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195-054
Marathon Oil Company Alaska Asset Team M Marathon P.O. Box 1949 Kenai, AK 99611 MARATHON OBI Company Telephone 907/283-1371 Fax 907/283-1350 August 27, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave ~~~~~~~ SAP y~ r~ 200$ Anchorage, Alaska 99501 ~~J~~"~ ~~ Reference: 10-404 Report of Sundry Well Operations Field: Kenai Gas Field Well: Kenai Tyonek Unit 43-6xRD Dear Mr. Maunder: Attached for your records is the 10-404 Report of Sundry Well Operations for KTU 43-6xRD well. No work was completed under Sundry #300-183, which was obtained to perform a coil tubing clean of KTU 43-6xRD. The work scope changed which led to a later side track work-over of the well. This sundry is being closed out as a non-work operation. This report is a reflection of the well arrangement at the time of work consideration and does not represent the well's current configuration. Submission of this report is part of Marathon's ongoing effort to resolve the backlog of outstanding sundries. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, ` ~~ ..e~TU-,cJ Kevin J. Skiba Engineering Technician Enclosures: 10-404' Report of Sundry Well Operations cc: Houston Well File Kenai Well File KJS ~, -F.i 4- STATE OF ALASKA ~ ~ :` A~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPER~~'~I~`~'` 9, 1. Operations Abandon Repair Well Plug Perforations imu a e "`'` ' `~''~`Other ~ ~~ Non-Work of Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^~ Extension ^ coil tubing Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ clean out 2. Operator Marathon Oil Company 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^~ ~ Exploratory^ 195-054' 3. Address: PO Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20328-01-00 J 7. KB Elevation (ft): 9. WeII Name and Number: 114' above MSL (31' AGL ~ Kenai T onek Unit 43-6xRD 8. Property Designation: 10. Field/Pool(s): A - 028142 ~ Kenai Gas Field / Tyonek Pool 11. Present Well Condition Summary: Total Depth measured 9,535' ' feet Plugs (measured) 9,499' (EZSV) true vertical 8,882' - feet Junk (measured) 9,358' (Fill) Effective Depth measured 9,461' feet true vertical 8,$21' feet Casing Length Size MD TVD Burst Collapse Structural g2' 20" 113' 113' Conductor Surface 2,477' 13-3/8" 2,508' 2,427' 3,090 psi 1,540 psi Intermediate 7,415' 9-5/8" 7,446' 6,880' 6,870 psi 4,750 psi Production 9,503' 7" 9,534' 8,890' 8,160 psi 7,020 psi Liner Perforation depth: Measured depth: 8,453' - 9,462' - True Vertical depth: 7,850' - 8,822' Tubing: (size, grade, and MD) 3-1/2" L-80 7,732' Packers and SSSV (type and measured depth) Baker SAB-3 Packer 7,651' 12. Stimulation or cement squeeze summary: Intervals treated (measured): No well was performed under this sundry. Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA - - - - Subsequent to operation: NA - - - - 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development Q - Service ^ Daily Report of Well Operations 16. Well Status after work: Oil ^ Gas ^~ ~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 300-183 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician ~ Signature s ~ Phone (907) 283-1371 Date August 27, 2008 ~ ~F ~ SEA' ~ ~ X009 Form 10-404 Revised 04/20 ~+ s '~ ~ ~ ~ ~ Submit Original Only ~~ `~ ) ) Alaska Business Unit Domestic Production , --. M MARATHON 4 Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 November 8, 2005 RE C F '''lief) NOV 1 di?n05 Alaska Oi' &~~;~i~ (.IC:¡~~. "..... Anchol'sga Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 Reference: KTU 43-6xrd Abandonment 10-407 Sundry Number: 305-215 ~. . /o-6LY \~J Dear Mr. Aubert: Enclosed is the 10-407 Well Completion or Recompletion Report and Log to abandon the existing perfs in KTU 43-6xrd. This well had been shut in for several months due to apparent casing damage following the addition of perforations. A sidetrack was permitted to recover access to the Tyonek D-1 zone. Prior to drilling the sidetrack, the existing perfs were abandoned. The attached Operation Summary Report details the CIBP placement at 9030'. The plug was then pressure tested to 1500 psi and topped with 90' of displaced 15.8ppg abandonment cement. A second CIBP was placed at 7740' before setting the whipstock. The casing was tested to 2500 psi for 30 minutes prior to milling the sidetrack window. If you need any additional information or have questions, I can be reached by phone at 907-283- 1333 or bye-mail atdmtitus@marathonoil.com. Sincerely, /) ~ ;/1 ,A ~~ 111t..~ 1(,' (4"'11 Denise M. Titus Production Engineer ${;ANNED NOV 1 V 2005 Enclosures: 10-407 Sundry Operations Summary Report Well Schematic STATE OF ALASKA -\ RECEIVEI ALASKA .t AND GAS CONSERVATION COMMIS~ )N i WELL COMPLETION OR RECOMPLETION REPORT AND LOGNOV 1 4 2005 Oil U Gas U Plugged U Abandoned LJ Suspended U WAG U 1 b. Well Class: Alaska Oil 8« Gla ~ônl, Com 20AAC25.105 20AAC25.110 Development [] EXPlorato~~h,,)ragl GINJ 0 WINJ 0 WDSPLD No. of Completions Other Service 0 Stratigraphic TestD 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Marathon Oil Company Aband.: 8/18/05 95-054 3. Address: 6. Date Spudded: 13. API Number: PO Box 196168 Anchorage, AK 99516-6168 July 7,1995 50-133-20328-01-00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 233' FNL, 4160' FWL, Sec 7, T4N, R11W, S.M. August 9, 1995 KTU 43-6xrd Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): 114' KB above MSL Kenai Gas Field/Tyonek 9. Plug Back Depth(MD+ TVD): 9508' MD 8866' TVD 10. Total Depth (MD + TVD): Zone- 4 9535' MD 8892' TVD Zone- 4 11. Depth Where SSSV Set: Zone- 4 NI A 19. Water Depth, if Offshore: NIA feet MSL 1a. Well Status: Total Depth: 2791'FSL, 3796'FWL, Sec. 6, T4N, R11W, S.M. 4b. Location of Well (State Base Plane Coordinates): Surface: x- 275068 y- 2361779 TPI: x- 274656 y- 2364360 Total Depth: x- 274703 y- 2364798 18. Directional Survey: Yes [] No 0 16. Property Designation: A-028142 17. Land Use Permit: NIA 20. Thickness of Permafrost: NIA 21. Logs Run: NIA 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASI NG FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 94 0 113 0 113 Driven 13-3/8" 61 K-55 0 2508 0 2427 17-1/2" 1093 sx 9-518" 47 N-80 0 8370 0 7770 12-1/4" 1792 sx 7" 29 P-110 0 9534 0 8891 8-1/2" 1690 sx 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 9079-99; 9256-76; 9405-62 MD 1 8453-73; 8624-43; 8767-822 24. SIZE 3-1/2" TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 7732 7651 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9405-9462 53k Ibs 20/40 Carbolite + 3.1 k Ib Propnet 26. Date First Production: NIA Date of Test: NIA Hours Tested: Production for Test Period ..... Calculated Oil-Bbl: 24-Hour Rate -. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.): Abandoned Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Flow Tubing Press. 27. Casing Press: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". NIA RBDMS 8Ft NOV 1 (; 2005 O r\ ¡ 1""\ , r\ r A L K i lJ t r\J Form 10-407 Revised 12/2003 CONTINUED ON REVERSE NAME GEOLOGIC MARKERS ML ) TVD 29. 10RMATION TESTS Include and briefly sum. . Ize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 28. Abandoned- 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Denise Titus Printed Name: Den...i~.< M. T.i~tuS.. .......'. ¡Iii 1/1,., Signature: ~I J/W" V Title: Production Engineer Phone: 907-283-1333 Date: 11/8/2005 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for I njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with prod Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional in Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ) ) Page 1 of 8 Marathon Oil Company Operations Summary Report Legal Well Name: KENAI TYONEK UNIT 43-6X Common Well Name: KENAI TYONEK UNIT 43-6X Event Name: RE-ENTRY Contractor Name: GLACIER DRILLLlNG Rig Name: GLACIER DRILLING Date From - To Hours Code Sub Phase Code 7/23/2005 07:45 - 08: 15 0.50 SAFETY MTG_ WBPREP 08:15 - 08:30 0.25 SAFETY MTG_ WBPREP 08:30 - 11 :45 3.25 RURD - SLlK WBPREP 11 :45 - 13:00 1.25 DRIFT_ TBG - WBPREP 13:00 - 14:30 1.50 RURD - SLlK WBPREP 8/2/2005 15:00 - 15:30 0.50 PREP LOC - WBPREP 8/3/2005 09:15 -10:00 0.75 SAFETY MTG - WBPREP 10:00 - 10:15 0.25 SAFETY MTG WBPREP 10:15 - 13:00 2.75 RURD - STIM WBPREP 13:00 -13:15 0.25 TEST_ EQIP WBPREP 13:15 -13:30 0.25 PUMP - WTR_ WBPREP 13:30 - 13:45 0.25 LOAD - TRCK WBPREP 13:45 - 14:00 0.25 PUMP - WTR_ WBPREP 14:00 - 16:00 2.00 RURD STIM WBPREP 8/4/2005 07:30 - 08:00 0.50 SAFETY MTG - WBPREP 08:00 - 08:30 0.50 SAFETY MTG - WBPREP 08:30 - 10:00 1.50 RURD - SLlK WBPREP 10:00 - 11 :30 1.50 TAG_ BOTM WBPREP 8/5/2005 11 :30 - 14:00 2.50 BAIL_ FILL WBPREP 14:00 - 15:00 1.00 RURD - SLlK WBPREP 15:00 - 18:00 3.00 RURD EQIP WBPREP 07:30 - 08:00 0.50 SAFETY MTG - WBPREP 08:00 - 08:15 0.25 SAFETY MTG - WBPREP 08: 15 - 09:00 0.75 RURD - SLlK WBPREP 09:00 - 10:00 1.00 TAG - BOTM WBPREP 10:00 - 11 :00 1.00 RURD - SLlK WBPREP 06:30 - 08:30 2.00 08:30 - 10:30 2.00 10:30 - 10:40 0.17 10:40 - 11 :30 0.83 11 :30 - 13:00 1.50 13:00 - 14:00 1.00 14:00 - 15:00 1.00 15:00 - 17:30 2.50 8/8/2005 Start: 8/11/2005 Rig Release: Rig Number: 1 Spud Date: 7/5/1979 End: Group: Description of Operations Arrive on location, sign in, hold safety meeting and issue permit Complete location safety meeting. Fill out JSA making note of high pressure operations. RU slickline unit. Have problems with PWS tree x-over not holding pressure. Break down x-o, clean, teflon, and reassemble. Good pressure test. RIH wi 2.52" GR to EOT at 7830' KB. No tubing obstructions. POOH. RD slickline unit and depart. Disconnect power from wellhouse. Move in crane truck and pick house from well. Arrive at gas field, sign in, discuss job, and issue permit. Hold wellside safety meeting making note of potential hazards. RU pump truck to well. Wait on tree cxn o'-ring. Wait on pressure transducer to read. RU vac truck to pump truck. Pwh=900psi Pressure test surface lines to 4500psi. Pump KCI water down tubing (initially 900psi). Wellhead pressure fell to zero and started to build slowly. Empty vac truck. Pwh=320psi wi 66bbl KCI away. Re-Ioad vac truck with KCI and observe unchanging pressure Resume pumping. Well started to catch pressure at 68bbl away. Continued pumping to 2500psi wi 92 bbl away. Close valves and leave pressure on well for tomorrow's work. RD pump truck. Arrive on location, sign in and obtain work permit. Hold location safety meeting. Fill out JSA. Rig up slickline unit. RIH wi 2.80" GR. Tag high around 30', manage to work through. Tag again at about 800', unable to penetrate. PU 2" bailer and verify ice plug. RU methanol at the tree and RIH wi GR, attempt to work through fill. Decide to pump methanol over night and rig back wireline. RD slickline RD flowlines and house components to prepare for rig mob Arrive at gas field, sign in, and obtain permit. Inspect work area and fill out JSA RU wireline lub & BOPs to well. RIH wi 2.80" Gauge cutter tag ice at 960'. Hand spang making some progress to 975'. Decide to rig down and continue with methanol RD wireline unit and move to KU 43-7. Wireline unit and crew left shop. Arrived on location. Held PJSM and secured a work permit prior to starting job on site. On location RU on tree. Used wellhead pressure to PT lubricator. MU a 1.5" tool string with spang and oil jars. @.25" star bit on bottom. RIH to confirm if ice still in tubing or has melted. Ran bit down to 2000' POOH no ice in tubing. MU 2.5" GR RIH to 7732' KBD, POOH MU brush to clean out across the X nipples. RIH cleaned both upper an lower X and XN nipples with brush, POOH with brush. MU 2,75" XN plug, RIH to 7729' plug would not set in the 2.635" no-go. POOH with plug. MU a 2.80" GR, RIH tagged up at 7729' confirmed there is a 2.75" no-go. POOH RIH with the 2.813" PX plug to 7697' KBD, Set plug POOH with tool Printed: 11/8/2005 2:23:33 PM ) ) Marathon Oil Company Page 2 of 8 Operations Summary Report Legal Well Name: KENAI TYONEK UNIT 43-6X Common Well Name: KENAI TYONEK UNIT 43-6X Event Name: RE-ENTRY Contractor Name: GLACIER DRILLLlNG Rig Name: GLACIER DRILLING Date From-To Hours Code Sub Phase Code 8/8/2005 15:00 - 17:30 2.50 17:30 - 18:00 0.50 18:00 - 19:00 1.00 19:00 - 19:30 0.50 8/10/2005 08:00 - 08:30 0.50 SAFETY MTG_ WBPREP 08:30 - 08:45 0.25 SAFETY MTG_ WBPREP 08:45 - 09:00 0.25 RURD - ELEC WBPREP 08:45 - 12:00 3.25 BLOWDNTBG_ WBPREP 12:00 - 14:00 2.00 PUMP - WTR_ WBPREP 14:00 - 16:00 2.00 CUT _ TBG_ WBPREP 1.00 RURD_ ELEC WBPREP 18.00 RURD_ RIG_ MIRU 8/11/2005 16:00 - 17:00 12:00 - 06:00 Start: 8/11/2005 Rig Release: Rig Number: 1 Spud Date: 7/5/1979 End: Group: Description of Operations string MU 2" 2." SB and 4' prong to 7697' KBD, set prong POOH Bleed pressure from 3100 psig, to 2275 psig, no change in pressure after 30 minutes. Continue with RD. RD clean up around the area. Left lease for the shop. Arrive at gas field, sign in and obtain work permit Conduct job sight safety meeting Spot and begin RU of APRS equipment. Unit not equipped to run with pressure on tubing. Bleed 2250psi off the tubing to atmosphere through a needle valve. RU Pollard pump truck to fill remaining 3000' of tubing to avoid U-tube problems during pipe cut. Pollard truck had leaking valve stem resulting in small antifreeze spill on liner. Clean up spill and replace valve. Pump 29bbl KCI to fill tubing. RIH wi 2.7" cutter and 1-11/16" tool string. Locate two -6' pups and correlate depth. PUH 15' and cut tubing at 7623'. RD APRS and move out. PJSM, commence move in I rig up on KTU 43-6xrd2. Spot all major components, begin plumbing I elect I hyd connections, scope out mast, cont spot all equip trlrs. Move - 100%, Rig up - 75% No acc I dn time. 8/12/2005 06:00 - 01 :00 19.00 RURD - RIG - MIRU PJSM, cont R/U on KTU 43-6xrd2. To include offload all trlrs for return, CIO pods on pumps CIO section torque tube, calibrate console gauges. Make all plumbing I elect I hyd conn's, test same. Mix brine while R/U, trial run mud system. 