,59569 14.39331 17,18992 14,98823 11.6453 19.59788 19.49129 8.791281 6.18187 6.395214 5.663189 4.991115 5.65121 7.53355 9.749199 9.675987 6.999329 6.278659 7.631966 7.898538 7.999213 8.611765 19.74711 11.48324 19.31845 9.324842 9.433645 9.459993 T1BK -9.92957457 -9.92189672 -9.9195837 -9.91319594 -9.91327991 -9.9145793 -9.997612795 -9.995994198 -9.992557278 -9.999988398 9.992235413 -9.991174927 -9.9993814697 9.992585411 -9.99613451 -9.99877142 -9.99966692 -9.993611988 -9.91721954 -9.91644516 -9.92458996 -9.91579994 -9.92537298 -9.91978392 -9.92123165 -9.91189327 -9.92184957 -9.01279294 -9.91976199 -0.91168728 -9.91561499 -9.912115 -9.91199743 -9.993157139 -9.992543926 9.991893997 9.9992837181 9.993268242 -9.99475359 -9.91182842 -0.01464791 -9.90837183 -9.99480175 -0.991639843 -9.995232811 0.993935337 9.903913493 9.092681732 -9.994218192 -9.9995979991 -9.995627632 -9.992441496 -0.91261282 -0.998277416 -9.91168966 -9.91339895 -0.91899168 -9.01936483 -0.02918452 -9.91999113 -9.92309656 -9.92598524 T2BK 9.991155853 9.993127098 9.998388519 0.992642155 -9.99924921 -0.91143932 -9.996683826 -9.994412174 -9.991877844 -9.991943922 -9.90392583 -0.90267694 -9.991943737 -0.991741976 -9.902197531 -9.991719893 -0.995466914 -9.998107722 -0.993852159 -9.992898332 -9.9909964795 -5.242229E-95 9.902234459 0.991311451 9.901384979 -9.9991299378 9.9999929895 9.991423717 9.901458317 -0.9094377967 -9.901995113 -9.992747596 -9.092351761 -9.991373291 Schi~Umberger LIST AKDVXISMUBO:E]LiSA.DAT; 2T-DEC-95 12:5~:08 Page 49 -0.004295558 -0.005239904 0.004836023 0.003029406 0.001251668 0.005126655 0.001792967 -0.001136005 -0.005919456 -0.904063964 -0.091466483 -9.904724115 -0.995464077 -0.906484991 -0.0073888 -9.996104976 ERBK 4.790048 4.78875 4.804875 4.808189 4.895485 4.892372 4.819689 4.811113 4.798958 4.899056 4.79911 4.791911 4.803195 4.898297 4,796607 4,794163 4.810154 4.810022 4.798338 4.795189 4.783271 4.78395 IRBK -0.003955722 -0.001946718 0.003486276 -0.001971245 -0.003690004 -0.006259471 -0.005100369 -0.003645569 -0.002268523 0.003677994 -0.0e4165798 -0.902655298 0.9003936857 -0.9904937649 -0.002140224 -0,001628131 -0,093486127 -0.992641797 -9,005158901 -0.004465878 -9.095883843 -0.005620629 -0.005673081 -0.096132126 0.004001081 -0.001496196 0.002291948 -e.905114853 -0.001168787 -0.003242946 -0.005224884 -0.903464431 4.78989 4.796629 4.797276 4.796179 4.802779 4.807519 4.817936 4.812333 4.808946 4.802459 4.807199 4.897966 4.815727 4.812749 4.811696 4.812338 4.802e7 4.798489 4.799777 4.89662 4.792755 4.799738 4.78518 4.78855 4.788612 4.894923 