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Ima ~roject Well History File Cover XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. /~_- _~ ~_' Well History File Identifier Organizing RESC~N~ Ja/' Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type BY: BEVERLY ROBI~'~~MARIA WINDY Project Proofing BY: BEVERLY ROBIN VINCENT Scanning Preparation OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other DATE:~ /S/ BY: BEVERLY ROBIN~I~ SHERYL MARIA WINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: " .COU.TMATC"ES"UMBER'" SCA..,.G PREPARAT,O.: y. YES Stage 2 IF NO IN STAGE t, PAGE(S) DISCREPANCIES WERE FOUND: YES E~Y: BEVERLY ROBIN VINCE~ARIA WINDY · (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES ) NO NO DATE: -~'/0 /SI RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: IS/ Quality Checked (do.c) 12110/02Rev3NOTScanned:wpd Marathon OilCompany Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 9071564-6305 Fax 9071564-6489 May 28, 2002 Steve McMains AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr. McMains: Attached in triplicate is the completed Form 10-407 Well Completion of Recompletion Report and Log for the abandonment of the producing intervals in well KU 24-5. The lower portion of this wellbore was permanently abandoned prior to initiating work to drill and complete a sidetrack wellbore identified as KU 24-5RD. Also attached for your records is the final well schematic which includes detail for both wellbores. If you would like any other information,Please contact me at 564-6305 or kdwalsh~marathonoil.com. Sincerely, Ken D. Walsh Advanced Production Engineer Enclosures RECEIVED HAY 2 9 2OO2 Alaska Oil & Gas Cons. ~;~'~,t,,,s~,~, Anch0ra.n¢, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL[~ GAsE~ SUSPENDEDF~ ABANDONED [~'-~ SERVICEr--] 2. Name of Operator 7. Permit Number MARATHON OIL COMPANY 82-98 3. Address 8. APl Number P. O. Box 196168, Anchorage, AK 99519-6168 50-133-20358 Classification of Service Well 4. Location of Well at Surface 332' FNL, 4331' FWL, Sec. 7, T4N, R1 lW, S.M. At top of Producing Interval 768' FSL, 496' FWL, Sec. 5, T4N, R1 lW, S.M. 9. Unit or Lease Name Kenai Unit ~ ¥~~~ 10. Well Number KU 24-5 At Total Depth 11. Field and Pool 1337' FSL, 1486' FWL, Sec. 5, T4N, R1 lW, S.M. . 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kenai Gas Field, Sterling Pool 4 21.5' DF-GL I A-028142 12. Date Spudded 13. Date T.D. Reached 114. Date Comp., Susp. or Aband. 1 15. Water Depth, if offshore 1 16. No. of Completions 7/16/1982 7/28/1982 I 11/27/2001 I N/A feet MSL I one 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 5900' MD, 4965' TVD 3494' MD, 3048' TVD Yes X~J No [J I N/A feet MD Ii N/A 22. Type Electric or Other Logs Run VDL-GR; BHC Sonic; LDT/CNL/GR; DLL/MSFL; DIL/SFL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94 H-40 0 136 N/A Driven 13-3/8" 61 K-55 0 2012 17-1/2 1500 sx N/A 9-5/8" 47 N-80 0 5900 12-1/4 1800 sx N/A 25. TUBING RECORD 24. Perforations open to Production (MD+TVD of Top and Bottom and 27. interval, size and number) Sterlinq Pool 4 'B' Sand (Cement Squeezed): B-l: 4498'- 4553' MD B-3: 4691' - 4731' MD B-4: 4789' - 4864' MD B-4: 4899'- 4909' MD 3853' - 3897' TVD 3988' - 4028' TVD 4066' - 4141' TVD 4155' - 4165' TVD SIZE DEPTH SET (MD) 3 1/2",9.2#,N-80 9-5/8"., 47# 4453 MD (Removed) 3494' MD 9-5/8", 47# 4375' MD 9-5/8", 47# 4886' MD IPACKER SET (MD) Baker Model D @ 4607' MD Cast Iron Bridge Plug Cement Retainer Cement Retainer 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) IAMOUNT & KIND OF MATERIAL USED 4899'-4909' ]300 sks. Class G cement w/additives 4644'-4816' 160 sks. Class G cement w/additives 4375'-4553' 161 sks. Class G cement w/additives PRODUCTION TEST Date First Production 8-Aug-82 Date of Test I Method of Operation (Flowing, gas lift, etc.) flowing Hours Tested I PRODUCTION FOR 24 ITEST PERIOD I CALCULATED 124-HOUR RATE OIL-BBL 0 GAS-MCF Flow Tubing Pres. Casing Pressure OIL-BBL GAS-MCF 0 0 28. WATER'BBL ICHOKE SIZE I GAS'OIL RATIO WATER-BBL lOlL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. B-1 lithology is interbedded, light brown to gray, fine to medium grained graywacke sandstone, with m_.i=nor si!,t,,stone. (Mu~Lqg description) Density log porosity ranges from 30-37°/o in the Sterling B-1 sandstone. R. ~! C ~ !'~/ ~ ['~ The Sterling B-1 sandstone is depleting gas (C1 methane) reservoir. Form 10-407 Rev. 7-1-80 N:\drlg\kg f',wells\K BU SS-6~OG C024-5ab dn407.xls Submit in Triplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered NAME MEAS. DEPTH 'TRUE VERT. DEPTH and gravity, GOR, and time of each phase. __ Sterling 4225 3629 31. LIST OF ATTACHMENTS Daily operations summary, wellbore schematic, directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed I~,.. ~ ~ Ken Welsh Title Advanced Production Eng. Date 5/28/2002 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other- explain. Item 28: If no cores taken, indicate "none". Form 10-407 N:\drlg~sterling~u32-9~OG CC24-5abdn407.xls 20" 94# H-40 Drive Pipe @ 136' 13-3/8" 61# K~55 BTC @ 2012' Cmt'd w/1500 sks of Class G Pad 41-7 KU 24-5 Original Wellbore KU 24-5RD Sidetrack Wellbore Liner Hanger at 3250' ITop of 9-5/8~' bridge plug at 3494' MD 9-5/8" cement retainer set at 4375' MD. Squeezed 13 bbls 15,6 ppg cement below Peals 4498-4553' DIL (08-04-1982) l B-1 perfs sealed offwith LCM IXA Sliding Sleeve @ 4587' ID 275" Baker Model 'D' pkr @ 4607' Ddlled har~'~"~cement out o~ubingTrom 4365 4608 w/CT prior to fishing job, left hard Cement @ 4608' IKOP 3500' MD I 275" 'x' Nipple @ 4633' w/Mule shoe tbg tail @ 4644' Sqz Cement of B-3 & B~4 Pen's Fill @ 4781' (Sli~klin~) 08:~7:~995 Sterling B-I Sand Perforations: 4380'-4430' MD 4-5/8" Millenium StimGun SJSPF 17" 26 ppf L-80 casing at 4608'MD I Pen's 4691-4731' DIL (08-04-1982) B-4 Pen's 4789-4864' DIL (08-04-1982) B-4 Pen's 4899-4909' DIL (Sqz'd) 9-5/8" 47# N~80 BTC @ 5900' Cmt'd w/1800 sks of Class G TD @ ~900' MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KU 24-5 RD 17-Nov-01 Demob. Rig down. 18- Nov-O 1 R/D rig at GO #2 location and begin move to KU 24-5 Icoation. 19- Nov-01 R/U on KU 24-5rd. 20-Nov-01 R/U on KU 24-5rd. 21-Nov-01 R/U on KU 24-5rd. 22-Nov-01 Complete R/U rig. Fill well with water. Set BPV. N/D Xmas tree. N/U BOPE. Tested BOPE. 23-Nov-01 Test BOPE. Pull and L/D hanger. Pull 3.5" TBG. M/U bit and scraper 24-Nov-01 Run bit and scraper. Circ hole. POOH. RIH with 9 5/8" EZSV Set at 4375'. Perform squeeze job. 25-Nov-01 Complete circulation after squeeze. POOH and L/D stinger. Test CSG to 1500 psi. RIH with 8.5" bit and 9 5/8" scraper. POOH. RIH with gauge ring junk basket. RIH with Bridge plug. 26-Nov-01 RIH with overshot fishing assembly. Fish out setting tool. RIH. Drill out bridge plug chase to 4300'. POOH and test casing. Run bit and scraper to 3900'. CBU. MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KU 24-5 RD 27-Nov-01 Run gauge ring and set bridge plug. M/U whipstock/Mill assembly and RIH. Orient whipstock and set at 3494'. Displace hole to milling fluid. 28-Nov-01 Milling window. POOH for mill change. Milling at 3484'. 29-Nov-01 Mill window. Open to 8 1/2" to 3514'. Displace to FIo-Pro. Test shoe to 16.3 ppg. POOH. Test BOPE. 30-Nov-01 Test BOPE. RIH with MWD and motor. Drilli from 3514' to 3830'. 1-Dec-01 Drill to 3853' with PDC. Tripped for bit. Drilled to 4675'. 2-Dec-01 Drill to 4816'. Short trip. Circ sweep. POOH. Started running liner. 3-Dec-01 Ran 7" liner. Circ and add LCM. Cemented liner. Set packer. Circ out cement from liner top. Tested csg to 1500 psi. POOH. MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKPJKenai Peninsula/KU 24-5 RD 4-Dec-01 Clean out to landing collar. Changeover to 6% KCL. Logging. 5-Dec-01 Finish logging. Reverse KCL from 4450' with nitrogen. Pick up perforating guns and RIH. 6-Dec-01 Run perforating guns. Correlate and hang on depth. Lay down D.P. Nipple down stack, 7-Dec-01 Nipple down stack. Nipple up tree and test. Release rig at 1800 hrs. Demob rig. 8-Dec-01 Move rig to Susan Dionne #1 9-Dec-01 Move rig to Susan Dionne #1 MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 12/22/2001 FIELD: Kenai Gas Field WELL #: KU 24-5rd FILL DEPTH/DATE: 4717' Top LC LINER: 7", 26 # L-80 CASING: 9-5/8, 47#, N-80" WORK DONE: EOB Perforated Sterling B-1 TREE CONDITION: New PRESENT OPERATION: Complete CREW: BJ Services OTHER: Perforations: 4380' - 4430' MD Hrs. SUMMARY OF OPERATIONS 7:45 BJ Services nitrogen pumper on location. MIRU Nitrogen pumper. Lay out and make up surface lines from wellhead to nitrogen pumper and to choke and diffuser tank. Halliburton TCP rep on location at 9 AM. Held PJSM to discuss operations and 9:00 hazards. Connected SPIDR gauge and TCP listening device to wellhead. Shut down to replace failed relief valve 10:30 on BJ Services nitrogen pumper. Pressure tested surface lines to 2800 psi with nitrogen. Pumped nitrogen at 2800 scfm until wellhead surface pressure reached 2150 psi at which time the listening device indicated firing of the perforating guns. Stopped pumping nitrogen and observed wellhead pressure drop from 2150 psi to 1550 psi in 10 13:00 minutes and then from 1550 psi to 500 psi in another 10 minutes. ... Began flowing back nitrogen to diffuser flowback tank. Total of 176,400 scf of nitrogen pumped into 14:30 wellbore. Vendor Equipment Daily Cost Cumulative Cost Marathon Supervision $1,200.00 $1,200.00 BJ Services N2, pump, crew $10,700.00 $11,900.00 Halliburton Listening Device N/C $0.00 $0.00 Costs Forward ...... $0.00 DAILY COST: $11,900.00 CUM: $0.00 REPORTED BY: Walsh Marathon OilCompany Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907~564-6305 Fax 907/564-6489 April 2, 2002 Tom Maunder AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Attached in triplicate are the Sundry Notice of Abandonment for Well Number KU 24-5 and the Well Completion Loq for Well Number KU 24-5RD. You will note that KU 24- 5RD is a sidetrack wellbore from the KU 24-5. Also attached for your records is the final well schematic in triplicate. If you would like any other information, please contact me at 564-6305 or kdwalsh~.marathonoil.com. Sincerely, Ken D. W alsh Advanced Production Engineer Enclosures RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCCaband24-5rd.×LS 1. Type of Request: Abandon X Suspend Operation Shutdown Re-enter Suspended Weld Alter Casing m Repair Well__ Plugging Time Extensior Stimulat6~ Change Approved Program Pull Tubing Variance Perforate Other 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 332' FNL, 4331' FWL, Sec. 7, T4N, R1 lW, S.M. At top of Productive Interval 5. Type of Well: Development X Exploratory Stratigraphic Service At Effective Depth I Abandoned lower zones prior to sidetrack At Total Depth 1336' FSL, 1763' FWL, Sec. 5, T4N, R11W, S.M. 12. Present Well Condition Summary Total Depth: 6. Datum Elevation (DF or KB) KB 7. Unit or Property Name Kenai Unit 8. Well Number KU 24-5 9. Permit Nu~ll~ber 82-98/ lO. APl ~,¢nber 250-133-20358 E'eld/Pool Kenai Gas Field, Pool 4 measured 5900 feet Plugs (measured) Cast Iro~Plug @ 3494' MD true vertical 4988 feet Ce @ 4375' MD Cel Retainer @ 4886' MD 94 feet Effective Depth: measured true vertical 4512 feet Junk (measured) 3865 feet Joints and Parts of Mill Shoe @ 4512' MD Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented Measured Depth True Vertical Depth 136' 20" Drivel 136' 2012' 13-3/8" 150(: 2012' 136' 1861' 5900' 9-5/8" sks 5900' 4836' B-l: 4498' - 4553' MD I) true vertical B-3: 4691' - 4731' ~t squeezed) true vertical B-4: 4789' - 4864' MI ~ent squeezed) true vertical B-4: 4899' - 490~c ;ement squeezed) true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachments Description 14. Estimated Date for Commencing Completed 11/26/01 3 ' 9.2#, N-80 tubing to 4453 MD (Removed) model D packer @ 4607' MD 16. If Proposal was Verbally Name of Approver B-1'3853'-3897'TVD B-3:3988'-4028'TVD B-4:4066'-4141'TVD RECEIVED APR 3 2002 of Proposal.~ Detailed Operations Program BOP Sketch 15. Status of Well Classification as: Date Approved Oil Gas X Suspended Service 17. I hereby certify that the foregoing_is true and correct to the best of my knowledge. Signed 1 ~'~ ~~en Walsh Title Advanced Production Engineer Date 4/2/2002 FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness Plug Integrity BOP Test Location Clearance Mechanical Integrity Test Subsequent Form Required 10- Yl_Cr 501- Approved by Order of the Commission Form 10-403 Rev. 06/I 5/88 IApprovalNo. -- ,2%0 //¢/ _ Commissioner Date Subm it in Triplicate ALASKA OIL AN~D GAS CO~SERYATION COMMI$SIO~ TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Watkins State of Alaska Department of Environmental Conservation 555 Cordova St. Anchorage, AK. 99501 October 15,2001 Dear Robert: Marathon continues to perform the periodic inspections of the Spark and Spur Platforms as conditioned in the initial exemption from the oil spill contingency plan for these facilities. Jeff Jones, one of our inspectors accompanied the last inspection and found no problems. Tom Maunder and I both recommend these facilities remain exemptible from an oil spill contingency plan. The KBU 44-6 and KU 24-5 wells are Kenai Gas Field wells. There is no oil in the Kenai structure and never has been. We consider the Kenai Field as a gas only field; all wells within it are gas wells. If you have any questions or concerns, please contact Tom Maunder or myself at 279-1433. Senior Petroleum Geologist DEPARTMENT OF FISH AND GAME Habitat and Restoration Division TONY KNOWLES, GOVERNOR 333 Raspberry Road Anchorage, AK 99518-1599 PHONE: (907) 267-2338 FAX: (907) 267-2464 TO: FROM: DATE: SUBJECT: MEMORANDUM Tom Atkinson Project Review Coordinator Division of Governmental Coordination Office of Management and Budget Mark Fink f~ Habitat Biologist Region II Habitat and Restoration Division August 28, 2001 MarathOn Oil KU 24'5, Kenai Gas Field State ID No. AK 0108-0lOG RECEIVED SEP 0 5 2001 Alaska Oii & Gas Cons. Commission Anchorage The Alaska Department offish and Game (ADF&G) has reviewed the subject proposal to work over~an existing gas production well, located on Pad 41-7, in the Kenai Gas Field. The pad is located in Section 31, T4N, R11 W, Seward Meridian. ~ the event sidetracking becomes necessary., the existing completion intervals .will be isolated and abandoned with cement and plugs, as directed by the Alaska Oil & Gas Commission and the Bureau of Land Management, prior to performing the sidetracking. The redrill will be renamed well KU 24-5RD. A 20-mil synthetic impermeable liner will be placed over the operational footprint for the drilling rig, diesel storage tank, and mud system; the liner would be bermed to create a six inch freeboard. Diesel will be stored in a double-walled tank. Drill cuttings will be dewatered on location, and the cuttings and excess mud will be hauled to Pad 41-18 for injection into an approved Class II disposal well. Oil spill response equipment would be maintained on-site to handle accidental leaks or releases of oil, gas, or other toxic materials. Marathon plans to use an existing temporary water use permit (TWUP A99-20). The department has no objection to the project proposal and recommends the 'Project be. found consistent with the Alaska Coastal Management Program. A FiSh Habitat Permit from ADF&G is not required for the project as proposed. We appreciate the opportunity to review and comment on this proposal. 24-5SAN Wellhead Report and Flow Rat~s, UTT Data tar Flowlines Subject: 24-5SAN Wellhead Report and Flow Rates, UTT Data for Flowlines Date: Tue, 7 Aug 2001 08:05:38 -0800 From: "Eynon, Donald E." <DEynon~MarathonOil.com> To: "Jane Williamson (E-mail)" <jane_williamson~admin.state.ak.us> Jane, Attached is the wellhead inspection report for the 24-5 tubing head which was removed from the well and replaced with a riser spool during the 5/10/01 workover. Production data for the 24-5S annular flow path for dates prior to 1/1/01 is in an old database which is no longer used. The rate history for the well from the time it was made an annular to 1/1/01 is in the excel spreadsheet named CPFR_2405SAN.xls. Production for the period from 1/1/01 to the 5/10/01 workover totaled 2.5 hours. The well has been produced through the annulus for a total time of 579.5 our~) since becoming an annular producer. We produce out the annulus only at peak demand! ~ime~- which is why the well has produced only 2.3% of the time it has been capable of annular production. Rates through the tubing head annular outlets (average rate of 5,135 MCFD) were below erosive velocities at the 1.469" ID VR threads. I have faxed the UTT inspection report of the flowlines to you as I do not have access to an electronic copy. This information is a baseline survey which is analyzed, put in a database and then periodic inspections of critical areas of concern are inspected as they become due. I apologize for the delay in delivering this material. If any additional information is needed please let me know and I will get it to you as soon as possible. Thanks. Don' Eynon Production Engineer Intern 907-564-6302 work 907-268-7868 pager 907-529-0523 cell <<CPFR_2405SAN.xls>> <<ABB Vetco 24-5 Wellhead Inspection Report.doc>> ~CPFR 2405SAN.xls Name: CPFR 2405SAN.xls -- Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 Description: CPFR_2405SAN.xls ~ABB Vetco 24-5 Wellhead Inspection Report.doc Name: Type: Encoding: Description: ABB Vetco 24-5 Wellhead Inspection Report.doc WINWORD File (application/msword) base64 ABB Vetco 24-5 Wellhead Inspection Report.doc 1 ofl 8/12/01 5:17 PM Au~-08-01 03:4gpm · From-MARATHON OI L ,, +g15564545g T-Sg4 P.01 ,,' Alaska 4 n Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561.5311 FAX COVER LETTER PLEASE DELIVER THE FOLLOWING TO: Name: ,J/~ ~d e ~J: ((~ ~-fo ~u Fax No.; ~ 7g - 7~ Y~ Number of Pages (i~l~i~ c~~): - - RECE!VED ., AUG U 6 2001 _ , Na~ka 0il & (~as Cons. (;ommmmm Anchorage FROM: NOTE: ff transmission is not complete, please call 907/561-5311. A subsidiary of USX Corporation Environmentally aware for the long run. Auj-O$-D1 03:49pm From-BARATHON OIL +g1~s84548g T-894 P.O,/lO F-$85 ~n ASCG company ASCG Inspection, Inc. July 9, 1999 RECEIVED Marathon Oil Company Alaska l~gion Domestic Production Attention: Mark Susich Subject: KGF Annular Flow Line Baseline Inspection. AUG 0 6 2001 Naska 0il & ~as Co~s. Gom~s~o~= Anchorage During the months of March, April, aad May Ultrasonic and Radiographic Inspection was performed on annular flow well lines 21-6-LAN, DU-SL-AN, 14-32LAN, 24~5SA, 1 I-8S, and 43-6ALAN. Both the Production and Test I-leader for Pads 34-31 and 41-7 were also inspected. The detailed baseline inspection had a total of two hundred and ninety-one items inspected. These items included forty-one elbows, seventy-one tee's, twenty-six reducers, one- hundred twenty pipe segments, sixteen'end caps, and fourteen impingement areas. APl 570 guidelines were used to establish inspection criteria. Included in this report is all pertinent data for each piping system inspected. Each system has it's own section. Sections E lhrottgh N each include a cover page, summary, spreadshe~, photographs, and a drawing of the linc inspected. The individual summary's were taken from this overall inspection summary, The spreadsheet has all UT and RT information, The UT information has been color coded by wall loss from the known nominal thickness values, The RT information list's thickness information calculated by the use cfa Gamma Gauge or "Rinkt Tee" Gauge. The gauge compensates tbr the geometrical unsharpness and blow of the image on the Illin. From the gauge a correction factor is ot~aiaed which is multiplied into the actual measurement obtained offthe film, The actual measurement multiplied by the correction fact'or genera~es an "Adjusted" or true measurement of the wall thickness profile. The drawings show pertinent damage info.'madon and inspection point locations. The inspection points on the drawings are color coded to match the wall loss percentage on the spreadsheets. Section B lists an dverview of the number and' type 0fitems inspected for each individual line, Section C includes pictures and a sloe, ch showing examples of the grid layout used. Section U has a listing of the UT rawdata DMtII files for each line. Section V is a cost tracking spreadsheet giving a cost breakdown for personnel and equipment used for the entire job. Section W is a photograph index for all pictures taken during the inspection. The digkal photo's are stored on the Zip Disk in Section XYZ. Section XYZ has a digital copy of/his report stored on a 100MB Zip Disk. Well Line 14-32LAN Well Line I4.32LAN was ultrasonically inspected in thirty-seven areas and radiographed in six areas. These items consisted of four elbows, nine tees, eighteen pipe segments, three reducers, two end caps, and one impingement point. Pipe diameters and schedules consisted of 2" x .218", 3" x .300", 3" x .438", 4" x .337", 4" x ,435", $" x .500", and $" x .322" wall pipe. The 2" items had thickness readings ranging between 0,250" to 0.290", The 3" x .300" wall items had thiclmess readings ranging between 0,271" and 0.407". The 3" x .438" wall items had thickness readings ranging between 0.423" to 0,454". The 4" items had thickness readings 1 301 Arctic Slope Ave,, Suite 100 Anchorage, Alaska 99518 phon~ (907) 349.5148 fax (907) 267.6480 Aul-O6-01 an ^SCG comp,ny 03:49pm From-MARATHON OIL ASCG Inspection, Inc. +g15s64648g AUG 0 6 2001 Alaska 0ii & ~.s 00r~$. Co~'J~,~: Anchorage ranging between 0.317" to 0.373'. The $" x .322" item had thickness readings ranging between 0.314" to 0.374"'. The g" x .500" items had thickness readings ranging between 0.