01 :00 - 01 :30 0.50 TEST_ TREE CMPPUL PJSM, test xmas tree, confirm hgr seal prior to removal. Sting in BPV, no press on tbg, vac on annulus. Accept Glacier rig #1, this date, 0100 hrs. 01 :30 - 02:30 1.00 NUND TREE CMPPUL PJSM, NID prod tree, inspect hgr neck threads, OK. 02:30 - 06:00 3.50 NUND BOPE CMPPUL PJSM, NIU BOPE No acc I dn time. 8/13/2005 06:00 - 10:00 4.00 NUND BOPE CMPPUL Cont NIU BOPE, function test same. 10:00 - 10:30 0.50 NUND BOPE CMPPUL Pull BPV, install TWC. 10:30 - 13:30 3.00 TEST_ BOPE CMPPUL Prepare I test BOPE, all related components, including choke mnfld, kill I choke lines, mud lines, floor valves, top drive to pumps. 250 I 2500 psi (10 min) Volume I press test accumulator unit. 13:30 - 18:30 5.00 TEST_ BOPE CMPPUL Multiple leaks Ire-tests (CIO top drv valve, re-test XO, choke lines, misc fig conn's) 18:30 - 22:30 4.00 TEST_ BOPE CMPPUL Re-test aforementioned leaking components. All tests successful. 22:30 - 23:00 0.50 TEST_ BOPE CMPPUL PJSM, check for press below TWC, Pull TWC 23:00 - 01 :00 2.00 PULD - TBG - CMPPUL PJSM, back out LDS, M/U Idg jt, work tbg with torque I pull, (incomplete cut), pull tbg free with 140K, (70K over), remaining string wt 70K. Flow check, fill hole 5 bbls. Fluid column stable. 01 :00 - 05:00 4.00 CIRC_ MUD - CMPPUL Circ I displace well bore with 12.2 ppg Flo-Pro. No loss I gain. Circ final 80 bbls gas I fluids thru open choke. Printed: 11/8/2005 2:23:33 PM ) ) Marathon Oil Company Page 30f8 Operations Summary Report Legal Well Name: KENAI TYONEK UNIT 43-6X Common Well Name: KENAI TYONEK UNIT 43-6X Spud Date: 7/5/1979 Event Name: RE-ENTRY Start: 8/11/2005 End: Contractor Name: GLACIER DRILLLlNG Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Sub Phase Description of Operations Code 8/13/2005 01 :00 - 05:00 4.00 CIRC_ MUD - CMPPUL Circ I cond gas cut (11.8 ppg), build to 12.2 ppg. No gain I loss. 05:00 - 06:00 1.00 PULD - TBG - CMPPUL PJSM, RIU equip I floor for 3 1/2 tbg pull I lay dn. No acc I dn time. 8/14/2005 06:00 - 15:00 9.00 PULD - TBG - CMPPUL PJSM, commence POH laying dn 3 1/2 prod tbg. No gain I loss, correct hole fill. 242 jts tot, 1 partial jt 14.86 ft. Note clean cut. 15:00 - 15:30 0.50 RURD CSG - CMPPUL Lay dn tbg pull equip, clear rig floor. Release Weatherford. 15:30 - 17:30 2.00 RUNPULTBG - CMPPUL Rig up rig floor for BHA I overshot run. 17:30 - 19:30 2.00 PULD - BHA_ CMPPUL Set pipe racks, layout I strap BHA #1, MU overshot assy, RIH same. 19:30 - 06:00 10.50 PULD - DP - CMPPUL Follow BHA with 4" DP. 7500 ft at 0600 hrs. No loss I gain, correct displacement. No acc I dn time. 8/15/2005 06:00 - 07:00 1.00 ENGAGE FISH CMPPUL Engage fish at 7612 ft, (3 112 tbg stub), confirm catch. 07:00 - 08:00 1.00 CIRC_ CFLD CMPPUL Pump wt pill, prepare POH 08:00 - 14:00 6.00 TRIP - DP - CMPPUL PJSM, flow check, POH 4" DP, slow go with fish No drag I gain I loss, correct hole fill. 14:00 - 14:30 0.50 PULD - BHA_ CMPPUL Flow check, handle BHA #1, no fish, adjust overshot, handle BHA #2, RIH same assy. 14:30 -15:00 0.50 SERVIC RIG_ CMPPUL Service rig 15:00 - 19:00 4.00 TRIP - DP - CMPPUL Flow check, follow BHA with 4" DP to 7612 ft. 19:00 - 20:00 1.00 ENGAGE FISH CMPPUL Engage fish at 7612 ft, (3 1/2 tbg stub), confirm catch with pump press and up I dn wt. Release "K" anchor. 20:00 - 20:30 0.50 CIRC - CFLD CMPPUL Pump wt pill, prepare POH 20:30 - 03:00 6.50 TRIP - DP - CMPPUL PJSM, flow check, POH 4" DP, slow go with fish No drag I gain I loss, correct hole fill. 03:00 - 03:30 0.50 PULD - BHA_ CMPPUL Flow check, handle BHA #2, fish tight in wellhead, appears to be "ring" at btm K anchor. Work fish, "ring" falls in wellbore. retrieve tbg stub I "K" anchor. Lay dn fish I related BHA. 03:30 - 04:00 0.50 PULD - BHA_ CMPPUL Flow check, MU BHA #3 (Pkr mill assy), RIH same. 04:00 - 06:00 2.00 TRIP - DP - CMPPUL Flow check, follow BHA with 4" DP to 2800 ft at 0600 hrs. No gain I loss, correct displacement. No dn drag. No acc I dn time. 8/16/2005 06:00 - 08:30 2.50 TRIP - DP - CMPPUL Cont RIH 4" DP to tag at 7634 ft. 08:30 - 10:00 1.50 CIRC_ MUD - CMPPUL Flow check, wash fill to pkr at 7639 ft 10:00 - 16:00 6.00 MILL_ PKR_ CMPPUL PJSM, mill I catch pkr 7639 - 7646 ft, pkr free Flow check, push pkr to 7788 ft. Drop bar to pump out sub. Shear pin with 1300 psi. 16:00 - 20:00 4.00 CIRC_ MUD - CMPPUL Flow check, circ pkr cuttings I btm hole gas to surface. Shut in BOPE, circ through choke at first indication gas. 300 psi ann, 0 psi tbg. Create pumping schedule, cont circ btms up gas through choke. Max 1500 units. PJSM, Open BOPE, flow check, circ hi-vis I wt pill. 20:00 - 03:00 7.00 TRIP - DP - CMPPUL PJSM, POH pkr on 4" DP, slow going, pkr drag. No gain I loss, correct hole fill. 03:00 - 05:30 2.50 PULD - BHA_ CMPPUL Flow check at BHA. lay dn pkr I fish tools. PJSM, drill relief holes above I below X nipple, no gas. Lay dn tail pipe I X nipple. Entire assy retrieved. 05:30 - 06:00 0.50 CLEAN - RIG_ CMPPUL Clear rig floor, prepare scraper run. No acc I dn time. 8/17/2005 06:00 - 06:30 0.50 REPAIR RIG - PLUGAB Replace link tilt hyd mounts, Top Drv 06:30 - 07:30 1.00 PULD - BHA_ PLUGAB MU BHA #4, 7" csg scraper, RIH same. Printed: 11/8/2005 2:23:33 PM ) ) Marathon Oil Company Page 4 of 8 Operations Summary Report Flow check, follow BHA with 4" DP to 7680 ft Slow going, pipe flow back. Attempt pump wt pill for flow back, immediate gas buildup. CBU through choke as precaution, pump wt pill. Max gas 400 units. Flow check, resume RIH 4" DP to 9072 ft. Flow check, circ wellbore clean, max btms up gas 600 units. Pump hi-vis sweep, follow with wt pill. no gain I loss Flow check, POH 7" scraper for CIBP. No gain I loss, up drag normal. Handle BHA, lay dn 7" scraper I junk bskts I jars. Replace link tilt hyd mounts, Top Drv. PJSM, MU 7" CIBP I BHA No acc I dn time 1.5 hrs top drv Service rig Handle BHA, MU CIBP, RIH same. Flow check, follow BHA with 4" DP to 9030 ft. Circ I cond fluids, balance out spotted mud wts. Well bore clean. Set CIBP 9030 ft, confirm set. Test csg I CIBP 1500 psi I 30 min. Test successful. Mix I pump cmt plug as follows: Prehydrate chems, pump 3 bbls H2o, test lines 2500 psi, pump 3.5 bbls 15.8 ppg cmt, pump 1 bbl H2o behind. Displace correct displacement 89 bbls mud Full returns, no loss I gain Circ I cond fluids at 8830 ft, trace cmt at surface. PJSM, POH 4" DP, no gain I loss Repair elevator control switch Resume POH 4" DP to BHA. Flow check, lay dn CIBP run tools. MU CIBP #2, RIH same Flow check, follow BHA with 4" DP to 7740 ft. No acc I .5 hr dn time Test CIBP & CSG. 2,500 psi Hold F 30 Min Test Good PJSM; Slip 40' Drlg. Line Monitor Well, Pump Dry Job, Pooh WI CIBP Running Tool Safety meet, all personnel. Flow check, lay dn CIBP run tools release HOWCO Handle BHA #5, MU mill, drcnl assy, RIH same, drift possible tight csg to 400 ft, csg free, test MWD, all tests successful. MU whipstock assy to BHA Flow check, follow BHA with 4" DP to 7723 ft. Orient whipstock, set I shear at 7723 ft. Commence mill window 7" csg 7723 -7748 ft Metal shavings I cmt I 10% formation to surface No gain I loss No acc I dn time 2.50 MILL_ WNDW SIDET Cont mill window 7" csg, 7748 - 7756 ft. Trace metal I cmt, 100% fmtn returns. No gain I loss 0.50 CIRC_ MUD_ SIDET Circ I cond fluids for FIT Legal Well Name: KENAI TYONEK UNIT 43-6X Common Well Name: KENAI TYONEK UNIT 43-6X Event Name: RE-ENTRY Contractor Name: GLACIER DRILLLlNG Rig Name: GLACIER DRILLING Date From - To Hours Code Sub Phase Code 8/17/2005 07:30 - 12:30 5.00 TRIP - DP - PLUGAB 12:30 - 14:30 2.00 CIRC_ MUD - PLUGAB 14:30 - 16:30 2.00 TRIP - DP - PLUGAB 16:30 - 21 :00 4.50 CIRC_ MUD - PLUGAB 21 :00 - 03:00 6.00 TRIP - DP - PLUGAB 03:00 - 04:00 1.00 PULD BHA_ PLUGAB 04:00 - 05:00 1.00 REPAIR RIG - PLUGAB 05:00 - 06:00 1.00 PULD - BHA_ PLUGAB 8/18/2005 06:00 - 06:30 0.50 SERVIC RIG - PLUGAB 06:30 - 07:30 1.00 PULD - BHA_ PLUGAB 07:30 - 13:30 6.00 TRIP - DP - PLUGAB 13:30 - 14:30 1.00 CIRC_ MUD - PLUGAB 14:30 - 15:00 0.50 SETREL PLUG PLUGAB 15:00 - 16:00 1.00 TEST_ CSG_ PLUGAB 16:00 - 17:30 1.50 PUMP - CMT_ PLUGAB 17:30 - 18:30 1.00 CIRC_ MUD - PLUGAB 18:;30 - 20:30 2.00 TRIP - DP PLUGAB 20:30 - 21 :00 0.50 REPAIR RIG_ PLUGAB 21 :00 - 22:30 1.50 TRIP - DP - PLUGAB 22:30 - 23:00 0.50 PULD - BHA_ PLUGAB 23:00 - 00:00 1.00 PULD - BHA_ PLUGAB 00:00 - 06:00 6.00 TRIP - DP - PLUGAB 8/19/2005 06:00 - 07:00 1.00 TEST - PLUG PLUGAB 07:00 - 07:30 0.50 SLPCUT DLlN PLUGAB 07:30 - 12:00 4.50 TRIP - DP - PLUGAB 12:00 - 13:00 1.00 SAFETY MTG_ PLUGAB 13:00 - 13:30 0.50 PULD - BHA_ PLUGAB 13:30 - 15:30 2.00 PULD - BHA_ SIDET 15:30 - 16:00 0.50 PULD - BHA_ SIDET 16:00 - 22:30 6.50 TRIP - DP - SIDET 22:30 - 23:00 0.50 SURVEY DIR_ SIDET 23:00 - 06:00 7.00 MILL_ WNDW SIDET 8/20/2005 06:00 - 08:30 08:30 - 09:00 Start: 8/11/2005 Rig Release: Rig Number: 1 Spud Date: 7/5/1979 End: Group: Description of Operations Printed: 11/8/2005 2:23:33 PM KTU 4 d ment Pad 41..7, Kenai Gas Field J API: '50-133-20328-00 AOGCC: 95-054 RT-MSL (Original Drlg): 31.1' KB-THF 2791'FSL, 3796'FVVL, Sec. 6, T4N, R11VV, S.M. Lift threads: ??? Tree cap: 4-3/4" Otis Cement plug: 8936' -9030' 15.8ppg cmt CIBP @ 9030' Fill: 9491' KB (7/99) 9155' MD (3/02) 9467' KB (4/03) 9141' KB (7/04) l 94#, drivepipe @ 113' 13-3/8",61#, K-55, BTC Surface Casing @ 2508' Cmt w/1 093 sks of class "G" ... milled in 9-5/8" @ 7446'-7510' (7/18/95) . Cmt w/1792 sks of class "G" CIBP @ 7740' Active Perfs (Tvonek Formation) 84-6: 9,079'-9,099' (1/30/97 & 12/16/96) 9,088'-9,098' (reperf2/13/04) 86-2: 9,256'-9,276' (2/13/04) D-1: 9,405'-9,462' (9/1/95 & 9/26/95) 9,442'-9,462' (reperf 2/13/04) 7", 29#, N-80, BTC, 9,534' Cmt w/1690 sks of class "G" '- "-' Alaska Business Unit Domestic Production r ~ M Marathon "MARATHON~ ' Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 August 11 , 2005 RECEIVED AUG 1 8 2005 Alaska Oil & 68 C s on8. Commission Anchorage Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 fq'7~~'Ó~ Reference: KTU 43-6xrd SClA.~\j,h!E' . ì r:; ~? ? Dear Mr. Aubert: In preparing Sundries for upcoming work, I VIlas unable to find a subsequent report for perforating which took place in February 2004. Enclosed is the 10-404 Report of Sundry Well Operations for perforating Marathon well KTU 43-6xrd. Additionally, a summary of events and an updated schematic are included to complete the records for this event. Although the perforating initially yielded good results, it is believed to be the cause of severe sanding which ultimately required shutting the well in. An upcoming sidetrack will be required to restore production to the zone that was flowing prior to the perf additions. If you need any additional information, I can be reached at 907-283-1333 or bye-mail at dmtitus@marathonoil.com. Sinc~rely, I~ [1 ¡ , ; l\~' ~ / Denise M. Titus Production Engineer Enclosures STATE OF ALASKA AlA~\ Oil AND GAS CONSERVATION COMrvn-òION REPORT OF SUNDRY WELL OPERATIONS RECEI\/ED PlUG 1 8 2005 1. Operations Abandon U Performed: Alter Casing D Change Approved Program D 2. Operator Name: Repair Well U Pull Tubing D Operat. Shutdown D Plug Perforations U Perforate New Pool D Perforate 0 4. Current Well Class: Development D Stratigraphic D Stimulate U AlatR~EßilB1 COmml8SÎC n WaiverD Time Extension D Anthûr~ge Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 95-054 ServiceD 6. API Number: 50-133-20328-01 Marathon Oil Company P. O. Box 196168, Anchorage, AK 99519- 6168 7. KB Elevation (ft): 3. Address: 9. Well Name and Number: 114' above MSL KTU 43-6xrd 8. Property Designation: 10. Field/Pool(s): Kenai Unit Kenai Gas Field/Tyonek 11. Present Well Condition Summary: Total Depth measured 9535 feet true vertical 8892 feet Effective Depth measured 9461 feet true vertical 8821 feet Casing Length Size MD Structural 113 20" 113 Conductor Surface 2,508 13-3/8" 2508 Intermediate Production 8,370 9-5/8" 7446 Liner 3,905 5-1/2" 3905 Perforation depth: Measured depth: 9079-99; 9256-76; 9405-62 True Vertical depth: 8453-73; 8624-43; 8767-822 Plugs (measured) N/A Junk (measured) N/A TVD Burst Collapse 113 N/A N/A 2427 3090 1540 6880 6870 4750 3827 7740 6280 Tubing: (size, grade, and measured depth) 3-1/2" 9.3ppf N-80 7732 Packers and SSSV (type and measured depth) Baker SAB-3 packer 7651' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS BFL AUG 1 9 1005 Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure Tubing Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: OilD Gas 0 WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service D x GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: 304-033 Contact 'DtlA.ì~ '1 ,~? lJeV\\se \\A~ \\\0.., it '"- \ } /}A. I 'LAr-=- vvr ¡/UIY[I" ~ Title y r"J,1Ac; t\,¡V. ~ '~f- o RTG \lNÄt-I?'~) <;.Î I /' Date D j 'l t S I Submit Original Only Printed Name Signature Form 10-404 Revised 04/2004 " , AA MARATllOI t KTU 43-6xrd Pad 41-7, Kenai Gas Field '~ API: '50-133-20328-00 AOGCC: 95-054 -- RT-MSL (Original Drlg): 31.1' KS-THF 2791'FSL, 3796'FVVL, Sec. 6, T4N, R11W, S.M. Lift threads: ??? Tree cap: 4-3/4" Otis TubinQ StrinQ - 3-1/2", 9.3#, L-80,EUE 8rd to 7,729' Cameo sidepocket inj mandrel @ 1014' Saker 80-40 K-Anchor @ 7650' Saker SAS-3 Packer @ 7651' X-nipple @ 7697' ID = 2.813" X-nipple @ 7729' ID = 2.750", no-go 2.635" Wireline Re-entry Guide @ 7732' Fill: 0'10'1' KB (7/99) 9'155' MD (3/02) 9'167' KB ('1/03) 9141' KB (7/04) ~~ j .. ~.1 J 'I ~ ¡ ~ J ] :! i AI t 'i " i ~ A . =- ::II: ::J ::II: ::II: ::II: :::a ..IIIIIIIIII PSTD - 9499' TD - 9534' ..... 