4.796225 4.891116 4.796391 4.802676 4.8~7984 4.812253 4.811155 4.810653 4.891826 4.809642 4.895057 4.809691 4.8058 4.811711 4.803816 4.898661 4.801408 4.803575 4.794786 4.793966 4.787919 4.78703 4.78867 4.787735 -9.01145172 -9.91268387 -0.01046085 -9.004972189 -0.004157966 -0.005456448 0.01224995 9.01751137 -0.9098654594 -9.0901263618 9.097947922 0.006771988 9.090351429 -9.9095440712 9.001519143 9.903218651 0 0.011765 0.906565571 -0.002316475 0.002439922 0.004710674 0.007749557 9.098741379 9.01170826 0.0~5511761 -9.008996695 -0.007322311 -9.01966017 -0.0121088 -0.902770424 -0.00256443 -0.096492138 -0.902992153 9.01101685 0.009406567 9.01239109 0.0007510185 0.004321098 0.007483006 0.01180458 0.004994747 0.008525848 0.0e08454323 -0.002566814 -0.0041852 -0.009968281 -9.01397371 -0.01686239 .0102787 0.01135826 0.092988338 -9.01545811 -0.01271772 -0.001974583 0.004369259 0.003899038 0.003495216 -0.00896883 -9.906668091 -0.01625913 -0.003580093 -9.01063824 0.90596571 0.006578922 -0.002705574 -9.905524158 0.91395819 0.01303625 0.006681442 -0.993489971 -9.91924199 -0.01106167 TTBK 63.25867 63.34702 63 64.46431 64.75887 64 64.50883 64.40622 64 64.30525 64,22841 64 62,86324 62.7392 62 62.00263 61.53731 61 61.24652 61.43735 61 69.97749 60.90195 61 61.8808 61.94016 61 62.3464 62.38046 62 62.89857 62.94374 THBK 0.0002626181 9.9001974404 -0.0008853674 -9.0905355775 -0.003325552 -0.905967259 9.004374921 0.003451914 0.~03598779 0,901702756 -0.0099152591 -0.0001280606 9.09e1937449 9.005626738 0.0991692176 54252 63.86779 63.96931 64.02063 64.33527 87242 65.08235 64.91438 64.75143 64.50131 52101 64.541 64.69394 64.50194 64.373 20839 63.79316 63.57277 63.40431 63.46152 31837 62.4584 61.99031 62.02723 61.83399 71103 61.35526 61.50939 61.27486 61.29649 39715 61.49696 61.40717 61.48357 61.29824 13908 61.39027 61.4604 61.40871 61.7916 82115 62.95956 62.01895 62.25757 62.05916 47653 62.46907 62.57821 62.70148 62.88614 3.293157E-e5 0.001143992 0.003132552 -0.902155095 9.006976485 0.09339213 9.00393343 -9.003778994 0.0001967251 -9.001711696 0.003524542 0.001135349 0.0058i8456 -0.902025336 -0.0005i48351 0.902444148 9.00i646698 2.384i86E-97 0.0905i23317 0.0003984869 -0.00066787 0.002019525 -0.0096070435 ~,096141543 0.0006442666 0.0944324~ -0.00297439~ 0.0004206598 0.00208804 0.003564179 -0.003099442 0.005169868 0.007267118 0.091004457 -0.001923501 Sch1~umberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page 50 -0.001549542 -0.004119009 -0.002959907 -~.0015051~7 UFLG 0. 0. 0. 0. 0. 0. 0. 0. 0. 0. 0. 0. 0. 0. 0. 0. 0. 