$00" to 0.524". UT results indicated no areas where erosion or damage could be verified fi:om normal pipe geometry. The greatest percent wall loss from nominal was 10%, located on item #25, a 3" x .300" wait pipe segment. That low and others noted in the spreadsheet may indicate minor general erosion or normal thickness variations due to manufacturing tolerances. Radiographic Inspection indicated item #26, a 3" tee, had a minor pitting network located at The end cap end of the tee. The damage is vel3, minor and is well above the nominal thickness oft_he 3" pipe schedule. Item #33, an 8" schedule 40 elbow was located in-between the $" schedule $0 items. lmms 4/22 and #24 were found to be 3" schedule 160, 0.435" wall pipe. Those items are Iocated at the inlet and outlet of the Willis Choke. No significant areas of damage were detected during the inspection of the line. Well Line 21-6-LAN Well Line 21-&LAN was ulxrasonically inspected in thirty-two areas and radiographed in tbar areas. These items consisted of six elbows, eight tees, thirteen pipe segments, three reducers, one end cap, and one impingcnnent poim. Pipe diameters and schedules consisted ofT' x .218", 3" x .300", 4" x .337", g" x .500", and 8" x .322",wall pipe. The 2" items had fl~ickuess readings ranging between 0.234" to 0.285". The 3" x .300" wall items had thickness readings ranging between 0,294" to 0.413". The 4'~ items had thickness readings ranging between 0.288" to 0.393", The 8" x .322" item had thlclmesa readings ranging between 0,267" to 0.365". The 8" × ,500' items had thickness readings ranging betwee~ 0.450" to 0.487". UT results indicated one area, item #33, an 8" schedule 40 elbow had an erosion pattern located on the outside radius of the elbow. Item #33 was located in-between the 8" schedule 80 items. The greatest wall loss fi.om nominal was 17% or 0,267", located on item #33. Item #19, a 4" elbow indicated a 15% wall loss from nominal on the outer radius. There was no definite damage pal~em to est~/bli~ if the elbow was experiencing minor erosion. All other lows noted in the spreadsheet were 10% or less and may indicate minor general erosion or normal thickness variations dne to manufacturing tolerances. Radiographic Inspection indicated no re'ess of concern. No other signiflcam areas of damage were detected during the inspection of the line. Well Line DU-SL-AN Well Line DU-5L-AN was ultrasonically inspected in forty-one areas and radiographed in six areas. These items consisted of five elbows, ten tee,,, nineteen pipe segments, four reducers, two md caps, and one impingement Point, Pipe diameters and schedules consisted of 2" x .218", 3" x .300', 4" x .337", 8" x ,500"~ and 8" x ,322" wall pipe. The 2" items had thielm~s readings ranging between 0, ] 97" to 0.320", The 3" x' ,300" wall items had thidmess readings ranging between 0.238" ~o 0,451". The 4" items had thickness r,adings ranging between 0.305" to 0.416". The 8" x ,322" item had thickness readings ranging between 0.32T' to 0.366". Tho 8" x .500" items had thickness readings ranging between 0,483" to 0.495". 301 Arctic Slope Ave., Suite lo0 Anchorage, Alaska 9951 2 phone (907) 34%5348 fax (907) 267-6480 comp,my 03:49pm From-MAI~ATHON OIL +g15554845g T-Sg4 P.04/10 ASCG Inspection, [ Vt C. UT results indicated one area, item #33, a 3" schedule B0 pipe segment had a uniform general wall loss pattern located 360 degree arotmd the pipe. The greatest wall loss fi.om nominal was 21% or 0.235', located on item #33. There was no definite pattern to establish if the pipe segment was experiencing minor erosion or was generally thinner than the other 3' items. All other lows noted in the spreadsheet were 10% or less and may indicate minor general exosion or normal thickness variations due to manufacturing tolerances. Radiographic In.~ection indicated minor scattered pitting in the body of item #34, a 3" x .300" wall tee.. The damage is very minor and is well above the nominal thickness of the 3" pipe schedule. Item #41, an schedule 40 elbow was lees, ed in-between the $" schedule 80 items. No othJ~jsiJ~a~Jl_n_ tlalje/l~sl- of damage were detected during the inspection of the line. I~CLCIV E Well Line 24-flSA AUG 0 6 2001 Well Line 24-58A was ultrasonically inspected in forty-two areas an~~e~qq~ GOIIIlTIt~'OI, areas. These items consisted of three elbows, thh'teen tees, seventeen pipe segme~,qL~rage reducers, 'two end caps, and one impingement point. Pipe diameters and ache&des consisted of 2" x .218", 3" x .300", and 4" x .337" wail pipe. The 2'items had thickness readings ranging betwee~ 0.261" to 0.29Y'. The 3" x 300" wall items had thickness readings ranging between 0.27Y' to 0.497". The 4" items had thickness readings ranging between 0.3 I3" to 0.398".. UT results indicated one area, item #36, a 3" ~chedule 80 pipe segment had a uniform general wall loss pattern located 360 degree around the pipe. The greatest wall loss Ii, om nominal was 9% or 0.27Y', located on item #36. There was no definite pattern to establish if the pipe segment was experiencing minor erosion or was generally thinner than the other 3" items. All other lows noted in the spreadsheet were 8% ca' less and may indicate minor general erosion or normal thickne,s variations due to manufacturing tolerances. Radiographic Inspection indicated no areas of concern. No significant areas of damage were detected during the inspection of the llne. Well Line 11-8S Well Line 1 l-RS was ultrasonically inspected in forty-one areas and radiographed in eight areas. These items consisted of four elbows, eleven tees, sixteen pipe segments, six reducers, two end caps, and two impingement points. Pipe diameters and schedules eonslsted of 2" x .218", 3" x .300", 4" x .337', and 8" x .500=' wall pipe. The 2" items had thickness readings ranging between 0.271" to 0.309". The 3" x .300" wall items had thielmess readings ranging between 0,273" to 0.50I". The 4" item, had thielmess readings ranging between 0.31 $" to 0.427". The 8" item had a thickness rc'ading of 0.465". LIT results indicated no areas where erosion or damage could bo verified from normal pipe geometry. The greatest percent wall loss fi`om nominal Was 9%, located on item #35, a 3" x .300" wall end cap. All other lows noted in the spreadsheet were 8% or less and may indicale minor general erosion or normal thickness variations due to manufacturing tolerances. Radiographic Inspection indicated item #38, a 3" tee and end cap, had minor pitting damage located on the outs radius of the tee. The damage ig very minor and is well above the nominal thielmess of the 3" pipe schedule. No other significant areas of damage were detected during the inspection of the line. 301 Arctic Slope Ave., Suite 100 Anchorage, Alaska 9951 3 phone (907) 349-5148 fax (907) 267-6480 ^us-06-01 an A Company 03:$Opm From-MArATHON OIL ASCG Inspection, Inc. Well Line 43-6ALAN +g15~$4548g T-8g4 P.0~/10 F-365 I CEIVED Alaska Oil & Bas Boris. L;o~lmtssso~ Anchorage Well Line 43-6ALAN was ultrasonically inspected in fortT-three areas and radiographed in six areas. These items consisted of five elbows, ten tees, twenty-two pipe segments, three reducers, one end cap, and two impingement points. Pipe diameters and schedules consisted of 2" x .215", 3" x .300", 4" x .337", and 8" x .500" wall pipe. The 2:' items had thickness readings ranging between 0.282" to 0.320", The 3" x .300" wall items had thickness readings ranging betwema 0.283" to 0.44Y'. The 4" items had thickness readings ranging between 0.314" to 0.393". The g" item had a thickness reading of 0.445". ' UT results indicated no areas where erosion or damage could be verified fi.om normal pipe geometry. The greatest percent wall loss from nominal was 11%, located on item #42, an $" x .500" wall imping0anent point. All other low~ noted in the spreadsheet were 7% or less and may indicate minor general erosion or ncs'mal thickness variations due to manufacturing tolerances..Radiographic Inspection indicated no areas of concern_ No significant areas of damage were detected during the inspection of the line, 34-31 Production E[eader Production Header 344 lwas ultrasonically inspected in twenty-six areas and radiographed in three areas. These items consisted of eight elbows, fifteen pipe segments, and three impingement points, Pipe diameters and schedules consisted of 4" x ,337", 6" x ,280', 6" x .432", and 12" x .375" wall pipe. The 4" items had thickness readings ranging between 0328" to 0,39Y', The 6" x .280" wall items had thickness readings ranging between 0.280" to 0,33Y'. The 6" x .432" items had flaickness readings ranging between 0.369" to 0.503". The 12 x .375" wall items had thickness readings ranging between 0,376" to 0.443" UT results indicated one ~rea, item ~22, a 6" schedule 80 elbow had a possible general wall loss area located on the outer radius, The greatest wall loss fi.om nominal was 15% or 0,269", located on item #22, There was no definite pattern to establish i£the elbow was experiencing minor erosion or normal thickness tolerances, All other lows noted in the spre~adsheet were 10% or less and may indicate minor general erosion or normal thickness variations due to manufacturing tolerances. Radiographle Inspection indibated no areas of concern, No significant areas of damage were detected during the inspection of the line, 34.31 Test Headelk ~ The 34-31 Test header was inspected in a fe~v key areas where damage could possible occur first. There were a trial often locations ultrasonically inspected and six areas radiographieally examined, These items consisted of six tees and four end caps. All pipe was 4" sdiedule 80, 0,337" wall piping. Thickness readings ranged between 0.325" to 0,487" UT results indicated no areas et'interest or wall thickness readings below the nominal thickness value, Radiographic Inspection also indicated no areas of concern. 301 ArCtic Slope Ave., Suite 100 ^ncnorage, Alaska 995] 13 4 phone (907) 349-51.4.8 fax (907) 267-6480 Aul-08-01 03:BOpm F rom-MARATHON O I L ,.. +g15584848g T-Sg4 P. 0~/10 ASCG Inspection, I n c. 41-7 Production l-leader Production Header 41-7 was ultrasonically inspected in twelve areas and radiographed in three areas. These items consisted of six elbows, one tee, two pipe segments, one reducer, and two impingement points. Pipe diameters and schedules consisted of 6' x .280", 6" x ,432", 10' x .365", and 12" x .375" wall pipe. The 6" x .280" item had thickness readings ranging between 0.236" to 0.268". The 6" x .432" items had thickness readings ranging between 0.419" to 0.479". The 10' items had thickness readings ranging between 0.332" to 0.704". The 12" x .375" wall items had thickness readings ranging between 0.370" to 0.450" UT results indicated two re'cas worth noting, item #9, a 6" schedule STD, 0.280" elbow had a general erosion pattern located on the outside and side radius areas. The greatest wall loss from nominal on the elbow was 16% or 0.236". Item #7, a 10" schedule STD, 0.365" elbow indicated a possible general erosion pattern on the outside radius. It had a wall loss of 0.332", or 9% wall loss from nominal. There was no definite pattern to establish if the elbow was experiencing minor erosion or normal thickness tolerances. All other readings noted in the spreadsheet were above the nominal thickness values for their pipe schedules. Racliograplhie Inspection indicated scattered pitting on the outside radius of items #7, a 10' elbow, and item #9 a 6" elbow. The damage was minor in depth but was present in large quantities in both items. The damage type was typical of sand production impacting the pipe at high velocities. No other significant areas of damage were detected during the inspection oft he line. 414 Test Header ~The 41,7 Te~ header was inspected in a few key areas where damage could possible occur first. There were a total of seven locations ultrasonically inspected and two areas radiographlcally examined. These items consist~ of five tees and two end caps. All pipe wa~ 4" schedule 80, 0.337" wall piping. Thickness readings ranged between 0.341" to 0.478" UT results indicated no areas of interest or wall thielmess readings below the nominal thickness value. Radiographic InsPection als0 indicated no areas of concern, If you have any question please contact me at our Kenai office. Sincerely, Kevin D. Amett ASCG Inspection, ~c. Kenai Project Supervisor RECEIVED AUG 0 6 2001 Alaska Oil & Gas Cons ,,~m.~.,~'"" 301 Arctic Slope Ave., Suite 100 !~Anchorage, Alaska 99518 '5 phone (907) 349.5148 fax (907) 267-6480 ^ui-OG-01 03:$1pm From-MARATHON OIL , ( +gl$$64548g T-894 P.OT/IO F-365 company ASCG Inspection, Inc. RECEIVED February 27, 2000 Marathon Oil Company Alaska Region Domestic Production AUG 0 6 2001 Attention: Mark Susich Subject: Second Phase of the KGF Annular Flow Line Baseline Inspection. Mark, Between the months of October 1999 and February 2000, Ultrasonic and Radiographic .Inspection was performed on annular flow well lines 13-6LAN, 14-X6LAN[, 14.6LAN, 21- 7LAN. The Production and Test Ileade~ for Pad 14-6 were also inspected. This inspection is the second phase of the baseline survey. The Prior inspection involved well and header piping on pads 34-31 and 41-7. The d~tailed baseline inspection had a total of one hundred and ninety items inspected. These itcnns includ~ twenty.eight elbows, forty tees, sixteen reducers, seventy-nine pipe segments, thirte~ end caps, five chokes, one SS¥ valve, and eight impingement areas. AP1570 guidelines were used to establish inspection criteria. Included in this report is all pertinent data for' each'piping sy~tera inspected. Each system has it's own section. Sections O through T each include a cover page, summary, spread,heet, photographs, and a drawing of the line inspected. The individual summaries we~'e taken from this overall inspection summary. The spreadsheet has all UT and RT information. The UT information has been color-coded by wall loss from the known nominal thickness values. The RT information list's thickness information calculated by the use ora Gamma Gauge or "Rink, Tee" Gauge. The gauge compensates tbr the geometriml un~arpness and blow of the image on the film. From/he gauge a correction factor is obtained which is multiplied into the actual measurement obtained offthe film. The actual measurement multiplied by the correction factor generates an "Adjusted" or true measurement of the wall thickness profile, The drawings show pertinent damage information and inspection point loc~tions. The inspection points on the drawings are color coded to match the wall loss percentage on the spreadsheets. Section B lists an overvlew of the number and l~ype of items inspected for each individual line. Section C includes pie,ares and a sketch showing examples of the grid layout used. Section V is a cost tracking spreadsheet giving a cost breakdown for personnel and equipment used for. both the firs~ and second phases of inspection. Section W is a photograph index for all pictures taken durlng both inspections. The digital photo's are stored on the Zip Disk in Section XYZ, Section XYZ ha, a digital copy of this report stored the 100MB Zip Disk. Well Line 13.6LAN Well Line 13-6LAN was ultrasonically inspected in forty-six areas and radiographed in one areas. These items consisted of four elbows, twelve tees, twenty-one pipe segments, four reducers, thre~ end caps, two impingement points and one choke. Pipe diameters and schedules consmted of 2 x .218 , 3 x .300 , 4 x .337 , and 8 x .500" wall pipe. The 2" items had thiekne,s readings ranlglrlg be~Wce..n 0.252" to O.306". 'the 3" x .300" wall item~ had thickne.q~ readings 301 Arctic Slope Ave,, Suite 100 Anchorage, Alaska 99518 1 phone (907) 349-5148 fax (907) 267-6480 Aog-O6-Ol ~n ASCG company 09:51pm F rom-MARATHON O I L +915'5646489 T-894 P.08/10 F-365 RECI ( ASCG Inspection, Inc. ranging between 0.264" and 0.4ti$". The 4" items had thickness readings ranging between 0.313" to 0.480". The $" x .500" item had a thickness reading of 0.460". UT resuks indicated no areas where erosion or damage could be verified flora normal pipe geometry. The greatest percent wall loss fi'om ntnninal was I 1%, located on item tt43, a 3" x .300" wall end cap. That low and others noted in the spreadsheet may indicate minor general erosion or normal thickness variations due to manufacturing tolerances. Radiographic inspection of the 3" Willis choke internals indicated no problems. No distinguishable area5 of damage w~e detected during the inspection of the line, ii Well Line 14-X6LAN Well Line 14-X6LAN was ultrasonically inspected in twenty-three areas and radiographed in one area. These items consisted of four elbows, four tees, eight pipe segments, three reducers, two end caps, two hnpingement points, and one chok~. Pipe diamet~s and schedules consisted of 2" x .218", 3" x ,300", 4" x .337", and 8" x .500" wall pipe, The 2" item had thickness readings ranging between 0.196" to 0.207". The 3" x .300" wall items had ~ickness readings ranging between 0.275" to 0.469', The 4'~ items had thickness readings ranging between 0,300" to 0,420", The g" x .500" item had a thictmess reading of 0.430'. The greatest wall loss from nominal was 14% or 0.430", located on item #21. Item 21. was an impingement point area where the well llne ties into the production header. No distinguishable wall loss paaern was detectable. Item #19.1, a 4" impingement point indicated an 1 !% wall loss'from nominal, There was no definite damage pattern to establish if the area was experierteing minor damage or normal thickness variations. All other lows not~ in the spreadsheet were 10% or less and may indicate minor general erosion or normal thickness variations due to manufacturing tolerances, Radiographic inspection of the 3" Willis choke internals indicated no problems. No distinguishable areas ofdamag~ were detected dm'lng the impemion of the line, Well Line 14-6LAN Well Line 14-6LAN was ultrasonically inspected in thirty-seven areas and radiographed in two areas, These items consisted of three elbows, eleven teeS, fifteen pipe segments, three reducers, tba'ee end caps, two impingement points, one choke, and'one SSV valve. Pipe diameters and schedules consisted of 2" x .218", 3" x .300", 4" x .337", and 8" x .500" wall pipe. The 2" items were not inspected due to the ice level in the well house cellar. The 3" x ,300" wall items had thickness readings ranging between 0.269" to 0.482". The 4" items had thickness readings ranging Between 0.300" to 0.406". The 8" 'x .$00" item had a lhickness reading of 0.465'. UT results indicated one area, item #32, a 3" schedule XS, 0.300" wall pipe segment had. a uniform general wall loss pattern located 360 degree around the pipe. The greate.qt wall loss fi.om nominal was I0% or 0.269', located on item #32, There was no definite pa~em to establish if the pipe segment was experiencing minor erosion duo to production or was generally thinner than the other 3" itcnns. Item #36, a 4" test header impingement point had a thlekness of 0,$00", ca' 11% below the 0.337" nominal. There was no definite damage pattern to establish if this area was experiencing minor damage. All oth~r lows noted in the 301 A~:tic Slope Ave., Suite 100 Anchorage, Alaska 99518 2 phone (907) 349-5148 fax (907) 267-6480 ~n A, company 03:51pm From-MARATHOH OIL .. { ASCG Inspection, Inc. +g15564548g T-Sg4 P.Og/lo F-355 .., RECEIVED AUG 0 6 2001 spreadsheet were 95/0 or less and may indicate very minor general erosion or nmmal thickness variations due to manufacturing tolerances. Radiographic inspection of the 3" Willis choke internals and the SSV Valve in the well house did not indicate any problems. No distinguishable areas of damage were detected during the inspection of the line. ']ii Well Line 21-7LAN Well Line 21-7LAN was ultrasonically inspected in thirty-two areas and radiographed in one area. These items Consisted of eight elbows, five zees', thirteen pipe segments, two reducers, two end caps, two impingement points, and one choke. Pipe diameters and schedtde, consisted ofT' x .218", 3" x .300", and 4" x .337", and 8" x .500" wall pipe, The 2" item had a rahiclmess reading ranging betw~ 0,186" to 0.31t0". The 3" x .300" wall items had thickness readings ranging between 0.271" to 0.40g". The 4" items had thielmess readings ranging between 0,320" to 0,410". The 8" x .500" wall item had a thickness reading 0.420" The greatest wall loss from nominal was 16% or 0.420", located on item #24, Imm 24 was an impingemem point area where the well line ties into the production header. A very small shallow diameter pit was located at the backside, immediately opposite of the well line tie-in area. Item #23, a 3" pipe section indicated a 10% wall loss Ii:om nominal, There was no definite damag, pattern to establish if the area was experiencing minor damage, general wall loss, or normal thiclmess variations due re manufacturing tolerances. All other lows noted in the spreadsheet were S% or less and may indicate very minor general erosion or normal thielmess variations due to manufacturing tolerances. Radiographic inspection of the 3" Willis choke and 2" valve internals indicated no problems. No other distinguishable areas of damage were de~eaed during the inspection et'the llne. 14-6 Prodttction Header Production Header 14-6 was ultrasonically inspected in forty areas. These items consisted of seven elbows, four tees, ~xvenBr-rwo pipe segments, and three end caps. Pipe d~ameters and schedules consisted of 6" x .432:', 8" x ,406", 8" x .500", 10" x .365~', and 12" x 375" wall pipe. The 6" items had thielmoss readings ranging between 0.408" to 0.75 l". The $" x .406" wall items had thickness readings ranging between'0;420" to 0.493". The $" x ,500' items had thickness readings ranging between 0.505" to 0.603". The only 10" x .365" wall item was not inspected due to the reducer being blinded and not in the main flow ofprodu~. The 12 x 375" wall items had thickness readings ranging berw~n 0.347" m 0.455" UT remits indicated no areas of damage. All lows noted in the spreadsheet were 7% or less and m ay indicate very m~or general erosion or normal thickness variations due to manufacturing tolerances. Items #34 and #35 are noted on the spreadsheet as being "deleted" from the inspection. This was dne to an error in the item coum during layout. 