120",94#, drivepipe @ 113' ~ 13-3/8",61#, K-55, STC Surface Casing @ 2508' Cmt wI 1093 sks of class "G" ~ 9-5/8",47#, N-80, STC @ 8,370' Hole milled in 9-5/8" @ 7446'-7510' (7/18/95) Orig. Cmt wI 1792 sks of class "G" Ie: -= r:: -== -== Active Perfs (Tvonek Formation) 84-6: 9,079'-9,099' (1/30/97 & 12/16/96) 9,088'-9,098' (reperf 2/13/04) 86-2: 9,256'-9,276' (2/13/04) D-1: 9,405'-9,462' (9/1/95 & 9/26/95) 9,442'-9,462' (reperf 2/13/04) -== -== 7", 29#, N-80, STC, 9,534' Cmt w/1690 sks of class "G" " =-' Marathon Oil Company Operations Summary Report Legal Well Name: KENAI TYONEK UNIT 43-6X Common Well Name: KENAI TYONEK UNIT 43~6X Event Name: MAINTENANCE/REPAIR Contractor Name: Rig Name: S b ' I Date From - To Hours Code C~de I Phase ' i 1/25/2004 - 11 :00 3.50 \ WBPREP 11:00 -13:00 2.00 WBPREP 13:00 - 14:30 1.50 WBPREP 14:30 - 15:00 0.50 I WBPREP 2/13/2004 08:00 - 11 :00 3.00 11 :00 - 11 :30 0.50 11:30-12:30 1.00 12:30 - 13:00 0.50 13:00 - 13:30 0.50 Page 1 of 1 Start: 1125/2004 Rig Release: Rig Number: Spud Date: 7/5/1979 End: Group: Description of Operations Expro arrive on location. MU tool string with 2.300" GR. PT well with WHP. WHP= 950 psig. No leaks RIH to tag fill. RIH making a dummy run with GR. Ttagged fill at 9507 KBD. POOH with 2.3" GR. MU tandem gauges, RIH making 3 minute stops at the following depths. 0,2000,4000,6000,6500,7000,7500,8000,8500,9000, 9200 & 9436'. POOH at 120 FPM. Check data, data good. Turn well over to production. Move to CLU#1. MI RU Expro. Held safety and envirinmental meeting and discussed procedure. Well flowing at 1.8 MMCFP, 825 psig at well. MU 2 3/8" Owen guns with 4 SPF, 60 deg phasing. PT lubricator with WHP. Lubricator good, used safe firing system. RIH correlate depth with Gammy ray & CCL to previous log. Locate 1st gun run at 9442' - 9462', 20' gun. WHP= 825 psig, fired gun. POOH with 1st gun. WHP @ 825 psig, Rate at 1500 MMCFPD. * unable to test well problem with the test separator. OOH all shots fired MU 2nd gun run, RIH to 9256' 9276' (20') gun. locate gun on depth. WHP = 820 psig. Fire gun. WHP came up 75 psig @ rate increased to 2800 MMCF after 10 minutes. POOH with gun Well acting like making fluid, no way to meter rate. OOH with gun, all shots fired RIH with 3rd gun, correlate to 9088'- 9098' (10') gun, fired gun pressure at tree at 825 psig. No change in pressure. No change in flow rate. Well at 2547 MMCFP rate. RD wire line secure well EPG IMt lease. Printed: 8/11/2005 3:01 :06 PM , , M MARATHON . ~ Alaska Business Unit Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 August 2, 2005 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 RECE.\VE,D AUG 0 2 2005 L. Q'\ &. Gas Got'\Š. GQ('nmiAs~O" A\ª~"a .t Anchorage Reference: KTU 43-6xrd Abandonment Sundry Dear Mr. Aubert: Enclosed is the 10-403 Sundry Application to abandon the existing perfs in KTU 43-6xrd. This Tyonek well has not been capable of production since the addition of the 86-2 perforations and has been idle since March 2004, A sidetrack has been proposed to resume production from the well. Marathon would like to abandon the existing zone, and twin the well bore to regain access to the Tyonek 0-1 zone. ,,/ The attached procedure to abandon the perfs conforms to State regulation 20 AAC 25.112 for abandoning isolated perforations in casing. With approval, a CIBP will be set no more than 50' above the perfs and capped with a minimum of 75' of cement prior to a sidetrack perthe attached procedure. This work is expected to begin as soon as we receive agency approval. I have attached a procedure and a proposed well bore diagram. If you need any additional information or have questions, I can be reached by phone at 907-283-1333 or bye-mail atdmtitus@marathonoil.com. Sincerely, t1/1 ~ · Cor 'J)W\r Denise M. Titus Production Engineer Enclosures: 10-403 Sundry Abandonment Procedure Proposed Well Schematic ORIGINAL Cj?J- S .- 2 -0 5' V-JGI\- -K 12( LO o~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL / 20 MC 25.280 Suspend U Operational shutdown U Repair well 0 Plug Perforations 0 Pull Tubing 0 Perforate New Pool 0 4. Current Well Class: /' 5. Permit to Drill Number: Exploratory 0 95-054./ o 6. API Number: 01 50-133-20328-:0&- Abandon ~ Alter casing 0 Change approved program 0 2. Operator Name: Marathon Oil Company 3. Address: 1. Type of Request: PO Box 196168 Anchorage, AK 99516-6168 7. KB Elevation (ft): 114' above MSL 8. Property Designation: Kenai Unit 11. Total Depth MD (ft): 9535 Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 9079-99; 9256-76; 9405-62 Packers and SSSV Type: Total Depth TVD (ft): 8892 Length 113 2508 8370 9534 RECEIVED AUG 0 2 Z005 Perforate U AI w~Yei Ar;mular Dispos·.U . D. a~L-a wi as Cons. Comml~ m Stimulate Time "Extension Oflìer U Re-enter Suspended Well chorage Development Stratigraphic o o Service wCJ.\ 9. Well Name and Number: KTU 43-6xrd / 10. Field/Pools(s): Kenai Gas FieldlTyonek PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9461 8821 N/A N/A Size Burst Collapse 20" N/A N/A 13-3/8" MD TVD 113 113 2508 , 2427 ~ 4~9/ 6880 -9534 / 8890 Tubing Size: Tubing Grade: 3-1/2" 9.3ppf N-80 9-5/8" 7" Perforation Depth TVD (ft): 8453-73; 8624-43; 8767-822 Packers and SSSV MD (ft): Baker SAB-3 packer 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: 8/9/2005 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: ~ Oil 0 Gas ~ ~G~IUgged WAG 0 GINJ 0 WINJ Date: Commission Representative: 17; I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Denise Titus Printed Name Denise M. Titus Title Production Engineer Signature f?!( (?~ Þ D V)T Phone 907 -283-1333 Date COMMISSION USE ONLY 3090 1540 6870 8160 4750 7020 Tubing MD (ft): 7732 7651' / Service 0 o o Abandoned WDSPL o o 8/2/2005 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .3ÐS--Øl../ ~ Plug Integrity 0 BOP Test ~ o Location Clearance 0 "- 7 ~ J,,¡ teð~4 RBDMS BFl AUG 0 4 2005 Mechanical Integrity Test Other:\ e ç l- ß 0 P E ffi' l S (!) ([) p ~~ / L~ ~ Form 10-403 Revised 12/2003 COMMISSIONER BY ORDER OF THE COMMISSION ORIGINAL INSTRUCTIONS ON REVERSE Date: o/(¿ Submit in Duplicate , ~ M MARATHON 4 Marathon Oil Company Alaska Region KTU 43-6xrd Kenai Gas Field, Pad 41-7 Abandonment Procedure History: Well KTU 43-6xrd is a 3-1/2" tubing Tyonek completion in 7" casing. The well has /' previously been sidetracked out a window in 9-5/8" casing. A pennit to sidetrack the well again has recently been submitted due to suspected casing damage from the addition of a high pressure zone. Objective: Abandon the existing Tyonek perforations prior to sidetracking operations. A CIBP will be installed within 50' of the top of the Tyonek perforations and capped with at least 75' of cement to abandon the perfs. Procedure: 1. PU CIBP. Rlli to 9030' (within 50' above top perf). Set CIBP and pressure test casing to 1500psi. 2. Displace at least 3bbl (16fe) 15.8ppg abandonment cement to end of drillpipe ('--77' in 7" csg). ..~ 3. PU 200' and circulate. POOH. ( L 'G..k. Th,{¡ s \ 0," 4 o'~ "'-'P rye·l/t;.. . \hi.. 4. PU another CIBP and set at ",7700'MD as a platfonn to run whipstock and proceed wi sidetrack. f2< ~r .-\--c ...Jd;k''Vl~1 JA~ I , I .......,.... '~ì 1') z· 0 5-- I '7 . \t..i G 1\-'0 Attachment Cement Volumes: Cement above CIBP: Top ofCIBP: 4360' Required cement: 75' Casing volume in 7", 29ppf: 0.2085 ft3/ft Density: 15.8 ppg, Yield: 1.15 fe/sx Minimum Required Cement: 15.6 ft3 " , AA 1UU11I0II f KTU 43-6xrd Pad 41-7, Kenai Gas Field API: '50-133-20328-00 AOGCC: 95-054 ~ RT-MSL (Original Orlg): 31.1' KB-THF 2791'FSL,3796' FVVL,Sec.6, T4N, R11VV, S.M. ~ Lift threads: ??? Tree cap: 4-3/4" Otis TubinQ StrinQ - 3-1/2",9.3#, L-80,EUE 8rd to 7,729' Camco sidepocket inj mandrel @ 1014' Baker 80-40 K-Anchor @ 7650' Baker SAB-3 Packer @ 7651' X-nipple @ 7697' 10 = 2.813" X-nipple @ 7729' ID = 2.750", no-go 2.635" VVireline Re-entry Guide @ 7732' Fill: 9-19-1' KB (7/99) 9-155' MD (3/02) 9-167' KB (-1/03) 9141' KB (7/04) ~1 ~,~ ~ ... .~ I ~ I , II '. I ~ ¡ I ~ ; ~ : ~ : !i =- =- ::J =- =- :::Ie =- PBTO - 9499' TD - 9534' .. \20",94#, drivepipe @ 113' ~ 13-3/8",61#, K-55, BTC Surface Casing @ 2508' Cmt w/ 1093 sks of class "G" ~ 9-5/8",47#, N-80, BTC @ 8,370' Hole milled in 9-5/8" @ 7446'-7510' (7/18/95) Orig. Cmt w/ 1792 sks of class "G" / II:':: II:':: I::: c:: c::: Active Perfs (Tvonek Formation) 84-6: 9,079'-9,099' (1/30/97 & 12/16/96) 9,088'-9,098' (reperf 2/13/04) 86-2: 9,256'-9,276' (2/13/04) D-1 : 9,405'-9,462' (9/1/95 & 9/26/95) 9,442'-9,462' (reperf 2/13/04) c:::: c:::: 7",29#, N-80, BTC, 9,534' Cmt wi 1690 sks of class "G" " , N& IlARATllOII ~ KTU 43-6xrd Proposed Abaondonment Pad 41-7, Kenai Gas Field API: '50-133-20328-00 AOGCC: 95-054 ~ ~ 120", 94#, drivepipe @ 113' RT-MSL (Original Orlg): 31.1' KB-THF 2791'FSL, 3796' FVVL,Sec. 6, T4N, R11VV, S.M. A ~ 13-3/8",61#, K-55, BTC Surface Casing @ 2508' Cmt w/ 1093 sks of class "G" Lift threads: ??? Tree cap: 4-3/4" Otis Tubinq Strinq - 3-1/2", 9.3#, L-80,EUE 8rd to 7,729' Camco sidepocket inj mandrel @ 1014' ... ~ Baker 80-40 K-Anchor @ 7650' Baker SAB-3 Packer @ 7651' 9-5/8",47#, N-80, BTC @ 8,370' Hole milled in 9-5/8" @ 7446'-7510' (7/18/95) Orig. Cmt w/ 1792 sks of class "G" X-nipple @ 7697' 10 = 2.813" X-nipple @ 7729' 10 = 2.750", no-go 2.635" VVireline Re-entry Guide @ 7732' CIBP -9030' w/ at least 75' / cement cap -8955'-9030' / /' J =- =- ::I =* ::x II: c: a:: II:::: c: Active Perfs (Tvonek Formation) 84-6: 9,079'-9,099' (1/30/97 & 12/16/96) 9,088'-9,098' (reperf 2/13/04) 86-2: 9,256'-9,276' (2/13/04) 0-1: 9,405'-9,462' (9/1/95 & 9/26/95) 9,442'-9,462' (reperf 2/13/04) =- =- II:::: -= Fill: 9~9~' KB (7/9-9) 9~ 55' MD (3/02) 9~6T KB (~/03) 9141' KB (7/04) 7", 29#, N-80, BTC, 9,534' Cmt w/ 1690 sks of class "G" PBTD - 9499' TO - 9534' Alaska Business Unit Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 February 3, 2004 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: KTU 43-6xrd Dear Mr. Aubert: Enclosed is the 10-403 Application for Sundry Approvals for Marathon well KTU 43-6xrd. / The proposed work is to target additional pay by adding perforations to the well bore. The perfs to be added are included in the enclosed procedure. This work is expected to begin around Monday, February 9th. If you need any additional information, I can be reached at 907-283-1333 or bye-mail at dmtitus@marathonoil.com. ~ ~qq- L 1 "S ) Sir~ Denise M. Titus Production Engineer Enclosures RFr'c~VED F ç u 4 2004 Alaska O.i & hk~ Jns. Commj~$iQn; ArH.:norage 8(ÇÞ~INj~E¡Ü rEB 1 8 2ÛOl~ ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS n :\d r'9\k9f\43-6xrd\AoGcc021's \1--161\ 'liS ¡.oc>L( /}rJ 2rs/~ 1. Type of Request: Abandon Alter Casing Change Approved Program Suspend - Repair Well- Pull Tubing 5. Type of Well: Development~ Exploratory - Stratigraphic - Service Operation Shutdown Plugging - Variance Re-enter Suspended Well- Time Extensior Stimulate Perforate X Other 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 6. Datum Elevation (DF or KB) 114' KB above MSL 7. Unit or Property Name Kenai Tyonek Unit 8. Well Nu feet At Effective Depth I Add Perforations ) / KTU 3~,6xrcl 9. Per ." -Number .94-~ i c¡ 5- Des . . 10. API Number 50-133-20328..08" " 11. Field/Pool Kenai Gas Field/Tyonek vJ'* lIJ(¡k 233' FNL, 4160' FWL, See 7, T4N, R11W, S.M. At top of Productive Interval At Total Depth 2791' FSL, 3796' FWL, Sec. 6, T4N, R11W, S.M. 12. Present Well Condition Summary Total Depth: measured true vertical 9535 feet 8892 feet Plugs (measured) Effective Depth: measured 9461 feet true vertical 8821 feet Casing Length Size Structural 113 20" Conductor Surface 2508 13-3/8" Intermediate Production Liner Perforation Depth: measured true vertical Junk (measured) Cemented Driven Measured Depth 113 True Vertical Depth 113 1 093 sks 2508 2427 8370 9-5/8" 1792 sks 9534 7" 1690 sks 84-6 Sand: 9079' - 9099', D-1 Sand: 9405' - 9462' 7446 9534 6880 8890 Tubing (size, grade, and measured depth) 3-1/2", L-80, 7732' MD R'E C r:" ~ ,. FEr' " 4 ?nn4 ) 84-6 Sand: 8453' - 8473', D-1 Sand: 8653' - 8708' Packers and SSSV (type and measured depth) Baker SAB-3 packer @ 7651' ,'\'Jaska Oil (~ \,~";,,¡¡¡,.~...mm¡ssÎon Anctwfage 13. Attachments Description Summary of Proposa~ Detailed Operations Progra~ BOP Sketch 14. Estimated 'á~~ for Commencing Operation /9,?2'Q04 as Verbally Approved 15. Status of Well Classification as: 16. If Propo Oil Gas X Suspended- Name of Approver Date Approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Denise M. T Title Production Engineer R COMMISSION USE ONLY Conditions of Approval: Notify Commission so represe tive m y witness Plug Integrity - t Location Clearance Mechanicallntegrit ent Form Required 10--efO 4- Date 2/3/2004 Signed Approval No. 30 -033 Approved by Order of the Comm io Form 10-403 Rev. 06/15/88 Commissioner \G\NAL --~L f'iß 0 ~ 'lU"' Marathon Oil Company Alaska Region KTU 43-6xrd Kenai Gas Field, Pad 41-7 Add Perforations Procedure WBS # WO.03.09902.EXP History: KTU 43-6xrd is completed with 3-1/2" tubing in a 7" wellbore. Objective: Add new perforations in KTU 43-6xrd and reperforate existing zones. / Procedure: 1. Ensure location and tree are prepped for wireline including liner installation and house removal if necessary. 