0. GE 41.55937 AX -0.001345664 -0.0005013347 -0.003018439 -0.002325416 -0,00374338 -0.003480166 -0.003532618 -0.003991663 -999.25 -999.25 -999.25 -0.005282099 AY -999,25 -999.25 -999.25 AZ -999.25 -999.25 -999.25 FX -999.25 -999.25 -999.25 FY -999.25 -999.25 -999.25 6A - -999.25 -999.25 -999.25 FZ -999.25 -999.25 -999.25 0.0009716749 -0.001101583 -0.003084421 -0.001323968 0.0189265 9.843386 0.1806765 0.4261905 0. 0.2567538 0.0006739795 -0.003323615 -0.005248338 -0.002583653 -0.004343629 -0.003964514 File %railer USIT .045 ** FILE TRAILER FILE NAME : USIT .045 SERVICE NAME : PLAYBA VERSION # : 7C0-427 DATE : 95/12/12 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI 1390 2766 0 1371 1371 DEPT .liN 827280 DEPT F 6894. DEPT M 2101.2912 (EOF) File header USIT .048 MINPI 745080 6209. 1892.5032 SchlUmberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 12:50:05 Page =* FILE HEADER FILE NAME : USIT .048 SERVICE NAME : SAVE-S VERSION # : 7C~-427 DATE : 95/12/12 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : File trai let USIT .048 ** FILE TRAILER ** FILE NAME : USIT .048 SERVICE NAME : SAVE-S VERSION # : 7C~-427 DATE : 95/[2/12 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SUMMARY ~LR #PR #ENC #DR #FM PI PI_UNITS MAXPI MINPI 14 18 0 (EOF) Tape trailer 4~ 7 USI ** TAPE TRAILER SERVICE NAME : FUSIT DATE : 95/12/12 ORIGIN : DLIS TAPE NAME : 41 7 USI CONTINUATION #: [ NEXT TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY TAPE SUMMARY FILES #LR #PR 3 5241 14258 Reel trailer 41 7 USI Schlumberger LIST AKDVXISMUBO:[]LISA.DAT; 27-DEC-95 12:50:08 Page 52 *~ REEL TRAILER SERVICE NAME : USIT DATE : ORIGIN : DLIS REEL NAME : 41T USI CONTINUATION ~: 1 NEXT REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY REEL SUMMARY FILES TAPES #LR #PR 3 ~ 5243 14260 (EOF) (EOD) LU SUMMARY FILES TAPES REELS #LR #PR 3 1 ~ 5243 ~4260 End of listing AKDVXISMUBO:[]LISA.DAT; YEBIFIC~T]OM LISTING SERViICE NA~E :EDIT [)ATE :79112/19 O~IGIN : REEL NA~: :P.C.A,L. CONTiNUATiON P~EV IOUS ' REEL : COMMENTS : LIS ~'ORMAT CUSTOMER TAPE HEADER SERVICE NAME :EDIT DATE :79/12/19 ORIGIN : TAPE NAME :60057 CONTINUATION # :01 PREVIOUS TAPE : COMMENTS : FILE NAMe] :EDIT .00] SERVICE NA~iE VERSION # : DATE : ~AXI,~U~ LENGTH : 1024 FiLE TYPE : PREVIOUS FILE : ENTRY BLOCKS DATA FOR~iAT P, ECORD TYPE SIZE 0 ] 66 0 DATU~ SPECIFICATION BLOCKS MNEM, SERVICE ORDER NO UNI? API .hPI APl API FILE SIZE; PROCESS SAMPLE ¢EPR LOG TYPE CI.,~SS ~'IOD NO. L.EVF, I~ CODE DEPT FT 0 0 0 0 0 4 0 I 68 SP DIL MV, 7 1 0 0 0 4 0 I 6~ ILD DiL OH~B 7 ~2 46 0 0 4 0 1 68 IL~ DIL O~M 7 1~ 44 0 0 4 0 ~ 68 LLBU DIL 0~ 7 22 8 0 0 4 0 1 68 GR OIL GAPI 7 31 32 0 0 4 0 1 68 DT DIL US/F 7 52 32 0 0 4 0 1 68 GR CNL GAPI 42 31 32 0 0 4 0 1 68 CALl CML IN 42 ~8 1 0 0 4 0 1 68 DRHO FDC G/C3 4~ 44 0 0 0 4 0 ~ 68 NPHI CNL PU 4~ 6~ 3 0 0 4 0 1 6R RHOB CNL G/C3 42 35 1 0 0 4 0 1 6R NRAT CNL C/C 42 4,:2 1 0 0 4 0 1 68 NCNL CNL CPS 42 34 92 0 0 4 0 ~ 68 FCNL CNL CPS 42 34 93 0 0 4 0 ~ 68 DEPT DT DRHO NRAT DT DRMO NRAT DEPT IbM DT DRHO NRAT DEPT IbM DT DRBO NRAT DEPT DT DRHO NRAT DEPT DT DRHO NRAT DEPT IbM DRHO DEPT IbM DT ORHO DEPT DT DRHO NRAT DEPT OT ORHO NRAT 7032.0000 30.2031 75.5625 0.0366 2.8242 7000.0000 24.0937 75.7500 0.0546 3.1914 6900.0000 13.8593 90.1875 0.0053 3.5429 6800.0000 14.7265 100.1875 0.0107 3.5664 6700.0000 9.5625 95.3750 0.0156 3.5332 6600.0000 11.9921 95.7500 0.0590 4.4492 6500.0000 31.3437 89.3750 0.0043 2.8613 6400.0000 20.25O0 96.7500 0.0263 3.1621 6300.0000 19.8593 95.1875 0.0385 3.4785 6200.0000 12.6015 100.3750 0.0209 3.3437 DA TA SP GR NPH I NCNL SP b L 8 U SP LL$1t GR N P I-! I ~C t,~L SP I., L 8 NPHI NCNL SP L I, 8 U NPHI NCNI, SP LLSU NPH] NCNL SP LLSU GR NP~,I NCNi, SP LI, RI..1 GR NPHI SP LL~U G¢ NCML SP G? N C N b 66.8750 4,2.2812 84.0625 24.5117 2414.0000 73.0625 32.5312 95.0625 40.1367 2482.0000 60.3437 1,3.0625 64.9375 40.3320 1790.0000 64.5625 22.4062 60.7812 40.6738 1661.0000 63.0312 8.703~ 56.5625 40.087R 1840.0000 60.5625 13.2734 57.4687 56.6894 1395.0000 100.5000 35.656~ 53.5625 2~.710g 2118.0000 72.1250 25.9531 ~7.2500 33.1054 1586.0000 75.2500 19.~125 46.1250 39.3066 15~6.0000 67.5625 16.2656 57.31~5 36.7187 ~6~4.0000 ILD GR CgbI RHOB FCNL ILD C A L I RHOB FCNI, I 'I,D GR CILI RH OB ~,'CNI., ILD GR CALI RI-lOB FCNL ILD GR CALl RBOB FCI~)L ILD CALl FCNL ILD GR Cg~LI FCNL II, D GR CAbI FCNL ILD Ge CaLl FCNL IBP_, GR CALl F H O ¢ FC 29.3437 60.7187 12.2500 1.8750 801..5000 23.9687 69.4375 6.7226 2.041.0 741,.0000 14.3906 6~.2187 12.1093 2.4160 464.0000 14.9062 57.5312 12.2500 2.3164 459.2500 9.7187 55.1875 12.2968 2.4179 476.2500 1i.953~ 65.1875 12.J015 1.9511 275.7500 34.3125 59.6875 11.7500 2.3281 714.5000 18.5312 55.4687 11.9609 ?.3417 463.7500 21.3750 54.9062 11.9375 2.3496 406.7500 12.0078 5~.4375 12.2265 2.3808 531.5000 DT DRHO DE~T DT DRHO NRAT DEPT IBM DT DRBO NRAT DEPT DT DRHO NRAT DEPT DT DRHO NRAT DEPT DT DRHO NRAT DEPT DT ORHO NRAT DEPT 1BM DT DRHO NRAT DE]PT I LM PT ORHO NRAT OEP% DT DRHO NRAT i DT DR HO NRAT D~;PT 97.3750 0.0927 3.9023 6000.0000 i.t.3281, 107.5625 0.0668 3.1562 5900.0000 8.9531, 105.7500 0.0703 4.1210 5800.0000 8.4531. 