14.6 Test Header The 14-6 Test header was inspected ia a few key areas where damage could possible occur first. Ther. wmr~ a total of six locations ultrasonically inspected. These items consisted of fern' 301 Arctic Slope Ave., Suite 100 Anchorage, Alaska 99518 phone (907) 349.5148 ,. fax (907) 267-6480 ^ui-08-01 03:$~pm From-MARATHON 0IL T-sg4 P.I0/10 F-355 company ASCG Inspection, Inc. tees and two elbows, All pipe was 4" schedule 80, 0.337" wall piping. Thickness readings ranged between 0.323" to 0.477". UT results indicated no areas of interest or wall thickness readings below the nominal thickness value. If you have any question please contact me at om- Kenai office. Sincerely, RECEIV[D Kevin D. Ame:t ^SC~,..~on, X.,~. AUG 0 6 2001 Kenai Project Supervisor 301 Arctic Slope Ave,, Suite 100 4 Anchorage, Alaska 99518 phone (907) 349.5148 fax (907) 267-6480 , ABB Vetco Gray, Inc. Wellhead Equipment Inspection Report No. 85-22896 Date: 7-02-01 Customer: Marathon Oil Company Well: KU 24-5 Requested by: Mr. Don Eynon Scope: Inspect wellhead equipment removed from well for erosion damage. Method: Visual and dimensional inspection, and partial hydrotest. Equipment Inspected: 1 ea. Tubing spool, 13-5/8" 3M x 11" 5M DCB w/2-1/16" 5M Studded outlets 2 ea Gate valve, 2-1/16" 5M, FE, HWO, Gray Model "D" Equipment Specifications: PSL 1, PR 1, "U". ( Standard service APl 6A spec trim) Tubing Spool Inspection; Disassemble tubing spool, remove lockscrews, studs and secondary seal and clean. Visual inspection of bore side outlets and seal areas revealed no damage or erosion patterns. Dimensional inspection showed internal bore dimensions of spool and side outlets to be within tolerances that are acceptable for new manufactured equipment. The intersection of the side outlet bore to the main bore was found to be sharp, and without any rounding or tear drop patterns associated with erosion. Tubing spool was reassembled and hydrotested to full WP with no leaks. ( 3M shell test ). Tubing spool was then utilised on Falls Creek # 1. Gate Valve Inspection; Opened gate valves and visually inspected bores, seal faces and ring grooves for damage or erosion patterns, and found no damage. Dimensional inspection showed all bore and seal area dimensions to be within tolerances that are acceptable for new manufactured equipment. Gate valves are currently in Marathon inventory located at ABB Vetco Gray awaiting disposition. Marathon Oil Company Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 9071561-5311 Fax 9071564-6489 July 17, 2001 Mr. Tom Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Reference: Field: Kenai Gas Field Well' KU 24-5 Permit No.' 82-98 Regarding: Abandonment Dear Mr. Maunder: Enclosed is the 10-403 APPLICATION FOR SUNDRY APPROVALS form for Marathon well KU 24-5. The proposed work is to abandon the open perforations in KU 24-5 prior to sidetrack as previously discussed. If you require further information, I can be reached at 907-564-6310 or by e-mail at wjtank@marathonoil.com. Sincerely, Willard J. Tank Senior Drilling Engineer JUL 1 $ 2001 Alaska Oil & Gas Cons. Commission AnChorage ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCCaband24x-5.~ 1. Type of Request: Abandon X Suspend Operation Shutdown Alter Casing ~ Repair Well~ Plugging~ Change Approved Program Pull Tubing~ Variance Re-enter Suspended Well Time Extensior Stimulat6 Perforate Other 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface ~/. v/' v'" 332' FNL, 4331' FWL, Sec. 7, T4N, R1 lW, S.M. At top of Productive Interval 5. Type of Well: Development._~.X Exploratory Stratigraphic__ Service At Effective Depth I Abandon lower zones prior to sidetrack At Total Depth 1336' FSL, 1763' FWL, Sec. 5, T4N, RllW, S.M. 6. Datum Elevation (DF or KB) KB 94 feet 7. Unit or Property Name Kenai Unit 8. Well Number KU 24-5s 9. Permit ~jnber 82-98 lO. APl Number 50-- 133-20358 11. Field/Pool Kenai Gas Field, Pool 4 12. Present Well Condition Summary Total Depth: measured true vertical 5900 feet 4988 feet Plugs (measured) Cement Retainer @ 4886' MD Effective Depth: measured 4512 feet Junk (measured) true vertical 3865 feet Blast Joints and Parts of Mill Shoe @ 4512' MD Casing Length Size Cemented Measured Depth True Vertical Depth Structural Conductor 136' 20" Driven 136' 136' S u dace 2012' 13-3/8" 1500 s ks 2012' 1861' Intermediate Production 5900' 9-5/8" 1800 sks 5900' 4836' Perforation Depth: measured B-l: 4498' - 4553' MD true vertical B-1:3853' 3897'TVD JUL 19 2001J../. 2001 Tubing (size, grade, and measured depth) 3 1/2", 9.2#, N-80 tubing to 4453. M~Dlaska_ 0il & Gas Con~l...~.,~~-u..-; -_--Z_- _%~¢~dc'a~&-~a'q_C~t~t'~' C01flITIJssJSF Packers and SSSV (type and measured depth) Baker model D packer @ 4607' MD Anchorage / Anchorage',,,, 13. Attachments Description Summary of Proposal Detailed Operations Program.~_X BOP Sketch 14. Estimated Date for Commencing Operation 16. If Proposal was Verbally Approved Name of Approver Date Approved 15. Status of Well Classification as: Oil Gas X Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed I ~'~ ~'~ ~ Title Production Engineer Date 7/9/2001 FOR COMMISSION USE ONLY Conditions of Approval:Plug I nteg rity.*~.N°tify CommissiOnBopsOTestirep res, entative may LocationWitness Clearance ~ r~,~ (~r~ ~ ,~L%.¥.~:.~,~,,~ Ap p rove I__ No. Mechanical Integrity Test._._ Subsequent Form Required 10- ~,O ~ Approved by Order of the Commission D Taylor Seamount Commissioner Date Form 10-405 Rev. 06/15/88 Submit in ~iplic~.te Marathon Oil Company Alaska Region KU 24-5 Kenai Gas Field, Pad 41-7 Abandonment Procedure History: KU 24-5 is a shut-in Sterling completion that was worked over in May 2001, in an attempt to improve deliverability by reworking it as an annular producer. The attempts to clean out the well below the B-1 perforations from 4498'-4553' DIL were unsuccessful. The well could not be unloaded to production after the workover, which encompassed the killing with LCM pills, milling and fishing operations that were eventually suspended. Attempts to pump into th6 perforations or otherwise establish communication into the B-1 perforations have been unsuccessful. Objective: To return the B-1 to production, the well will be sidetracked to a bottomhole location practically twinning the existing wellbore. Prior to sidetracking operations, the B-1 perforations will be isolated from the portion of the wellbore (9-5/8" casing) that will be retained for the sidetrack. The lower perforations, below the B-l, were previously isolated during the aforementioned workover operations. The following procedure will result in isolation of the remaining perforation section from the rest of the wellbore in preparation for the setting of a whipstock (see proposed abandonment schematic). Procedure: o MIRU Glacier Drilling Rig No. 1. Monitor casing and tubing for gas head; 9-5/8" annulus and 3-1/2" tubing pressure should be 0 psig. Line up to circulate water down tubing and out casing flowline valve. Shut in annulus and verify that perforations are not taking fluid by pressuring up to 250 psi and monitoring pressure bleedoff. 2. Install BPV and nipple down tree; nipple up adapter spool and BOPs. Pull BPV, install 2- way check valve & test BOPE to 250 psi/3000 psi. Pull 2-way check valve. 3. Make up landing joint into tubing hanger and pull out of hole laying down 3-1/2" tubing. . Make scraper run in 9-5/8" casing on 4" drill pipe to 4450' md. If during Step #1 the perforations were taking fluid or gas was required to be bled from the tubing or casing, continue to next step, otherwise proceed to Step #6. 5. Make up retainer and RIH on drill pipe to +/- 4400' md. Set retainer and attempt to establish injection .rate. If injection.fate is achieved, squeeze cement into B-1 perfs. Attempt to place at least 60 sacks of Class G cement below retainer. If injection rate cannot be achieved, spot 50 sacks of cement on top of retainer. POOH. 6. Test cement and retainer to 1500 psi. Run in and set CIBP at about 3496' md (original KB reference elevation). Test CIBP and casing to 2500 psi. Notes: o o . The sidetrack well will be completed in the same B-1 interval. Cement and an additional barrier isolating the B-1 perforations from the new wellbore will be provided by the cemented liner lap across +/- 3250' - 3500' md. Based on previous work to establish/determine the hydraulic connectivity between the 9-5/8" wellbore and the B-1 perforations, and verbal discussions with AOGCC and BLM, it is anticipated that the cement retainer and cement squeeze outlined in Step #5 will not be performed. The attached drawing only depicts the CIBP at -3496' md as the most likely procedure to be followed. A final drawing illustrating actual abandoned conditions will be subsequently filed. KU 24-5, Pad 41-7 13-1/2" 9 3# L-80 EUE 8~d tb9 il 71" Seating Nipple @ 4450' Joint 3-1/2" 9 3¢~ L-80 EUE 8rd tbg, ~ed§e to 2 i 3/8 th§ and 2 3/8 pup joint i lB-1 peffs sealed offwith LCM (08~04-1982) (05-04-1982} (08-04-1982) (Sqz'd) ICement Retainer ~ 4886' i9-5/8" 47# N-80 BTC @ 5900~ Cmt'd wi1800 sks of Class G KU 24-5~ ~'~?: I Kenai Gas Field I ~20" 94¢ H-40 Drive Pipe ty 136' h 3-3/8" 61# K-55 BTC ty 2012' ICmL ~d w/1500 sks of Class G Proposed Abandonment w/ LS detrack We Ibore j IXA Sliding Sleeve ty 4587' tD 2 75" iBaker Mode~ 'D' pkr ty 4607' 7" 26 ppf L-80 casing at 4608'MD ] ~ ~;'%X~ipple ty 4633' w/Mule Cement of B-3 & B-4 Peris ~¢~ ~4 ~ ~r (S~c kline) 08-27~1993 (08-04-1982) ]Cement Retainer ~886' ~ i9-518" 47# N~0 BTC @ 5900' !Cmhd w/1800 sks of C?s~ G ] [COunty or Parish: Kenai, AK Stste~Prov. Alaska Countw: IPerfor~dons (~-D~' [ Pool 4- $-I -- (TVD} RE: KU 24-5 W.O. Subject: RE: KU 24-$ W.O. Date: Tue, 10 Apr 2001 11:34:36 -0800 From: "^ffinito, Ralph J." <RJAffinito{~MarathonOil.com> To: "Jack Hartz" <jack_hartz@admin.state.ak.us> CC: "Maunder, Thomas" <tom_maunder@admin.state.ak. us> Mr. Hartz, My objective is to lift lost water from the wells following the workover. Most of our wells do not produce water from the Sterling Sands (except water of condensation). However, during a workover, by nature of milling up packers etc, we may lose 500-1000+ bbls to the reservoir. The objective of the workover is to remove downhole restrictions and eliminate friction thus increasing production. The resultant 'tbgless' wellbore can produce at higher rates; however, we had relied on coil tubing as a means to lift liquid from the csg and return the well to flowing production following the workovers. The problems is that to unload a 9-5/8" wellbore at 120 psig FTP requires approximately 8 MMCFGPD to lift liquids. Realizing this rate with CT is #1 not possible with Dowell's equipment (we committed funds to bring a larger nitrogen pump up here from B J) and #2, and more importantly, to realize 8 MMCFGPD rate by pumping, you end up with a BHP that is greater than the SBHP of the reservoirs. Thus you have no inflow and can not recover any liquid but what may be in the casing at that time. With the Iow (245-360 psia) SBHP the csg volume is very small as you know and pumped nitrogen would be injected instead of returning to surface. In summary, we have not been able to produce our KU 14-32 tbgless well since the workover in October. We have spent several hundred thousand dollars to no avail. I feel the solution is artificial lift. After researching PC pumps, SR pumps, ESP's, plunger lift, etc. the option of a concentric gas lift system jumps to the front from the standpoint that it is efficient, does not increase the flowing bottom hole pressure (critical), does not run rods through our tree (environmentally sound), and can be accommodated with the established services on the Peninsula. This option is more costly, but I feel it will serve us well. To more directly answer your question: 1. We will only lift water following the workover and only when the well will not kick off. I fully expect the well to kick off and unload the majority of the fluid up the 3-1/2" x 9-5/8" annulus once we lift a portion of the lost load fluid. The system will not provided added draw down. 2. The high pressure lift gas and the low pressure lift gas would only mix if the system were allowed to operate alter the water was evacuated. I say that assuming only a negligible volume of gas will be dissolved in our water (reasonable at low pressures). We do not want to have to unnecessarily compress gas. Thus, it will likely be a closely monitored system when in use to prevent operation when liquids are not being lifted. Additionally, once the well kicks off, the Sterling gas rate up the annulus will increase. Our in field telemetry system (complete with digital pager notification) will immediately notify the KGF operator at that time; thus, it will rely solely upon operators routine checking the welt system. 3. The HP lift gas will have already been metered. We proposed taking the gas off of our test or group separator which is after all allocation meters. The predicted gas usage volume is 2 MCF/BBL lifted to surface. Thus, I expect to lift at most 50 bbls per day immediately following the workover. This would yield 100 MCF (maximum) on a given day after the workover. Again, following the initial workover unloading operation (several days) this system would be used 1-2 times per year to lift an even smaller volume (only as needed). I expect the 100 MCF daily volume for the post workover rate to be a high estimate. The royalty issue is that there exists a different royalty interest between the low pressure Steding and the high pressure Beluga and Tyonek. The State and Pdvate sectors have an interest only in the Sterling reservoirs thus would benefit. However, the MMS has a larger (4% interest) in the Sterling and a smaller interest (0.5%) in the high pressure intervals, Please keep in mind however, that this is a trial installation, and the gases will not be commingled. We are proposing to use the energy only from the HP gas after it has been metered. 4. I expect the rate increase to only be associated with being able to produce the welt. In KU 14-32 for example it should go from zero now to 20 MMCFGPD rate (this is really speculative not knowing what damage has been done from the workover). 5. This is a good question. I am likely not the best to answer. Generally, we do not book reserve additions to our workovers. However, I think that by keeping our compressors well supplied we lower operating expenses. This may enhance economics and further field life. But honestly, this is a question better answered by Brent Senette (KGF Facility Engineer) or Ben Schoffmann (KGF Res Eng). I hope I have answered your questions. Please do not hesitate to call to further discuss. ! have alot of technical energy into this design and would like it kept confidential if possible. Please let me know if you have any other concerns or questions. I would be happy to meet you to discuss further. We plan to commence the workover in conjunction with frost laws (Late April). ! would then like to install the lift system in early May. I look fom/arcl to discussing this further. 1 of 2 4110101 12:03 PM RE: KU 24-5 W.O. Respectfu~y, Ralph J. Affinito Marathon Oil Company - Alaska 907-564-6303 ~-- ~Original Message--- From: Jack Hartz [mailto:jack hartz~,admin.state.ak, us] Sent: Tuesday, April 10, 2001 9:16 AM To: Affinito, Ralph J. Cc: Maunder, Thomas Subject: KU 24-5 W.O. Ralph, The program you propose looks intriguing. I have several questions about the lilting and gas accounting. Will the lifting be done only as long as water is present, i.e., is this also a method to draw ? Do the streams of lift gas and produced gas mix?, Has the lie gas been metered or has custody been transferred elsewhere and are them any issues with royalty and taxes? What kind of Rate increase do you expect? Are there any reserves increases associated with this type of effort or does it delay a compressor upgrade? Thanks, Jack Hartz 2 of 2 4/10/01 12:03 PM Alaska ~ .. )n Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 April 5, 2001 Tom Maunder .State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 1000 Anchorage, AK 99501 Reference: Proposed Workover Well: KU 24-5 APl Number: 50-133-20358 Permit Number: 82-98 Dear Mr. Maunder: Attached is FORM 10-403, APPLICATION FOR SUNDRY APPROVALS. Also attached are a proposed procedure, current and proposed wellbore diagram, and a post-workover artificial lift installation. I plan to commence the pre-rig work April 09, 2001 and begin the rig work on April 16th. Please call me to discuss any necessary changes. If you have any questions or need additional information, I can be reached at 564-6303 or riaffinito@ marathonoil.com. Sincerely, Ralph Affinito Production Engineer RECEIVED APR 09 2_001 Alaska Oil & Gas Cons. Commissio~ Anchorage ORIGINAL A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS O:~EXCE LV~CX3 CC02.X LS~ 1. Type of Request: Abandon Suspend Operation Shutdown Alter Casing Repair Well Plugging X Change Approved Program Pull Tubing Variance Re-enter Suspended Well Time Extensior Stimulate Perforate Other X 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 332' FNL, 4331' FWL, Sec. 7, T4N, R1 lW, S.M. At top of Productive Interval 5. Type of Well: Development X Exploratory Stratigraphic Service At Effective DepthPlug Back Pool 5.1 and Workover Pool 4 for enhanced Annular Flow w/Art. Lift At Total Depth 1336' FSL, 1763' FWL, Sec. 5, T4N, R11W, S.M. 12. Present Well Condition Summary Total Depth: measured true vertical 5900 feet Plugs (measured) 4988 feet 6. Datum Elevation (DF or KB) 29 feet 7. Unit or Property Name Kenai Unit 8. Well Number KU 24-5 9. Permit Number 82-98 lO. APl Number 50- 133-20358 11. Field/Pool Kenai Gas Field, Pool 4 Cement retainer @ 4886' MD Effective Depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length 136' 2012' Size 20" 13-3/8" 9-5/8" 5900' measured B-l: 4498' - 4553' MD Cemented Driven 1500 sks 1800 sks true vertical B-1: 3854' - 3897' TVD Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3-1/2", 9.2#, N-80 tubing to 4450' MD Baker model A-5 dual packer @ 4439' MD Baker model D packer @ 4607' MD Measured Depth 136' 2012' 5900' True Vertical Depth 136' 1864' 4988' RECEIVED APR 09 2001 AND 3-1/2" 9.2 # N-80 tubing to 4644' on LS. Alaska Oil & G,~S Co~s, Co~llrrljssier Anchorage 13. Attachments Description Summary of Proposal Detailed Operations Program X BOP Sketch 15. Status of Well Classification as: 14. Estimated Date for Commencing Operation 4/9/2O01 16. If Proposal was Verbally Approved Name of Approver Date Approved Oil Gas X Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Signed ~~/f/~ R. Affinito Title Production Engineer / ~' /'~' FOR COMMISSION USEONLY Date 4/5/2001 JConditionsof Approval: Notify Commission so repr,e~entative may witness '~~~ ~,i~'~.~,¥. JApproval Plug integrity BOP Test,~_ Location Clearance I N°~/'O~ Mechanical Integrity Test Subsequent Form Required 10-~-~)~"~ v . ORIGINAL ,SIGNED BY JApproved by Order of the Commission D TayJor Seamount commissioner Date Form 10-403 Rev. 06/15/88 Submit in Triplicate ,-% Ala~. ~ ~ Dom, ~duction DATE: Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 FAX COVER LETTER II PLEASE DELIVER THE FOLLOWING TO: Name: ~~k~~ ~ .... Company: Fax No.: Number of Pages (including cover page): FROM: Name: Location/Extension: Fax No.: 907/564-6489 NOTE: If transmission is not complete, please call 907/561-5311. A subsidiary of USX Corporation Environmentally aware for the long run. MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field . KU 24-5 Deliverability Workover Procedure AFE # 92069O1 1) 2) 3) 4) 5) 6) 7) 8) 9) 10) MIRU Slickline unit on SS. Pressure test lubricator. · RIH and close Otis 'XA' sliding sleeve @ 4427' (Sleeve ID = 2.75"). RU Slickline on LS. Pressure test lubricator. · Close Otis 'XA' sliding sleeve at 4587' (sleeve ID is 2.75"). Mix approximately 300 bbls of 3%KCI. Fill annulus with approximately 218 bbls and pressure test annulus to 1000 psig. Fill LS tubing with up to 40 'bbls of 3% KCI water. Pressure test tubing to 1000 psig. RU Slickline on LS. Retrieve PXN plug set in Otis 'X' nipple at 4633'. RIH w/2.70" GR and tag fill for calculating cement volume of squeeze. RD Slickline Unit. RU BJ Services on SS. Mix and pump a 10 bbl LCM pill as follows. 