2. MIRU wireline unit. 3. Perforate the following zones with 2-3/8" 4SPF, retrievable guns: /' 9442' -9463' (21') 9256' -9276' (20') 9088'-9098' (10') 4. Clean up location. RDMO eline, and return well to system per instruction of production engineer. Flow back to open top tank if necessary. ( ~ MEMO TO EACH WELL FILE LISTED BELOW Date January 7, 2004 Two previously undefined intervals, the Dl sand of the Tyonek Formation and the Beluga Formation in the Kenai Unit of the Kenai Gas Field, have been combined into a single defined pool the Kenai, Beluga/Tyonek Gas Pool, field & pool code number 448571. This change was effective in January 2004. Production from these two intervals had previously been reported to production codes 448569 Kenai, Beluga Undefined Gas and 448570 Kenai, Tyonek Gas. These codes have been deleted from some of the wells listed below. The wells listed below have had their production records modified reflecting this change. 184-109 181-153 195-055 174-050 178-055 177-029 185-181 202-043 179-029 184-108 199-024 200-188 200-1 79 ~~;ÇANNEfC) JU\N 2 ~ 2004 KBU 23X-06 KBU 31-07 KBU 31-07RD KU 14-06RD KDU5 KBU 13-08 KBU 33-07 KTU 32-07H KBU 41-07 KTU 13-05 KBU 33-06 KBU 24-06 KBU 44-06 200-023 168-049 184-108 199-024 195-054 203-066 199-073 195-054 169-012 179-030 199-025 202-025 KTU 32-07 KDU2 KTU 13-05 KBU 33-06 KTU 43-06XRD KBU 43-07X KTU 24-06H KBU 43-06XRD KDU4 KBU 43-06X KBU 42-07 KBU 41-07X IVlarathon Oil Company Alaska Business Unit Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907~564.6489 June 26, 2003 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: KTU 43-6xrd Dear Mr. Aubert: Enclosed is the 10-422 Facility Report of Produced Gas Disposition for Well KTU 43-6xrd in the Kenai Gas Field. The attached reports detail the planned disposition which took place In conjunction with coiled tubing jetting operations. A total volume of 146 MCF of gas was vented over a 7 hour duration. If you need any additional information, I can be reached at 907-283-1333 or by e-mail at d mtitu s@ ma ratho noil. com. Sincerely, Denise M. Titus Production Engineer Enclosures ,CANNED/~UG 0 & 2003 ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION Facility Kenai Gas Field IOperator Marathon Oil Company Field Well KTU 43-6xrd Month/Year Disposition June, 2003 Disposition Volume MCF* 1. Sold 0 2. Reinjected 0 3. Flared or vented less than 1 hour 0 4. Flared or vented greater than 1 hour 146 ,/ (Supplemental report required - see 2(I ACC 25.235) 5. Pilot and Purge 0 6. Used for lease operation 0 7. Other 0 TOTAL items 1-7 146 8. NGL gas equivalent produced 0 9. Purchased gas 0 10. Transferred from: 0 11. Transferred to: 0 Remarks: Planned venting during CT jetting operation. I hereby certify ?hat the foregoing i~stJ~ue and correct to the best of my knowledge. i '1 '-//L ,.. //. Form 10-422 Rev. 4/95 / *Indicate contribution of each pool to total Pool Name Code Percent' ' 100% Kenai Tyonek Unit ~?6fficial Use~0nly ~:Flaring Authorization > t hrr 1. Safety MCF 2. Lease Use MCF ~ConservPurposes~, ,,'"', I/~/.o MCF Co~n(nissione~ Date Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60 degrees F. Report due by the 20th of the month following the month of disposition. Authority 20 AAC 25.235. Marathon Oil Company Gas Flare /Vent Incident Report Field' Kenai Gas Field Well: KTU 43-6xrd June, 2003 Time Total Date Flare / Reason Mitigation Start Stop Duration Vent Planned MCF Y/N , Unload well using CT 6/24/2003 19:00 0:00 5hrs 104 Y Continue operation Work complete 6/25/2003 0:00 2:00 2hrs 42 Y Flare - Vent Incident Report ~u 01:08pm From-MARATHON OIL +gl$$$4545g T-733 P.O1/OB F-182 Alask~ F~ 1 Domestic.. ,~duction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 FAX COVER LETTER PLEASE DELIVER THE FOLLOWING TO: Name: ~~ &- ~)0~0~ ~(..~ Company: ~] 0 ~ ~-~.~' ·, Fax No.: Number of Pages (irmludtng cover page): FROM: Name: Location/Extension: Fax No.: 907/564-64~ NOTE: A subsidiary of USX Corporation ff transmission is not complete, please call 907/561-5317. ~nv~ronmema,~ ~ware for the long r,~t~ EC E ~VE D ,JUL 1 2 2000 ~aska 0ii & Gas Cons. C0mmi~i~ Annhnrnn~. 01:0gpm From-MARATHON 0IL +gl$~64~4gg T-733 P.OZ/05 F-l~2 Alaska R~ Domestic ~, ..Juction Marathon Oil Company P.O, Box 196168 Anchorage, AK 99.519-6168 Telephone 907/561 -$311 July 12, 2000 Mr. Blair Wondzell State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99513-7599 Reference: Field: Kenai Gas Field Well: KTU 43-6xrd Permit No.: 94-39 APl Number: 50-133-20328-00 Project: Coil Tubing Cleanout Operation Dear Mr. WOndzell: Attached please find FORM 403 - APPLICATION FOR SUNDRY APPROVAL for the KTU 43-6xrd well. We intend to utilize coil tubing on approximately July 17, 2000, to clean out suspected frac sand from this wellbore. Your earliest attention is thus appreciated. Please call me if there is any additional data that can be provided. I can be reached at 907-564-6303 (work) or 231-3775 (pager). Ralph J. Affinito Advanced Production Engineer RECEIVED JUL 1 2 2000 Alaska 0ii & Gas Cons. Commission Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. ~u 01:1Opm From-MARATHON OIL +9155646499 T-753 P.03/05 F-lag STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS I. Type of Request: Abandon Suspend ~ Operation Shutdown~ Re-enter Suapended Well,..., Alter Casing ~ Repair Well~ Plugging ~ Time Extension Stimulate ~ Change Approved Program . Pull Tubing ~ Variance Perforate ~ Other X Name of Operator MARATHON OIL COMPANY Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Loc~tion of Well at Surfaoe 288' FNL. 4160' FWL, Sec 7, T4N, R11W, At top of Productive Interval At Effective Depth At Total Depth 2791' FSL, 37~6' FWL, Sec, 6, T4N, R11W, S,M, Type of Well~ Development,, X Exploratory ~ Stratigraphic 6. Datum Elevation (DF or KB) 114' KB above MSL 7. Unit or Prope~/Name Kenal Tyonek Unit 8, Well Number K'ru 43-bxrd 9. Permit Nurn~;~- 94-39 10, APl Number ~0-13a-20:~28-00 11, Field/Pool Kenai Gas Fieldrl-yonek 12. Present Well Condition Summa~ Total Depth: meaeured true vertical 95aB feet Plugs (measured) 8892 feet Effective Depth: measured 9461 feet Junk (measured) true vertical 882t feet Fill ta~ged at 9~S8' MD on 06/22/00 Casing Lenglh Size Cemented Structural 113 20" Driven Conductor Surface 2508 13-3/19" 1093 sks Intermediate Production 8370 9-6/8" 1792 aks Liner 9634 7" 1690 ske Perforation Depth: measured 84-6 Sand; 9079' - 909~', D-1 Sand: 9406' - 9462' true vertical 84-6 Sand: 845,3'. 8473', D-1 Sand; 8653'- 8708' Tubing (size, grade, and measured depth) $.t12', L-80, 7732' MD Packers and SSSV (type and measured depth) Baker SAB-,3 packer @ 7651' Measu~dDepth 115 2508 7446 9534 Tme Vedical Depth 113 2427 6880 8890 ORIGINAL 'Clean c ut fill w/coil tbg. 13. Attachments Description Summary of Proposal 14. Eetimated Date for Commenoing Operation 7/t 7/2000 15. la. If Proposal was Verbally Approved Name of Approver Date Approved Detailed Operations P~ogmm ~ BOP Sketch Status of Well Cle~ificMion as: Oil GasX..~. Sugpended~ Servi~e 17. I hereby certify that the foregoing is true and correot to the best of my knowledge, Sig .n_ed Ralph Affinite Title Produotlon Engineer I ..... FOR COMMISSION USE ONLY Conditions of Approval; Notify Commission so repreeentalive may witness Plug Intesrlty__ BOP Test /,/ Location Clea, ranc~ Mechanical Integrity Teat_.__ ---~ubsequent Form Required 10."'T~- ~ ORIGINAL SIGNED BY Approved by Order of the Commission Date 7/12/2000 Form 10-40'~ Rev. oe/9~8 Commission? Submit In Triplicate RECE!VED ,JUL 1 2 2000 Alaska Oi~ & Gas Cons. Commission Anchorage · .-00 01:1Opm From-MARATHON OIL +gl~$8484gg MARATHON OIL COMPANY ALASKA REGION T-733 P.O4/OS F-182 Kenai Gas Field KTU 43-6xrd AFE 0488700 Coil Tubing Cleanout Procedure Use coil tubing to jet4n well KTU 4$-6xrd (Tyonek Sand completion) whioh has sand fill to 9358' MD (47' above the D-I perforations), Smallest downhole ID is 2_635" 'XN' nipple at 7729'. Tubing is 3-1/2" 9,3 ppf L-80 EUE 8rd landed at 7732' w/WL re-ent~y guide. Procedu!"e: , Set up 400 bbl tank, Mix 150 bbls of 3% KCl water. Set up gas buster and open top tank with choke and flowback iron. MIRU Dowell Schlumberger 1.75" OD coil tubing, high pressure pumping, and nitrogen equipment. , Pressure test coil tubing and BOP equipment to 3,500 psi using 3% KC! water. Commence RIH washing fill from 9358' to 9494' using 3% KC! water. Apply hi-vis sweeps as necessary. When solids returns have cleaned up, commence jetting with nitrogen at 300 to 500 SCFlmin rate. Continue to RIH and jet as necessary to ulfload well. POOH and allow well to flow. Note that well should not be drawn down below 1,500 psig following unloading. Shutqn well, RD coil tubing. Secure well and clean up location. 3. Produce well to clean up as per engineer's instruc'don. 9:t4 AM 07/12/00 JUL 1 2 2000 Ow, & Gas Cons, ' ~nc~omge ..~00 01:1Opm From-MARATHON OIL +8155545488 T-T33 Kenai Gas Field Well KTU 43-6xrd, Pad 41-7 Marathon Oil Co., Alaska Region P.O,/OS F-182 KB-THF: 31,1' KB-GL: 34.0' 233' S & 4160' E of NW Como- Sec. 7, T4BI, R11W, S,M, Camco Sidepocket Mandrel ~ 1014' with 1/4" chemical il0eetion line Either a KBUO-LTS et KBC~-2-SP-LTS Sqtu~eze P~ffS (8qzd 7114195) 5105' - 5118' 5214'- 5227' 5248' - 5256' 5274' - 5294' 5606' - 5626' 5632'- 5646' 20", 94# Drive pipe ~ 113' ~ 13-3/8", 61#, K-55, BTC Casing (~ 2508' C,nt w/1093 sk$ of Class "Er" 9-5/8", 47#, N.80, BTC Casing Set ~ 83'70' Hole Milled in 9-5/8" @ 7446' - 7510' (7/18/95) Orig. Cmt w/1792 sk5 ofClass "O" Tubing: 3-I/2", 9.3#, L-80, ~t3E 8rd Frae stimulated Tyonek 84-6 (9079'- .9.099') w/14,700 lbs of 20/40 EconoProp (~ 2 to 8 ppg (6t17/99) Frac sthmflated Tyonek D-t (9405' - 9462') w/53,000 lbs 20140 Carbolite ~ 2 to 8 ppg plus 3,100 lbs Prophet (10130/95) .E_.xj_stir~_t_t_t_t_t_t_t_n_3,g~P. erfs- (2.1/8" strip guns, 6 ~f, ~,A5°, 14 gm E J-Ill) 84-6 9079'- 9099' CBL (1/30/97 & 12/16196) D-I 9405' - 9462' CBL (911/95 & 9/26/95) Baker K-Anti,or ~ 7650' Baker SAB-3 Packer ~ 765 I' Cami:o X Nipple ~ 7697' [] = 2.813" Cameo XIq Nipple (~ 7729' ID -- 2.750", no-go = 2,635" B~ker SOS Wireline Re-mary guide ~ 7732' ',.",:L, :' : ~'.2.' 2.-~-] Tagged fill f~ 9494' KB (7/7/99) · .2. .... % ~'-;'~X s ' EZ,. V (~ 9499 ,d 7.~'-~'"'~.':.---~'~"~'~'~ 11~ 7", 29/~, P-110, B'rc Casing (~ 9534' TD = 95.14' Cmt w/1690 sks Last Rev: JGE, 7/22/99 RECEIVED ,JUL 1 2 2000 Alaska Oii& Gas Cons, Commi~ion Alaska F,~on Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 July 26, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: Report of Sundry Well Operations Well KTU 43-6xrd Dear Mr. Wondzell: Enclosed is the Report for Sundry Well Operations for Well KTU 43-6xrd. If you have any questions, please call me at 564-6315. J_./G:~.l.er P~on Engineer M:~qRSDocs~Drilling~ge726.doc Enclosure A subsidiary of USX Corporation Environmentally aware for the long run. g:~crnn~drlg~kgflwells~kul 1-Ss~AOGCCO1A.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate X 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 233' FNL, 4160' FWL, Sec 7, T4N, R11W, S.M. At top of Productive Interval At Effective Depth At Total Depth 2791' FSL, 3796' FWL, Sec. 6, T4N, R1 lW, S.M. 5. Type of Well: Development .~X Exploratory Stratigraphic __ Service 6. Datum Elevation (DF or KB) 114' KB above MSL feet 7. Unit or Property Name Kenai Tyonek Unit 8. Well Number KTU 43-6xrd 9. Permit Number lO. APl Number 50-133-20328-00 11. Field/Pool Kenai Gas Field/Tyonek 12. Present Well Condition Summary Total Depth: measured true vertical 9535 feet Plugs (measured) 8892 feet Effective Depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented 113 20" Driven 2508 13-3/8" 1093 sks 7446 9-5/8" 1792 sks 9534 7" 1690 sks 84.6 Sand:9079'-9099', D-1 Sand:9405'~9462' Measured Depth True Vertical Depth 113 113 2508 2427 7446 688O 9534 8890 true vertical 84-6 Sand: 8453' - 8473', D-1 Sand: 8653' - 8708' Tubing (size, grade, and measured depth) 3-1/2", L-80, 7732' MD Packers and SSSV (type and measured depth) Baker SAB-3 packer @ 7651' 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) '84-6 Sand: 9079' - 9099' Treatment Description Including Volumes Used and Final Pressure Fracture stimulated with 35,600 lbs. of 20/40 EconoProp in 4500 gal of 3% ClearFrac fluid ramped from 2 to 10 ppg. Screened off with 14,700 lbs. of proppant behind perfs. 14. OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Prior to Well Operation 0 3950 8 0 Subsequent to Operation 0 4461 8 3330 Tubing Pressure 1800 725 15. Attachments 16. Status of Well Classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil Gas X Suspended · ',- ---, ~ '-..,~ Form 10-404 Rev. 06/15/88~ Service Date 7t22/9!p~~ Submit in Du ., ,~60-5 (June 1990) UNITF'~'~TATES SUBMIT IN DEPARTMEN'i _,: THE INTERIOR TRIPLICATE* BUREAU OF LAND MANAGEMENT (Other instructions on reverse side) SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals. SUBMIT IN TRIPLICATE 1. Type of Well Oil Gas E~ Well r~ Well E~ Other 2. Name of Operator MARATHON OIL COMPANY 3. Address and Telephone No. P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well (Footage, Sec., T., R., M., or Suvey Description) 233' FNL, 4160' FWL, Sec 7, T4N, R11W, S.M. at surface 2791' FSL, 3796' FWL, Sec. 6, T4N, R11W, S.M. atTD FORM APPROVED BUDGET BUREAU NO. 1004-0135 Expires: March 31, 1993 5. Lease Designation and Serial No. A-028142 6. If Indian, Allottee or Tribe Name 7. If Unit or CA, Agreement Designation Kenai Tyonek Unit 8. Well Name and No. KTU 43-6xrd 9. APl Well No. 50-133-20328-00 10. Field and Pool, or Exploratory Area Kenai Gas Field/Tyonek 11. County or Parish, State Kenai Peninsula Borough ! 12. CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF ACTION TYPE OF SUBMISSION r--j Notice of Intent J'~ Subsequent Report J'-"-J Final Abandonment Notice r--] Abandonment r-~ Change of Plans E~ Recompletion ~ New Construction r-~ Plugging Back FI Non-Routine Fracturing r-~ casing Repair E~ Water Shut-Off r--] Altering casing ~ conversion to Injection r--] Other E~ Dispose Water (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionall drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.)* Fracture stimulated the 84-6 Sand (9079' - 9099' DIL) with 35,600 lbs. of 20/40 EconoProp in 4500 gal of 3% ClearFrac fluid ramped from 2 to 10 ppg. Screened off with 14,700 lbs. of proppant behind perfs. R.f c,f VEL) A/aska Oil & ¢~as Cons. Anchorage. TITLE Production Engineer DATE July 22, 1999 18. I hereby certif~/~-~he for~ true and correct SIGNED x~, ~~,~_~_~.. Gary Eller (This space for Federal o~office use) APPROVED BY TITLE DATE Conditions of approval, if any: Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. *See Insstruction on Reverse Side n:\d rlg\kgt~wells\43-6xrd\BLM0 la.xls 6/96 Kenai Gas Field Well KTU 43-6xrd, Pad Marathon Oil Co., 41-7 Alaska Region KB-TI-W: 31.1' KB-GL: 34.0' 233' S & 4160' E of NW Comer Sec. 7, T4N, R11W, S.M. Camco Sidepocket Mandrel ~ 1014' with 1/4" chemical injection line Either a KBUG-LTS or KBG-2-SP-LTS Squeeze Per~ (Sqzd 7/14/95) 5105'-5118' 5214'-5227' 5248'-5256' 5274'-5294' 5606'-5626' 5632'-5646' Tubing: 3-1/2", 9.3#, L-80, EUE 8rd Frac stimulated Tyonek 84-6 (9079' - 9099') w/14,700 lbs of 20/40 EconoProp ~})~ 2 to 8 ppg (6/17/99) Frae stimulated Tyonek D-1 (9405' - 9462') w/53,000 lbs 20/40 Carbolite ~} 2 to 8 ppg plus 3,100 lbs Propnet (10/30/95) Existing Perfs - (2-1/8" strip guns, 6 spt', +45°, 14 gm EJ-III) 84-6 9079'- 9099'CBL (1/30/97 & 12/16/96) D-1 9405' - 9462' CBL (9/1/95 & 9/26/95) TD = 9534' 20", 94# Drive pipe @ 113' ~. 13-3/8", 61#, K-55, BTC Casing (~ 2508' Cmt w/1093 sks of Class "G" 9-5/8", 47//, N-80, BTC Casing Set ~ 8370' Hole Milled in 9-5/8" ~ 7446'- 7510' (7/18/95) Orig. Clnt w/1792 sks of Class "G" Baker K-Anchor (q)~ 7650' Baker SAB-3 Packer (~ 7651' Camco X Nipple @ 7697' [13=2.813" Camco XN Nipple @ 7729' ID = 2.750", no-go = 2.635" Baker SOS Wireline Re-entry guide Q1 7732' Tagged fill (,(} 9494' KB (7/7/99) EZSV @ 9499' 7", 29//, P-110, BTC Casing (~ 9534' Cmt w/1690 sks Last Rev: JGE, 7/22/99 990614.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 6/14/99 FIELD: FILL DEPTH/DATE: TUBING: DATE LAST WL WORK: 5/5/99 WORK DONE: PRESENT OPERATION: Set sand plug over D-1 perfs OTHER: Day 1, AFE 9203599 - Frac the 84-6 Sand Kenai Gas Field WELL #: KTU 43-6xrd 3-1/2", 9.3#, L-80 CASING: 7", 29#, P-110 TREE CONDITION: good BENCHES OPEN: Beluga Sand SUMMARY OF OPERATIONS 6/13/99 MIRU 1-3/4" coil tubing. Mix 550 bbl of 4% KCI. 6/14/99 Finish RU coil tubing. Held safety & operations meeting. Test BOPs to 4500 psig. SITP = 3400 psig. Bullhead 4% KCIto begin kill operation. When SITP reduced down to 1OO0 psig, RIH circulating KCL fluid. Tag fill at 9420' CTM. PU to 9400', circulate KCL all the way around. Well dead. Mix slurry with 5000 lbs of 20/40 sand and gel. Attempt to pump sand slurry, but suction lines packing off with sand. Made numerous unsuccessful attempts to clear lines of sand and resume pumping. Decide to SDFN. POOH. Secure well, SDFN. ,, Vendor Equipment Daily Cost Cumulative Cost Dowell coil tubing $15,000 $15,000 R&L Construction vac truck $960 $960 Misc. car rental, airline $500 $1,000 Trucking $4,000 $4,000 Toloff Crane $2,310 $4,810 DAILY COST: $22,770 CUM: $25,770 REPORTED BY: J.G. Eller 990615.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 6/15~99 FIELD: FILL DEPTH/DATE: TUBING: DATE LAST WL WORK: 5~5~99 WORK DONE: PRESENT OPERATION: Set sand plug over D-1 perfs OTHER: Day #2, AFE 9203599 - Frac the 84-6 Sand Kenai Gas Field WELL #: KTU 43-6xrd 3-1/2", 9.3#, L-80 CASING: 7", 29#, P-110 TREE CONDITION: good BENCHES OPEN: Beluga Sand SUMMARY OF OPERATIONS RU 1-3/4" coil. Test lubricator to 4500 psig. Bled off trapped pressure, RIH with coil tubing. Work to clear blender unit of sand while RIH. Tag up at 9400' CTM (approximately 20' higher than yesterday). Prepare to pump sand plug. Centrifugal booster pump down. Standing by for replacement booster pump. Note: Having much difficulty killing well. Fluid weight should balance formation pressure, but unable to keep the well completely dead. Replacement pump arrived, but inadequate electrical power source to operate. Decide to abandon hope of getting existing blender unit operating. Instead, call for cementing unit with its own blending system. Cementing unit arrived. RU and pressure test to 4500 psi. Held safety and operations meeting. Mix 20 bbl gel. Mix 3400 lbs of 20/40 sand in gel and pump downhole. Lay sand plug from 9460' MD to 9309' MD (approximately 100' over D-1 perfs). Displace with 4% KCI and PU to 7700'. Shut in returns and pressure up to 3000 psi to pack sand plug. POOH. OOH with coil tubing. SITP = 2900 psig (applied pressure). RD coil tubing. Note: Tomorrow, will install a pressure gauge in the sidepocket mandrel using slickline. Will also refill frac tank with 4% KCI, and finish RU of flowback equipment. Frac planned for Thursday morning. Vendor Equipment Daily Cost Cumulative Cost Dowell coil tubing $7,900 $22,900 Dowell frac units $0 $0 M-I Drilling Fluids KCI $5,200 $5,200 Misc. car rental, airline $500 $1,500 R&K vac truck $1,650 $1,650 R&L Construction vac truck $1,200 $2,160 Toloff Crane $2,475 $7,285 Trucking $150 $4,150 DALLY COST: $19,075 CUM: $44,845 REPORTED BY: J.G. Eller 990616.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 6/16/99 FIELD: Kenai Gas Field FILL DEPTH/DATE: TUBING: 3-1/2", 9.3#, L-80 CASING: DATE LAST WL WORK: 5/5/99 TREE CONDITION: WORK DONE: BENCHES OPEN: PRESENT OPERATION: Install pressure gauge downhole OTHER: Day #3, AFE 9203599 - Frac the 84-6 Sand WELL #: KTU 43-6xrd 7", 29#, P-110 good Tyonek 84-6 Sand SUMMARY OF OPERATIONS MIRU slickline on KTU 43-6xrd. SITP = 2600 psig. Test BOPs and lubricator to SITP. RIH with 2.4" gauge ring, tag sand plug at 9349' MD (approximately 56' over the top of the D-1 perfs). POOH. RIH with "F" collar stop and set at 1150'. POOH. RIH with OK-1 kickover tool to 1014' MD. Pull 1" chemical injection valve. POOH. RIH with pressure bomb, install in sidepocket mandrel at 1014' MD. POOH. RIH, ~ull "F" collar stop at 11 50' WLM. POOH, RDMO slickline. =inish RUtemporary flowbackequipment. Fueled fracequipment for tomorrow's frac. Pressure test 7" casing to 3000 psig. Left pressure on casing. Built 560 bbl of 4% KCI and heated it to 90 deg F. Vendor Equipment Daily Cost Cumulative Cost Dowell frac units $10,000 $10,000 ...... Doyles diesel fuel $1,355 $1,355 Halliburton slickline $2,375 $2,375 Misc. car rental, airline $500 $2,000 R&K vac truck $220 $1,870 R&L Construction vac truck $480 $2,640 Steam on Wheels heat frac water $1,460 $1,460 Toloff Crane $1,980 $9,265 DAILY COST: $18,370 CUM: $63,215 REPORTED BY: J.G. Eller 990617 .xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 6/17/99 FIELD: FILL DEPTH/DATE: TUBING: DATE LAST WL WORK: 6/16/99 WORK DONE: PRESENT OPERATION: Frac Tyonek 84-6 Sand OTHER: Day ~4, AFE 9203599 - Frac the 84-6 Sand Kenai Gas Field WELL #: KTU 43-6xrd 3-1/2", 9.3#, L-80 CASING: 7", 29#, P-110 TREE CONDITION: good BENCHES OPEN: 84-6 Sand SUMMARY OF OPERATIONS Prepare to frac stimulate the 84-6 Sand. Finish installing lines. RU tree saver. Test Halliburton well test lines to 5000/1OOO psi. Test frac lines to 9500 psi. Held safety and operations meeting. SITP = 2230 psig. Hole was loaded with 4% KCI. Begin stimulation by pumping 4% KCI down tubing at 15 bpm. Formation broke down at 5730 psi (1.12 psi/ft), then immediately recorded step-down information and ISIP (3740 psi -- 0.88 psi/ft). Pump 3000 gal 4% KCI for aminifrac, then shut down for closure. ISIP -- 3218 = 0.82 psi/ft. Analyzed data for frac closure, perf friction, tortuosity, and fluid efficiency of 4% KCI. Preliminary analysis shows minimal perf friction but significant tortuosity. Unable to pick closure pressure or calculate fluid efficiency. Decide against any changes to planned job design. Resume pumping with 2000 gal of 10% mutual solvent (EGMBE) at 5 bpm, then pump 10 bbl KCI spacer also at 5 bpm. Pump 3000 gal (71 bbl) of 3% ClearFrac pad at 5 bpm until the last 20 bbls, when we increased the rate to 1 5 bpm. Ramped 35,600 lbs of 20/40 EconoProp proppant from 2 to 10 ppg in 4500 gal of 3% ClearFrac. Displaced with 4% KCI. Net pressure plot showed normal fracture extension until 5 ppg proppant hit perfs, then got signs of significant height growth. This continues until the 10 ppg sand hit the perfs, when we immediately screened out at the wellbore. Only placed 14,700 lbs of proppant in the formation (43% of design). Quit pumping immediately pn screenout; did not pack sand. Total fluid used = 407 bbl. Well bled off below 4000 psig naturally. RD tree saver, RDMO fracture equipment. Decided to perform coil tubing cleanout tomorrow. Vendor Equipment Daily Cost Cumulative Cost Dowell frac stimulation $97,385 $107,385 Halliburton well testing $10,000 $10,000 Mi-I Drilling Fluids KCI $1,300 $6,500 Misc. car rental, airline $1,000 $3,000 R&K vac truck $660 $2,530 Toloff Crane $990 $10,255 Trucking $110 $4,260 DAILY CQST: $111,445 CUM: $174,660 REPORTED BY: J.G. Eller 990618.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 6/18/99 FIELD: Kenai Gas Field FILL DEPTH/DATE: TUBING: 3-1/2", 9.3#, L-80 CASING: DATE LAST WL WORK: 6/16/99 TREE CONDITION: WORK DONE: BENCHES OPEN: PRESENT OPERATION: Clean out frac sand with coil tubing OTHER: Day #5, AFE 9203599 - Frac the 84-6 Sand WELL #: KTU 43-6xrd 7", 29#, P-110 good 84-6 Sand SUMMARY OF OPERATIONS RU 1-3/4" coil tubing. Mix 560 bbl of 3% KCI. Pressure test iron to 5000 psig. SITP = 850 psig. RIH with coil tubing. Top of sand expected at 5900'. Started circulating 5100' CTM, getting clear returns. Washing at 30 fpm, checking PU weight every 100'. At 61 50' CTM, start getting frac sand in returns. Washing easily: not setting down any weight at all nor seeing any increased pump pressure. Now getting considerable frac gel in returns, but not much sand. Wash to EOT at 7700' CTM. Still washing easily, but building a large amount of foam in the returns tank. Have to shut down circulating when foam filled up the tank. PU to 6800' CTM while waiting for defoamer. Received defoamer, applied it to the returns tank. Slowly breaking foam back. RIH with coil. Resume circulating at 7500'. Wash into casing at 15 fpm, checking PU weight every 50' or so. Still washing easily. Wash to 9220' CTM (1 20' past 84-6 Sand perfs). Started getting heavy sand returns in the vicinity of the perfs. Circulate at maximum rate, then POOH slowly to 8200' CTM. Continue getting strong sand returns for an entire circulation, but not getting any sign of gas production or any build in wellhead )ressure. When returns cleaned up, RIH circulating at minimum rate to 9000' CTM. Stop circulating, and RIH. Tag fill at 9049' CTM. POOH circulating. OOH. RD coil tubing. SDFN. Note: In the morning, plan to re-tag fill with coil tubing. Then will wash to 9300' CTM. Nitrogen will be on location tomorrow in case we elect to jet the well. Vendor Equipment Daily Cost Cumulative Cost Dowell coil tubing $24,000 $46,900 Halliburton well testing $0 $10,000 Misc. car rental, airline $500 $3,500 R&K vac truck $275 $2,805 R&L vac truck $640 $3,280 Toloff Crane $2,640 $12,895 Trucking $0 $4,260 DAILY COST: $28,055 CUM: $202,715 REPORTED BY: J.G. Eller 990619.x15 MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 6/19/99 FIELD: Kenai Gas Field FILL DEPTH/DATE: TUBING: 3-1/2", 9.3#, L-80 CASING: DATE LAST WL WORK: 6/16/99 TREE CONDITION: WORK DONE: BENCHES OPEN: PRESENT OPERATION: Clean out frac sand with coil tubing OTHER: Day #6, AFE 9203599 ~ Frac the 84-6 Sand WELL #: KTU 43-6xrd 7", 29#, P-110 good 84~6 Sand SUMMARY OF OPERATIONS RU 1-3/4" coil tubing. Mix 560 bbl of 3% KCL. Pressure test iron to 5000 psig. SITP = 220 psig. Pressure bled off rapidly; mostly water with a little entrained gas. RIH with coil tubing. Tag fill at 9050' CTM. Start circulating KCI at 1.8 bpm. Wash easily to 9300' CTM. Still no indication of formation gas. PU to 9000', stop circulating, and tag for fill. Tag at 9213' CTM within 15 minutes of having washed to 9300' CTM. PU to 8900' and shut down for one hour. RIH, tag fill at 9067' CTM. PU to EOT (7750' CTM). RU nitrogen unit and pressure test lines to 4500 psig. Pump nitrogen down coil tubing, taking returns on annulus. Nitrogen pressure built up to 2780 psig before exiting the coil tubing. Blew tubing dry with no evidence of formation feed-in. Shut-in well, and RIH. Rag fill at 9064' CTM. Circulated nitrogen again. Unloading more fluid. Pump slugs of water with the nitrogen and wash fill to 91 35' CTM. Circulate nitrogen at 91 35' CTM until nitrogen tank empty. POOH with coil tubing, leaving annulus open to allow well to flow. Well continued to blow nitrogen while POOH, but never showed any indication of wanting to flow on it's own. OOH. RD coil tubing. SDFN. Vendor Equipment Daily Cost Cumulative Cost Dowell coil tubing $27,000 $96,004 Doyle's diesel fuel $311 $1,666 M-I Drilling Fluids KCI $1,300 $7,800 Misc. car rental, airline $500 $4,000 R&L vac truck $560 $3,840 Toloff Crane $2,310 $15,205 Trucking $130 . $4,390 Veco fluids disposal $7,500 $7,500 DAILY COST: $39,611 CUM: $281,937 REPORTED BY: J.G. EIler 990621 .xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 6/21/99 FIELD: FILL DEPTH/DATE: TUBING: DATE LAST WL WORK: 6/16/99 WORK DONE: PRESENT OPERATION: Pull pressure bombs OTHER: Day #7, AFE 9203599 - Frac the 84-6 Sand Kenai Gas Field WELL #: KTU 43-6xrd 3-1/2", 9.3#, L-80 CASING: 7", 29#, P-110 TREE CONDITION: good BENCHES OPEN: 84-6 Sand SUMMARY OF OPERATIONS MIRU slickline on KTU 43-6xrd. SITP = 3250 psi. Test lubricator and BOPs to SITP. RIH with 2.25" gauge ring, tag fill at 91 50' KB. POOH. RIH with OK-1 kickover tool, but unable to get through tree because of hydrates. Pump methanol. RIH with tools, attempt to latch pressure gauge in sidepocket mandrel at 1014' KB. POOH. Did not retrieve gauge. Repin and rerun same. Latch gauge, POOH. RIH with 1" chemical injection valve, set in mandrel at 1014' KB. POOH. Verify injection into chemical injection line, then bled pressure to verify a seal. All OK. RDMO slickline. Vendor Equipment Daily Cost Cumulative Cost , Dowell coil tubing $0 $96,004 Halliburton slickline $6,300 $8,675 Halliburton well testing $14,000 $24,000 Misc. car rental, airline $500 $4,500 R&L vac truck $0 $3,840 Toloff Crane $990 $16,195 Trucking $0 $4,390 Veco fluids disposal $0 $7,500 DAILY COST: $21,790 CUM: $264,116 REPORTED BY: J.G. Eller 990622.