101.1875 0.0048 3.9433 5700.0000 14.7031 ,96.7500 0.0263 3.4472 5600.0000 6.2070 101.1875 0.0463 3.7617 5500.0000 17.5937 92.3750 0.0239 3.4238 5400.0000 10.1328 96.7500 0.0190 3.6464 53O0.0O00 10.2734 101.3750 0.0180 3.4160 5200.0000 14.6796 108.5625 0.0097 3.3378 5100.0000 10.1953 110.0000 0.0278 3.8593 5000.0000 35.8437 NCNL SP L L 8 U G~ NPH 1 NCNL SP L L 8 U G~ NPHI SP L L 8 U GR NPH I NCNL SP L I; 8 SP L I, 8 U GR NPMI N C N I, LLSU GR NPHI NCNI, SP LLSU GR NPHI N C N I, SP LLSU GP NPHI NCNL SP LLSU GR NPHI NCNL SP l,T~81~ Ga NPHI NCNL SP Lib 8!I 50.5312 46,5820 629 , 0000 78.8750 !4,@593 55.8125 32.9589 ~837.0000 69.8750 8.9296 64.8750 50.6347 1520.0000 60.0937 7.2968 52.4062 47.4121 1753.0000 86.3750 I7.5156 56.8750 38.6230 1619.0000 67,31,25 4,9453 56.78!2 44,0917 1606,0000 88.5625 18.8906 44.5937 38.2812 ~760.0000 74,1250 11.421.8 53.53~2 ~2.0410 1817.0000 73,5625 13,6250 51.0625 38.0371 ~623.0000 80.3125 !7.g067 43.9375 3~.7187 1798.0000 75.5625 11.2031 56.7500 45.9960 1457.0000 500 GR CALl RHOB FCNL I L b CALl FCNL ILD CB C~L1 FCNL ILD CAI, I RHOB FCNL ILD CALl RHOB FCNL 1LD CALl RHOB FCNL ILD GR CALl FCNL ILD GR CALl RHOB FCNL ILD GR CALl FCNL I LD CALl FCNL I LB GR CALl FCN b 57.5000 12.6093 2.4238 399.0000 10.7656 57.2500 12.1796 2.3730 541.5000 9.6562 69.750O 12.3750 2.3906 340.5000 8.9218 55.2812 1.~.4453 2.3984 421.7500 14.2578 52.3750 1~.0859 2.3632 440.2500 7.6250 55.0625 12.5312 2.3789 416,0000 17.0781 50.0312 11.9375 2.3691 421.7500 9.7187 61.7187 12.4453 2.3964 416.2500 10.2734 53.4687 12.1484 2.3398 455.7500 13.1562 44.3437 11.9375 2.2890 543.0000 lO.n6o9 58.3125 12.1953 ~.2421 364.2500 42. ;3437 43.2812 1 o ~oR~ DEPT DT NRAT DEPT ILM DT DRHO NRAT DEPT DT DRHO DEPT ILM DT DRHO NRAT DEPT ILM DT DRMO NRAT OEPT DT ORHO NRAT OEPT OT DEPT DT DRHO NRAT DEPT DT DRHO NRAT DEPT DT N~AT DEPT IL~ DT DP, gO 3.2480 4900,0000 33.5000 i01.3750 0.0263 3.0019 4800.0000 1.1,9375 90,1875 0.0380 3,6171 4700.0000 1,7,9843 107.1875 0.0224 3,4023 4600.0000 10,2890 122,3750 0.0336 3,1035 4500.0000 21.5781 138.1250 0,0200 2,8378 4400.0000 8,6250 111,1875 0.0253 4,1093 4300.0000 7.4414 114.5625 0.0200 3.9238 4200.0000 10.9921 114.5625 0.0078 3.3925 4100,0000 9.7578 127.3750 0.0283 3.4414 40OO.0000 10.6171 130.0000 0,0136 3.2851 3900.0000 3.9843 114.0000 0,1201 N C N L SP LLSU GR N P H I N C N L SP L L 8 U GR NPHI N C N L SP I, L 8 I1 GR NPHI NC NL SP I, I., 8 U GR NPHI N C N I, SP L I., 8 [J GR N P H I NCNL SP GR NC~,~ L SP LLSU GR NPHI NCNL SP LI,SU NPHI SP SP I, L 8 U [',PUl SP L L 8 U NPB! )oooo 88.3125 36.2812 46.8125 30 71~ . z8 1,753,0000 84.1250 14.2421 53.5000 41.3574 1627.0000 81.2500 17.9843 48,7187 37.6953 1646.0000 92.1250 13.531~ 37.2500 32.0800 1752.0000 92.0000 20.5000 47.8750 28.3203 1.768.0000 71.6250 7.4960 50.53!2 50.6347 1497.0000 84.5625 7.2343 44.