60 Ibm/bbl graded calcium carbonate mixed 75% medium and 25% coarse in 5 Ibm/bbl HEC. Displace LCM pill with 39 bbls of 3% KCI water. RU BJ Services on LS. Pump 3%KCL water to establish injection rate into the Pool 5.1 perfs. Pump approximately 70 bbls (minimum). Mix and pump 60 sks of Class 'G' cement. Volume from tubing tail to fill is 10 bbls or 49 sacks. Displace cement and plug with 40 bbls of 3% KCI water. RD cementing service. RU Slickline on SS. Pressure test lubricator. · RIH and attempt to set PX plug in 'XN' nipple at 4450'. A similar attempt to set a PX plug failed in 08/1998. If unable to set plug, then set blanking plug directly above 'XN' nipple. · RIH with tubing punch and punch two (2) holes in SS tubing between Baker A-5 dual packer and Otis sliding sleeve. Holes should be punched at 4435' and 4430'. RD Slickline. RU R&K pump. Hook up chicksan and iron to open top tank and SS. Attempt to circulate down the tbg and up the annulus. It will be likely necessary to reverse circulate numerous times in an effort to remove any sand fill from above packer. Once adequate reverse circulation is achieved, rig down chicksan and pump. RU Slickline to SS. RIH and retrieve PX plug in 'XN' nipple at 4450'. RD slickline. If unable to retrieve plug, will jet cut tbg in next step to allow communication. RU APRS with Pollard Mast truck. RU 2.70" OD jet cut tool. Cut LS tbg at 4602' (above Iocator sub on Baker Model 'D' seal assembly). RU on SS. Jet cut SS @ approximately 4436' (2' above packer). RD APRS. KU 24-5 Sterling Workover Procedure-001 RJA 4/5/2001 1:40 PM 11) 12) 13) 14) 15) 16) 17) Bleed off trapped pressure on tubing strings and annulus. Install BPV's in both the short and long string tubing hangers. Have wellhead vendor prep all necessary wellhead and tree studs for removal. MIRU Glacier Drilling Rig #1. Haul to location 4500' of 4" 14 Ibm/ft HT-38 DP. Drift drill pipe to a 2.3". Nipple down existing dual tree. NU BOP with upper pipe rams equipped with dual 3-1/2" rams and lower pipe rams equipped with single 4" rams. Remove BPV's and install two way checks. Pressure test BOP to 250 / 3000 psig. Pull two way checks. RU dual elevators. PU on Short and Long strings and attempt to release Baker A-5 dual packer at 4439. Maximum pull on single string of 3-1/2" 9.2 ppf buttress N-80 tubing is 159,090 Ibf (100%). Recommend not pulling more than 110,000 Ibf (70%). If packer does not release, then RU to SS and establish circulation conventional and then reverse lowering tubing to packer to more fully clean fill from top of packer. Attempt to release packer again. a) If Packer releases, then TOH laying down SS, LS, packer, and tailpipe and proceed to bit and scraper run as per Step #17 b) If packer does not release, proceed to Step #11 Operations assuming tubing does not release. RU APRS 1.375" OD freepoint service on LS. Free point tubing. Assuming LS tubing is free to packer, then RU 2.625" OD chemical cutter and cut LS at 4415' (below the Otis 'XA' Sliding sleeve - cut must be 20' above where the SS was jet cut. RD APRS. TOH laying down SS and LS 3.5" N-80 tubing. PU the following a) 8-1/8" or 7-5/8" overshot for 9-5/8" 47 ppf casing dressed with a basket grapple for 3-1/2" tubing b) 6.25" OD Bumper sub c) 6.25" OD Hydraulic Jars d) 6.25" OD Drill collars e) 6.25" OD Accelerator f) 4" HT-38 drill pipe TIH to LS tbg fish. Latch fish and work good hold. Commence tool work to release Dual packer by jarring. If packer does not release, then RU APRS and RIH w/1.375" OD free point tool. Free point tubing to verify if packer is released or tailpipe is stuck. a) If packer is released then chemical cut tubing below the packer and above the free point in tail pipe and COH w/packer and proceed to fishing tailpipe as per Step #16. b) If packer is stuck, then chemical cut LS tubing immediately below and above packer and COH laying down 3-1/2" tubing and proceed to milling packer as per Step #15. 18) Prepare to mill over Baker A-5 dual packer. TIH with the following: a) Baker mill shoe for 9-5/8" 47 ppf casing and Baker A-5 dual packer. b) Bumper sub c) Hydraulic jars d) Drill collars TIH on 4" DP to packer at approximately 4439'. Commence milling operations using 3% KCI water. Use only 3% KCI water throughout remainder of procedure. If inadequate KU 24-5 Sterling Workover Procedure-001 RJA 4/5/2001 1:40 PM circulation is being maintained then consider reverse circulating and using LCM as necessary. Wash over packer tripping for new mill shoe as necessary. Once packer is free, then TOH w/shoe. TIH w/spear and retrieve packer. 19)TIH with the following to retrieve tailpipe fish. a) 8-1/8" or 7-5/8" overshot for 9-5/8" 47 ppf casing dressed with a basket grapple for 3-1/2" tubing b) 6.25" OD Bumper sub c) 6.25" OD Hydraulic Jars d) 6.25" OD Drill collars e) 6.25" OD Accelerator f) 4" HT-38 drill pipe Latch tubing fish and TOH laying down tubing fish. Utilize washpipe as necessary. 20) TIH w/RBP and set at 1,000'. TOH w/DP. Remove existing tubing head. Install spool and then 11" 3K tubing head with 7-1/16" annular outlet. 21) PU bit and scraper for 9-5/8" 47 ppf casing and TIH to jet cut tbg at 4602'. TOH w/DP. 22) Haul to location 4,500' of 3-1/2" 9.3 ppf EUE 8 rd tbg and full set of pup joints all from Tuboscope. Drift and talley tubing. 23) PU cement retainer for 9-5/8" casing and TIH and set retainer at 4600'. Partially unsting from retainer and PT DP to 1000 psig. Sting back into retainer and pressure test below retainer to 1,000 psig. TOH w/retainer while laying down DP. 24) Change rams to 3-1/2". Pressure test same to 250/3,000 psig. Change elevators to 3-1/2". Install 15' bales. RU Weatherford power tongs and dual split slips for 3-1/2" tbg. Have on location a floor valve for 3-1/2" EUE 8rd tbg. STERLING POOL 4 (B-l) SAND COMPLETION RESERVOIR INTERVAL PERFS B-1 4498-4553' 55' 25) Hold safety meeting and prepare to run tubing conveyed perforating completion. Radio silence is not necessary. PU completion equipment as follows: a) 2-3/8" WL re-entry guide b) 2-3/8" EUE 8rd Type 'A' seating nipple (ID = 1.71") c) 2-3/8" EUE 8rd tbg sub pin x pin d) 3-1/2" EUE 8rd box X 2-3/8" EUE 8rd pin e) 1-20' x 3-1/2" EUE 8rd Blast Joint w/4.5" OD x 2.992" ID f) 3-1/2" 'X' nipple with 2.813" 'X' profile by 4.5" OD. g) 2 - 20' x 3-1/2" EUE 8rd blast joints w/4.5" OD x 2.992" ID h) 3-1/2" EUE 8rd Y- block (w/pin x pin cross over) for perforating the Sterling B-I. Perf guns are to be 3-3/8" Low Side 6 SPF guns loaded with Super DP 22 gram RDX charges loaded to perforate the Sterling B-1 (Pool 4) from 4,498-4,553 (55 feet of perforations). Equipped with a Model K Firing head set to fire at 2,000 psig surface pressure or 3,700 psig downhole pressure. i) 1 - 20' x 3-1/2" EUE 8rd Blast Joint w/4.5" OD x 2.992" ID (RA tag to be placed in box end - 20' above firing head) KU 24-5 Sterling Workover Procedure~001 RJA 4/5/2001 1:40 PM 26) 27) 28) 29) 30) 31) 32) 33) 34) j) 3-1/2" EUE 8rd 9.3 ppf L-80 tubing to surface with estimated pups for space out. Tubing tailpipe will be at base of perfs. Note all OD's and ID's along with serial numbers on all components being run downhole. RU Schlumberger Logging service. Install pump in sub and pack off. Run 1-11/16" OD GR/CCL. Stand back Schlumberger. Determine required space out for placing annular guns on depth. Make up necessary space out pups and mandrel hanger (Full set of 3-1/2" EUE 8rd pups are at Tuboscope). Land hanger and re-run Schlumberger GR/CCL to verify space out and perf gun placement. Pressure test hanger seals. CLOSELY MONITOR TUBING PRESSURE. TUBING MUST NOT BE PRESSURED ABOVE 2000 PSlG AS PERFORATING GUNS WILL FIRE. Flange up tree. Pressure test tree and seals. Install BPV. Release rig and commence rig down. RU Pollard Slickline unit. RIH and set ESV 1.781" in 3-1/2" tubing. RD Pollard slickline unit. Fill tubing to 2,000' if not already full. Verify fluid level. RU BJ Coil Tubing Service. Install 2-3/8" 0.134" wall HO-70 CT w/1.81" ID CT 'A' nipple located 150' from end of tubing. Run and land CT as per ABB Vetco Gray's landing procedure. Pressure test CT landing assembly and RD CT unit. A separate procedure for the CT installation will be provided. RU Pollard Slickline Unit. Install 1.81" pilot valve in CT 'A' nipple. RD Pollard WL unit. Commence injecting gas down coil tubing through wing valve and unload water out coil tubing spool until well begins to flow up the 3-1/2" x 9-5/8" annulus. Following rate stabilization, analyze well performance and plan to reperforate as necessary. RU Pollard Slickline Unit. Retrieve 1.81" pilot valve. RD Pollard WL unit. Fill CT and CT annulus w/3% KCI water. Pressure up to 2000 psig. Fire perforating guns. Resume gas injection to displace water from CT. RU Pollard slickline unit. Install 1.81" pilot valve in CT 'A' nipple. RD Pollard WL unit. Unload well as necessary using gas lift equipment. Flow test well to determine deliverability of the Pool 4 completions. KU 24-5 Sterling Workover Procedure-001 RJA 4/5/2001 1:40 PM Kenai Gas Field Well KU 24-5, Pad 41-7 Marathon Oil Co., Alaska Region RT-GL: 29.0' 322'S & 4331' E of NW Comer Sec. 7, T4N, R1 lW Shortstring Tubing: 3-1/2", 9.2//, N-80, Butt. Otis "XA" Sliding Sleeve ~ 4427' ID = 2.750" Sleeve opened for annular flow 8/26/98 Baker A-5 Dual Packer @ 4439' Otis "XN" Nipple ~ 4450' ID = 2.635" Unable to set PXN plug 8/22/98 Shortstring Peffs B-I 4498'- 4553' DIL (8/4/82) Longstring Peffs B-3 4691' - 4731' DIL (8/4/82) B-4 4789' - 4864' DIL (8/4/82) B-4 4899' - 4909' DIL (Sqzd) m @ 59oo' 20", 94/t, H-40 Drive pipe ~136' 13-3/8", 61//, K-55, BTC Casing ~ 2012' Cmt w/1500 sks of Class G Longstring Tubing: 3-1/2", 9.2//, N-80, Butt. Otis "XA" Sliding Sleeve @4401' ID = 2.750"7 Blast Joints 4480' - 4578' Otis "XA" Sliding Sleeve @ 4587' ID = 2.750"7 Opened 3/21/91 ?77 Locator sub ~ 4606' Baker Model "D" Packer @ 4607' Otis "X" Nipple @ 4633' ID = 2.750" Muleshoe @ 4644' Fill @ 4781' WLM (8/27/93) Cement retainer @ 4886' 9-5/8", 47//, N-80, BTC Casing @ 5900' Cmt w/1800 sks of Class G Last Rev: JGE, 9/1/98 [20" 94# H-40 Drive Pipe @ 136' 13-3/8" 61# K-55 BTC @ 2012' Cmt d w/1500 sks of Class G 3-1/2" 9.3# L-80 EUE 8rd tbg 2.813" 'X' Nipple @ 4420' Y-Block w/perforating guns along with 3-1/2" Blast Joints 1.71" Seating Nipple @ 4550' 2-3/8" WL re-entry guide @ 4553' ICement Retainer @ 4590' IBaker Model 'D' pkr @ 4607' I2.75" 'X' Nipple @ 4633' w/Mule shoe tbg tail @ 4644' ISqz Cement of B-3 & B-4 Perfs Fill @ 4781' (Slickline) 08-27-1993 ICement Retainer @ 4886' 9-5/8" 47# N-80 BTC @ 5900' Cmt d w/1800 sks of Class G PROPOSED WELLBORE B-1 Perfs 4498-4553' DIL (08-04-1982) B-3 Perfs 4691-4731' DIL (08-04-1982) B-4 Perfs 4789-4864' DIL (08-04-1982) B-4 Perfs 4899-4909' DIL (Sqz'd) IWell Name & Number: I County or Parish: Perforations (MD) I Angle/Perfs IBHP: I 245 BHT:I Dated Completed: KU 24-5 Lease: J S1ate/Prov. Kenai, AK Pool 4 - B-1 (TVD) Angle @ KOP and Depth 1051 Completion Fluid: Alaska Kenai Gas Field TYPICAL M ETHAN E WE LL FLUID PRODUCTION 9-5/8" 2-3/8" x.134" WALL COILED TUBING 3E"TUBING~ BI-2T CHOKE 2" ANSI 600 TIME CYCLE CONTROLLER & 2" ANSI 600 RF MOTOR VALVE INJECTION LIFT GAS r---~GAS PRODUCTION PROPOSED MARATHON ALASKA WELL # KU 24-5 2-318" CTA-1,812 LANDING NIPPLE BOTTOM OF 2-3/8" COILED TUBING @ 4,488'+ 4,800' M!4,000' V WIRELINE RETRIEVABLE IY:~" PILOT VALVE (RUN W/SHEARDOWN TOOL) 01.781" WIRELINE STANDING VALVE IN 01.710" NO-GO NIPPLE @ 4,495' + IN 3Y2" TUBING TP @ 4,498' BST LIFT SYSTE MS VENTURA, CALIFORNIA U.S.A. g:~cmntddg~kgl~wetlstku24-55tAOGCCO1A.xls STATE OF ALASKA ^i_ASl~ OIL AND GAS CONSERYAIION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown~ Stimulate Plugging .. , Perforate~ Pull Tubing __ Alter Casing Repair Well... Other 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 332' FNL, 4331' FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval 5. Type of Well: Development X Exploratory.. Stratigraphic. Service At Effective Depth Convert to Annular Flow At Total Depth 1336' FSL, 1763' FWL, Sec. 5, T4N, R11W, S.M. 6. Datum Elevation (DF or KB) 29 feet 7. Unit or Property Name Kenai Unit 8. Well Number KU 24-5s 9. Permit Number 82-98 lO. APl Number 50- 133-20358 11. Field/Pool Kenai Gas Field, Pool 4 12. Present Well Condition Summary Total Depth: measured true vertical 5900 feet 4988 feet Plugs (measured) Cement retainer ~ 4886' MD Effective Depth: measured true vertical feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length 136' 2012' Size 20" 13-3/8" 9-5/8" 5900' measured B-1: 4498' - 4553' MD Cemented Driven 1500 sks 1800 sks Measured Depth 136' 2012' 5900' true vertical B-1: 3854' - 3897' TVD Tubing (size, grade, and measured depth) 3-1/2", 9.2~, N-80 tubing to 4450' MD Packers and SSSV (type and measured depth) Baker model A-5 dual packer {~ 4439' MD Baker model D packer @ 4607' MD True Vertical Depth 136' 1864' 4988' RECEIVED 0CT G 1998 Alaeka 011 & Ga~ Cons. Commla~. 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) Treatment Description Including Volumes Used and Final Pressure 14. Prior to Well Operation Subsequent to Operation Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 47O0 0 0 unknown, not yet tested Tubing Pressure 110 15. Attachments 116. Status of Well Classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations X Oil__ Gas X Suspended__ 17. I hereby certify that the foregoing is t~ue and correct to the best of my knowledge. Signed~ ,~ 0~.~"~ ',~~ J. Gary Eller Title Production Engineer Form 10-404 Rev. 06/15 '18~'~"'" ~-~ -- ~ Service Date 10/1/98 Submit in Duplica~)~· (/f~~ Kenai Gas Field Well KU 24-5, Pad 41-7 ~.~::::., ...... ::,.:.,,,. Marathon Oil Co., Alaska Region RT-GL: 29.0' 322'S & 4331' E of NW Comer Sec. 7, T4N, R11W Shortstring Tubing: 3-1/2", 9.2//, N-80, Butt. Otis "XA" Sliding Sleeve @ 4427' ID = 2.750" Sleeve opened for am~ular flow 8/26/98 Baker A-5 Dual Packer @ 4439' Otis "XN" Nipple @ 4450' ID = 2.635" Unable to set PXN plug 8/22/98 Shortstring Perfs B-1 4498'- 4553' DIL (8/4/82) Longstring Perfs B-3 4691' - 4731' DIL (8/4/82) B-4 4789' - 4864' Dm (8/4/82) B4 4899'- 4909' Dm (Sqzd) 900' 20", 94//, H-40 Drive pipe ~136' 13-3/8", 61//, K-55, BTC Casing @ 2012' Cmt w/1500 sks of Class G Longstring Tubing: 3-1/2", 9.2//, N-80, Butt. Otis "XA" Sliding Sleeve ~4401' ID = 2.750"? Blast Joints 4480' - 4578' Otis "XA" Sliding Sleeve @ 4587' ID = 2.750"? Opened 3/21/91777 Locator sub ~ 4606' Baker Model "D" Packer ~ 4607' Otis "X" Nipple @ 4633' ID = 2.750" Muleshoe @ 4644' Fill ~ 4781' WLM (8/27/93) Cement retainer ~ 4886' 9-5/8", 47//, N-80, BTC Casing @ 5900' Cmt w/1800 sks of Class G Last Rev: JGE, 9/1/98 980930.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 9/30/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field WELL #: KU 24-5s TUBING: 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: BENCHES OPEN: Sterling B-1 Convert to annular flow Day#11- AFE 0481998 SUMMARY OF OPERATIONS Produced annulus (not the tubing) of KU 24-5s for several hours to try to clear debris off of "N" test tool. RU Pollard slick, line on KU 24-5s. Tested lubricator and BOPE to SITP. RIH with RS pulling tool with turned down sk,irt (OD = 2.62"). Latched "N" test tool, POOH. Full recovery. RDMO slick, line. Vendor Equipment Daily Cost Cumulative Cost Air Liquide nitrogen $0 $4,165 APC roustabouts $0 $400 Dowell nitrogen pumping $0 $9,100 Misc. $500 $5,000 Pollard slickline $900 $6,885 R&L Construction vacuum truck $0 $400 ,,= Vetco Gray 2" gate valves $0 $1,600 , .... DAILY COST: $1,400 CUM: $28,750 REPORTED BY: J.G. Eller 980905.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 9~5~98 FIELD: FI LL DEPTH/DATE: TUBING: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: Convert to annular flow OTHER: Day #10 - AFE 0481998 Kenai Gas Field WELL #: KU 24-5s 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: BENCHES OPEN: Sterling B-1 SUMMARY OF OPERATIONS iRU Pollard slickline on KU 24-5s. Tested lubricator and BOPE to SITP. RIH with 2.625" tapered impression block to 4487' WLM. POOH, poor impression of clean fishing neck. Cut lines on inside taper of impression block to get a better impression and rerun. POOH, impression still not clear. RIH with 1-3/4" hydrostatic bailer with side openings to top of plug and fired bailer. POOH, bailer full of water only. RIH with 2-1/2" JDC, unable to latch, POOH. Pin not sheared. RIH with 3" split skirt JDC, jar down for 20 minutes, still unable to latch, POOH. Pin not sheared. RDMO slickline. Vendor Equipment Daily Cost Cumulative Cost Air Liquide nitrogen $0 $4,165 APC roustabouts $0 $400 Dowell nitro~len pumpin~ $0 $9,100 Misc. $500 $4,500 Pollard slickline $960 $5,985 R&L Construction vacuum truck $0 $400 Vetco Gray 2" ~ate valves $0 $1,600 DAILY COST: $1,460 CUM: $27,350 REPORTED BY: J.G. Eller 980903.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 9/3/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: TUBING: Convert to annular flow Kenai Gas Field WELL #: KU 24-5s 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: BENCHES OPEN: Sterling B-1 OTHER: Day #9 - AFE 0481998 SUMMARY OF OPERATIONS RU Pollard slickline on KU 24-5s. RIH with 2.25" impression block to 4487' WLM. POOH, clean impression of fishing neck. RIH with 3" JDC pulling tool, jarred tools down on prong for 20 minutes, unable to latCh fishing neck on "N" test tool. POOH, JDC not sheared. RIH with 2" hydrostatic bailer to top of plug and fired bailer. POOH, bailer full of water only. RIH with 2-1/2" JDC, unable to latch, POOH. RIH with 3" JDC, jar down for 20 minutes, still unable to latch, POOH. RIH with 3" split skirt JDC, still unable to latch. RIH with 2.625" impression block, POOH with clean impression of top of fishing neck. SDFN. Vendor Equipment Daily Cost Cumulative Cost Air Liquide nitro~len $0 $4,165 APC roustabouts $0 $400 Dowell nitrogen pumpin~l $0 $9,100 Misc. $500 $4,000 Pollard slickline $1,660 $5,025 R&L Construction vacuum truck $0 $400 Vetco Gray 2" ~late valves $0 $1,600 DALLY COST: $2,160 CUM: $25,890 REPORTED BY: J.G. Eller 980903.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 9/3/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: TUBING: Convert to annular flow Kenai Gas Field WELL #: KU 24-5s 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: BENCHES OPEN: Sterlin~l B-1 OTHER: Day #9 - AFE 0481998 SUMMARY OF OPERATIONS RU Pollard slickline on KU 24-5s. RIH with 2.25" impression block to 4487' WLM. POOH, clean impression of fishing neck. RIH with 3" JDC pulling tool, jarred tools down on prong for 20 minutes, unable to latch fishing neck on "N" test tool. POOH, JDC not sheared. RIH with 2" hydrostatic bailer to top of plug and fired bailer. POOH, bailer full of water only. RIH with 2-1/2" JDC, unable to latch, POOH. RIH with 3" JDC, jar down for 20 minutes, still unable to latch, POOH. RIH with 3" split skirt JDC, still unable to latch. RIH with 2.625" impression block, POOH with clean impression of top of fishing neck. SDFN. Vendor Equipment Daily Cost Cumulative Cost Air Liquide nitro~len $0 $4,165 APC roustabouts $0 $400 Dowell nitrogen pumpin~l $0 $9,100 Misc. $500 $4,000 Pollard slickline $1,660 $5,025 R&L Construction vacuum truck $0 $400 Vetco Gray 2" ~late valves $0 $1,600 DAILY COST: $2,160 CUM: $25,890 REPORTED BY: J.G. Eller 980902.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 9/2/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: TUBING: Convert to annular flow Kenai Gas Field WELL #: KU 24-5s 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: BENCHES OPEN: Sterlin~l B-1 OTHER: Day #8 - AFE 0481998 SUMMARY OF OPERATIONS MIRU Pollard slickline on KU 24-5s. Test lubricator and BOPE to SITP. RIH with 3" JDC pulling tool, unable to latch fishing neck on "N" test tool @ 4450' MD. POOH, JDC not sheared. Rerun JDC, jar down for 20 minutes, still unable to latch. POOH, SDFN. Vendor Equipment Daily Cost Cumulative Cost Air Liquide nitrogen $0 $4,165 APC roustabouts $0 $400 Dowell nitrogen pumping $0 $9,100 Misc. $500 $3,500 Pollard slickline $355 $3,365 R&L Construction vacuum truck $0 $400 Vetco Gray 2" gate valves $0 $1,600 DAILY COST: $855 CUM: $23,730 REPORTED BY: J.G. Eller 980827.xls MARATHON OIL COMPANY DATE: 8/27/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: Day #7 - AFE 0481998 DAILY WELL OPERATIONS REPORT PAGE 1 OF I FIELD: Kenai Gas Field WELL #: KU 24-5s TUBING: 3-112", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: BENCHES OPEN: Sterling B-1 Convert to annular flow SUMMARY OF OPERATIONS RU Dowell nitrogen pump on 9-5/8" casing of well KU 24-5. Pressure test nitrogen lines to 2400 psig. TP = 1650 psig. Held operational and safety meeting. Bled tubing pressure to zero. Began pumping nitrogen down the casing while taking returns of packer fluid off the shortstring tubing. After pumping 156,1 50 SCF of nitrogen (maximum pump pressure = 1650 psig) got nitrogen returns to surface. Shut down nitrogen pump, then continued to blow nitrogen from the tubing to make sure all packer fluid was unloaded. Shut in well at casing and tubing. RD nitrogen. Final TP = CP = 500 psig. Vendor Equipment Daily Cost Cumulative Cost Air Liquide nitrogen $4,165 $4,165 APC roustabouts $0 $400 Dowell nitrogen pumping $3,000 $9,100 Misc. $500 $3,000 Pollard slickline $0 $3,010 R&L Construction vacuum truck $400 $400 Vetco Gray 2" gate valves $0 $1,600 DALLY COST: $8,065 CUM: $22,875 REPORTED BY: J.G. Eller 980826.