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 6~22~99 FIELD: FILL DEPTH/DATE: TUBING: DATE LAST WL WORK: 6/16/99 WORK DONE: PRESENT OPERATION: Flow well OTHER: Day #8, AFE 9203599 - Frac the 84-6 Sand Kenai Gas Field WELL #: KTU 43-6xrd 3-1/2", 9.3#, L-80 CASING: 7", 29#, P-110 TREE CONDITION: good BENCHES OPEN: 84-6 Sand SUMMARY OF OPERATIONS MI Halliburton well testers. Test upstream iron to 5000 psig, downstream iron to 1000 psig. Held safety and operational meeting. SITP = 3450 psig. Open well to flow through well test equipment. Gas being routed to sales via Iow pressure gathering system. Flow well throughout the night. See Halliburton report for details of the flowback. By 2300 hrs the well started to improve. At 0600 hrson 6/23/99, well was producing 2.3 MMCFDwith 147 psig FTP on a 48/64" choke. Have recovered 21 bbl liquid. 6/23/99 Flow well to LP gathering system. Final rate = 3.6 MMCFD with 608 psig FTP, 29 bbls recovered. 6~24~99 Final rate = 4.0 MMCFD with 655 psig FTP, 41 bbls recovered. 6/25/99 Final rate = 4.4 MMCFD with 695 psig FTP, 57 bbls recovered. Vendor Equipment Daily Cost Cumulative Cost Dowell coil tubing $0 $96,004 Halliburton slickline $0 $8,675 Halliburton well testing $14,400 $38,400 Misc. car rental, airline $2,000 $6,500 R&L vac truck $0 $3,840 Toloff Crane $0 $16,195 Trucking $0 $4,390 Veco fluids disposal $0 $7,500 DALLY COST: $16,400 CUM: $280,516 REPORTED BY: J.G. Eller Marathon Oil Company · ., Alask~ .~lion Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 July 29. 1997 LETTER OF TRANSMITTAL Alaska Oil & Gas Conservation Commission Attn: Lori Tavlor 3001 Porcupine Drive Anchorage, AK 99501-3192 The following logs are enclosed: Kenai Gas Field Kenai Gas Field 43-6X-RD Core Analysis Report Kenai Gas Field 43-6X-RD Core Description Kenai Gas Field 31-7RD Core Analysis Report Quantity This data is considered confidential until the normal released date. MARATHON OIL COMPANY Kirsten K. Gamel Enclosures A subsidiary of USX Corporation Received By: Date: PERMIT 9=-05N~ 95-05~ AOGCC Individual Well Geological hiater'ials Inventory DATA T DATA_PLUS COHP RCD t~/Otc/q[~ ~900-9~2 COMP PROD RCD 1/30/'97~ HYLAR 7570-9430 PRC, F,~/j/¢-2 ~/X'8830-gL~6h P a 9 e: 1 Date: 07/08/97 RUN DATE_RECVD FINAL olt~t~7 o~to,sl~? o~t~f~? 'i 0 - z~ 0 7 COMPLETION DATE c:~/OI/'qJ¥ qS,/o '~//76 / DALLY WELL OPS FR 7/0~ /qj-/ TO ~ --- q j- ~'/ /~ w Are dry ditch samples Was the well cor'ed? Ar'e wel '1 tests r'equi red? ~ ~,-~s ':,qel 1 is 'in cornpl'~ance I n "? 't 'i a 1 COMMEt.tTS r"equir'ed? yes ~And r'ece'ived? yes Ana~s & ~ r'ece:ved? ~ Rece'¥ ved? yc~-~-' Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 May 6, 1997 Mr. Jack Hartz Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Hartz: Please find attached a completed Gas Well Open Flow Potential Test Report for Kenai Gas Field Well KTU 43-6Xrd. The test was completed on April 21, 1997. Marathon respectively requests this information be kept confidential for a period of two years for strategic planning purposes. Sincerely yours, Michael J. Stover Advanced Reservoir Engineer attachments A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la. TEST: INITIAL ...... x lb. TYPE TEST STABLILIZED __~-~ NON STABILIZED -- ANNUAL MULTIPOINT Ix / CONSTANT TIME SPECIAL OTHER ISOCHRONAL 2. Name of Operator 7. Permit No. Marathon Oil Company 95-0054 3. Address ~8. APl Number 3201 C Street, Ste. 800, Anchorage, Alaska 99503-3934 50- 133-20328-01 4. Location of Well 9. Unit or Lease Name At surface Kenai Unit 233' FNL, 4160' FWL, Sec. 7, T4N, R11W, S.M. 10. Well Number At TD KTU 43-6Xrd 2791' FSL, 3796' FWL, Sec. 6, T4N, R1 lW, S.M., @ 8892' TVD 11. Field and Pool Kenai Gas Field/Tyonek 5. Elevation in feet (KB, DF etc.) 16. Lease Designation and Serial No. 114' KB above MSLI A-028142 12. Completion Date 113. Total Depth 114. Plugback T.D. 115. TyPe Completion (Describe) 9/1/95 I 9535'MD/8892'TVD I 9508'MD/8866'TVDI Single Tbg. String / Cased Hole 16. Csg. Size Weight per foot, lb. I.D. in inches Set at ft. Perforations: From To 7" Liner 29 6.184 9534'MD 17. Tbg. Size Weight per foot, lb. I.D. in inches Set at ft. 9079'-9099 MD 3 1/2" 9.2 2.992 7732'MD 9405'-9462' MD 18' Packer set at ft' 119' GOR cf/bbl' 120' APl Liquid Hydr°carb°ns 21' Specific Gravity Fl°wing fluid (G)7651 'MD ...... 0.558 22. Producing thru: Reservoir Temp. °F. Mean Annual Temp. °F. Barometric Pressure (Pa), psia Tbg. [~ Csg. ~_--~ 143 33 14.73 23. Length of flow channel (L)7809, I VerticalDepth (H)17732 Ga. %co 0.14 %H2S I Pr°ver Meterrunl Taps0 x 24. Flow Data Tubing Data Casing Data Choke Prover Orifice Line Size X Size Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. (in.) (in.) psig hw °F. psig °F. psig °F. Hr. 1. 3.826 X 2" 748.225 8.65 61 3,050 64 .... 6.00 2. 3.826 X 2" 756.9 8.7 61 2,850 66 .... 6.00 3. 3.826 X 2" 756.9 8.7 61 2,650 71 .... 6.00 4. 3.826 X 2" 756.9 8.7 61 2,340' '73 .... 6.,00 5. X Basic Coefficient -~ (24-Hour) hwPm Pressure Flow Temp. Factor Gravity Factor Super Comp. Factor Rate of Flow No. Fb or Fp Pm Ft Fg Fpv Q, Mcfd 1. 24.5 80.4 762.9 0.99904 1.338699 1.058089 1,970 2. 37.6 81.1 771.6 0.99904 1.338699 1.058778 3,050 3. 47.3 81.1 771.6 0.99904 1.338699 1.058778 3,837 4. 59.9 81.1 771.6 0.99904 1.338699 1.058778 4,860 5. Temperature for Separator Gas for Flowing Fluid No. Pr T Tr Z Gg G 1. 1.117706 520.6 1.527 0.893215 0.558 2. 1.130415 520.6 1.527 0.892052 3. 1.130415 520.6 1.527 0.892052 .;ritical Pressure 682.58 4. 1.130415 520.6 1.527 0.892052 .?,ritical Temperature 341.1801 ,'-~.- ~ ~) Rev.'~.- 1-80 . . kz~AOGCCGAS.XLS CONTINUED ON REVERSE SIDE Submit in duplicate Pc 3,455 Pc2 11,937,025 Pf PF NO. Pt Pt2 PC~ - Pt~ Pw Pw~ Pc~ - Pw~ Ps Ps2 PF - Ps~ 1. 3,050 9,302,500 2,634,525 ...... 2. 2,850 8,122,500 3,814,525 ...... 3. 2,650 7,022,500 4,914,525 ...... 4. 2,340 5,475,600 6,461,425 ...... 5. 25. AOF (Mcfd) 9,321 n 1 Remarks: Surface data only was collected during test. Perforations 9079'-9099' MD notcontributing to rate based on production log. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~-~-,-,-_.~ Title Advanced Reservoir Engineer Date 5/6/97 ~.-- DEFINITIONS OF SYMBOLS AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z Form 10-421 Rev. 7-1~80 kz~.OGCCGAS.XLS Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/ ~ hw/Pm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor = ~ 1/Z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air = 1.00), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60° F.) per barrel oil (60° F) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow ctian.nel, feet (MD) Exponent (slope) of back-pressure equiation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static presssure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psia ' ,,~" ',' ": "' I" Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60°F.) Reduced temperature, dimensionless MAY 8 1997 Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the MANUAL OF BACK-PRESSURE TESTING OF GAS WELLS, Interstate Oil Compact Commission, Oklahoma City, Oklahoma CONTINUED ON REVERSE SIDE Submit in duplicate KTU 43-6Xrd - D-l, 84-6 4-Point Test Results Q Pflow Pstatic (mscfd) (psia) (psia) Pres. Drop (psia) (Surface data - Electronic gauge failed, used chart recorder) Actual Actual Calc. Regression (Q) (Pr^2-Pwf^2) C (Q) 1,970 3,050 3,455 405 3,050 2,850 3,455 605 3,837 2,650 3,455 805 4,860 2,340 3,455 1,115 m= 0.9952 (psi^2/mcf) l/m = n = 1.0049 (mcf/psi^2) AOF = 9,321 mscfpd 1,970 2,634,525 0.0007 2,023 3,050 3,814,525 0.0007 2,935 3,837 4,914,525 0.0007 3,786 4,860 6,461,425 0.0007 4,984 Ave. Coeff. C 0.00072 Regression 'C 0.00071 KTU 43-6Xrd (4121197)1 10,000,000 1,000,000 _l 1000 Perforations 9079'-99' not contributing based on 3/3/97 production log) '1 Q, (mscfpd) e 4-Pt. Test RegressionI 10000 h:\excel\kenai\beluga4PT436X1.XLS 5/5/97 Alaska r,egion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 March 27. 1997 LETTER OF TRANSMITTAL Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3192 The following logs are enclosed: Description Kcnai Gas Field Production Profile KBU 41-7 March 4, 1997 Production Profile KTU 43-6XRD March 3, 1997 Beaver Creek Completion Record BC-6 February 7, 1997 Print Reproducible Film 1 1 1 1 '~\- I~c> 1 1 This data is considered confidential until the normal released date. MARATHON OIL COMPANY Kirsten K. Gamel Enclosures ReceivedDate: A subsidiary of USX Corporation Environmentally aware for the long run. Alaska .~ion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 February 5, 1997 Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Blair: Please find attached Sundry Form 10-404 Report of Sundry Well Operations. KTU 43-6Xrd was perforated in the Upper Tyonek sand 84-6 on 12/16/96 and 1/30/97. If you have any questions, please contact me at 564-6315. Sincerely, Michael R. Olson Production Engineer Attachments cc: CEF RECEIVED FEB '10 1 97 Alaska Oil & Gas Cons. Commission Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASK, IL AND GAS CONSERVATION C,,...MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate Plugging Pull Tubing Alter Casing Repair Well Perforate X Other 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 5. Type of Well: Development X Exploratory Stratigraphic. · Service 233' FNL, 4160' FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval . 2664' FSL, 3771' FWL, Sec. 6, T4n, R11W, SM {~ 8454' TVD At Effective Depth 2279' FSL, 3795' FWL, Sec. 6, T4N, R11W, S.M., @8866' TVD At Total Depth 2791' FSL, 3796' FWL, Sec. 6, T4N, R11W, S.M., @ 8892' TVD ORIGINAL 6. Datum Elevation (DF or KB) 114' KB above. MSL feet 7. Unit or Property Name Kenai Tyonek Unit 8. Well Number KTU 43-6Xrd 9. Permit Number/Approval Number 95-0054 10. APl Number 50- 133-20328-O1 11. Field/Pool Kenai Gas Field/Tyonek 12. Present Well Condition Summary Total Depth: measured true vertical 9535 feet 8892 feet Plugs (measured) 9508' md Effective Depth: measured 9508 feet true vertical 8866 feet Junk (measured) Fill {~ 9479' md Casing Length Size Structural 113' 20" Conductor Surface 2508' 13-3/8" Intermediate Production 7446' 9-5/8" Liner 9534' 7" Cemented Measured Depth True Vertical Depth Driven 113' 113' 1093 SX 2508' 2428' 1792 SX 7446' 6880' 1690 SX 9534" 8891' Perforation Depth: measured 9079-9099', 9405-9462' true vertical 6454-8473', 8767-8793' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3-1t2.', L-80, 7732. md Baker SAB-3 packer, 7651' md RECEIVED FEB 10 1997 J~aska Oil & Gas Cons. Commission Anchorage 13. Stimulation or Cement Squeeze Summary N/A Intervals Treated (measured) N/A Treatment Description Including Volumes Used and Final Pressure N/A 14. OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl Casing Pressure Prior to Well Operation 4000 1 0 Subsequent to Operation 4700 I 0 Tubing Pressure 2400 240O 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of Well Classification as: Oil Gas X Suspended Service 17. I hereby certify that the foregoing is true and c(prrect to the best of my knowledge. Signed/ '~/'"-~ ~,~'~,~--~,~'~..