~875 47.2656 1469.0000 77,6250 11.9218 60.6562 37,5976 1619.0000 87.1.250 8.3828 41.1569 38.4765 1820.0000 80.5625 10.3828 45.7812 35.742~ 1730.0000 60.5937 4.3984 56.1562 47.021~ FCNL ILD GR CALl PMOB FCNL ILD CALl FCNL I L D G~ CALl FCNL I LD G~ CALl RHOB FCNL ILD GR CALl RHOB FCNL I LD CALl FCN L ILD GP CALl PHOB FCNL ILD GR CALl FCNI, ILD GP CALl ILD GI~ CaLl FCNL I LD CALl PHOB 53O 49 545 12 51 12 2 416 20 45 12 2 456 10 4:3 12 5'~3 23 44 11. 2 576 9 61 11 2 343 7 43 11 2 343 1! 56 12 2 421 10 43 12 2 487 0 44 11 2 511 4 57 !3 2 ~7~ .z_88 .5000 .4375 .8750 .9609 .3320 .0000 .4687 .2187 .7812 ,4140 .0000 .2343 .4062 .3750 .3085 .0000 .6093 .5000 .4609 .2617 ,5000 .7187 .0000 .9062 ,0761 .0000 .4296 .3437 .9765 .2382 .0000 .2304 .4062 ,9843 .0585 .2500 .2968 .7500 .!~53 .2265 .0000 .6015 ,5312 ,1953 .1113 .0000 ,9687 ,9375 .9765 .0664 .2500 .0820 .0312 .3671 .0742 nO00 DEPT I bivi DT DRHO NRAT DEPT I bM DT DEPT DT NRAT DEPT DT DRHO NRaT DEPT IbM DT DRHO DEPT DT NRAT DEPT IbM DT DRHO NRAT DEPT 1LM OT ORHO NRAT DEPT IbM DT DRHO NRAT DEPT IL~ DT DRHO NRAT OEPT ILW NRAT 3800.0000 21.3437 153.1250 0.0224 2.9746 3700.0000 31.3437 163.7500 0.0053 2.9492 3600.0000 10.8906 1.51.3750 0.0195 3.6972 3500.0000 11.0781 102.1875 0.0302 3.7500 3400.0000 8.7031 126.1875 0.0200 3.9101 3300.0000 8.5390 130.5000 0.0244 3.7382 3200.0000 3.9296 138.1250 0.0400 4.1992 3100.0000 16.9062 132.7500 0.0131 3.8261 3000.0000 9,5390 117.0000 0.0166 3.95~9 2900.0000 16.5000 132.5000 0.0004 3.4316 2800.0000 6.3710 1,33.0000 0.0478 4.3671 SP L 1.., 8 ti G~ N P Ft I NC NL SP L I., 8 U G~ NPHI N C N L SP L L 8 U NPHI NCNL SP LLBU NPHI NCNL SP L I,, 8 U GP, NPHI NC NL SP LLSI.) GR NPHI NCNb SP LLSU G~ NPHI NCNL SP LL 8U NPHI NCNb SP l,I_, 8 U G~ NPH] N C ~ L SP i.,I; 8 U GF NPHI NCNI, SP G~ NPHI 78.0625 28.2812 42.5625 30.1757 1706.0000 92.5625 32.8125 46.0312 29.7851 1755.0000 79.5625 9.88P8 50.7187 43.1640 1632.0000 80.6250 12.3125 41.2~87 43.8964 1627.0000 81.6250 6.7578 47.8125 47.0214 1640.0000 67.5625 ~0.85~5 41.0625 43.7988 1609.0000 62.3437 3.5761 51.1.250 51.5625 1442.0000 86.5625 16.2031 40.0000 45.4101 1703.0000 67.3750 7.6640 43.8437 47.4609 1621.0000 80.0625 14.7031 40.6250 38.2324 1634.0000 59.3750 5.9~82 53.0000 Sa.a433 C }o (') 0 0 . °7 q R 7 ~ 0 l LD G~ CALl FCNL ILO GR CALl FCNL I. 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