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT DATE: 8/26/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: Convert to annular flow OTHER: Day ~ - AFE 0481998 PAGE 1 OF 1 FIELD: Kenai Gas Field WELL #: KU 24-5s TUBING: 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: BENCHES OPEN: Sterling B-1 SUMMARY OF OPERATIONS MIRU Pollard slickline unit on KU 24-5s. Tested BOPE and lubricator to SITP. RIH with "B" shifting tool, latched into XA sliding sleeve at 4427' MD. Shifted sleeve open, POOH. RDMO slickline. Vendor Equipment Daily Cost Cumulative Cost APC roustabouts $0 $400 Dowell nitrogen $0 $6,100 Misc. $500 $2,500 Pollard slickline $660 $3,010 Vetco Gray 2" gate valves $0 $1,600 DAILY COST: $1,160 CUM: $14,810 REPORTED BY: J.G. Eller 980825.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/25/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: TUBING: Convert to annular flow Kenai Gas Field WELL #: KU 24-5s 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: BENCHES OPEN: Sterling B-1 OTHER: Day #5 - AFE 0481998 SUMMARY OF OPERATIONS RU Dowell nitrogen pump on tubing of KU 24-5s. Held operational and safety meeting, and tested lines to 3000 psig. Pressured up tubing on KU 24-5s to 1850 psig using 29,000 SCF of nitrogen. RD nitrogen pump. Vendor Equipment Daily Cost Cumulative Cost APC roustabouts $0 $400 Dowell n itrog en $1,500 $6,100 Misc. $500 $2,000 Pollard slickline $0 $2,350 Vetco Gray 2" gate valves $0 $1,600 DALLY COST: $2,000 CUM: $13,650 REPORTED BY: J.G. Eller 980824.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/24/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: TUBING: Convert to annular flow Kenai Gas Field WELL #: KU 24-5s 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: BENCHES OPEN: Sterling B-1 OTHER: Day #4 - AFE 0481998 SUMMARY OF OPERATIONS Held operational and safety meeting. Removed blind flange from secondary casing outlet on tubing head. Installed a newly tested 2-1/16", 5M gate valve. Removed old casing valve, and installed another newly tested 2-1/16", 5M gate valve. Closed casing valves, released roustabout crew. Vendor Equipment Daily Cost Cumulative Cost APC roustabouts $400 $400 Dowel l nitrogen $0 $4,600 Misc. $500 $1,500 Pollard slickline $0 $2,350 Vetco Gray 2" gate valves $1,600 $1,600 DAILY COST: $2,500 CUM: $11,650 REPORTED BY: J.G. Eller 980822.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/22/98 FI LL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: TUBING: Convert to annular flow Kenai Gas Field WELL #: KU 24-5s 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION' BENCHES OPEN: Sterling B-1 OTHER: Day #3 - AFE 0481998 SUMMARY OF OPERATIONS RU Pollard slickline unit on KU 24-5s. RIH with 2.80" wire brush and cleaned off XN nipple @ 4450' MD. POH. RIH with PXN plug, still unable to get PXN plug to set. POOH, replace XN keys on plug. RIH with new plug, still will not set. POOH. RIH with 2.63" gauge ring to check no-go in XN nipple, but nipple checked out OK. POOH. Swapped out X-line running tools, rerun PXN plug with same results. POOH. Discussed options with Production Engineer, decided to try a different type of plug. RIH with a 2.75" "N" test tool on a JDC running tool. Set "N" test tool at XN nipple at 4450' MD. POOH, RDMO slickline. Note: The "N" test tool will hold pressure only from above, which ought to suffice for this operation. Vendor Equipment Daily Cost Cumulative Cost Dowell nitrogen $0 $4,600 Misc. $500 $1,000 Pollard slicklin e $2,350 $2,350 DAILY COST: $2,850 CUM: $9,150 REPORTED BY: J.G. Eller 980821 .xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/21/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: TUBING: Convert to annular flow Kenai Gas Field WELL #: KU 24-5s 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: BENCHES OPEN: Sterling B-1 OTHER: Day #2 - AFE 0481998 SUMMARY OF OPERATIONS MIRU Pollard slickline unit on KU 24-5s. Test BOPE and lubricator to SITP. RIH with 2.72" gauge ring to 4450' WLM, tag XN nipple. POOH. RIH with PXN plug, attempt to set in XN nipple @ 4450' MD. Unable to get plug to set. POOH, made one more unsuccessful attempt to get PXN plug to set. POOH, SDFN. Vendor Equipment Daily Cost Cumulative Cost Dowel l nitrogen $0 $4,600 Misc. $500 $1,000 Pollard slickline $700 $700 DAILY COST: $1,200 CUM: $6,300 REPORTED BY: J.G. Eller 980820,xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/20/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: TUBING: Convert to annular flow Kenai Gas Field WELL #: KU 24-5s 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: BENCHES OPEN: Sterling B-1 OTHER: Day #1 - AFE 0481998 SUMMARY OF OPERATIONS MIRU Dowell nitrogen pump on 9-5/8" casing on well KU 24-5. Pressure test lines to 2400 psig. Pressure up on 9-5/8" casing to 1900 psig using only 2,800 SCF of nitrogen. RDMO nitrogen unit. Opened valve to 13-3/8" surface casing, bled trapped pressure to zero to confirm that it isn't communicated with the 9-5/8" production casing. Installed a chart recorder on the 9-5/8" casing today to record pressure test. Note: Over the weekend will set a PXN plug in the tubing of KU 24-5s. Will replace casing valves on Monday. Vendor Equipment Daily Cost Cumulative Cost Dowell nitrogen unknown unknown Misc. $500 $500 DAILY COST: $500 CUM: $500 REPORTED BY: J.G. Eller SENT BY:Marathon 0ti Company ' 8-.5-98 ' 8:4-5AI~1 ' AnchoraEe-~ Alaska Region Domestic Production 907 276 7542'# 1/ 4 Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephon~ 907/561-5311 August 5, 1998 Mr. Blair Wondzell Alaska Oil 8, Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Kenai Gas Field. Annular Flow Conversion Dear Mr. Wondzeli: As per your request, attached is a review of potential problems associated with converting Wells KU 11-8s, KU 24-5s, and KU 43-6AI at the Kenai Gas Field to annular flow. As the analyses show, Marathon does not anticipate that these conversions will cause undue stress, corrosion, or erosion on the production casing strings. Sincerely, [~rr~ion Engineer .4u o ? 1995 A subsidiary of USX Corporation Environmentally aware for the long run. SENT BY'Mararh0n 011 Company ' 8- ~-08 ' 8:46AM ' Anchor age-, 007 276 7542:# 3/ 4 WELL KU 24-55, KENAI GAS FIELD ANNULAR FLOW CONVERSION POTENTIAL PROBLEMS ADDRESSED This conversion will allow gas from the Sterling B- ! Sand (Pool 4) in well KU 24-5s to be produced up the 3W' tubing and 9%" casing simultaneously. This is expected to increase gas deliverability at a Iow cost. Potential problems associated with this type of completion are addressed below. Potential Problem .... ,,, , Erosional Velocity Corrosion Surface Safety Controls Burst/Collapse of Casing Solution The highest potential tbr erosive flow exists at the 2-1/16", 5M flanged outlets of the tubing head. Flow will be out both outlets &the tubing head to reduce velocity. Erosion could potentially occur if flow out the annulus exceeds 12 MMCFD. Marathon plans to produce the well below erosive limits. Also, Marathon will conduct periodic UTT inspection of the wellhead and towlines for signs of unusual wear. Partial-pressure of CO2 is less than 1.0 psi. If the partial pressures of CO2 is less than 7 psi the gas is generally considered noncorrosive, Furthermore, there is no H2S produced in the Kenai Gas Field. Corrosion of the casing is highly unlikely, The annulus will be produced via a separate towline from the existing tubing completion. Surface safety controls will be similar to that of other Kenai Gas Field completions, Pressures imposed on the 9%" casing during this procedure will not compronfise the integrity of the casing. Worst-case forces will not exceed 53% of the rated ~a~sing burst or collapse. . ........... O:~EXCEL~,ogcc01 .xls 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 Time Extension Stimulate Change Approved Program Pull Tubing Variance Perforate Other X 2. Name of Operator 5. Type of Well: 6. Datum Elevation (DF or KB) MARATHON OIL COMPANY Development X 29 feet 3. Address Exploratory 7. Unit or Property Name P. O. Box 196168, Anchorage, AK 99519-6168 Stratigraphic Kenai Unit 4. Location of Well at Surface Service 8. Well Number 332' FNL, 4331' FWL, Sec. 7, T4N, RllW, S.M. KU 24-5s At top of Productive Interval 9. Permit Number 82-98 At Effective Depth Convert to Annular Flow lo. APl Number 50- 133-20358 At Total Depth 11. Field/Pool 1336' FSL, 1763' FWL, Sec. 5, T4N, R1 lW, S.M. Kenai Gas Field, Pool 4 12. Present Well Condition Summary Total Depth: measured 5900 feet Plugs (measured) Cement retainer @ 4886' MD true vertical 4988 feet Effective Depth: measured feet Junk(measured) true vertical feet Casing Length Size Cemented Measured Depth True Vertical Depth Structural Conductor 136' 20" Driven 136' 136' Surface 2012' 13-3/8" 1500 sks 2012' 1864' Intermediate Production 5900' 9-5/8" 1800 sks 5900' 4988' Liner Perforation Depth: measured B-1: 4498' - 4553' MD true vertical B-l: 3854' - 3897' TVD Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 tubing to 4450' MD Packers and SSSV (type and measured depth) Baker model A-5 dual packer @ 4439' MD Baker model D packer @ 4607' MD ,Anchorag~ 13. Attachments Description Summary of Proposalm Detailed Operations Program X BOP Sketch , , 14. Estimated Date for Commencing Operation 15. Status of Well Classification as: 8/5/98 16. If Proposal was Verbally Approved Oil Gas X Suspended Name of Approver Date Approved Service i7. I hereby certify that the foregoin~ is true and correct to the best of my knowledge. Signed~ ,~~~ Title Production Engineer Date 7/30/98 \ -- co ss o. Conditions of Ap v .' N~y~mmission so representative may witness ~' Iii' "r'",~- IAppr°val Pl~tegrity __ BOP Test Location ~learance Mechanical Integrity Test Subsequent Form Required 10- m/~ I Form 10-403 Rev. 06115/88 Subrr ' ITripi]'cate Approved Copy Retqrned Alaska RUgion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 July 28, 1998 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99513-7599 Reference: Kenai Gas Field, Wells KU 11-8s, KU 24-5s, and KU 43-6al Dear Mr. Wondzell' Please find attached procedures for permitting annular flow in wells KU 11-8s, KU 24-5s, and KU 43-6al in Kenai Gas Field. The increased flow area by producing up the production casing and tubing simultaneously is expected to double the well's gas deliverability. Flow up the production casing will not subject the well to excessive wear from erosion, corrosion, or burst/collapse stresses. This work is expected to commence early August 1998. Please contact me if further information is needed. on Engineer M:\WP\OPNS98~JGE728. Enclosure A subsidiary of USX Corporation Environmentally aware for the long run. WELL KU 24-5S- AFE 0481998 KENAI GAS FIELD CONVERT TO ANNULAR FLOW Obiective: Allow flow up the tubing-casing annulus in well KU 24-5s to increase gas deliverability. Procedure: 1. Shut in both sides of well KU 24-5. MIRU slickline on KU 24-5s. Test BOPs and lubricator to SITP. Set PXN plug in XN nipple (ID = 2.635") at 4,450' MD. Verify proper setting of mandrel in nipple using check-set tool. RDMO slickline. 2. MIRU nitrogen unit on KU 24-5. Using nitrogen, pressure test 9%" casing to 1,900 psig. Monitor 13%" casing for potential communication. When test is complete, bleed all pressure off 9%" casing. Note: If volume of nitrogen pumped indicates annular fluid level is low, we may be able to reduce the pressure test requirement on the casing. 3.When casing is completely bled down, remove blind flange on tubing spool across from the existing 9%" casing valve. Have the existing casing valve open to atmosphere while performing this operation. If applicable, remove VR plug from the new outlet. Install a newly tested 2-1/16", 5M gate valve on the outlet. When that valve is completely installed, pull off.the old 2-1/16", 5M gate valve and replace it with one that is newly tested. Send old gate valve in for testing. Close both gate valves when complete. 4. RU nitrogen unit on KU 24-5s. Using nitrogen, pressure test PXN plug to 1,900 psig. Do not bleed off.tubing when .complete. RD nitrogen. 5. MIRU slickline. Test lubricator and BOPs to SITP. MU tool string with XA shifting tool, spang jars, & oil jars. RIH and locate XA sliding sleeve at 4427' MD. Shift open sliding sleeve at 4427' MD while monitoring tubing and casing pressure. POOH. RDMO slickline. 6. Bleed all nitrogen pressure off of tubing. 7. RU nitrogen unit on 9%" casing of KU 24-5. Pump nitrogen down casing, taking fluid returns on tubing to catch tank. Do not exceed casing test pressure. Continue until nitrogen is blowing around the tubing, then shut in the tubing. RD nitrogen. Note: Leave at least 500 psig on the tubing and casing after shutting in. If necessary, apply necessary pressure with nitrogen. 8. MIRU slickline on KU 24-5s. Test BOPs and lubricator to SITP. Pull PXN plug at 4,450' MD. RDMO slickline. Well KU 24-5s Convert to Annular Flow Page 2 9. As soon as possible, produce well at maximum flow rate up tubing to clear any residual packer fluid from wellbore. Put well in test separator, and record flow rate and tubing pressure. 10. Shut in KU 24-5s. Install flowline to produce out both sides of the tubing head on KU 24-5s. When complete, flow casing side and tubing side simultaneously to test separator and compare with previous test. When testing is complete, produce as per instructions of' Production Foreman. JGE July 27, 1998 N:kDRLGkKGF~WELLSkKu24-5s~ANNFLOW. WPD Kenai Gas Field Well KU 24-5, Pad 41-7 Marathon Oil Co., Alaska Region RT-GL: 29.0' 322'S & 4331' E of NW Comer Sec. 7, T4N, RI 1W Shortstring Tubing: 3-1/2", 9.2#, N-80, Butt. Otis "3LA" Sliding Sleeve ~ 4427' ID = 2.750"? Baker A-5 Dual Packer ~ 4439' Otis "XN" Nipple @ 4450' ID = 2.635" Shortstring Perfs B-I 4498' - 4553' DIL (8/4/82) Longstring Perfs B-3 4691' - 4731' DIL (8/4/82) B-4 4789' - 4864' DIL (8/4/82) B4 4899' - 4909' DIL (Sqzd) 900' 20", 94#, H40 Drive pipe ~136' 13-3/8", 61#, K-55, BTC Casing ~ 2012' Cmt w/1500 sks of Class G Longstring Tubing: 3-1/2", 9.2#, N-80, Butt. Otis "XA" Sliding Sleeve (~4401' ID = 2.750"? Blast Joints 4480' - 4578' Otis "XA" Sliding Sleeve @ 4587' ID = 2.750"7 Opened 3/21/91.9?? Loeator sub @ 4606' Baker Model "D" Packer (~ 4607' Otis "X" Nipple @ 4633' ID = 2.750" Muleshoe (8 4644' Fill @ 4781' WLM (8/27/93) Cement retainer @ 4886' 9-5/8", 47#, N-80, BTC Casing ~ 5900' Cmt w/1800 sks of Class G Last Rev: JGE, 7/27/98 ALASKA OIL A/tD GAS CO#$E£VATIO# CO.'-fMISSIOT~ DATE: TO: RE: Well Lo'c. Permit No. / - i · _ Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501'-3192 TELEPHONE (907) 279-1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well which our records indicated was completed ~J~--z~-~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, · ~, Chat~' Chairman RECEIVED Alaska Oil & &as Cu,~s. Commission Anchr}m,.qe WoCo ~79.86 East NW Corner SEC. 7 SCALE 1" = 300' 4331' N.T.S. LEGEND AND NOTES: Found G.L.O. brass cap monument. Center of Cellar~Set H+T~ Lat. 60-27-30.875 N -- Long. 151-14-42. 563 W ~ X= 275,233.42 ~.... m Y= 2,361,662.95 ~ ~ .,.~'~' PP // ~ o ~ G:.!5 ~ ~2, 32 .~? ll Ail bearings refer to the West line of Section 7 as being North. Top of gravel pad elevation is 77.2 feet above MLLW of Cook Inlet or 66.1 feet above Mean Sea Level. Basis of coordinates is USC&GS Tri Station AUDRY 'in ASP Zone 4. Z~ AUDRY Lat. 60-3'0-50.559 N Long.151-16-37.445 W X= 269~866.75 Y= 2,382,045.42 · Added ref. bearing for drill rig, 7/15/82 K.U. 24-5 ,i ., PREPARED FOR UNION OIL COMPANY OF CALIF. OPERATOR i ~ SURFACE LOCATION: 332 Ft. South and 4331 Ft. East from the NW Corner Section 7, T4N, RllW, S.M.',..Alaska Surveyed by: McLane & Associates, Inc Date of Survey: June 18, 1982 Bk.No. 82-23 RECEIVED AUG 2 ! 19B4 Al~.~ka rill ~ ~-' .... ~ .............. ..... ,..,, ,,~, UUI l Il i II))ll,,llJ Anchorag~ .-~ , -- .,'.j ~ STATE OF ALASKA '-' d ALASK/'~-.!L AND GAS CONSERVATION C, .~4MISSION //~ W'ELL COMPLETION'OR RECOMPLETION REPORT AND LOG -1. Status of Well ' Classification of Service Well · OIL [] GAS [] SUSPENDED [] ' ·ABANDONED [] SERVICE [] · 2. Name of Operator 7. Permit Number UNION 0IL COMPANY OF CALIFORNIA 82-98 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 5o_133-20358 4. Location of well at surface 9. Unit or Lease_Name 322' S & 433 ' E of NW corner, Sec. 7, T4N, RllW, SM. KENAI UNIT At Top Producing Interval 10. Well Number KU #24-5 At Total Depth 11. Field and Rool KENAI GAS FIELD 5. Elevation in feet (indicate KB, DF, etc.} I 6. Lease Designation and Serial No. I A-028142 STERLING ROOL · , 12. Date Spudded7/16/82 13. Date I.D. Reached7/28/82 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116' N~' °f C°mpleti°ns08/08/82 ----- feet MSL .17. Total Depth (MD+TV·D) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafros't I YES [] NO [] feet MD 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD ~CASlNGSIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED . · , . , . · 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) ' . 261 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMouNT& KIND OF MATERIAL USED · . . 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 8!/-'17/82: ~ . ..._ J.. - · ~Flowing . .- '- ' Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 8/9/82 24 TEST PERIOD [~ 8500/7500 Flow Tubing :- Casing Pressure ' CALCULATED ..~' OILLBBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 750# .... . 24-HOUR RATE"~ 8500/7."00 ,, · 28. . : , . -. : - ; CORE DATA Briefde~cripti~n~f~ith~~~gy~p~r~si~y~fractures~apparentdip~andpre~ence~f~i~~gas~rwater~Submitc~rechips. · .. . OCT 1 19/)2 Alaska 0il & Gas Cons, - ,,o A~hora~e Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE Document Transmittal Union Oil Companv of Califor union HAND DELIVERY DATE SUBMITTED ACCOUNTING MONTH 9/17/82 TO Mr. William Van Alen FROM R.C. Warthen Alaska Oil & Gas P.O. BOx 6247 AT Conservation Commission ~^T Anchorage, AK 99502 3001 Porcupine Drive An~.h~r~g~ .- AK TELEPHONE NO. TRANSMITTING THE FOLLOWING: KU 24-5 1 ea blueline and sepia of the following: DIL 2" & 5" DT,T, 5" OH VDL/GR 5" BHC-sonic 5" & 2" LD/GR 5" .~.~ ..~. '~" --= LDT/C~L/GR 5" ACBL 5" i ea of the following: Dir Surveys o° ~, CT,] Angle-Ave FORM 1-2M02 (REV, I 1-72) PRINTED IN U.S.A. STATE OF ALASKA ...,N HLY REPORT OF DRILLING AND WORKOVER OPERATIONS , Drilling well~ Workover operation [-I I/~~' 2. Name of operator 7. Permit No. UNION OIL COHPANY OF CALIFORNIA 82-98 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 133-20358 4. Location of Well at surface 332'S & 4331'E of NW Corner, Sec. 7, T4N, RllW, SM. 5. Elevation in feet(indicate KBpad 66' MSL , DF, etc.)I 6. Lease Desig~a.t~Ld~rial No. 9, Unit or Lease Name KENAI UNIT 10. Well No. KU #24-5 11. Field and Pool KENAI GAS FIELD STERLING POOL For the Month of, August ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 5900 TD - 4886 ETD Released Rig ~ 24:00 hrs. 8/10/82 13. Casing or liner run and quantities of cement, results of pressur9 tests Tested 9 5/8" csg to 3000 psi-OK 14. Coring resume and brief description None 15. Logs run and depth where run CBL-VDL-GR f/ 5800'-1800' 16. DST data, perforating data, shows of H2S, miscellaneous data Perf & Sqz'd 4899-4909 MD w/ 300 sxs, Perf'd 4789-4864 MD 8 HPF 4691-4731 8 4498-4553 8 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 'SI ITLE_ DIST DRLG SUPT DATE 8/30/82 _~.~ port on this orm is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska ~fFand Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate ...... ALASKA G~-AND GASCONSERVATION COL....41SSION WELL COMPLETION OR RECOMPLETION REPORT AND 1. Status of Well Classification of Service Well \ OIL [] GAS[] SUSPENDED I--]~ . ~ ABANDONED.[] SERVICE [] Shut-~_n 7. Permit Number 2. Name of Operator UNION 0IL COMPANY OF CALIFORNIA 82-98 3. Add~e6s BOX 6247 ANCHORAGE AK 99502 50- 4. Location of well at surface 9. Unit or Lease Name 322'S& 4331' E of'NW corner, Sec. 7, T4N, RllW, SM. KENAI UNIT At Top Producing Interval 10. Well Number 9i4' N & 1044' E of SW corner, Sec. 5, T4N, RllW, SM. KU #24-5 At Total Depth 11. Field and Pool 1336' N & 1763' E of SW corner, Sec. 5, T4N, RllW, SH. KENAI GAS FIELD 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. - . PAD 66' MSL A-028142 STERLING POOL ,12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. 115. Water Depth, ifoffshore 116. No. of Completions .. 7/16/82 7/28/82 08/08/82 ------ feet MS L 2 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of PermafroSt 5900 ' & 4965 ' 4886 ' ETD y ES ~] N 0 [] feet M DI , ,, 22. Type Electric or Other Logs Run DIL-13HC-SONIC-VDL-SP-GR, LDT-CNL-GR, HLL-GR, CBL-VDL-GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" ~4# H-4U ' O, 136, Driven Driven --- 13 3/8" 61# K-55 0, 2012, 17 1/2" 1500 sxs --- 9 5/8,, 47#- N-80 0' 5900, 12 1/A" 1800 sxs --- . 24. Perforations open. to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, siz~ and number) f/~ sIZE DEPTH SET (MD) PACKER SET (MD) POOL MD TVD HPF 3 1/2" 4645 4606 5.1 B-4 4789-4864 4068-4128 , 8 ~3 1/2" 4452 4442 5.1 B-3 4691-4731 3990-4022 8 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. .... 4 B-1 4498-4553 3838-3881 ~ : 8 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4899-4909 300 sxs cl "G" 27. PRODUCTION TEST Da~eF,.i~st Production : ~ ' I .,- , · Method of'Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-MCF WATER-BBL CHOKE sIZE IGAS-OILRATIO TEST PERIOD:II~ FioW Tubing . .Ccnsing pressure CALCUL_A~ED~ OIL~BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ch'ips. NONE ~ AUG 2 ? ]982 : i , ~'~' ~' :' :. , ,Alaska 0ii & Gas Cons. Comrnissj£ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ GEOLOGIC MARKERS 'FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. B-4 4789-4864 ND= 8.60 HHCFPD w/ 4.8 BWPD ® 815 psi. T/Sterling 4256' 3648' .B-3 4691-4731 MD & B-1 4498-4553 MD.=9.75 FM. Gas Sands N~CFPD Dry $ 825 psi. Final LS test = 7.53 NHCFPD w/ 13.2 BWPD $ 755 psi-3 hour test. T/Beluga FH :.. 