~ /'C ~"~,;~-'t Title Production Engineer Date 2/5197 Form 10-404 Rev. 06115188 Submit in Duplicate OPERATION SUMMARY REPORT: PERF 84-6 SAND WELL: KTU 43-6Xrd 12/16/96 9463' RU SWS. MU 20' 2-1/2" Hollow Carrier gun, 6 spf, 60 deg phasing, 31J ultrajet charges. PT against SI WHP (3300 psig). Grease hose ruptured. Replace same. PT to 3300 psig. OK. RIH and perforate 9079-9099' (Upper Tyonek 84-6 sand) w/ 900 psig underbalance. POOH and RD. Stabilize well at 4300 mscfpd, 2400 psig. 1/16/97 9479' RU HES. MU tandom electronic gauges. PT against flowing WHP. OK. RIH making gradient stops. Tag fill at 9479'. Make several flowing temperature passes from 8800' to 9470'. POOH and RD. Temperature survey did not indicate any flow from the 84-6 sand. 1/30/97 9479' RU SWS. MU 20' 2-1/8" EJ3 expendible strip gun, 6 spf +/- 45 deg phasing, RDX charges. PT against SI WH? (3310 psig). OK. RIH and reperforate 9079-9099' (Upper Tyonek 84-6 sand) w/ 650 psig underbalance. POOH and RD. Stabilize well at 4700 mscfpd, 2400 psig. KTU 43-6Xrd CAMCO INJECTION MANDREL: 1014.0 - 1020.2 (OO:5188 IO:2859) CAMCO X NIPPLE: 76965 - 7~/97 5 (OD:4,25D tD:~Z813) RECEIVED FEB 10 UWI 50-133-20328-01 Alaska F:, ',n Domestic rroduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 February 4, 1997 LETTER OF TRANSMITTAL Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3192 The following logs are enclosed: Description Print Kenai Gas Field (Z~ff. C~q 3) Completion Record KTU 43-6XRD Jan. 30, 1997 Reproducible Film 1 1 This data is considered confidential until the normal released date. MARATHON OIL COMPANY Received By~_~ Kirsten K. Gamel Date: Enclosures A subsidiary of USX Corporation Environmentally aware for the long run. Alaska R? n Domestic r-,coduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 December 18, 1996 LETTER OF TRANSMITTAL Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 PorCupine Drive Anchorage, AK 9950 I-3192 The following logs are enclosed: Description Cannery Loop Unit #5 q (~ , O'7~ Print Reproducible Film 1) Gamma/Ray Collar Log Cannery Loop #5 Dec 21, 1996 2) ?ackm' Set Cannery Loop #5 Dec 22, 1996 1 1 1 1 Kenai Gas Field 3) Completion Record KTU 43-6Xt~ Dec 16, 1996 Beaver Creek ~ I -- I :~q3 4) Completion Record BCU-6 Dec 26, 1996 I 1 jA~,I 1 5 i997 Received .... . .... -".-,,.,,- :'7.--:~':;io?. Date' ,,~,~.~.t.-,-,~ This data is considered confidential until the normal released date. MARATHON OIL COMPANY Kirsten K. Gamel Enclosures A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation Shutdown ,.. Alter Casing __ Repair Wellm Plugging Change Approved Program Pull Tubing Variance ,,~ Re-enter Suspended Well Time Extension Stimulate Perforate X Other 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 233' FNL, 4160' FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval 2750' FSL, 3788' FWL, Sec. 6, T4N, R11W, S.M., @ 8765' tvd At Effective Depth 2279' FSL, 3795' FWL, Sec. 6, T4N, R11W, S.M., {~ 8866' tvd At Total Depth 2791' FSL, 3796' FWL, Sec. 6, T4N, R11W, S.M., @ 8892' tvd S. Type of Well: Development X Exploratory Stratigraphic Service ,,. 6. Datum Elevation (DF or KB) 114' KB above MSL feet 7. Unit or Property Name Kenai Tyonek Unit 8. Well Number KTU 43-6Xrd 9. Per~.N~_r ~ 10. APl I{I;~"-I~r -- ~'~)~ ~ 5~ 13~32~1 11. Field/P~l Kenai Gas Fiel~yonek 12. Present Well Condition Summary Total Depth: measured 9535 feet true vertical 8892 feet Plugs (measured) Effective Depth: measured 9508 feet true vertical 8866 feet Junk (measured) Casing Length Size Structural 113' 20" Conductor Surface 2508 13-3/8" Intermediate Production 7446' 9-5/8" Liner 9534' 7" Perforation Depth: measured 9405-9462' true vertical 8767-8793' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Cemented Driven 1093 SX 1792 SX 1690 SX 3-1/2", L-80, 7732' md Baker SAB-3 packer, 7651' md Measured Depth 113' 2508' 7446' 9534 True Vertical Depth 13. Attachments Description Summary of Proposal X Detailed Operations Program . BOP Sketch 14. Estimated Date for Commencing Operation July 30, 1996 16. If Proposal was Verbally Approved Name of Approver Date Approved 15. Status of Well Classification as: Oil Gas X ,. Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ( ~ , Title Operations Superintendent N FOR COMMISSION USE ONLY Conditions of Approval: otify Commission so representative may witness Date I^ppr°va'"°' Plug IntegrityM Mechanical Integrity Test BOP Test Location Clearance Subsequent Form Required 10- Approved by Order of the Com.m.i..,sr,s~?~t~e6 Form 10-403 Rev. 06115188 Returued.. Original Signed By Commissioner Date Submit in Trip i~cate KTU 43-6Xrd HANGER: 32.1 (OD:10.500 ID:2.992) ~ STRUCTU.~AL CASING: 113.0 {CD:20.00D) SURFACE CASING: 2508.0 (OD:13.375) --~ PRODUCTION LINER: 9534.0 (OD:7.000) J/ PRODUCITON CASING: 7446.0 (OD:9.625) ~ 3-1/2" TUBING: 32.1-1014.0 (OD:3.500 ID:2.992) CAMCO INJECTION MANDREL: 1014.0-1020.2 OD:5.187 ID:2.867) 3-1/2" TUBING: 1020.2-7650.4 (OD:3.500 ID:2.992) BAKER 80-40 K-ANCHOR: 7650.4-7651.5 (OD:4.750 ID:3.250) BAKER 84-40X32 SAB-3 PACKER: 7651.5-7656.4 (OD:$.687 ID:3.25 3-1/2" TUBING: 7656.4-7696.5 (OD:3.500 ID:2.992) CAMCO X NIPPLE: 7696.5-7697.5 (OD:4.250 ID:2.813) 3-1/2" TUBING: 7697.5-7729.4 (OD:3.500 ID:2.992) CAMCO XN NIPPLE: 7729.4-7731.0 (©D:4.250 ID:2.75D) j BAKER SOS WLREG: 7731.0-7731.7 (OD:3.867 ID:3.000) F~CTURE TREATMENT 9405.0 - 9462.0 Perf 9405.0 - 9462.0 Perf 9422.0 - 9462.0 Icore 9404.0 - 9464.0 Marathon APl # 50-133-20328-01 7~23~96 Field/Platform: Kenai Gas Field Lease: A-028142 Site: 41-7 Sand: D-1 Tyonek KB: 31.10' Est Start Date: 7/30/96 Est Comp Date: 7/30/96 OBJECTIVE: Marathon Oil Company Wireline Work Request Well KTU 43-6XRD Packer: 7651.46' Tbg: EOT: Min ID: 3.5" L-80 8RD EUE 7731.65' 2.75" @ 7729.37' Tubing Clear: OK Fill depth: 9496' (5123196) Tree Connection: 3-1/2" 8RD EUE Perf 9076-9099' using 2-1/2" Hollow carrier guns POTENTIAL PROBLEMS: Hydrates could be a problem at the high pressures, explosives. LAST WlRELINE WORK: 5/23/96 - SBHP survey. PROCEDURE: 1. Conduct safety and environmental meeting. Discuss procedure. 2. RU SWS E-line unit. Place containment basins below engines, shivs, etc to prevent spills. 3. Establish communication blackout. 4. MU 23' 2-1/2" Hollow carrier gun, 6 spf, 60 degree phasing. 5. PT equipment against SI WHP. 6. Flow well at 2.5 mmscfpd, FWHP should be approximately 2650 psi (84-6: approximately 1100 psi underbalance assuming 0.51 psi/ft gradient, 700 psi underbalance assuming 0.46 psi/ft gradient). 7. Perforate the following interval: Run// Interval Footage Comments 1 9076-9099' 23' 84-6 sand 8. SI well and POOH (establish communication blackout w/guns 300' from surface). 9. RD SWS and clean up area. 10. Open well into test separator, high pressure system, flowing well at 2.5 mmscfpd rate. QUESTIONS/COMMENTS? APPROVALS: Mike Olson, 564-6315 (Terry J. Kovacevich) Fax to KGF Foreman H:excel\wireline\kgf\ktu43-6x\O 12.xls STATE OF ALASKA ALASKA 'OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Welt OIL F~] GAS~] SUSPENDED [] ABANDONED [] SERVICE ~] 2. Name of Operator ~T~I~ i 7. Permit Number' HARATHON 0IL COMPANY ~f 95-54 , 3. Address !'~_.]i 8. APl Number P. 0. Box 196168, Anchorage, Alaska 99519-6.168~'.~~. 5o-133-20328-01 4. Location of welt at surface ~~ 9. Unit or Lease Name 233' FNL, 4160' FWL, Sec. 7, T4N, R11W, S.M.i'~i::'i:'i': ' ~ Kenai T.yonek Unit At Top Producing Interval !~~~~/'~"¢~' : i0. Well Number 2750' FSL, 3788' FWL, Sec. 6, T4N, R11W, S.M!. :i!~::~ =~ KTU 43-6X RD At Total Depth i-~.<~]"_ . 11. Field and Pool 2791' FSL. 3796' FWL. Sec. 6. T4N. R11W. S.M: .................. ~: Kenai Gas Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Tyonek 31.1' KB A-028142 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J 15. Water Depth, if offshore --]-~6. No. of Completions 7~7~95 R/9/95 911195 ·I /feet MSL Single 17. :F~)ta[ Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9535'MD/8892'TVD 9508'MD/8866'TVD I Y.,E.,S~] NO[Z] N/A feetUDI N/A 22. Type Electric or Other Logs Run AIT. DSST. SGT. CBT. gET. CCL. GR 23. CASING, LINER AND CEMENTING RECORD .. SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ........ 7" 29# N-80 0' 9534' 8-1/2" 1690 SX ,, , 1 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) 9405'-9462'MD (8767'-8793'TVD) 3-1/2" 7732' 7651' 2-1/2" ltollow Carriers, 6 SPF 9405' -9462 ' MD (8767' -8793 'TVD ) "2'6. ACI D, FRACTURE, CEMENT SQUEEZE, ETC. 2-1/8" EJ3, 6SPF DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED' ' 9405-9462~ 52.744¢/ 20/40 ProDDant , , , , _ ~7.. PRODUCT,ON TEST APR 0 4 Date First Production Method of Operation (Flowing, gas lift, etc.) 9/1/96 F 1 ow i n g A~s~,a Oit & <,~as Cons. DateofTest IH0ursTested PRODUCTION FOR OIL-DEL GAS-MCr WATER-DEL CHOKESIZE I,~,~(~ATIO .......... .9../2/9624 hrs TEST PERIOD I~ 1990 0 . I Flow Tubing "C'~sing Pressure CALCULATED OIL-DEL GAS-MCr WATER-BEE OIL GRAvITY-APl (corr) Press. 2290 0 24-HOUR RATE I~ 1990 0 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core (D,) 9404-9465 ORIGINAL' Sandstone ,l t-med gray, moderately sorted, subang-subrounded, vf-med grained occas, gravel, some disseminated carbonoceous grains and greenstone l ithic fragments, micaceous, berttoni.tic matrix, mod consolidated, porosity 10-15%. , Form 10-407 Submit in duplicate c~.,, -~_~_~n CONTINUED ON REVERSE SIDE 29. 30. NAME Top Tyonek Tyonek 72-8 Tyonek 73-1 Tyonek 75-8 Tyonek 84-6 Tyonek 86-2 Tyonek D1 GEOLOGIC MARKERS MEAS. DEPTH 7807 7848 7880 8170 9090 9256 9404 FL .~ATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, TRUE VERT. DEPTH GOR, and time of each phase. 7228 7267 7298 7577 8464 8624 8766 31. LIST OF ATTACHMENTS Operations Summary, Perforation Summa_r~c, Directional Survey, Wellbore Diaqram 32. I hereby certify that the foregoing ~s true and correct to the best of my knowledge Sign Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types oF lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Ftowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" Form 10-407 KTU 43-6XRD WellView 4.0 9128195 PETROLEUM SERVICES MARATHON OIL CO. CORE ANALYSIS REPORT 43-6X-RD KENAI GAS FIELD, ALASKA CL FILE NO. BP-3-1583 Performed by: Core Laboratories 8005 Schoon St. Anchorage, AK 99518 (907) 349-3541 Final Report Presented August 24, 1995 RECEIVED JUL 30 199~ Alaska Oil & Gas Cons. C0mmi~0n Anchorage These analysis, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgement of Core Laboratories (all errors and omissions excepted); but Core Laboratories and it's officers and employees assume no responsibility and make no warranty of representation as to the productivity, proper operations, profitabiLity of any oil, gas or other mineral well or formation in connection with which such report is used or relied upon. Core Laboratories, Inc. 8005 Schoon Street, Anchorage, Alaska 99518-3045, (907) 349-3541, Fax (907) 344-2823 INTRODUCTION Core Laboratories was requested to perform a core analysis study on behalf of Marathon Oil Co. for samples recovered from the 43-6X-RD well from the Kenai Peninsula, Alaska. Presented herein are the results of this study. Conventional core cut with a water based mud was processed on site by Core Lab and Marathon personnel, and transported to Anchorage during August of 1995. Service description and methodology are presented in section 1. The core analysis results and lithological descriptions are presented in section 2. Section 3 contains copies of shipping and receiving transmittals. In conjunction with the report, the tabular results of the analysis are supplied on an IBM compatible diskette. We sincerely appreciate this opportunity to be of service and hope this data prove beneficial in the development of your reservoir. CORE LABORATORIES MARATHON OIL COMPANY 43-6X-RD KENAI GAS FIELD KENAI, ALASKA FILE: BP-3-1583 DATE: 24-AUG-95 ANALYSTS: P B, D S, DA CORSMPL D H PRESSURE # # P~G 1 1 9405.9 atm 4000 atm 4000 atm 40O0 atm 4000 atm 4000 atm 4000 atm 40OO atm 4000 atm 4000 atm 4OO0 1 2 9409.4 1 3 9413.5 1 4 9425.9 1 5 9434.9 1 6 9442.4 1 7 9445.4 1 8 9453.4 1 9 9460.1 1 10 9462.9 PERMEABI UTY KAIR MD POROSITY (HEUUM) (%) DEAN STARK ANALYSIS HORIZONTAL PLUG SAMPLES SATURATIONS I GRAIN Ot L WATERI DENSITY I % Pv % Pv I GM/CC DESCFIPTION 0.01 1.66 7.76 2.72 0.68 59.7 89.6 43.0 43.3 0.02 9.1 0.0 100.1 2.67 8.9 16.2 0.0 92.4 2.66 15.1 17.2 0.0 88.1 2.67 15.9 16.3 0.0 94.6 2.68 15.1 14.4 0.0 82.2 2.68 13.5 18.8 0.0 76.4 2.66 17.8 19.5 0.0 79.7 2.65 18.2 19.3 0.0 76.1 2.66 17.9 19.8 0.0 85.7 2.66 18.0 5.4 0.0 85.6 2.68 5.0 SS-dkgy,vfgr,wsrtd,sbrnd,vwcmt, qtz,sltylams,bit lams SS-Itgy,vf-mgr,predfgr,wsrtd,sbrnd,wcmt, qtz,dk lith gr SS- mgy,vf-fgr,predfgr,wsrtd,srnd,wcmt, qtz,dk lith gr SS-mgy,vf-fgr,predfgr,wsrtd,srnd,wcmt, qtz,dk lith gr SS- mgy,vf-mgr,predfgr,wsrtd,srnd,wcmt, qtz,dk lith gr SS-mgy,m-cgr,predcgr,wsrtd,srnd,modcmt, qtz,dklith gr,glauc, tr cab SS- m gy, m-cgr,predmgr,wsrtd,srnd,modcmt, qtz,dklith gr,glauc SS- mgy,f-cgr,predm gr,wsrtd,srnd, modcmt,qtz,dk lith gr,glauc SS- mgy,f-cgr,predm gr,wsrtd,srnd,modcmt,qtz,dk lith gr,glauc SS- mgy,f-cgr,predm gr,wsrtd,srnd,vwcmt, qtz,dk lith gr,calc CORE LABORATORIES "IARATHON OIL CO. .,tVELL 43-6X ENAI, ALASKA SLEEVlNGWEIGHTS i AMPLE DEPTH FRESH TEFLON LEAD SCREEN TOTAL SPL NUMBER FEET SAMPLE TAPE SLEEVE ENDS & SLEEVE DATE 10-AUG-95 FILE 1583 FROZEN SEATING BEFORE AFTER SEATING SEATING ~ 1 11 9404.5i 138.1931 0.2551 16.122t 2.882i 157.497ii 157.5051 157.542 i~ 1 2 9406 0/ 156.256! 0.237 17.041 I ...... 2.890 176.547 176.563 ', 176.617 ~.~,,i~. 3 9408.01 145.948[ 0.271 17.067 _ 2.908 166.2701 166.289. 166.332 , _ 1 41 9409.5 145.797 0.244 17.042 2.913 166.035 166.048 166.102 1 I 1 5 ~ 9411.5 148.915 0.270 17.397 2.906 169.555 '~i;~!i 169.568 ~ 169.620 IIIi1 6 9413.6 144.259 0.226 17.321 2.885 164.761 164.7791 164.795 ~' 1 7 9415.5 146.022 0.285 17.064 2.946 166.392 166.404 166.445 ..~ 1 8 9418.5 144.425 0.331 16.967 2.925 164.724 164.725 164.743 ~ 1 9 9420.5 149.034 0.324 17.391 2.900 169.719 169.739 169.775 I 110 94.22.5 98..6571 0.262 11.818 2.978 113.768 113.7771 113.795 !1~ 1 11 9424.5 152.615 0.298 17.543 2.978 173.507 173.541 173.556 1 12 9426.0 149.009 0.317 17.028 2.982 169.397 169.405 169.449 !1! 1 13 9429.5 143.039 0.277 16.737 2.951 163.068 i! 163.151 163.140 I1! 1 14 9431.5 139.948, 0.289 17.456 2.957 160.708 il 160.698 160.737 ..,, 1 15 9433.4 146.400 0.294 17.061 2.888 166.711 ii 166.720 166.786 II 1 16 9435.0 149.460 0.379 17.087 2.957 169.975 i!iiii 169.983 170.034 1 17 9438.0 152.962 0.332 16.718 2.952 173.0411i 173.069 173.116 I~ 1 18 9439.4 SAMPLE :ALLURE ~!~i:::ii 1 19 9440.5 162.620 0.303 17.197 2.962 183.174 183.195 183.266 '"~ 1 20 9442.5 149.674 0.354 17.071 2.944 170.104 170.110 170.169 ~ 1 21 9443.6 147.081 0.363 17.989 2.920 168.395 i 168.421 168.446 ~, 1 22 9445.5 147.155 0.354 17.945 2.969 168.468. 