5630' 4745" Final SS test = 8.32 MHCFPD w/ 1.6 BWPD' $ 715 psi-3 hour test. 31. LIST OF ATTACHMENTS , 32. I hereby~ify that the foregoing is true and c°rrect to the best of my knowledge Signe Title DIST DRLG SUPT Date 8/25/82 ... /"/' -, ~,- INSTRUCTIONS General: This fort~ is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. .Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE Kenai Unit FIELD Kenai Gas Field WELL NO. KU #24-5 LOCATION: 322'S & 433'E of NW corner~ . Section 7~ T4N~ RllW~ SM. SPUD DATE ?/16/82 CONTRACTOR Brinkerhoff TYPE UNIT SHEET A ~' PAGE NO. 1 COMP. DATE 8/8/82x~ RIG NO. 59 ; - DRILL PIPE DESCRIPTION 5" 195# 4 1/2" IF PERMIT NO. 82-98 SERIAL NO. A-028142 TD 5900' (MD) TVD 4965' DEVIATION (BHL) COMPANY ENGINEER Watson~. Abe.~nathy ELEVATIONS: WATER DEPTH RT TO OCEAN FLOOR RT TO~GL RT TO DRILL~O..EC~ RT TO PRODWCTIO~C~- CASING & TUBING RECORD'"/~/' SIZE NEIGHT THREAD GRADE DEPTH REMARKS 20" 94# Drive Pipe H-40 136' Driven 13 3/8" 61# Buttress K-55 2012' Cmt'd w/ 1200 sxs "G" omt& 2 1/2% -- prehy¢ gel & 2% CaCL2. 300 sxs w/ 2% CaCL2 tail slurry 5/8" 47# ButtresS N-80 5900' 1800 sxs "G" cmt w/ 5% kcl, 0.8% D-28 3 1/2". 9.2# Buttress N-80 0.4% D-31~ 0.4% D-47 & 0.2% D-6. LS 4464' A-5 dual pkr e 4442' SS 4450' " " PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 8/2/82 4899-4909' 5810' Isolation Sqz B-4 Sq,z w/ 300 sxs 8/4/82 4789-4864' 4886' (Ret) Production B-4 8 HPF - Open to production 8/6/82 4691-4731' 4886' (Ret) Production B-3 4498-4553' " B-1 8 HPF - Open to ,production II (Note: 4 HPF w/ 2 1/8" guns used on B-is 8-3 & 8-4 sands. 4 HPF w/ 4" gun,s, r,eperfed same intervals of B-l, B-3 & B-4). INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.R. T.R. CHOKE MCF GOR REMARKS WELL HEAD ASSEMBLY TYRE: Cameron CASING HEAD: CIW 13 3/8" SOW x 12" 3M csg head CASING HANGER: 9 5/8" CIW Type "AW" TUBING HEAD: 12" 3M x lC" 5M DCB CIW Spool TUBING HANGER: Dual Cameron 3 1/2" "DCB-B" 8rd TUBING HEAD TOP: 3 1/2" 8rd EUE MASTER VALVES: 3 1/16" 5000 psi CHRISTMAS TREE TOP CONN: 3 1/2" 8rd LEASE Kenai Unit UNION OIL COMPANY OF CALIFORNIA NELL RECORD SHEET D PAGE NO. WELL NO. KU #24-5 FIELD Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 13 3/8" CASING DETAIL OTS DESCRIPTION LENGTH TOP BTM 49 B&W Float Shoe Ot 61# K-55 Buttress B&W Float Collar Ots 61# K'55. Buttress KB to Top CIW Csg Head 1.83' 2010.17' 2012' 40.26' 1969.91' 2010.17' 2.20' 1967.71' 1969.91' 1937.33' 30.38' 1967.71' 30.38' 0 30.38' *Cmt'd w/ 1200 sxs cl "G" cmt w/ 2% CaCL2 and 2 1/2% prehyd gel. Followed by 300 sxs cl "G" cmt w/ 2.% CaCL2 mixed in fresh H20. Displ w/ 28 bbls of mud. Had good returns to surface. CIR 8 21:30 hrs 7/19/82. 9 5/8" CASING DETAIL JTS 24 105 DESCRIPTION LENGTH TOP BTM ,, B&W Float Shoe Ors 47# N-80 Butt B&W Float Collar Ots 47# N-80 Butt Split Jt 47# N-80 Butt Ors 47# N-80 Butt Split Jt 47# C-95 Butt Jts 47# N-80 Butt KB to Top CIW Csg Head 1.70' 5898.30' 5900.00' 87.10' 5811.20' 5898.30' 1.50' 5809.70' 5811.20' 1023.98' 4785.72' 5809.70' 41.42' 4744.30' 4785.72' 258.89' 4485.41' 4744.30' 42.85' 4442.56' 4485.41' 4413.06' 29.50' 4442.56' 29.50' 0 29.50' *Cmt'd w/ 1800 sxs cl "G" cmt w/ 5% kcl, 0.8% D-28, 0.4% D-31, 0.4% D-47, and 0.2% D-6. Displaced w/ mud. Got good returns to surface. CIP ~ 17:35 hfs 7/30/82. LEASE Kenai Unit UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. KU #24-5 FIELD SHEET D PAGE NO. Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS OTS DESCRIPTION LONG STRING TUBING DETAIL LENGTH TOP BTM , , , 86 46 Mule Shoe 3" ID, 3.865" OD Pup 3 1/2" Butt N-80 9.2# Otis X-Nipple Pup 3 1/2" Butt N-80 190-47 Baker Seal Assembly 190-47 Baker Locator Pup 3 1/2" Butt N-80 Pup 3 1/2" Butt N-80 Otis XA Sliding Sleeve Pup 3 1/2" Butt N-80 Blast Jts 3 1/2" Butt N-80 Tbg A-5 Dual Pkr 3 1/2" Butt N-80 Tbg Otis XA Sliding Sleeve 3 1/2" Butt N-80 Tbg Pup 3 1/2" Butt N-80 3 1/2" Butt N-80 Tbg Pup 3 1/2" Butt N-80 ~ 1/2" Butt N-80 Tbg Pup 3 1/2" Butt N-80 ~ 1/2" Butt N-80 Tbg Pup 3 1/2" Butt N-80 XO 3 1/2" 8rd Hanger (CIW 3 1/2" Dual) RT 0.65' 10.05' 1.5' 10.29' 15.79' 0.80' 4.74' 10.11' 3.92' 9.10' 98.30' 31.13' 12.75' 30.82' 3.92' 2628.23 ' 2.95' 179.85' 4.03' 1405.06 ' 2.7' 123.31 ' 26.63 ' 0.5' l' 26.95' 4644.43' 4634.38' 4632.88' 4622.59' 4606.80' 4606.00' 4601.26' 4591.15' 4587.23' 4578.13' 4479.83' 4448.70' 4435.95' 4401.21' 1772.98' 1770.03' 1590.18' 1586.15' 181.09' 178.39' 55.08' 28.45' 27.95' 26.95' 0 4645.08' 4644.43' 4634.38' 4632.88' 4622.59' 4606.80' 4606.00' 4601.26' 4591.15' 4587.23' 4578.13' 4479.83' 4448.70' 4435.95' 4405.13' 4401.21' 1772.98' 1770.03' 1590.18' 1586.15' 181.09' 178.39' 55.08' 28.45' 27.95' 26.95' LEASE Kenai Unit UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. KU #24-5 FIELD SHEET D PAGE NO. Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS OTS 42 27 43 14 DESCRIPTION SHORT STRING TUBING DETAIL XN Nipple Otis A-5 Dual Pkr Pup 3 1/2" Butt N-80 9.2# Otis XA Sliding Sleeve Pup 3 1/2" Butt N-80 Pup 3 1/2" Butt N-80 Pup 3 1/2" Butt N-80 Pup 3 1/2" Butt N-80 Ors 3 1/2" N-80 Butt 9.2# Tbg Pup 3 1/2" Butt N-80 Ots 3 1/2" N-80 Butt Pup 3 1/2" Butt N-80 Ots 3 1/2" N-80 Butt Jts 3 1/2" N-80 Butt PUp 3 1/2" N-80 Butt Ots 3 1/2" N-80 Butt Pup 3 1/2" N-80 Butt Sts 3 1/2" N-80 Butt Pup 3 1/2" N-80 Butt XO 3 1/2" 8rd CIW 3 1/2" Dual Hanger RT LENGTH TOP 1.91 ' 4450.06' 10.61 ' 4439.45' 9.0' 4430.45' 3.90' 4426.55' 8.02' 4418.53' 6.12' 4412.41' 3.-85' 4408.56' 3.12' 4405.44' 1282.94' 3122.50' 3.0' 3119.50' 272.18' 2847.32' 5.10' 2842.22' 824.48' 2017.74' 1314.89' 702.85' 4.8' 698.05' 211.36' 486.69' 2.32' 484.37' 427.12' 57.25' 28.80' 28.45' 0.5' 27.95' 1' 26.95' 26.95' 0 BTM , , 4451.97' 4450.06' 4439.45' 4430.45' 4426.55' 4418.53' 4412.41' 4408.56' 4405.44' 3122.50' 3119.50' 2847.32' · 2842.22' 2017.74' 702.85' 698.05' 486.69' 484.37' 57.25' 28.45' 27.95' 26.95' CONTRACTOR Brinkerhoff Si§hal Inc. OIL COMPANY Union Oil Company RIG NO. 59 BIT RECORD LEASE/WELL NO. KU #24-5 COUNTY Kenai STATE FIELD/TOWN Alaska TOOL PUSHER , DR ....... DR .............. DR .... SEC/TSHIP/ RAN_GE .... Sec. 7, T4N, RllW, SM. RIG MAKE SHEET TOOL & MODEL RECORD NO. NO. $OINTS MAKE 1F SIZE TYPE 4 1/2 OD 6 5/8" NO. 1 PUMP UNDER MAKE & MODEL Emsco F-lO00 Liner 6 1/2 SPUD DATE 7/16/82 SURF DRILL COLLARS NO OD ID LENGTH NO. 2 PUMP MAKE & MODEL Oilwell lO00-P Liner 6 INTER TD DRILL COLLARS NO OD ID LENGTH WT RUN SETS 32ND BIT DEPTH FOOT- ACCUM 1000 VERT PUMP No 1 No. 2 MUD DULL COND REMARKS NO_,J SIZE MAKE T.Y~E ..... 1 2. 3 ......._SER NOr.._ OUT AGE.. .... H.qURS ...HOURS LB. RPM... DEV.._ PRESS SPM LIN SPM LI_N ....... .WT .V.!S T ...B _G (FAILURE,_ ETC_,) 1RR Sec 17 1/2 S35J 16 16 16 2 3 4 5 7 8 8 8RR ~RR " " 20 20 20 " " 12 13 13 " " 13 13 13 HTC 12 1/4 X3A 3 13 13 " " 13 13 0 " " 13 13 0 Sec 12 1/4 S33S 13 13 0 " " 13 13 0 " " 13 13 0 Sec 8 1/2 S44G .16 16 16 " " Open 130100 300 264 151834 800 500 122290 1685 885 121416 2028 343 MM869 ST705 SX198 248814 I! Il 268189 3341 1313 4573 1232 5564 981 5900 326 5809 12 3 39 50/120 1100 67 6.5 55 6 65 110+ 1 1 I 7.5 52 2300 58 6.5 48 6 68 110 1 2 I Dyna Drill 6.5 94.6 110 2300 54 6.5 45 6 70 78 1 1 I 4 94.6 110 2300 58 6.5 48 6 72 68 1 1 I 10.5 75 100 2200 92 6.5 70 49 2 2 I 14 75 100 2200 92 6.5 72 52 5 2 I 10.5 75 ll5 2200 92 6.5 69 49 Inc. Stuck pipe w/ bit CO to btm '6 70 110 2200 92 6.5 .5 15 60 1650 100 6.5 60 6 70 69 1 2 I Wiper Run 70 54 1 1 I Drlg cmt Displacement run TUBING DETAIL ZC/C/S I. 31/2" OTIS "XA" SLIDING SLEEVE AT 4,401.2!1' 21. BAKER A-5 DUAL PACKER AT 4,435.95' ,5. BLAST dOINTS FROM 4,479.83' TO 4,578.13 4. 31/2" OTIS "XA" SLIDING SLEEVE AT 4,587.2_3' 5. BAKER LOCATOR SUB AT 4,606.00' 6. BAKER PACKER W/16' SEAL ASSY AT 4,606.80' 7. 31/2" OTIS "XN" NIPPLE AT 4,63£.88' 8. MULE SHOE AT 4,644.43' . A. 31/21" OTIS "XA" SLIDING SLEEVE AT 4~426.55' B. BAKER A-5 DUAL PACKER AT 4~4:59.45' C. 31/2_" OTIS "XN" NIPPLE AT 4,450.06' PERFORATION RECORD D/ITE //I/TE£//4L 8/4/82 4789' - 4864' B-4 Sd. PRODUCTION 8/6/82 4691' - 4731' B- 3 Sd. PRODdCTION " 4498' - 455:5' B- t Sd. PRODUCTION KU 24-5 OI 26.95' II 20,94~,H-40 DRIVE PIPE AT 136' 13 3/8", 61¢~ K- 55 CASING AT 2,012' 9 5/8", 47¢, N-80 CASING AY 5,900' unl, n KU 24-5 WELL SCHEMATIC COMPLETED'. 8/8/82 WelIKU 24-5 [Field KI~NAI Count~/ KENA! ~Oate 12/13/82_. Drawn By B.W. JChecked By Approved By UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142. WELL NO. KU #24-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS A 7/13/82 DAILY COST: $ 51,392 ACC COST: $ 51,392 AFE AMT' $2,300,000 -B 7/14/82 DAILY COST: $ 120,893 ACC COST: $ 172,375 AFE AMT: $2,300,000 C 7/15/82 20" D. 136' :DAILY COST: $ 44,422 ACC COST: $ 216,797 AFE AMT: $2,300,000 1 7/16/82 300'/264' 20" D. 136' 65 RCF ilO SEC DAILY COST: $ 38,137 ACC COST: $ 254,934 AFE AMT: $2,300,000 2 7/17/82 DAILY COST: ACC COST: AFE AMT: 1197'/897' 20" D. 136' 68 PCF 110 SEC $ 54,187 $ 309,121 $2,300,000 Commenced operations 00:01 hrs 7/13/82. RU Brinkerhoff Rig #59 on location. RU Brinkerhoff Rig #59 on location. RU Brinkerhoff Rig #59 on KU #24-5 location. Commenced operating rate ® 10:30 hrs. Drove 20" to refusal ® 136' RKB. Installed 20" SOW flange on 20". Weld 20" flange on csg & installed diverter. Welded on diverter lines. Spud well @ 14:00 hrs. Drld 17 1/2" hole f/ 36' to 300'. POOH. RIH w/ bit #2 on BHA #2 for Dyna Drill Run #1. Ran gyro surv. RU steering t-6-61. Survey: 274' 1° S56E Oriented dyna drl after confirming no magnetic interference. Dyna drld 17 1/2" hole f/ 300-800'. POOH. RIH w/ bit #3 on BHA #3 (angle bldg assy). Reamed dyna drl run f/ 275' to 800' & dir drld 17 1/2" hole f/ 800' to 1197'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 ~ELL NO. KU #2~-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 3 7/18/82 DAILY'COST: ACC COST: AFE AMT: 4 7/19/82 DAILY COST: ACC COST: AFE AMT: 5 7/20/82 DAILY COST: ACC COST: AFE AMT:' 2028'/831' 20" D. 136' 70 PCF 78 SEC $ 35,&66 $ 344,287 $2,300,000 2028'/0' 20" D. 136' 13 3/8" C. 2012' 72 PCF 68 SEC $ 163,365 $ 509,652 $2,300,000 2028'/0' 20" D. 136' 13 3/8" C. 2012' 72 PCF 68 SEC $ 35,963 $ 545,615 $2,300,000 Surveys: 325' 1° N82E 415' 2° 45' N60E 506' 5° N41E 597' 7° 30' N46E 689' 10° 15' Na5E 760' ll° 30' N49E All surveys taken w/ SDC single shot. Dir drld 17 1/2" hole f/ 1197' to 1685'. POOH. RIH w/ bit #4 on BHA #4 (30' belly). Dir drld 17 1/2" hole f/ 1685' to 2028'. Circ & POOH. RIH for wiper trip - replaced HWDR w/ regular DR. Cond hole for 13 3/8" csg. .Ran 13 3/8" 51# K-55 butt csg to 2012'. Cmt'd thru DP w/ 1200 sxs "G" w/ 2 1/2% pre-hydrated gel & 2% CaCL2 & tall slurry of 300 sxs "G" w/ 2% CaCL2. Had very good returns to surf. CIP ~ 21:30 hrs. POOH w/ DP. Install & test 13 3/8" SOW csg head. NU 13 5/8" BORE. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #24-5 FIELD KENAI GAS FIELD DATE ETD DETAILS'OF OPERATIONS, DESCRIPTIONS & RESULTS 6 7/21/82 DAILY COST: ACC COST: AFE AMT: 7 7/22/82 DAILY COST: ACC COST: AFE AMT: 8 7/23/82 DALLY COST: ACC COST: AFE AMT: 9 7/24/82 DAILY COST: ACC COST: 2882 '/854 ' 20" D. 136' 13 3/8" C. 2012' 69 PCF 63 SEC $ 29,715 $ 575,330 $2,300,000 4080'/1198' 20" D. 136' 13 3/8'~ C. 2012' 70 PCF 49 SEC $ 34,249 $ 609,579 $2,300,000 4980'/900' 20" D. 136' 13 3/8" C. 2012' 72 PCF 52 SEC $ 30,197 $ 639,776 $2,300,000 5564'/584' 20" D. 136' 13 3/8" C. 2012' 73 PCF 49 SEC $ 43,038 $ 682,814 Tested BOPE. RIH w/ bit #5 on BHA #5 (slick assy). Tagged FC ~ 1968'. Tested csg to 2500 psi. Drld out FC $ 1968' & CO cmt to 2002' & re- tested csg to 2500 psi. Drld out shoe 8 2012' & drld new hole to 90 PCF equiv w/o leakoff. POOH. RIH w/ bit #5 on BHA #6. Dir drld 12 1/4" hole f/ 2038' to 2882'. Dir drld 12 1/4" hole f/ 2882-3341'. POOH. RIH w/ bit #6 on BHA #7. Dir drld 12 1/4" hole f/ 3341' to 4080'. Dir drl 12 1/4" hole f/ 4080-4573'. POOH. Hole tight on trip out f/ 3773-3855' & f/ 3588-3240'. RIH w/ bit #7 on BHA #8. Ream tight spots f/ 3240' to 3301', 3434' to 3803' & f/ 4440' to 4573'. Dir drl 12 1/4" hole f/ 4573-4980'. Dir drill 12 1/4" hole f/ 4980' to 5564'. Stuck pipe while surveying w/ bit ~ 5544'. Ran Alaska pipe recovery system free point. (Had tool failure on 1st attempt.) Determined pipe free $ 4356' & stuck ® 4376'. ROOH w/ free point. AFE AMT: $2,300,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #24-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 10 7/25/82 DAILY COST: ACC COST: AFE AMT: 11 7-26-82 DAILY COST: ACC COST: AFE AMT: 12 7/27/82 5564'/0' 20" D. 136' 13'3/8" C. 2012' 69 PCF 49 SEC $ 33,054 $ 715,868 $2,300,000 5564'/0' 20 "D. 136' 13 3/8"-C. 2012' 70 PCF 73 SEC $ 27,071 $ 742,939 $2,300,000 5742'/178' 20 "D. 136' 13 3/8" C. 2012' 69 PCF 65 SEC DAILY COST: $ 71,662 ACC COST: $ 814,601 AFE AMT: $2,300,000 13 7/28/82 DAILY COST: ACC COST: 5900'/158' 20" D. 136' 13 3/8" C. 2012' 70 PCF 69 SEC $ 32,484 $ 847,085 Circ & cut MW to 69 PCF. Mixed 25 bbls black maglc SFT $ 56 PCF & pump 1nrc DP.Mixed another 231 bbls black magic SFT $ 70 PCF. Displaced black maglc SFT around flsh f/ 5564' to 3942' w/ 15% excess in OH. Left 46 bbls inside DP. Black magic SFT in place ® 12:45 hrs. Move 1/2 bbl every 1/2 hr & work plpe. Move SFT 1/2 bbl every 1/2 hr & work pipe. Pipe came free ¢ 06:45 hrs. (17 1/2 hrs after in place). POOH. Changed BHA & jars. RIH w/bit #8 on BHA #9 Circ Clean ~ 2000'. RIH to 2500' &circ clean - catching SFT in holding tanks. Ream f/ 2510' to 2570' & RIH to 2875'. Circ out SFT. RIH to 3089'. Ream f/ 3089' to 3263'; RIH to 4000'. Circ & cond mud ~ 4000'. RIH to 4472'. Ream f/ 4472' to 4484'. Circ & cond mud. Ream f/ 4484' to 4512'. RIH to 5035'. Circ & cond mud. RIH to 5539'. Ream f/ 5539' to 5564'. Dir drill 12 1/4" hole f/ 5564' to 5742'. Dir drill 12 1/4" hole f/ 5742' to 5900'. Circ & cond mud & hole for logs Trip to shoe. Bridges on trip in $ 5227' & 5506'. Circ & cond mud. Trip to shoe. No bridges. Circ clean. POOH. Rig up Schlumberger. AFE AMT: $2,300,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #24-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 14 7/29/82 DAILY COST: ACC COST: AFE ANT: 15 7/30/82 DAILY COST: ACC COST: AFE AMT: 7/31/82 5900'/0' 20" D. 135' 13 3/8" C. 2012' 70 PCF 54 SEC $ 85,410 $ 932,495 $2,300,000 5900 ' T. D. 5810' ETD (F.C.) 13 3/8-" C. 2012' 9 5/8" C. 5900' 71 PCF 49 SEC $ 382,407 $1,314,902 $2,300,000 5900' T.D. 5810' ETD (F.C.) 13 3/8" C. 20i2' 9 5/8" C. 5900' 70 PCF 54 SEC DAILY COST: $ 21,211 ACC COST: $1,335,113 AFE AMT: $2,300,000 17 8/01/82 DAILY COST: ACC COST: AFE AMT: 5900' T.D. 5810' ETD (F.C.) 13 3/8" C. 2012' 9 5/8" C. 5900' 54 PCF $ 40,663 $1,376,776 $2,300,000 Ran DIL-BHC-Sonic-VDL-SP-GR, LDT- CNL-GR & MLL-GR f/ 5900' to 13 3/8" shoe. LDT on LDT-CNL-GR not cor- rect. RIH w/ bit #BRR on BHA #9. C&C for 9 5/8" csg. POOH. Chg to 9 5/8" rams in BOP. Ran 9 5/8" 47# N-80 buttress casing to 5900'. Circ. and reciprocated csg. Pumped 50 bbls of water ahead of 1800 sxs cl "G" w/ 5% kcl, .8% D-28, .4% D-31, .4% D-47, and .2% D-5. Displaced top wiper plug. Bumped plug- ok. CIR e 17:35 hrs. Floats held ok. Removed BORE and landed csg. in slips. Cut off csg. Installed and tested DCB spool to 3000 psi. Installed BORE. Discovered seals on test plug broken. Laid down drilling BHA. Installed new test plug and tested BORE-ok. Installed wear bushing and RIH w/ 8 1/2" bit on 6" DC's. Tagged cement ~ 5788'. Cleaned out to float collar ¢ 5810', Circ and POOH, RU SDC and prep to run gyro survey Ran gyro survey f/ 5800' to surface. P.D.S.D.I. RU Dresser Atlas and ran CBL/VDL/GR log f/ 5800' to 1800'. R.D. Dresser Atlas. RIH w/ 8 1/2" bit to 5810'. Circ. btms up. Tested csg. to 3000 psi. Dumped and cleaned mud tanks. Filled tanks w/ water and began mixing KCL fluid while rigging up separator and test lines. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #24-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 18 8/2/82 DAILY COST: ACC COST: AFE AMT: 19 8/3/82 DALLY COST: ACC COST: AFE AMT: 20 8/4/82 DAILY COST: ACC COST: AFE AMT: 5900 '/0 ' ~810~ ETD (FC) 13 3/8" C. 2012' 9 5/8" C. 5900' 64 PCF BRINE $ 44,527 $1,421,303 $2,300,000 5900 '/0 ' 4886' ETD (RET) 13 3/8" C. 2012' 9 5/8" C. 5900' 64 RCF BRINE $ 68,948 $1,490,251 $2,300,000 5900' TD 4886' ETD (RET) 13 3/8" C. 2012' 9 5/8" C. 5900' 64 RCF BRINE $ 25,721 $1,515,972 $2,300,000 X-over to 3% KCL comp fluid. Set RTTS on 3 1/2" TBG @ 4843'. Displaced tbg w/ nitrogen. Perf'd lower "B-4" sand on 600 psi drawdown f/ 4899' to 4909'. Opened well to test. Tested well. Well died in 1 1/2 hfs RIH w/'press recorder. BHP=1208 psi fluid level ~ 1400'. Killed well. Well taking 75 bbls/hr into perfs. Spot safe-seal pill across B-4 perfs ROOH w/ test tools. Set cmt ret on WL 8 4886' DIL. RIH w/ DR. Sqz'd B-4 perf's f/ 4899' to 4909' w/ 300 sxs "G". W/ 10% Silica Flour 5% KCL .8% D-28, .4% D-31, .4% D-47 & '.2% D-6. Initial rate 4 BRM ~ 1400 psi. Final rate 3 BRM e 1800 psi. FOrmation held 0 psi before sqz & 1550 psi after sqz w/ pumps off. CIR ~ 22:11. CO to 4886' w/ 9 5/8" scrpr & 8 1/2" bit. Set test tools w/ tbg tail $ 4448'. Displaced tbg w/ nitrogen. Inflow perf'd upper "B-4" f/ 4789' to 4864'. Rate 8.60 ~MCFPD w/ 4.8 BWPD $ 815 psi. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #24-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 21 8/5/82 5900' TD 4886' ETD (RET) 13 3/8" C. 2012' 9 5/8" C. 5900' 64 PCF BRINE DAILY COST: $ 45,440 ACC COST: $1,561,412 AFE ANT: $2,300,000 22 8/06/82 DAILY ~COST: ACC COST: AFE AMT: 23 8/07/82 DAILY COST: ACC COST: 5900'T.D. 4886'-ETD (RET) 13 3/8" C. 2012' 9 5/8" C. 5900' 64 PCF BRINE $ 81,016 $1,642,428 $2,300,000 5900' T.D. 4886' ETD (RET) 13 3/8" C. 2012' 9 5/8" C. 5900' 64 PCF BRINE $ 159,061 $1,801,489 Inflow perf'd "B-3" f/ 4691' to 4731' & "B-i" f/ 4498' to 4553'. Final rate 9.75 MMCFPD dry ~ 825 psi. Killed well. Spot 20 RRB safe-seal pill f/ 4886' to 4200'. POOH. Perf'd an additional 4 HPF w/ 4" csg guns on 120° phasing the "B-4" f/.4789' to 4864'. Perforated "B-3" f/ 4691' to 4731' & B-1 f/ 4498' to 4553' w/ 4" csg guns loaded 4 HPF on 120° phasing. RIH w/ 8 1/2" bit & 9 5/8" csg scrpr. CO fill f/ 4876' to 4886' (safe- seal). Circ clean. Perf's not taking fluid. POOH. Ran GR & OB to 4650'. Set baker "D" pkr on WL ¢ 4606'. RIH w/ seals on DP & test pkr ~ 4606'. Layed down drill pipe. Rigged up & ran dual 3 1/2" comp assy. Spaced out & landed tbg w/ LS MS ¢-4645' SS MS ¢ 4452' & dual "A-5" pkr ~ 4442'. Set & tested dual pkr. Installed BPV'S, removed BOPE. AFE AMT: $2,300,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #24-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 24 8/O8/82 DAILY COST: ACC COST: AFE AMT: 25 8/9/82 DAILY COST: ACC COST: AFE AMT.' 26 8/10/82 DAILY COST: ACC COST: 5900' T.D. 4886' ETD (RET) 13 3/8" C. 2012' 9 .5/8" C. 5900' $ 165,022 $1,906,511 $2,300,000 5900' TD 4886' ETD (RET) 13 3/8" C. 2012' 9 5/8" C. 5900' $ 18,000 $1,924,511 $2,300,000 5900' TD 4886' ETD (RET) 13 3/8" C. 2012' 9 5/8" C. 5900' $ 14,959 $1,939,160 Installed & tested dual CIW tree. Open sleeve in LS ~ 4405' & displaced annulus above dual pkr w/ pkr fluid. 'Closed sleeve ~ 4405'. Opened sleeve in LS ~ 4587' & dis- placed LS & .SS w/ nitrogen. S~eared guide out. of MS w/ sinker bars. Put well on test. LS test 7.53 MMCFPD w/ 13.2 BWPD ~ 755 psi. SS test 8.32 MMCFPD w/ 1.6 BWPD © 715 psi. Shut in well. Installed BPV's. Released rig to moving rate ~ 1800 hfs 8-8-82. Moving rig to KU #11-8. Moved rig to KU #11-8. Released rig to KU #11-8 ~ 24:00 hrs 8/10/82. AFE AMT: $2,300,000 AMF SCIENTIFIC DRILLING INTERNATIONAL 1111 EAST 80TH STREET GYROSCOPIC DIRECTIONAL SURVEY FOR *UNION OIL COMPANY* **********~*****~** JOB NUMBER: 1369 WEL. L NAME: KU24-5 LOCATION: oURVbY DATE: S U R V E Y E N G I N E IE R: KENAI GAS FIELI) 08/02/82 V(],:)I"IAL..L. MAGNET]lC I)ECI..INATION: AT .00 E GYRO I;tEF'EI;~EiN(.,F.:: BLEARING: ,.~ 10-'47 W M E T H (] X) (] I'-" C A I...(.';, U I.. A T I (] N: 'l' H E R A I) I U S 0 F' C U R V A'F (J R E VI!i; R 'f' I C A L. ~ .................... ,~ o-",:.:,.;, E ,:)E. (., lr .I. (] N: (., A I...[., U L.. A 1 E. b U S :1: N G P R 0 P [) S A I... [) F N '::" o,::. COMME~'S: TMANK YOU ***, ****** .x.*****.x.*************.x.*** ,.x.,.x.***.x-.x..x. ~..x.,x..x. ,.x. * TFIIS StJI;~VI-'.::Y ..c ....... .I. o COR R E.C ! T(] TI"tlE B ES T 01:" M Y .x. 'x'KNOWL. li!:DGE AND IS SUPPORI'L::.;D ]BY AC, TUAL. i:'iEL. D DATA,'x' * , * **-X.* .X-* *-X.***** .X. C 0 M P A N Y R Iii: P R E: S E: N'r A T~?.:.: .x. , .)~ , , , , .X- * * -X. * * -X..X..X. -X. -X. * -X..X. * * * * * * * * * 'X' 'X' * .X' 'X' * ;~"* 'X' * * * * 'X' 'X' 'X' ** 'X' * * AMF SCIENTIFIC DRILLING INTERNATIONAL 1111 EAST 80TH STREET PAGE 1 JOB NUMBER 1369 ME. AS , VER T , VERT , D E P T I..I D El P T H S E C'l", 1 O0, O0 99,99 1,08 200 . O0 199,97 2,59 300 , O0 299,96 3,41 400 , O0 ~99,86 6,81 500,00 499,55 14,57 600 , 0'0 598.87 25.7(!} 700, O0 697,49 42, O0 8(I0, O0 795.30 62,51 90(I , O0 892.33 86,37 0(}0, O0 988, '13 114,60 100,00 1082,61 147,03 200, O0 1175,96 182,55 300, O0 1266,93 223,71 400. O0 1S55.43 270,06 500, O0 144~. 08 319.94 THE COUR INRUN SURVEY BY RADIUS OF CURVAI'URE oE I NC BEAR I NG I)EV, I) iq D Pi 1,(119 1-15 N 63..-46 E 1,96 1.-. (11S 58..- 0 IE 1 ,75 1-'- 0 S 64..-45 IE 4,14 ,3.-45 N 6 (11..- 3 (11 IE 7,85 5-15 N 40--41 11,54 8- 0 N 44-44 E 16,5111 11- (11N 46-.56 E 20,79 13- 0 N 47.-15 E 24,19 15-0 N 46-:30 I::'..' 28,61 '18'.-'15N 47-..46 Iii: 32,76 20- 0 N 48-48 E 35,83 22'- (11N 48....54 E 4'1,46 27.- 0 N 50- 8 IE 46,56 28'-30 N 5'1'-59 E 49,99 3'1-30 N 5:3- (11 t'.".'~ DATE: 08/02/82 C 0 0 R D I N A T E S i... A T I l' U I) E D E P A R T U R ,48 N ,39 N ,45 S ,30 S 4,66 N I) .- I_ E El PIER 100 ,98 E 1,25 2, !.35 E 1,12 4,,'5.9 E ,12 8,37 IE 3,28 14,40 E 2, '14 13,13 N 22,22 E: 2,79 24,63 N 34,06 E 3,02 38,78 N 49,29 IE 2.00 55,32 N 66,94 E 2,01 74,78 N 87,91 E 3,27 96,59 N 112,36 E 1,78 120,17 N 139,34 E 2,00 147,09 N 170,87 !".:: 5,03 '176,35 N 207,08 E '1,7S 206,79 N 246,74 E 3,04 ,:~'l" A'I' :il [) N I) I S P L A C E. M E N T I) I S T A N C E B ti!: A I'?. I N G 1,09 AT N 63-46 [ 2,88 A'l[' N 82-16 4,41 AT S 84 .... 10 8,38 A'I'!3 87-'57 15,14 AT N 72"" 5 ii 25,81 AT N 59'-25 t 42,03 AT N 54- 8 [ 62,72 AT N 51-48 [ 86,84 A'l[' N 50-26 115,41 AT N 49-37 Ii 148,17 AT N 49-'19 [ 184.00 AT N 49"'13 E 225,46 AT N 49 .... 17 [ 272,00 Al' N 49-35 Ii :32'1,93 A.'FN 50 .... 2 I! AMF SCIENTIFIC DRILl_lNG INTERNATIONAL 1111 EASI' 80TH STREET PAGE JOB NUMBER: 1367 HE:AS. VER'lr', VER T, D E P T H D E P T H S E C T, 1600,00 1525,63 374,64 1700, O0 1606,79 432,95 1800,00 1687,95 471 ,30 1700,00 176~, 86 548,5~ 2000,00 1851 ,78 805,92 21 (l(; , 00 '1933,69 663 , 18 2200,00 2015,10 721 ,21 2300, O0 2096,13 779,78 2400 , 00 2177,29 838.19 2500 , OO 2258,32 896,77 2600,00 2700,00 2 800,00 2900,00 3000,00 2339 , 22 955,52 2419,99 1014,45 2500,25 I074,07 2580.11 1134,21 2659,85 1194,53 INRUN SURVEY BY THE' RADIUS OF CURVATURE C [! U R S F..:: I N C B E: A R I N G I)EV, D H D H 54,82 35'- 0 N 52-22 E: 58,42 36-30 N 53.- 9 E 58,42 35-' 0 N 53-52 Ii: 57,36 :35'-- 0 N 53-51 E 57,36 35- 0 N 53.-'50 E 57,36 35'- 0 N 53".'49 E 58,07 36 .... 0 N 54-39 E: 58,60 35-45 N 54-.'37 E: 58,43 35'"'45 N 55-13 E: 58,60 36'"' 0 N 54-36 IE 58,78 36- 0 N 54-47 E 58,96 36-'15 N 54-34 E 59,66 37 .... 0 N 54-23 E 60,18 37-- 0 N 54 .... 10 E 60,:36:37 .... 15 N 54--45 E: DATE: 08/02/82 C (:) 0 R D ]: N A T E: S I) -- L E (:.; I... A'F I 'r U D E DIE P A R T U R E: P E: R 1 0 0 240,02 N 290,34 E: 3,52 275,38 N 336,85 IE 1,57 310,'12 N 383,82 E '1,56 343,95 N 430,13 E: ,01 377,81 N 476,47 E: ,01 411,64 N 522,74 E: ,01 445,59 N 569,85 E: 1,11 '479,52 N 617,63 E ,25 513,10 N 665,44 IE ,35 546,78 N 713,:~9 Iii ,44 580,76 N 761,36 E: ,11 614,84 N 809,46 E ,28 649,50 N 858,01 E: ,76 684,65 N 906,87 I::: ,'13 719,74 N 955,98 IE ,43 S T A T :[ 0 N I) :i: S P i.. A C I:.': M E: N T D :1: S 'l" A N C E B E: A R :1: N [.; 376,71 AT N 50-25 I 435,09 AT N 50-.44 I 493,45 A'I'N 5'.1.-. 4I 550,74 AT N 51 .... 21 I 608,08 AT N 5'1-.-35 I 665,36 AT N 51-47 723,38 AT N 51 .... 59 781,92 AT N 52-11 840,29 AT N 52--22 957,57 AT N 52-40 '1016,49 AT N 52-.-47 1076,12 AT N 52'...52 1136,29 AT N 52.-.57 1196,63 AT N 5:~ .... 1 AMF SCIENTIFIC DRILLING INTERNATIONAL 1111 EAST 80TH STREET PAGE JOB NUMBER: 1369 MEAS, VERT, VERT, D E P T H D E P 1° H S E C T, 31(tO.O[l 2739,31 1255,21 32(1(1,00 2818.38 1318,42 33fl0 , [lO 2896,91 1378,32 34(10,00 2975,44 1440,21 35[l[l,[10 3054,24 1501,74 38 (1 (1.0 (1 3700. fl 0 3900, O0 4 II 0 (1,0 II 41 O0. O0 42 (i 0, [l 0 430 (1, [lO 4400, O0 4498,0 Ill 3132,77 1583,83 3210,9(3 1826,04 3289,16 1688,29 3367,82 1750,01ll ~'~448,48 1811,72 3525,15 1873,46 3803,95 1934.99 3882.75 1996.52 37.81,41 2058,28 3838,25 2119,1il9 DATE: 08/0 ;.:Z/82 INRUN SLIRVEY BY THE RADIUS (IF CURVATURE COUR SE I NC BEAR I NG DEV, D M D M C 00 R D I N A T E S D"" I.. I!:' G I.. A T I T LID E D E P A R '1' U R El PIE R 1 (10 8(1,70 37-3(1 N 55- 2 E 61.22 38- (3 N 55-38 El 61 ,91 38'"'3(1 N 55'-22 E 61 ,91 38'- (1 N 54-'22 IE 8'1 ,57 38- 0 N 54'"58 E 754,85 N 1(1(15,63 El ,3(1 789.5(I N 1(355,97 E .61 824,57 N 111ll8,98 E ,52 880,20 N 1157.81 E .8(1 895,81 N 1207,83 E ,35 81 ,91 38'"'3(3 N 54-43 IE 62,42 38-45 N 56- S E 82,25 38-15 N 55- iii i::-' 61,74 38- Ill N 55- 2 li!] 81,74 38-15 N 55 .... '19 IE 931,47 N 1258,44 E ,52 988,93 N 1309,81 E ,87 llll02,11 N 1361,17 I""] ,78 1(137,44 N 1411,79 IE ,28 1(372,69 N 1482,48 IE ,31 61,74 38- (1 N 81,57 38- (1 N 81,57 38- (3 N 61,74 38 .... 15 N 8(1,84 38-3(1 N 56-'25 E 1107,33 N 1513,58 E ,72 53 .... 1(1 E 1142.82 N 1563,1il7 IE 2,[10 56""13 E 1178,4(1 N 1614,11 E 1,88 56- 7 Iii] 1212,78 N 1685,39 E ,26 57-33 Iii] 1246,06 N 1716,S1 E .94 S T A T I (] N D I S P I. A C E M IE N T I) I S T A N C E B IE A R I N G 1257,3(3 AT N 53- 7 1318,48 AT N 53.-.13 131it(1,34 AT N 53-19 1442,22 AT N 55-23 1503,77 AT N 53-28 1585,87 AT N 53-'30 1828, (38 AT N 53""34 '189(3,27 AT N 53-38 1751,98 AT N 53-41 1813,70 AT N 53'"'44 1875,39 AT N 53-'49 1938,94 AT N 53""51 1998,49 AT N 53'-'52 2[18(1,18 AT N 53""58 212(3,94 AT N 54-' 1 t' AMF SCIENTIFIC DRILLING INTERNATIONA[. 1111 EAST 80TH STREET PAGE 4 JOB NUMBER: 1369 MEAS, VER T, DEP TH I)EP TH 4500 , O0 S859 4600 , 000 5918 4700 , Oil S997 4800,000 400076 4864, O0 4127 49000, O0 4156 5 II II 00 , 0 0 42~'.~ 5 51 000 , O0 4,S15 5200 , O0 4396 5L':~ 00 , 00 4477 54 II 0,00 55000, O0 57 00,00 5775,00 VERI', oE. LT, ,81 2120,3~ ,54 2182,24 ,27 2245,62 ,61 2~04,47 ,55 2J4~,20 ,21 2564,96 ,94 2425,~0 ,~5 2485,24 ,52 2544,65 ,09 260~,47 4557 I 99 2662,1 (3 4638,89 2720,75 4720,05 2779,(33 48001,46 2836,89 4862,71 2879,97 I N R IJ N ,:::, U R V E Y BY THE RADIUS OF CIJRVATI. JRE C(]LIIRSIE INC BELAIR I)EV, D M D C 00 R I) I L. A T I T U I) El 1,24 38'-~'.~0 N 61,91 i~El'- (3 N 61 ,59 J.~7'"'45 N 600,EI8 ~7'-15 N ~'.~8,74 i'.~7'-15 N 57""~'34 E 1246,7Y.~ N 57'"' 1 E 12E10,18 N 57-'44 IE 1 i'.~ 1 ~.~ , 28 ' N 58""28 E 1~45,46 N 58'"~."~4E 1~65,74 N 21,79 37 .... 15 N 60,36 ~7"" 0 N 60,0I ~6""45 N 59,48 36""15 N 58,96 SA .... 0 N 58"-22 E 1377,16 N 58-'1EI E 1408,1il5 N 59-..49 E 14~.~9,71 N 59.-.4L~ E 1469,67 N 600--'25 E 1499,09 N 58,78 ~'.~6.- 0 N 58,78 ~6 .... 0 N 58,42 ~5"-L~00 N 58,07 3;5-.-3(3N 4[~,29 ~5 .... 0 N 60"-16 E 1528,17 N 6(3..- 8 El 1557,1'.~8 N 600-"52 El 1586,15 N 61 .... 4I) IE 1614,06 N 62"-17 El 161'.~4,41 N DATE: 08102/82 NATES I) '"' I.. E (:; D E P A R '1" U R E P E R 10 (3 1717,~.~6 E ,94 1769,46 E ,61 1821,16 IE ,50 1872,84 IE ,67 1905,86 E ,06 1924,4I Iii ,06 1975,79 E ,25 2027,25 E ,94 2078,65 E ,500 2.129.74 E ,48 S T A T I 0 N D I S P L A C E Pi Ii:.: N'1' I) I S T A N C E B E A R I N G 2122,19 AT N 54 .... 2184,00 AT N 54-' 7 2245,29 AT N 54 .... 12 2306,0S Al' N 54-18 2~44,68 AT N 54'"'22 2366,41 AT N 54""P5 2426,64 AT N 54""~;1 ;2.486.47 AT N 54-~'.~7 2545,72 AT N 54-44 2604,4~'.~ Al' N 54-52 8662,94 AT 2721 , 48 AT 2779,65 Al' 28~'~7,4(3 AT 2880,40 AT N 54-59 N 55 .... 6 N 55-'12 N 55-200 N 55-"26 PAGE AMF SCIENI'IFIC DRILLING INTERNATIONAL 1111 EAST 80TH STREET JOB NLIMBER: 1369 DATE: INRUN SIJRVEY MEAo, VER T, VIER (~,. I~ I) E P T H D E P T H ,.) r.. ~., BY THE RADIUS OF CLIRVAT~JRE COIJRSE] INC BEAR lNG COORDINATE. S gEV, g M g M I...ATII'UDE DEPARTLIRE D"'.I..IEG P I.:.]< 100 S T A T I O N I) I S F' L A CIE M E N T I) I S T A N CIE B E A P, I N G 5900,00 4985,10:29'51,S1 71,7(i S5.- 0 N 82-11 IE 1887,81 N 2435,;..'.).5 IE , (14 2951 62 AT N "-"'::' , ,., ,.~- S 6 THE HORIZONTAL DISPLACEMENT AT THE DEPTH OF' ·X..X. 'X. '×..X..X..X..X. .... r, ,.~,.~"- :.~ 8 Ii:.:, 59(10,00 F'IEET E. QUAL..o 2951,62 F'EIE'lr AT N ~":' ' ,X, .X, .X, ,X..X, ,X, ~(, ,X. AMF SCIENTIFIC DRILLING INTERNATIONAL 1111 EAST 80TH STREET GYROSCOPIC DIRECTIONAL SURVEY FOR *UNION OIL COMPANY* JOB NUMBER: 136(? WELJ.. NAME: KU24-5 L 0 C A l' I 0 N: SURVEY DATE: SURVEY ENGINE',ER: ~AGNETIC DECk. INATION: KENAI GAS FIELD 08/0 VOSHAL. L AT ,00 E CO~MENI'S: y. THANK Y(]IJ AMF SCIENTIFIC DRILLING INTERNATIONAL 1111 EAST 80TH STREET PAGE 1 JOB NUMBER: MEAS, VER T , I) E P l' H I) E P T H 1S69 VE:R T. <,~I IE C"f' . (]1(J , O0 99,99 1 , 08 Off , O0 199,97 2,66 3(]11[) , O0 299,96 3,47 0 (I, 0 O 399,87 7,1[]11 1[) 0 , 0 (]1 499,57 14,81 81[]11[]1 , 0 (]1 598,9 (]1 7(]10 . 00 697 , 53 81[) (J , (]10 795, S4 9(]1(I . O0 892.37 (]1 [I (]1 , 00988,19 30 O, O0 1267,03 40 (]1 , 00 1355,52 5 (]1 (]1,0 (]1 '1442,1 S 28, (]12 42,25 82,78 88.82 114,86 147,29 18;.:.)., 81 22:5,98 270,34 S2 (]1,22 INRUN SURVEY BY THE ANGLE-AVERAGED METHOD COUR <,SE: :[ NC BEAR lNG I)E:V, D M D M 11,54 8- 0 N 44-44 Ii:: 18,50 11- O N 46.-58 E 20,79 15- 0 N 47-15 E 24.19 15'-. (]1N 48-S0 Iii: 2).8,61 18-'15 N 47-48 E DATE: 08/(]12/82 C (:) (:) R I) :1: N A T E: S L.. A T :1'. '1' LJ D E: D Iii: I:' A R T LJ R Iii: I) '"' I... E: G PER 100 .48 N .98 E 1,25 .38 N 2,94 E 1,12 ,45 S 4,47 E .12 ,30 8 8,81 IE 3,28 4.68 N 14.67 E 2.14 13,18 N 22,50 I.:.: 2,79 24,86 N ~4,34 E: 3,02 38,(il2 N 49,57 E 2,00 55,35 N ,(..)7, ;..'.).2 E2, (]1 '1 74.82 N 88,19 E S,27 32,76 20'-. 0 N 48.-.48 E: 96,82 N 112,84 E: 1,78 S5,84 22- 0 N 48-54 E '!20,2'1 N '!39,8:~ Iii: 2,00 4'1,47 27- 0 N 50 .... 8 Ii!: 147,13 N '17'1, '17 E 5,0S 46,58 28-:~0 N 51-59 I.:.: 178,40 N 207,38 E: 1 ,73 50,00 :.l'l-SO N 53"- 0 E 208,84 N 247,05 E: 3,04 S"f' A '1' :!: C) N I) ]: S P L. A C' E M Ii!: N '1' D .i. ,::, t1' A N C i::. B E A R I N G 1,09 AT N 63-'46 E 2,96 AT N 82-34 E 4,49 AT S 84-13 I! 8,82 A'T'S 88-' 1 E 5,4(]1 AT N 72-18 I! 26,07 AT N 59-41 42,28 AT N 54-19 62,98 AT N 51-'56 87,08 AT N 50-32 I! 115,85 AT N 49....41 14(!t.41 A'F N 49-'23 [ 184,24 AT N 49-16 [ 225,71 AT N 4<?-19 Ii 272,28 AT N 4?-37 t S22,20 AT N 50 .... 4 I: AMF SCIENTIFIC DRILLING INTERNATIONAL 1111 EAST 80TH STREET PAGE 2 JOB NUMBER: ME'AS, VER l', VER l', DIE P T H D E P T H S E C T, 1600 , O0 1525.76 374, ?4 1700,00 1606,71 433,24 18(10,00 1688.07 491 , 59 1~?(10. OO 1767,9? 548,8? 2000,00 1851 , 90 606,19 21 00.00 19,3.3,82 663,4~? 2200,00 2015,23 721 .52 2300.00 2096,26 780,09 2400, O0 2177,41 838,50 2500,00 2258,44 897,08 2600 , O0 233~? , 35 755,83 2700,00 2420,12 1014,76 2800,00 2500,38 '1074,38 2900,00 2580,24 '1134,52 3000,00 265?,?7 '1'174 , 84 ]'HE COUR INIBUN StJRVEY BY ANGLE-AVIER AGED ME;TH[ID SE :[ NC BEAR I NG I)EV, D H D M LAT DATE: 08/02/82 C O O R D I N A T E: S I ]"UDi.:.: DEP AR TUR D'-i...EG PER 100 54,83 35'- 0 N 52.-22 E 240,08 N 290,65 Iii; 3,52 58,42 36-30 N 53- 9 E 275,44 N 337,'16 E '1,57 58,42 35- 0 N 53-52 E 310,18 N 384,14 E 1,56 57,36 35- 0 N 53-51 IE 344,01 N '430,45 E ,01 57,36 35'- 0 N 53-50 E 377,85 N 476,76 E ,01 57,36 35"- 0 N 53.-49 Ii".;411,71 N 523,06 E ,01 58,07 36"" 0 N 54-39 E 445,66 N 570, '18 E 1, '11 58,60 35'"'45 N 54-;'57 E 479,57 N 617,97 E ,25 58,42 35'"'45 N 55-'13 E 513,15 N 665,78 E 58,60 36'"' 0 N 54'"'36 E 546,84 N 713,73 Iii: ,44 58,78 36.- 0 N 54-47 E 580,82 N 761,69 E ,11 58,75 36 .... 15 N 54....:.~4 E 614,?0 N 807,80 Iii: ,28 57,66 37-- 0 N 54-23 Ii:.' 647,56 N' 858,35 E ,76 60,1.8 37-.- 0 N 54-'10 E 684,71 N 90'7,20 E ,'13 6(!,36 37 .... '.!.5 N 54'-.45 E 717',80 N ?56,31 i..'i.; ,43 ,:) Ir A"i" ]'. O N I) .1. ,:) P L A C E M I:: N l' .'0 ]: STANCtE BEAR I NG 376,98 AT N 50-'27 435,37 AT N 50-'45 493,73 AT N 51- 5 55'1 ,03 AT N 51-22 608,21;4 AT N 51 .... 36 665,66 AT N 51 .... 48 723,68 AT N 51""59 782,22 AT N 52""11 840,5~ AT N 52'"-23 899,13 AT N 52'-'32 957,87 AT N 52-40 1(116,80 A'lr' N 52.-47 1 076,43 A'IFN 52-53 '1'136,59 AT N 52-.57 1196 ?3 AT N 53 .... "~ AMF SCIENTIFIC DRILLING INTERNATIONAL 1111 EAST 8OTH STREET PAGE JOB NUMBER: MEAS, VER l' I)EP TH DEP T 1S69 VER T, ,~ i.':.. [, T, INRUN StJRVEY BY I'HE ANGLE-AVERA(3ED METHOI) C 0 U R S El I N C B E A R I N G DEV, D M D M DATE: 08/0~/82 C (] 0 R I) I N A TIE S I) .- L E (..'; L. A T I T JJ I) E D IF.'. P A R T U R E P E R 1 0 0 5100,00 2759,44 1;?.55,52 60,70 37-'S0 N 55- 2 E 754,71 N S200,00 2818,51 1316,73 61,28 38"" 0 N 55'"'36 IE 789,55 N 3300,00 8897,04 1378,64 61,91 38-S0 N 55-'88 E 884,63 N 34{)0,00 8975,57 1440,58 61,91 38- 0 N 54-88 E 860,86 N 3500,00 3054,37 1508,06 61.57 S8- 0 N 54-56 IE 86?5,87 N 360(I,00 3132,90 1563.95 61,91 38-30 N 54-"43 E 931,53 N 3700,00 32'11,03 1626,36 62,4;!~ 58-45 N 56- 3 IE 966.99 N 3800,00 3889.29 1688.60 62,25 38-15 N 55"- 8 E 1002.17 N S900,00 3367,96 1750,32 61,74 S8'- 0 N 55- 2 E 1037,51 N 4(}O0,OJJ 3446,62 1812,05 61,24 38 .... 15 N 55 .... 19 E 107;~],76 N 41('10,00 3525,29 1873,71il 61,74 38- 0 N 56'-25 IE 11(17,40 N 4;."Z()O,O0 3604,09 1935,S2 61,57 38 .... {~ N 53 .... 10 E 114;~,89 N 4300,00 3688,89 1996,86 61,57 38- 0 N 56'-13 E 1178,48 N 4400,00 3761,56 2058,60 61,74 38-15 N 56- 7 E 1212,85 N 4498,00 3838,39 2119,43 60,84 38'"'30 N 57"-33 E 1246,14 N 1005,97 E ,3(I 1(,156,31 IE ,61 11 (,l 7,32 IE , 5 P.'~ 1157,95 E , 8 1208,17 E ,35 1258,78 E ,52 1310,15 E: ,87 1361,51 E ,76 1412,14 E ,26 1462,82 E ,:551 1513,93 E ,72 1564,23 E 2,00 1614,47 El 1,Slit 1665,75 E ,26 1716.67 E ,94 ,:~, T A I .I. 0 N I) I S P !... A [,E.M I::. N 1' I) I S T A N C E B E A R I N [.; 1257,60 AT N 53-' 7 1311il,78 AT N 53"'13 131i!('l,64 AT N 53-19 1442,53 AT N 5S.'"23 15('14, (.18 AT N 53"'27 ' 1565,98 AT N 53-'30 1628.37 AT N 5~'5-34 16(?(i ,58 AT N 53'"'39 1752,S0 AT N 5~3"-42 1814,02 AT N 53-'45 1875,71 AT N 53-49 1937,27 AT N 53-'51 1998,83 AT N 53-'58 2060,52 AT N 53-56 2121,88 AT N 54 .... AMF SCIENTIF]iC DRILLING INTERNATIONAL 1111 EAST 80TH STREET PAGE 4 J[IB NUMBER ivil::. A,.~, VIER DIEP '1'14 I)EP 450(t, 00 3839 4600, O0 3918 4700. O0 3997 4800, O0 4076 4864, O0 .4127 4900, O0 4156 5000, O0 4236 5100, O0 4316 5200, O0 4396 5300, O0 447'7 5400, O0 4558 5500 . O0 4639 5600, O0 4720 57 (! 0,00 4:[301 5775,00 4862 T, VIER'F, (.~ ~*., ~"~ -V. T H ,:),=.~., · . ,96 2120,68 ,49 21 :[32,58 ,42 2243,(77 ,76 2304, :['.32 ,70 2343,5'3 ,36 2365,31 ,09 ;.:.).425,63 , 0:['3 24:[35,57 ,47 2544,95 ,24 260;.3,79 ,15 2662,43 ,05 2721 , (:}Iii ,20 2779,3(.') ,62 2837,22 , :[2628:[30, :.'50 INRUN SURVIEY BY THE AN(~,LE-..AVERAGED MIE'I"I.'IOI) (.,(]l..Jl;~ ,:)1::. I NC. BE:AR I NG I) EV, D H D M DATE: 081(:}2/82 C 00 R I) I N A T E S I)"" t... IE G I...A T I T U D E D El:) A R 'l" U R E P IF.; R 1 0 0 1,24 38-30 N 57-34 E 1246,81 N 61,91 3:[3'- 0 N 57-' 1, IE 1280,26 N 61,39 37-45 N 57--44 Iii; 1313,36 N 60,88 37-'15 N 58'-2:[3 IE '1345,53 N 38,74 37 .... '15 N 58-'24 E 1365,8'1 N 21,79 37-15 N 58'-22 E 1377,23 N 6:[!, 36 37- 0 N 5:[3'-18 Ii!: 1408,92 N 60,01 36..-45 N 59....4(? Iii: 1439,78 N 59,48 36-15 N 59....43 E 1469,74 N 58,95 36- 0 N 60 .... 25 E 1499,16 N 58,78 36 .... 0 N 6:[11.-16E 1528,;.:.).4N 5:[2,78 36- 0 N 6(1-- 8 Ii:.] 1557,45 N 58,42 35'"'30 N 60..-52 E '15:[36,22 N 58,07 35"-30 N 6'1 .... 4(i E 1614,14 N 43,2? 35-- 0 N 62 .... 17 E 1634,4:[3 N 1717,72 IE ,94 1769,:[32 E ,61 1821,52 E ,5(:} 1873,2.0 E ,67 1906.21 E ,06 1924,77 E ,06 1976,14 I!i: ,25 2087,60 E ,94 207 :Iii, (? 9 I.:-' ,50 21 '..'50 , 08 E ,4:iii 2181,16 E ,1)8 2232,17 Iii: ,08 2283,02 IE ,66 2:33:3,93 IE ,46 2372,14 tel ,82 ,:) l A l .[ 0 N I) :t: S P L A C E H E: N 1' I) :t:( ........ o I A N (., E. B tEA R :1: N [-; 2122,52 AT N 54-2 2184,34 AT N 54-7 2245,63 AT N 54-12 2306,37 AT N 54 .... 19 27.545,0'1 Al' N 54-23 2366,75 AT N 54""85 24;.:?.6,97 AT N 54-31 2486,79 A'['N 54-37 2546, (:}4 AT N 54""45 2604,75 AT N 54""52 2663,26 AT N 54'"'59 2721,8(1 AT N 55-' 6 2779,97 AT N 55 .... 13 2837,7~'5 AT N 55'"'20 2880,73 AT N 55'"'26 AMF SCIENTIFIC DRILLING INTERNATIONAL 1111 EAST 8QTH STREET PAGE 5 JOB NUMBER: 1369 DATE: INRUN SJJRVEY BY THE ANGLE-AVERAGED METHOD Pi E A <..i;, V E !;{ T, V E R T , D E t:" T H I) E I'') T I"1 '~" '"' '"' · .:) I::... ~., T , 4965,86 ;."!951 , 6~'~ .,:~, I.':.. I N C B El A R I N G C 0 U IR '~ ..... I) EV, D H D 71,70 35-- 0 N 62-11 C O O IR I) I N A T E S i- A T I T U I) E g E P AI~ T i.3 R IF.: E 1667,88 N 247.~5,59 E I) -- I... IE (; PIER 100 THE I..IOI;~IZON'rAL DIS~I...AL.E. HI..:.NI A'I" 'ri-tiE DEPTH OF 'X' .X' 'X..X. 'X..X..X..X' ,591) 0 .... 01) 1:"' IE E T E Q U A L.. S ;~. 9',31 9 ~.~ i::' lii:lE T A't" N '":',, ,.~ '- ,.~ 6'::' "E, · X' 'X' 'X..X' -X..X..X' 'X. S T A T I O N I) I S P L A C E M IE N'lr I) I S T A N CIE B E A R 2ti N G ;i!951 ,9S AT N ,., ,., '" .~ 6 I Suggested 'form to be inserted in each "Active" well folder to check for timely compliance with our regulations. 0p~r"a~or, ~ei 1vName and Number Reports and Materials to be received by: 9 -' ~ Date Required Date Received Remarks Ccmpletion Report YesC~_ -;~ d;~ " Well Histo~ ~' ..... ~~.~ Yes ~_ ,~..~ ~{. ~ .. _S~les-~ ..... . C°re ~scripti°n Registered ~ey Plat -Inclination Su~ey ~ , Drill St~ Test Re~s Pr~u~ion Test Re~s ~_. ~s ~. '-:~ ~es j Digitiz~ .ta G,7 F,'u* m 9-33C~ UNi] D STATES suBMiT IN OUPL~C^~ { S,'e other In- DEPARTMENT OF THE INTERIOR .~,,*.,'" ....... " reverse side) GEOLOGICAL SURVEY WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: b. TYPE OF COMPLETION: NEW [~] ,VORK [--] ~VEI.I, OVER O11, [] GAS ~-} DRY [---} Other WELl. WELl, EN BACI{ RESVR. Other 2. NAME OF OPERATOR UNION 0IL COMPANY OF CALIFORNIA 3. Al)DRESS OF OPERATOR PO BOX 6247 ANCHORAGE AK 99502 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* Form approved. Budget Bureau No. 42-R355.5. . . .~). I,EASE DESIGNATION AND SERIAL NO. A-028142 6. IF INDIAN, A~I,OTTEE OR TRIBE NAME 7. UNIT AGREEMENT NAME KENAI UNIT ,R. FARM OR LEASI~ NAME 9. WELL NO. KU #24-5 10. FIELD AND POOL, OR WILDCAT KENAI GAS FIELD l 1. SEC., T., R., M., OR BLOCR AND BUItVEY OR AREA At surface 332" S & 4331' E of NW corner, Sec. 7* At top prod. interval reported below 914' N & 1044' E of SW corner, Sec. 5* At total de~% 1336' 1763' E of SW corner, ~4. P~RMIT NO. Sec. 5* } *T4N, RIIW, SM. DATE ISSUED I 12. COUNTY OR ] PARIBH Kenai 13. STATE gK 15. DATE SPUDDED I 16. DATE T.D. REACHED] 17. 7/16/82 07/28/82 DATE COMPL. (Ready to prod.) 08/08/82 18. ELEVATIONS (DF, RKB, RT, OR, ETC.)* PAD 66' MSL 19. ~.LEV. CABINOHEAD 20. TOTAL DEPTH, MD & TVD 21. PLU0, BACK T.D., MD & TVD 22. IF 5900' & 4965' 4886' ETD .o,v Ny. DRILLED._ ROTARY TOOLS CABLE TOOLS I Totai I --- 24. PRODUCING INTERVAL(S), OF THIS COMI"LETION~TOP, BOTTOM, NAME (MD AND TVD)* B-4 4789-4864 MD 4068-4128 TVD B-1 4498-4553 MD 3838-3881 TVD B-3 4691-4731 MD 399Q-4022 TVD .: 25. WAS DIRECTIONAl, e RVEr MADE 26. TYPE ELECTRIC AND OTHER LOGS RUN DIL-BHC-SONIC-VDL-SP:GR, LDT-CNL~GR, MLL-GR, CIL-VDL-GR . . 27. WAS WI~LL CORED No' 28. ' CASING RECORD (Report al.! strings set in well) CA~INO SIZE WEIGHT, LB./FT.· DEPTH SET ("MD) HOLE SIZE CEMENTING RECORD AMOUNT PULLED , 20" 94# ~ ; ' 136: Drivem Driven .... 13 3/8" 61# .... 2012' 17 1/2" 1500 sxs .... 1800 sxs .... 9 5/8" 47# 7 ' ' 5900"'. 12 1/4" ,. 29. - ]LINER RECORD :. ': "' 30. TUBING RECORD SIZE TOP (MD) SACK-SI CEMENT* SC'REEN (MD) DEPTH SET (MD) [ PACKER 8ET (MD) 4645' [ 4606 4452 · 4442 31. PERFORATION RECORD (Interval, size and number) ~: _.:., .... :4899-4909 MD 4 HPF 4789-4864 8 .4691-4731 8 aa9R-4553 8 s2, ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH 'INTERVAL (MD) AMOUNT AND KIND OF MATERIAL. UBED 4899-4909 300 sxs cl "G" DATE FIRST PRODUCTION -. PRODUCTION PRODUCTION METHOD (Flowing, gas lift, pumping--size qnd type o! pump) [ WELL STATUS (Producing or · h_~lHt~-In ' 34. DISPOSITION OF GAS (~old, used for fuel, vented, etc.) TEST WITNESSED BY 35. LIST oF ATTACHMENTS 36. I hereby c r~tlfy)hat the for/eg~n~nd attached information is complete and correct as determined from all-available records DIST DRLG SUPT sI~N ~_~/_.~I~T LE .... __ .... DATE, ~ (See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases to either a Federal agency or a State age" or both, pursuant to applicable Federal and/or State laws and regulations. Any'necessary special instructions concerning the use of this form and the number of copies t; ' submitted, particularly with regard'to local, area, or regional procedures and practices, either are shown below or Will be issued by, or may be obtained from, the local Fed and/or State office. See instructions on items 22 and 24, and 33, below regarding ~eparate reports for separate completion.s.. If not' filed prior to the time this summary record is submitted, dopies of all currently available logs (drillers, geologists, Sample and core analysis, all types electric, etc.), tion and pressure tests, and directional surveys, should be attached hereto, to'the extent required by applicable Federal and/or State laws and regulations. All attachr. should be listed on this form, see item 35. ' Ifem 4: If there are no applicable State requirements, locations on Federal or Indian land should be described in accordance with Federal requirements. Consult local" or Federal office for specific instructions. : -- Ifem ] 8: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spa~es on thtSi~orm and in any'attachments. Ifems 22 and 24: If this well is compl'eted for separate 'production from more than one interval zone (multiple completion), so state'in item 22, and in item 24 Show the prod~-_~. interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 33. Submit a separate report (page) on th~ form, adequately iden'_i for each additional interval to be separately produced, showing the. additional data pertinent to such interval. I~em 29: "Sacks Cement": Attached supplemental records for this .well should show the details of any multipie stage cementing anal the location of the cementing tool. I~em 33: Submit a separate completion report on this form for each interval to be separately produced:~; (Se~tnstruction for iterfis 22 and 24 above.) 37. SUMMARY OF POROUS ZONES: SHOV,' Al,I. IMPORTANT ZONES OF POROSITY AND CONTENTS THEREOF; CORED INTERVALS; AND ALL DRiLL-STEM TESTS, INCLUDING ~8. GEOLOGIC MARKERS DEPTH INTERVAL TESTED~ CUSHION USED, TIME TOOL OPEN~ FLOWING AND SHUT-IN PRESSU'RES~ A~D R~COVERIES' '' { :' FORMATION TOP BOTTOM DESCRIPTION~ CONTE~8~ ETC. TOP NAME . ' MEAS. DE~H TRU~ ~T. ~.. 8-4 4789 4864 8.60 MMCFPD w:2 ~4,8 BWPD ~ 815~psi T/Sterling FM 4256' 3648 Gas Sands 8-3 46~1 4731 9.75 MMCPFD Dry $ 825 pSi T/BeiugJ FM 5630' 4745 B-1 4498 4553 " " ,'. ".. " ",' Final LS test=7.53 NNCEPD w/ I ' i $ 755 psi-3 hour test. - I .. I Final SS test=8.32 MMCFPD wy I. ~ 713 psi-3 hour test. :' ,.,. ~. ~ . -. ,~' . ,, , ... ; :. . ; ,. ,. _ . ,. . · .. .! : U.S. GOVERNMENT P~INTING OIrFICE: 1963---O.~83636 :f 871-2. STATE OF ALASKA 1 "? ,., ALASKA ~ AND GAS CONSERVATION CC~ISSION ONTHLY REPORT DRILLING AND WORI OVER OPERATI Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. UNION 0IL COMPANY OF CALIFORNIA 82-98 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 133-20358 4. Location of Well at surface 332'S & 4331'E of NW Corner, Sec. 7, T4N, RllW, SM. 5. Elevation in feet(indicate KB DF, etc.) I 6. Lease Designation and Serial No. Pad 66.1 MS~ I A-028142 9. Unit or Lease Name KENAI UNIT 10. Well No. KU #24-5 11. Field and Pool KENAI GAS FIELD STERLING POOL For the Month of Ouly ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced operations ~ O0:O1 hrs 7/12/82 Spud ~ 14:00 hrs 7/16/82 Stuck pipe ® 5564' - came free after soaking 17 112 hfs in Black Magic 5900' TD 5810' ETD (FC) 13. Casing or liner run and quantities of cement, results of pressur~ tests Drove 20" to refusal ® 136' RKB Ran 13 3/8" 61# K-55 butt csg to 2012' & cmt'd w/ 1500 sxs - tested to 2500 psi - ok Ran 9 5/8" 47# N-80 butt csg to 5900' & cmt'd w/ 1800 sxs 14. Coring resume and brief description None 15. Logs run and depth where run DIL-BHC-Sonic-VDL-SP-GR f/ 5900-2012' LDT-CNL-GR f/ 5900-2012' MLL-GR f/ 5900-2012' 1 6. DST data, perforating data, shows of H2S, miscellaneous data None I ECEIVED ' AUG -- ' 982 Alaska Oil & Gas Cons. Comrnlssior~ Anchorafje 17. I hereby certify that the foregoing is true and, correct to the best of my knowledge. NOT ton form is requi~d ;j~t~.ea~c~l~ndar month, regardless of the status of operations, and must be filed in duplicate with the Alask~ Oil~l' Gas Conser~[ion Commission b~"T~4~,~'~ucceeding month, unless otherwise directed. );zfm 10-404 // "~ Submit in duplicate UNITED STATES- Dcr.~ARTMENT QF THE I~NTEiql~ GEOLOGICAL SURVEY Form B-329 Rm.v. F-b 7'6 OMB _ MONTHLY REPORT OF OPtiOnS Le~se Ho.. _ _ ~ #1~-6. Cc~mumhzation A2re-emen; Ho .... F~id Nam, e KENAI GAS FIELD Umt Hame KFNAT IINTT P~rhapating Area County KFNAT RnR0~Jr'~ State = __ AK _ Operato¢. . LJNTflN flT~ CRMPANY OF' £AL]'FORNIA _ 1:3 Amenc~ Report Tre fc~wing is a ccnect repcct of ~-ations and ~u~ (i~l~ing status of all unpl~ wel~) fm t~ month (~ Re~r~ of F~m f~ Ins~ions) ~ ta~c ~ r~utr~d b7 ~ (~ O.S.C. 1~, ~ ~.S.C. 339, 25 U.S.C. 3~6 d), r~z~act~ (~ C~ 221.~), ~uc~ ~ ~arac~o~, or b~s for reco~att~ ~ ~cil ~e line ~ ~or~itc ~e bo~ (~ C~ 221.53). 3 1/2" tubing fish - TOF ~ 5395' ETD TMD 5500' Released Rig ~ 12:00 hrs 7-11-82 set Baker "O" pkr $ 5065 w/ 3 1/2" tbg string Set Baker "FH" ~ 4728' Set Baker "A-S" dual pkr ~ 4430 w/ 3 1/2" tbg string. Perfed for production 4521-4597 8 HPF 5178-5268 8 HPF I ECEIVED AUG - 6 'J982 Alaska Oil & Gas Cons. Commission Anchorage O~ a Condansa~e Cas - Water . aOn h~nd, Star: of Month ePzoduced =Sold *Spilled o: ~;C .... ~ed on .L~ .. '*I~Ject~ - *Surface ~Other · . . .'~DOO~X X X ~x .XX ~'~ X X X~ ' *On h~n~, End of Month - xmxxxx×:cx×Xx~xXXx x--xxxfx'XXxxxxxxxxx× ¢'API Gray fry/BTU Content j/ __ _-_~_ ~_../ _ _ , . ~xx~~xxxxxxx ~thori=ed Btsnature:_ _ O STR BRILL N SUPER NTENOENT / . P Se ""' June 17, 1982 Mro Kevin Ao Tab,er Land,an Union Oil Company of California P.O. Box 6247 Anchorage, Alaska 99502 Kenai Unit KU %24-5, A-028142 Union Oil Company of California 'Permit No. 82-98 Sur. Loc. 325'S & 4340'E of NW corner, Section 7, T4N, R11W, SM. Btmhole Loc. 1215'N & 1700'E of SW corner, Section 5, T4N, R11W, SM. Dear Mr. Tablet.. Enclosed is the approved application for permit to drill the abov~ referenced we! 1. Well samples and a mud log are not required. A continuous directional survey is required as per 20 AAC 25o050(b}(5). If available, a tape containing the digitized log information shal! be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys, Many rivers in Alaska and their drainage eystems have been classified as important for the spawning or migration of anadromous fish° Operations in these areas are subject to AS 16.05. 870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Co~e)° Prior to commencing operations you may be contacted by the liabitat Coordinator's Office, Department of Fish and Game° Pollution of a~ waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alask~ Administrative Code, Chapter 70) and by the. Federal ~ter ~llution Control Act, as amended. Prior to c~ncing operations you may be contacted bY a representative of the' ~part~nt of Environmental Conservation. F~ani Unit, KU ~Z4-5, A-025142 Page ~ To aid us in s~heduling field work, we would appreciate your r~tifytng this of/ice within 48 hours after the well is spudded. We would also l~ke to ~ notified so that a representative of ~he C~s~ion ~y ~ present to ~ns~ct the d~rter system ~fore the ~ondu~or sh~ is drilled and also to wit~ss testing office adequate advanc~ notification so ~at ~ ~y have a Very truly yours, C. V. Chatt~rto~ Ala~a Oil a~d ~s Conse~tion C~ission ~nclosure cc: Department of Fish & ~ame, Habitat Section w/o encl. D~partment of Environm~n~a! Conservation w/o enClo CV¢/~ Ih Union Oil and Gas Divis~estern Region Union Oil Company of Ca.fornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager .June 16, 1982 Mr. Chat Chatterton Ak. Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, AK 99504 KENAI SOLDOTNA AREA State of Alaska Kenai Gas Field Kenai Unit, KU #24-5, A-028142 (8-86-71-5 390-600972 ) Dear Mr. Chatterton: Enclosed for your approval are three (3) fully executed copies of the above captioned Permit to Drill KU #24-5 in the Kenai Gas Field. Also enclosed is our Check No. 19204 in the amount of $100.00 to cover filing fees. y truly yours, /-K~vinLandmanA. Tabler bde Enclosures cc: J. R. Callender Ann Lannin/LA Office RECEIVED JUN 1 0 1982 Naska Oil & Gas Cons. Commission /~nchorage ' ,,'"'-". ,.... ATE OF ALASKA ~'~""~ ~ ALASKA OIL A,.,'O GAS CONSERVATION COMMt,.,,.,I,. , PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC I-] REDRILL [] DEVELOPMENT OIL [] SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS 2. Name of operator UNION 0IL COHPANY OF CALIFORNIA 3. Address PO BOX 6247, ANCHORAGE, ALASKA 99502 4. Location of well at surface 9. Unit or lease name +;525'S & +4;540'E of NN Corner, Section 7, T4N, RllW, SH. KENAI UNIT At top of proposed producing interval 10. Well number +873'E & +733'N of SW corner, Section 5, T4N, RllW, SM. KU #24-5 At total depth 11. Field and pool +1215'N & +1700'E of SW corner, Section 5, T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. KENAI GAS FIELD KB +90' MSLI A-028142 STERLING POOL 12. Bond information (see 20 AAC 25.025) Natlonal Fire Insurance Company of Type Statewide Surety and/or number Hartford (B55;54278) Amount $200,000.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed South 6 miles 2800 feet well 2;500 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 6900' HD & 5840' TVD feet 2560 7/1/82 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures -I-] ]['}0 psig@ Surface KICK OFF POINT ;500 feet. MAXIMUM HOLE ANGLE 40°I (see 20 AAC 25.035 (c) (2) --~] R0l'}psig@_ 500Oft. TD (TVD) ..... 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 20 94# H-40 Plait 100' Surf I ___ +10~ +lO0 Driven 17 1/~ 1;5 ;5/~ 61# K-55 Butt. 2000' Surf ~ --- +_~00~. --- +llO0 sxs to surface 12 1/z 9 5/E 47# N-80 Butt 6900' Surf , --- +6900 +5840 +--1700 sxs inside ' ~ - i- ~';5 ;5/8" casing I I I ~ t 22. Describe proposed program: 1. Move in and rig up, 2. Drive 20" to refusal ~ +100' & install diverter, ;5. Directionally drill 17 1/2" hole to +_2000'. 4, Run & cmt 1;5 ;5/8" csg to +2000'. 5. Install & test BOPE to ;50'00 psi 6. Directionally drill 12 1/4" hole to +_~900' THD TM. 7, Run open hole logs, 8. Run and cement 9 5/8" csg to +_~900'. 9, Run CBL and gyro survey, 10. Test and complete well as dual ;5 1/2" Sterling gas producer, 23. I h~regoing ' ue an orrect t the S,GNED Robert T. Anderson~----~-,----.z-, ~ ~~TLE District Land Mgr DATE The space below for Commission use / CONDITIONS OF APPROVAL Samples required ~ Mud log required Directional Survey required I APl number []YES ~NO I-lYES ~O ~.~ ES []NO Permit number App_.G;~al date f~f/ ¢7,- ~/~ / ~-~ ~',//'//~//'~'GL., SEE COVER LETTER FOR OTHER REQUIREMENTS ~ [ / / by order of the Commission Form 10~01 Submit in triplicate t i. RECEIVED JUN 1 6 1982 A!a~ka Oil & Gas Cons. Commission Anchorage i i u m im I I i mm I u I iii u · m II · ui:i~d~ O,L 'c6~a,~' .o~ ~^UF-o~,Nu, .... i m IJ .... i m · · j i · .o .. · o -- ,41YGL ED ,FILL lip LINE ,. · o CHECK VALVE .~' £LI/;O ,e.'~/,;$ .RECEIVED JUN 1 6 1982 Alaska 0il & Gas Cons. Commission' 2o ... Anchorago ~OTE ' ALL CHANGES MUST HAV~ WRIT.~EN APPROVAL BY TH~ OISTRICT DRILLING SUPERINTENDENT " : .4#GLEO ·FILL UP Zlt~ · ,o · ~ HYDRIL .. ... . . ~/~,, ~ooo ~ . '~. · . o P,,E£EIVED ... jUN ! 6 1982 .... ~laska 0il & Gas Consl Commis.sion · Anchorage · 2.0" Zooo ~'~ 5 ~, .~. · · _ _REV. ~ nqT~ I 2,0" C~,~. ~1,~/l'' AL.t. CHA,'tGES ~IuST HAVE WRIT..T[N APPROVAL ElY THE DISTRICT ORILLING SUp-C'RIN TENOENT · i :..::~ .m-~m- ----- RECEIYEI) JUN ~ 6 i. g82 A!~s~'0il & Gas Cons. C;ommission ^nc.borage UN.ION OIL COMPANY OF-CALIFORNIA S~4LETS I SHEET ]3ct%om Wt. DESCRIPTION Grade Thread WEIGHT TENSION ~INI.~JM %0BF -top of 'STRENGT~K BFZ section TENSIOFI lbs lbs 1000 lbs TDP COLLAPSE COLLAPSE CDP BUP~T !I';TERNAL BDF PRESS. @ RESIST. PRESSURE bottom tension YIELD psi psi psi psi _ _ PRI~ PER FT. COS: 0 Y=Tensile Lpad/Pipe Yield Strength o° . ,2 ..... ,!.'-., .~; ..8____~..o i':..F~-~: ::::i~.::-'|:;:' :.;.; :::.;l'.ri~ '.~'.:":~: ~|","~: ..... ~ ' '1':'":.~'" ",'""1"..l'., /~ · .............. ,..o .... : .... ,~oo ,',,,~ 't'- ~ .... i:.:;'-I-";;:I:::'!:~.,: ::-'"!i:;';;'.'.;:-' I;~;t' .' ::::':'::;';;::1;.;:~ .*:.::l;r~':;~::";:./ Ii[iii ,.l...i ..... ~ .......... I .... , ..... I,,.1'. ~ ..... I .... ..!.,-..,-- ,::: .... : .......... 12:i,:!-Z;' oOl:".l..' .... I ' T'"l .... ! .... ~"~' I' '"t ..... ,~'"!: i..., ........ I ........ : ~..,,. ~; ~.. :::::::::::::::::::::: :::' .:.: ::::1.,::'. ~. 2 o ;.. ~ ~ L:.. , .... , -' ..... o.--.;TI. ~ i ' ° ~ 1'''--''~'~' ' 'i .... ! ~'''-''~' '''~ ~ .-.., .... -..I., ..1, i.., · ¢ ~. ~, ,'~. ........ ,.,.~ .. ,.I-.re. ,,.~.] -~ · · ,~o. .' · ). :. ~,,. ,''4.-., ~ornulae:~ - Collapse resistance in tension = X (Collapse pressure ratify) ~urst Pressure = ~mP +. ~e~t~ ( ~ya. Gr. IX --,~) ~F (~ouyancy Fac%or; = re.co- (o.om~3 x ~ua w~. m) Calculations: Tokai Cost CASING STRING ~F O~d~~,, CASIN~ SIZE CASING AND TUBING DESIGN ..... .._ ~ ~. ~~ mD aa..T._ _-.~s:~/f'L.. ~ ~,~, :ZZ ~ ~). OS. n: ~S~ · .o INTERVAL LENGTH Bottom Top Wt. DESCRIPTION '.~IGHT TENSION }~NIMUM TDF COLLAPSE COLLAPSE W/ BP -top of 'STRENG~K PRESS. @ RESIST. Grade Thread W/O BF~ section TEk, ION bottom tension lbs lbs 1000 lbs psi psi C~F BUP£T !I:T£RNAL P.W~SSURE YIELD psi psi s.s,~ 35~q q75'0 I.~2 359/./ BDF PR~ COS2 PER 1.91 .) 0 m 0 0 Formulae: Collapse ~esistance in tension = X (Collapse pressure ratify) Calculations: Total Cost Burst Pressure = ~m~ +.~th ( ~. ~r. ~ -.~) BE (Bouyancy Fa¢'tor) = ~.oo- (o.o%~ x ~ua w~. T) Pad ~imit$ 4j~ U. 45-7 JUN 1 619B2 Oil & Gas Cons. Commission Anchorage 2. J°o ,,~ *, J '* r-,----I +@ I ~ - I I I I aou-i -F % SITE 'me .u-$4-$~ I ICTU-43-ex ,(U- 44-1l \.-F I I I I I I I I I Peoo. ~mJm I I I I I I I I ! N 1 6 1982 Gas Cons, Commisslol Anchorage ,, union Aleeke pl*e~ KENAI OAS FIELD PROOUCTION FACILITIES CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. (1) ITEM APPROVE DATE (2) Loc 4.~,.,/~ yb,, .(~ thru 8) (3) Admin (Yf thru (4) Cas~g~'~~ ~-/(*;3~' ~1'2 thru 20) i · · 3. 4. 5. 6. 7. 8. · 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. (5) BOPE ~ ~-4(.-%z 21. '~21 thru 24) 22. 23. 24. (6) Add: ~~ ~-/6':~~''' 25. Is the permit fee attached ........................................ Is well to be located in a defined pool . .......................... YES NO Is Well located proper distance from other wells ............. Is sufficient .undedicated acreage' available in this po Is well to be deviated and is well bOre plat included Is operator the only affected party .................. Can permit .be approved before ten-day wait ..., .......... Does operator have a bond in force · Is conductor string provided ... ................... ................. Is enough cement used to circulate on conductor and surface ........ Will cement tie in surface and intermediate or production strings .. Od Will cement cover: all known pr uctive horizons .................... Will surface casing protect fresh water zones ...................... Will all casing give adequate safety in collapse, tension and burst. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ~ ···.®·..®·®...·..·.·......·.®®®·..·.®®· Are necessary diagrams of diverter and BOP equipment attached ....... ~~- Does BOPE have sufficient pressure rating - Test to 3ooo psig .._~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. ~.~. Additional requirements ............................................. Additional Remarks: R~qARKS 0 HO Z ;eology: Engineering: tWK LCS BEW WA J KT~R, AD -- rev'~ 01/13/82 iNITIAL GEo. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , 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. [,IS:TAPE cD, 6VP OIO,H01 VERIFICATION LISTING PAGE 1 ** REEb HEADER SERVICE NAME DATEI~82/08/27 ORIG REEb NAME ~REEb ID CONTINUATION # PREVIOUS REE6 COMMENTS ~REEL COMMENTS ** TAPE HEADER SERVICE NAME !SERVIC DATE TAPE NAME CONTINUATION # ~0! PREVIOUS TA COMMENTS ~T~E COMMENTS EOF ** F16E HEADER ** FIbE'NAME': ISERVIC,O01 8ERVTCE NAMf: 1 VERSION#: 51024 ** INFORMATION RECORDS CN l: I MNEM 'CONTENTS PRESl DIbO01F ** R:ECORD::Y'¥PE 047 000 00:0 018: :': '06'5 065 0i8~5 0,0,0 000 001 065 0'06 :06:5: 000 000 007 065 LVP OlO,HO1 VERIFICATION LISTING PAGE; 2 RECORD TYPE 047 %~ RECORD TYPE 047 my COMMENTS m, SCHLUMBERGER ALASKA COMPUTING CENTER COMPANY COUNTY STATE UNION OIL COMPANY OF CALIFORNIA KU 24-5 KENAI GAS FIELD KENAI ALASKA JOB NUMBER AT ACC{ 10707,65434 RUN {1, DATE LOGGED= 28-JUL-82 bDPI JR TYPE FL!U!D = 5890 FT, = 2000 ; 13:3/8 Z~,i,..2012 FT, = mm ,( bVP 010,HO1 VERIFICATION LI6TING ~. PAGE 3 DENSITY = ?0,0 bB/G VISCOSITY : 69,0 S ' PH : 10 0C] FLUID bOSS ?,~ RM = 5,380 P 76,0 DF R~F ~ 5,040 P 74,0 DF RMC =- 6,620 @ 67 0 DF R~ AT BHT 3,882 ~ 10~, DF *~ DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 4 I 66 1 8 4 73 60 9 4 65 ,ll~ 0 1 66 0 :bOG TYPE C~ASS ,HOD ,NO.. :: 4 FT 0 O: O 0 0 SIZE PROCESS SAMPLE REPR bEVeL 1i g 5VP 010~H01 VERIFICATION LI~TING PAG5 4 DPH! bDT LLD DLL GR DLL SP CA~I DLL PU 0 0 0 o 0 OH~ 0 0 0 o 0 OHM~ 0 0 0 0 0 OHM~ 0 0 0 0 0 GAPI 0 31 32 o 0 MV 0 1 0 0 0 IN 0 28 3 0 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 I 6B 1 ~8 I 68 I 68 1 68 1 b8 1 68 SP NPH! PgF DE:PT NPH! CAI.,:[ P£F 5928 5000 -999 2500 3~ 0020 I 4453 4 1484 -999 2500 GR NRAT DPHI GR 5900, 0000 SFLU 6104 RHOB 27. 7994 GR ..999 -999 51 -999 37, DEPT 570:0 0000' :'SFLU bi.,:& 6039:. GR D:EPT :5 CAb.! : 12 Lb& 13: 2500 2500 DT ~01 DRHO 30 NCNL 8809 ~SFL 2500 SP 3516 ILD 7813 DT 8369 DRHO 6934 NCN~ '3926 ~SFL 0000 SP -999.2500 -999.2500 GR ~.0112 GR 26 ,0000 FCNL -999,2500 LLD -999,2500 CALl 8,7188 Ih~ ,0000 FCNL 277~0107 GR ;656I hbD '43,7026 CALI 6719 O.,O.OtOG~ -999,2500 -999,2500 54,5313 885,5000 -999,2500 '999,2500 756 9,9922 1587... DRHD . ~0, O0 O0 ...... SF:b U 1 3" :0: 39t: :: 87-5.0 GR].:: 39-; 3L25:: 375o 628:9: :: 4950 GR 56, ,9.263: 5400.,00.00 .... SFLO O0 O0 5.3086 IhD ,: 92 9, 7 .04.3 O: ; ?O6. 3. ~ :0.9:3,6 2354:,000.0 FC~L 71.5 54'7500 CALl ; 453:1 ~:: 50O0 56'4:~: 57O3 5.4492 5,8125 bVP 010,H01 VERIFICATION LISTIN(I PAGE SP -40,i250 GE NPHI 39,5610 RHOB CALl 12,953! NRAT PEF ~.9570 DPHI bb~ .0992 GR DEPT SP NPH! CAb! DEPT 5P NPHI CAb! PEF LbS DEPT NPHI CAb2 PEr 5300 0000 -35 0000 45 3008 14 5647 2 8271 9 3791 SFbU GR RHOB NRAT DPH! GR 5~00,I000 SFLU 49, 375 GR 44,5335 RHOB 12,4219 NRAT 4t36 GR 5100 0000 ~0 SFLU GR DEPT NPH bbs : :i2 9957 GR DEPT NPX CAb ' P~F , DEPT 51,5625 DT ~56 DRHO 3. 39 NCNb 2~,7070 ~SF'L 5 ,6270 SP 10 52 2 3 19 62 8594 4688 DT 3321 DRHO 6234 NCNb 4145 9375 SP 3O 48 35~4 37 0 DT 151~ DRHO 52 NCNb 8359 MSFL 7637 8 8516 ILD 45 468 8 DT 1:258 DRHO 112,0000 GR 0 04'/4 (iR - 6857 CAbI 10 8516 0156 2031 6563 10 8255 '42,7813 GR GR CALI 8 O0 IbM i 0.,0288 GR 22 0,0000 FCNL 5049 LLD 9,2187 19;0840 5LD -61.4297 CALI 007.8 37:5.0GR 4 51,5625 5b,0938 623,5000 7,3447 13,2187 11,1250 52,468~ 63.5269 528,2500 9,2263 13,382~ 8,~844 38. 750 4~,1875 58 ,5000 9,4142 12.8085 8,7734 '9t:83 12'$5i7 54,,097.~ 451"3~90:4 ;:0'It:7 hVP 010,H01 VERIFICATION LISTING PAGg 6 DEPT 4600 SP -32 NPH! 5~ CA~! PEF 0000 SFLU 1875 GR 3242 RHOB 9993 NRAT 465 DPH! 106 GR DEPT 4500 CAbI per bbs 17 0000 8rbu 4375 GR 2610 RHOB 208 NRAT 667 DPHI 5745 GR DEPT 4400 SP -30 NeHI 58 CALI t5 PEF 2 LbS 12 0000 SFLU 9219 GR 304 RHOB 766 NRAT 6738 DPH! 8696 GR DEPT 4.300,0000 SFLU 0000 3'?50 O'O008FhU 1:4 0000 :: S'FbU 4,1914 48,0938 DT 1,9547 DRHO 4,1994 NCNb 43,8232 ~SFL 55,8125 SP 4,3633 IL~ 123,5625 GR O, GR 1133 CAb! 4 48 53 341 5 14 ,6992 ,0938 ,5605 4375 8681 5313 19 6406 I[.,D 8125 PT 0294 DRHO 3 NCNb 1161 aP 19,1719 1~3,0000 GR 0,0412 2678.5000 FCfib 14 6172 LLD -21:0486 CALl 2O 43 46 777 22 13 .3q06 8125 :6465 ,4088 ,8022 ,7031 14,2891 IbD 43,5625 DT ~:0508 DRHO 3750 NCNI., 37,6230 NSFL 47~5576 SP 15,757a IbM 125,3750 GR 0,0020 GR 1947.0000 FCNb 8,2112 hLD '11'.8887 CALl 11 43 47 399 9 13 1797 5625 3!45 5000 4873 8199 I4"3984 IbP 19~9375 DT $:'~;,oo59 24,0693 1:5 5:3t3 .. 0000: FCNb 5469bLD -15..6914 CALI 16,6094 19,9375 21'5098: ¥:ooo:o 14,115~ 0 5 l. D 6,8711 19'67:;'0:0::0:0 2187:: S ;~0':625 CAbI 10,92!9' :I~D: : : It'3672 , 2208,0000 ': 8'60 ...... :.:: .: :4 ,.52:88 9609 O0 00 9:016 . 1b,3,~38 48~9:37::5 19;5940 I2~'234:4: 3,8281 NCNb ,0:~::88 :': 1733 0000 t~Ct'b 5- 8:67p~ bVP OIO,HO1 VERIFICATION LISTING PAGE 7 PEF 2.6699 DPHI bG$ 5,2911 GR DEPT 3800,0000 SFLU SP -56.1250 GR NPHI 47.1129 RHOB PEF 2,~816 DPHI bbs 16. 818 GR DEPT 3700 &P -54 NPHI 49 CAb! 11 P£F 11 0000 SFLU 1875 GR 0890 RHOB 7823 NRAT 4193 DPH! 9824 GR DEP? 3600 8P -7O NPH! 0000 &FLU 9375 GR 1 21 RHOB 308 NRAT DE:PT 3500 0000 8FLU 75.0 GR 52'6: RHOB I GR DEPT: '330:0 O000~:'&FLU ElaT 3200: 'P .:73 2 SP 2461 GR O00'O'-,'SFbU 8906 GR 35 b2l 1 MSFL 49~9888 8P 5,8687 LLD -26.6133 CALl 7,8970 13,5140 11,3828 ILD 44.7188 ,0840 ,6992 NCNL 35,4746 ~SFL 42'5234 i2,203! Ib~ 12, 131,7500 GR 44, '0,0112 GA 44, 2240,0000 FCNL 583, 17,5083 bbD 18, -53,7500 CALl 12. 3a38 7188 6563 0000 16 11.3125 50.3438 DT 1:0117 DRHO ll.828! IL~ 12 135.7500 GR 50 '~,0368 GR 54 207 ,7969 FCNL 472 13.3916 LGD -54.6563 CALI 12 .1484 343B 3394 1875 4954 3416 22 36 2 2 469 ILD 687 DT 6722 DRHO 9829 ~CNI, 22 ~813 iLE 2~,0156 95:625 GR 3 .9687 0,0093 GR 44.4629 3388,9375 FCNL 1004.7500 . : 3203 Lb[ 29,125, 5078 CAL! 12~2725 7 75:39 0~ 1.978' 8:.; -34, 9414 : Ih~ 8.3672 3750 GR 46,6563 0034 GR 50;81614 O000.~Ct~ I416bLD: .9,9180 3652 CALl 12.0065 ,762,7 I3;I~84 906-2 DT ........ ~34.,1250 6:'~::8~i~ :::b~:80'''':'~'' ' :: ,': 0':~::008 i: 6543 SP -51'9629 8'2 81 5000 8745 7891 4 7500 DT 136,7500 GR 8.3;I::25 43.7500 bYP OIO,HO1 VERIFICATION LISTING PAGg a NPH! 47.2329 RHOB 2 CAL! 12,6719 NRAT 3 PEF 2.2969 DPH! 40 ~b~ 9.3799 GR 50 DEP~ 3000,0000 &FLU 9 SP -38,4063 GR 45 NPHI 45,5686 RHOB 2 CAb! 12,8089 NRAT 3 PEF 2,2538 DPH! 37 bbs !1,2859 GR 52 DEPT 2900 NPH! C~b! 12 P£r 2 Lb& 16 0000 SFLU 14 AH00 3837 NRAT 3 5151 DPHI 34 3757 GR 43 D£PT 8P NPH! 2800, 0000 -29 8594 8 DEPT 2700 SP ,-40 ~PH! 57 CAbI 1~ PEr 2 LbS 7 0000 DRHO -0.0132 GR 48.9487 ,6855 NCNL 1743,0000 FCNL 396,7500 .8457 MSFL 8,2240 bLD 10,3221 ,8906 SP '29,6406 CALl 12,8516 ,2157 ILD 9,7266 lbg 8 9531 '3750 DT 124,3750 GR 45:3750 "0549 DRHO 0,0317 GR 51.9429 ~5914 NCNL 1990.2500 FCNL 509,6719 7266 IbD 14.9766 IL~ 14.7266 0938 DT i38,0000 G~ 38,0938 1063 DRHO -0.0248 GR 43.0020 6120 NCNL 2256,4258 FCNL 579,7031 0148 MSFL 22,6094 [,LD 16,0708 2500 SP -64.4854 CALl 12.1719 SFLU 8,1406 ILD iLA 4~1328.. ,5000 GR 1250 GR 4 ,1250 DT 12~'5547 ~ ~OB ,0703 DRHO 0,0610 GR 54,3125 ,30.47 ~.SFL ~,5146 2509 GR 50'30:42 SP - ,5095 CAL! 13,0313 ,0000 SFbU 8 '6875 Ga 49 ,52.97 N.~A:~ .. ~5613 GR 54 7344 iLD 9. 1.979 000:0' I[,M 9, 1250 ~R 49' 02'56iG~ 37.50 FCNb 393' ,4258 CALl 13' 18:75 8t2:5 79:20 ~ 562 549 i: 1992 DEPT 250'0.0'000 '$FLU 8, :07:8::f':::' I:LD 8 ':4:453 I b~k 9.:~0.3:1'3 .SP ,-42., 406:3 GR 32,7:8t3 DT: 1~0,:7500 GA: 3:2,781.3 NPHi ' 46: ~ CAbt 12, 68 ::N:RAT 3,6456 FCNb 51.5,3!50 'bbs 10. 08 GR SP e:40,0654 CAbI 1:2 98~ ':NCNI:, ,~0,9!67 13; 0242 ( 5VP OIO,H01 VERIFICATION LISTING PAGE 9 DEPT 2300 SP -78 NPH! 44 CAb! 12 PEr 2 bbs 14 0000 SFLU 0000 GR 8714 RHOB 2168 NRAT 7883 DPHI 0122 GR 11,6016 ILD 32,9375 DT 144, 2.1377 DRHO -0. 3,5374 NCNL 2234, 32,0068 ~SFL 21. 37,0938 SP -73, DEPT 2200 SP -77 NPH! 46 CAb! 12 PEF ~ bLS 1 0000 SFLU 14 4375 GR 34 0679 RHOB 2 2909 NRAT 3 68~IGRDPHI 32 71 34 0078 IbD 14, 7813 DT 140. /240 DRHO O, 6076 NCNL 21~2, 7995 ~$FL 2~, 2930 SP -7 . DEPT 2100 SP -78 NPH! 47 CA 1~ pE~I 12 0000 SFLU 10,1875 ILD 10. 7969 DPH! 37;3301 Srb I ' 0591 GR 39,0801 SP SP NPH! Lb& 2.0,~0 0000 SrhU HI ' 0 20 O, I66, DEPT 19'81. 0'000 &F~U ':: :~20i0'0 0000:: !LD '9991 9375 IL~ 11.2578 3750 GR 32.9375 0369 GR 38.5645 3750 FCNL 577,0234 6~50 LbO 13,5949 1188 CALl 12,2266 3281 IL~i 13,5000 7500 GR 34.7813 0319 GR 40,9053 7666 FCNL 569.5469 7605 LLD 15,8293 3551 CALI 12,2422 5469 I5~ 11.0547 1250 GR 37,6563 oooo 1:oooo 1432 LbO I 4586 7803 CALl 12~2422 000:0 ILM ' 5000OR 0864 GR~ 37 0000 FCNL 366 479.2LLD 20 8799 CA:L:I 13 25:00 -9:99 25:00 25O0 2500 F.~NL bLD 2.500 5VP OIO,HOI VERIFICATION LISTING PAG& 10 NEXT TAPE NAME I COMMENTS ITAPE COMMENTS ** REEb TRAIbER SERVICE NAME ISERVIC DATE 182/08/27 REEb NAME IREEb CONTINURTION # !O1 NEXT REEb NAME COMMENTS IREEb COMMENT8 EOF EOF