168.491 168.530 !_~ 1 23 9448.5 145.792 0.303 18.186 2.961 167.279I 167.283 167.328 1 24 9453.5 147.319 0.325 17.474 2.928 168.122 iii!i~ 185.942 185.986 I~] 1 25 9450.5 164.882 0.541 17.466 2.928 185.921 !!!i 168.148 168.181 J" 1 26 9455.5 150.511 0.478 17.268 2.919 171.272 '"~'~ 171.276 171.345 :::::~ ,,~ 1 27 9457.0 148.938 0.481 17.388 2.902 169.798 ii 169.816 169.860 ]~ 1 28 9458.6 148.324 0.467 17.952 2.877 169.686 !!i169.701 169.749 1 29 9460.0 142.404 0.403 17.072 2.943 162.895 i 162.905 162.948 B 1 30 '9463.0 165.072 0.119 16.685 2.953 184.924 iii 184.950 184.967 1-10 SHORT SAMPLE 1.5 INCHES LONG Depth MD (not depth ~hif~ed) 9400 9410 9420 9430 9440 9450 9460 Graphic Lithology/ Structure Grain Size Remarks/Description Mud/Sltst, mgy-dkgy, root trcs (mottled) with vfn laminated Ss/Sltst SS, salt & pep, sa-st, mod sort, disseminated carbonacesous grains, sm greenstone lithic frags, sm bentonitic, siliceous matrix, mod consol~, occasional climbing riDDles and wispy ~-~) laminations, mud rid uD clasts (~) at base of sand, overall faiz porosity Ss, as above fewer wispy laminations, occas, pebbles at about 9430', gravel lag at base of sand Ss, as above, slightly coarser, sm portions calcite cemented tight occurring below basal lags, another below carbonaceous laminae at 9450', loosely consol. 9464-5 9470 RECEIVED JUL 30 ~,~l~on Oi 1 Company ; 1-3-96 ;lO:2§A~I ; Anchorage~ Alaska Region Domestic Production 907 276 78~t2;~t 2/ ;_1 Marathon Oil Company P.O. Box196168 Anchorage, AK 99519-6168 Telephone 907/501-531! November 6, 1995 Steve McManus Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 RE: Kenai Gas Field Completion Reports JAN O~ 'f~J~oG Dear Steve: Alaska Oil & Gas Cons. Commission Anchorage As we discussed last week, Maratl~on has plans to extensively test the redrills and workovers in the Kenai Gas Field after the rig has been released. This letter is to inform you of those plans. ~., KTU 43-6XRD Redrill Rig work completed on 8/16/95~ ~ ~) KBU 31-7RD Redrill Rig work completed on 9/30/95 KDU 4RD Workover R!g work completed on 10/24/95 KDU 2 Workover Rwg work in progress KBU 41-7 Workover TO be performed The Tyonek D.1 interval has been perforated and tested. An extreme overbalance surge treatment was attempted but was unsuccessful. A hydraulic fracture treatment was performed on 10/30/95. The well is currently cleaning up following this treatment, After the well cleans up, plans are to temporarily abandon the D-1 by setting a sand plug across the zone, The plans are to pedorate and test the Tyonek 86-2 zone and then sand it off. Then perforate and test the Tyonek 84-6 zone. At this time, the Tyonek 84-6 is expected to be the "permanent" completion interval. KBI, I 31-7.RD The Beluga L-17 and L-18 zones have been perforated and tested. A pressure build up test was run prior to sanding off these intervals. The Beluga L-12 and L-13 were then perforated and tested. A pressure build up test has been run on these zones, A subsidia~/of USX Corporation Environmentally aware for the long run. .athon Oil Company ; 1- 3-96 ;IO:2$AM ; Anchor age-~ 907 276 7542;~ 3/ ~ Alaska Oil & Gas Consew~tion Commission November 6,1996 Page 2 Plans are to perforate additional L-13 interval ancl then evaluate for a fracture treatment. Two scenarios are currently being evaluated. The first is to fracture treat the L-12 and L-13, then perforate and fracture treat the L-10 and L-11 intervals. Alternatively a single stage fracture treatment of the L-10 thru L- 13 may be performed. Irregardless of the fracture treatment method, the "permanent' completion interval is expected to be the Beluga L~10 thru L-13. No perforating or testing has been performed to date. Plans are to perforate and test the Beluga L-13 interval and perform a pressure build up test. The L-13 interval will then be sanded off. The Beluga L-9 and L-10 intervals will then be perforated, tested, and sanded off. Following that, the Beluga M-14 thru L-3 will be perforated and evaluatecl for a fracture treatment. The "permanent" completion interval is expected to be the Beluga M-14 thru L-3. KDU 2 Following rig operations, plans are to perforate the Tyonek 75-8 and evaluate for fracture treatment. Depending on the results of that interval, the Tyonek 73-1 and 72-8 may also be tested. ~BU_41-7 Current plans are to fracture treat two lower Beluga packages while the rig is on the well. Exact intervals will be determined based on the results in other wells. Due to the extensive testing programs for the wells, my plans are to delay filing Completion Reports until the "permanent" intervals are tested and treated, If further information is required, please advise, Sincerely, M. F. Sinclair Drilling Superintendent MFS/kz ;MF~ ~ 106b,ltr Alaska Oil & Gas Cons. Commission Anchom[le OPERATION SUMMARY REPORT ~ELL: KTU~36XRD ~3-6XRD 07'/07/95 1 0 8.500 ACCEPTED RIG FROM MOB AT 0308[ HRS 7/7'/95. MIXED MUD TO KILL ~/ELL. R/U LINES TO TREE ANO TUBING SPOOL. R/U TO PULL BPV. CONTINUEO MIXING MUO. 07/08/95 2 0 8.550 FINISHED MIXING MUD. CIRCULATED AND KILLED UELL. R/U SLICKLINE ANO RIH WITH TUBING PLUG. COULO NOT GET PAST SLEEVE AT 4987~. POOH ANO REORESS TOOLS. RIH. 07/09/95 3 0 8.550 ATTEMPTED TO SET PLUG IN X NIPPLE. COULO NOT GET TROUGH SLIOING SLEEVE. FILLEO WELL AND CXRCULATED. SET TUBING PLUG AT 200~. SET BPV. N/D TREE. N/U BOPE. STARTEO TESTING BOPE. 07/10/95 4 5017' 8.600 TESTED BOPE. RETRIEVED TUBING PLUG AT 200~. PULLED TUBING HANGER TO RIG FLOOR. CIRCULATEO. PULLED AND LAYEO OC~N TUBING. MAOE UP PACKER MILLING/RETRIEVING ASSEMBLY. 07'/11/95 5 5010 8.500 FINISHED M/U PACKER MILLING/RETRIEVING ASSEMBLY. RIH PICKING UP ORILL PIPE TO 4921~. CIRCULATED AND INCREASED MUO VISCOSITY. UASHEO TO 5008~ AND TAGGEO PACKER. STABBED INTO AND LATCHEO PACKER. MILLEO 2.5~ OF PACKER. CBU. POOH. BHA. TESTEO 5" PIPE RAMS. 07/12/95 6 7550 8.600 TESTED LC~ER PIPE RAMS AND KELLY. M/U GLOBE BASKET AND WASHPIPE. RIM TO 5000~. RIM P/U ORILL PIPE. TAGGEO UP AT 7167". REAMEO TO 7')04~. CBU. REAMEO TO 7360~. CBU. REAMEO TO 7550~. CBU FOR TRIP. 07'/13/95 7 7550 8.7'00 POOH. L/D GLOBE BASKET AND WASHPIPE, NO RECOVERY.M/U BIT AND SCRAPER AND RIH TO 7550~. CIRCULATED AND CONDITIONEO MUD. POON TO 4944~. TESTEO PERF~S, PUMPEO IN AT 700 PSI. POOH. M/U CEMENT RETAINER ANO STARTEO RIH. 07/14/95 8 7550 8.900 FINISHED RIH ~IITH CEMENT RETAINER AND SET SAME AT 5729~. TRIPPED FOR CEMENT OIVERTER TOOL. SPOTTED 260 SX CEMENT PLUG FROM 5729 TO 4975~. POOH TO 4975~, CBU. SPOTTED 260 SX CEMENT PLUG FROM 4975~ TO 42;$2~. POOH TO 3880~. CBU. SQUF~EZEO 9 BBLS CEMENT AWAY, FINAL PRESSURE 1400 PSI. ~OC HOLOING/1200 PSI. BLEO OFF PRESSURE, PREP TO POOH. 07/15/95 9 4604 8.800 WAITED ON CEMENT. M/U BIT RIH, TAGGED CEMENT AT 4267*. TESTED CASING TO 1500 PSI. ORILLED CEMENT FROM 4267~ TO 4604~. 07'/16/95 10 5729 8.700 ORILLED CEMENT FROM 4604~ TO 5300~. CBU. TESTEO PERF~S TO 750 PSI. ORILLEO CEMENT FROM 5300~ TO 5729~. CBU. TESTEO PERF~S TO 750 PSl. ORILLED ON RETAINER AT 5729~. 07/17/95 11 7456 8.800 F]NISHED DRILLING CEMENT RETAINER. RIH TO 7546". CIRCULATED AND CONOIT]ONEO MUD. POON. M/U SECTION MILL AND RIH. MILLED SECTION IN 9 5/8" CASING FROM 7446~ TO 7456~. 07/18/95 12 7510 8.800 MILLED SECTION IN 9 5/8" CASING FROM 7456' TO 7510'. CIRCULATED · AND CONDITIONED MUD. OPERATION SUMMARY REPORT WELL: KTU4~6XRD 43-6XRD :':i ............... :: :' ............... i::%~::i:ili,,' ':::::i i:i:i:i:i'i'i:i:i :'fi ' -i:~ ................ ' .......... ~:,:~:::; ....... i:Yi:ii:::ii ................. i:,:ii:~:;:::: ................. ' ........ ~"i': ............ :':":'" ......... ~?','i , i .............. ........ ":!::':i:, .... 07/19/95 1] 7195 9.200 CIRCULATED AND CONDITIONED MUD. POOH. P/U CEMENT DIVERTER TOOL AND RIH TO 7548'. SET 140 SX BALANCEO PLUG. POOH 10 STDS. CBU. POOH. 07/20/95 14 7195 9.250 SET RETRIEVABLE BRIDGE PLUG AT 1022". N/D TUBING HEADS AND N/U CASING HEAO. TESTEO CASING HEAO TO ]]00 PSI. N/U BOPE, BELL NIPPLE ANO FLOULINE. R/U ON WELL KDU & TO KILL THE WELL. REPAIR RIG. 07/21/95 15 7195 9.250 REPAIRED KOOMEY UNIT. TESTED BOPE. RETRIEVED BRIDGE PLUG AT 1022'. M/U OIRECTIONAL BHA. MWD TESTED BAD. M/U NEW MBT). RIH WITH NEW HbDP BREAKING IN CONNECTIONS. RIH WITH DRILL PIPE. 07/22/95 16 7618 9.350 RIH. TAGGEO CEMENT AT 7203'. DRILLED CEMENT TO 7215'. CIRCULATEO OUT GAS. ORILLEO CEMENT TO 7450". TIME ORILLED FROM 7450~ TO 7504~ D[RECTIONALLY ORILLEO FROM 7504' TO 7618'. 07/2]/95 17 78]5 9.600 DRILLED FROM 7618" TO 7835~, CBU. POOH TO SHOE. SECURE WELL. R/U TO WELL KDU #4. PUMPED MUD OOWN BACKSIDE TO KILL WELL. CLEANED MUD PITS 07/24/95 18 7835 9.250 CLEANEO RESERVE MUO PIT. FINISHEO KILLING WELL KDU #~. CLEANEO ACTIVE MUO PITS. TRANSFERREO KCL/POLYMER MUO INTO ACTIVE AND RESERVE PITS ANO WEIGNTEO UP. STARTEO OISPLACING WELL WITH KCL/POLYMER MUO. 07/25/95 19 7988 9.450 FINISHED DISPLACING HOLE WITH KCL/POLYMER MUD. CIRCULATED AND CONOITIONEO MUO. POOH. L/O 10 STDS OF ORILL PIPE. M/U NEW BIT ANO RIN. CIRCULATEO AND CONOITIONEO MUD. ORILLEO FROM 7835' TO 797~~. CIRCULATEO OUT GAS. DRILLEO TO 7988~. 07/26/95 20 8377 10.000 DRILLED FROM 7988' TO 8137'. CIRCULATED AND WEIGHTED UP MUD FROM 9.4 PPG TO 9.8 PPG TO CONTROL GAS. DRILLEO FROM 8137' TO 8242~. CIRCULATEO AND WEIGHTED UP TO 10.2 PPG TO CONTROL GAS. ORILLEO FROM 8242' TO 8~77'". CIRCULATED FOR WIPER TRIP. 07/27/95 21 8701 10.500 CBU. MADE SHORT TRIP TO SHOE. DRILLED FROM 8377~ TO 8441'. CIRCULATE OUT GAS, RAISEO MUD WEIGHT FROM 10.2+ TO 10.5 PPG. DRILLEO FROM 8441 TO 8701'. 07/28/95 22 8760 10.700 DRILLED FROM 8701' TO 8760'. CBU. SHORT TRIP TO 7690. CBU. POOH. STARTEO TESTING BOP'S. WELL START FLOUING. PULLED TEST PLUG. SHUT WELL IN. M/U STAND OF OC'S AND ATTEMPTEO TO STRIP IN HOLE. COULO NOT STRIP IN. STARTED PUMP AND BLEED. CASING PRESSURE 400 PSI. HAD TOTAL OF 7 BBLS MUD PUMPED IN AT 0600 HRS. 07/29/95 23 8760 10.800 PUMP AND BLEED WELL PRESSURE TO 170 PSI. R/U COILED TUBING UNIT. RIH WITH CTU TO 7450'. STARTED RAISING MUD WT. I 07/30/95 24 8760 11.100 RAISED MUD WEIGHT IN PITS TO 11.1 PPG. CIRCULATED AROUNO ON CHOKE. RIH WITH COILEO TUBING. HIT LEDGE AT 7510~. POOH TO OPERATION SUMMARY REPORT WELL: KTU436XRD /*3-6XRD 74/,O'.CIRCULATED 11.1 PPG MUD AROUND ON CHOKE. MONITER PRESSURES. CHECKED FOR FLOg, HAD SURGES OF MUD AHD GAS. WEIGHT UP TO 11./* PPG AND CIRCULATE AROUND ON CHOKE. 07/31/95 25 8760 11./,00 CIRCULATED A TOTAL OF TWO BOTTOMS UP OF 11./* PPG MUD ON CHOKE. SHUT DOUN PUMPS AND MONITERED WELL FOR FOUR HOURS, NO FLOU. CIRCULATED 11.4 PPG MUD AROUND ON CHOKE. 08/01/95 26 8760 11./*00 CIRCULATED 11./* PPG MUD ON CHOKE. POOH WITH COILED TUBING UNIT AND R%G OOgN SAME. RIH TO 7'590" WITH 8 1/2" BIT. CIRCULATEO. RIH TO 8084 AND CBU. RIH TO TO ANO CIRCULATED. POOH. 08/02/95 27 907'5 11./.50 FINISHED POOH. TESTED BOP'S. M/U BHA AND RIH. DRILLED AND SURVEYED FROM 87'60' TO 907'5'. 08/03/95 28 9137 11.900 DRILLED FROM 9073t TO 9121'. FLCM INCREASED. SHUT IN WELL. CASING PRESSURE 1/.0 PSI. ORILL PIPE 0 PSI. RAISEO MUD WEIGHT FROM 11.5 TO 11.7 PPG ANO CIRCULATED IT AROUNO ON CHOKE. WELL STILL FLOUING. CIRCULATEO AROUNO 11.9 PPG MUD ON CHOKE. SLIGHT FLC~. CBU WITH WELL OPEN. FLOW CHECK GAS 603 UNITS. CIRCULATED AROUND 12.1 PPG MUD. WELL DEAD. MADE 18 STAND WIPER TRIP TO SHOE. CBU. GAS 1105 UNITS. ORILLEO TO 9137'. 08/04/95 29 9404 12.100 DRILLED FROM 9137' TO 9404'. CBU. MADE 5 STAND WIPER TRIP. CBU. POOH. L/O MWO ANO MOTOR. M/U CORING ASSEMBLY. 08/05/95 30 9464 12.150 RIH WITH CORING ASSEMBLY. CBU. COREO FROM 9404t TO 9464'. CBU. POOH. · 08/06/95 31 9534 12.150 POOH WITH CORE BARRELS. L/D CORE BARRELS. FULL 60' RECOVERY. R/IH' CUT ORILL LINE AT SHOE. RIH. REAMEO FROM 9383' TO 9464'. ORILLED TO 9525'. CBU. DRILLED TO 953/*'. CBU. MADE 10 STO WIPER TRIP. CBU. POOH TO LOG. R/U TO LOG. 08/07/95 32 953/, 12.200 R/U TO LOG. LOGGED FROM 953/*'-7'450' WITH AlT DSST SGT. POOH WITH LOGGING TOOLS. PULLED OUT OF ROPE SOCKET IN LUBRICATOR. M/U FISHING ASSEMBLY ANO RIH. CBU AT 9/*00'. LATCHEO FISH AT 9427'. POOH TO SHOE. REPAIR SCR SYSTEM. POOH. 08/08/95 33 9534 12.100 POOH WITH FISH. FULL RECOVERY. REPAIRED SCR SYSTEM. STARTED IN HOLE. REPAIRED ORILLERS CONSOLE. RIH TO 9/*75'. REAMEO TIGHT HOLE FROM 947'5 TO 9534'. C&C MUD. POOH. R/U TO LOG. R IH FOR LOG RUN fi 2. LOG WITH CMRT/NGT/LDTCNL. 08/09/95 34 9534 12.100 FINISHED LOGGING WITH CMRT/NGT/CNL/LDT FROM 9534' TO 7/.50e. RIH TO 9534' WITH BIT. CIRCULATE ANO CONDITION MUD. POOH. START CHANGING RAMS PRIOR TORUNNING CASING. 08/10/95 35 9534 12.100 FINISHED RIGGING UP TO RUN CASING. RAN 7" CASING TO 9534'. CIRCULATED AND CONDITIONED MUD. STARTED FIRST STAGE CEMENT JOB. OPERATION SUMMARY REPORT ~ELL: KTU436XRD 43-6XRD 08/11/95 36 9534 12.100 FINISHED FIRST STAGE CEMENT JOB (1130 SACKS). CIRCULATED WHILE WOC. MIXED AND PUMPED SECOND STAGE (560 SACKS). NIPPLE UP TUBING HEAD. CHANGE RAMS, STARTED TESTING BOPJS. 08/12/95 37 9534 12.100 FINISHED TESTING BOPE. LAID DOWN 5" DRILL PIPE FROg DERRICK. STARTED PICKING UP 3 1/2" DRILL PIPE AND RIH WITH 6" BIT. 08/13/95 38 9508 12.200 FINISH PICKING UP 3 1/2" DRILL PIPE. DRILL OUT STAGE COLLAR AT ?014~. TAG FLOAT COLLAR AT 7447~. DRILL OUT TO 9508~. CIRCULATE. POOH. RIG UP ELECTRICLINE. STARTED LOGGING WITH CBT/CET/GR. 08/14/95 39 9508 8.600 FINISHED RUNNING CBT/CET/CCL/GR FROg 9507~ TO 7000'. STARTED RUNNING VERTICAL SEISMIC PROFILE. 08/15/95 40 9499 8.700 FINISHED RUNNING VERTICAL SEISMIC PROFILE. SET RETAINER FOR PLUG BACK AT 9499~. RIH. DISPLACE MUD WITH 6~ KCL. STARTED POOH AND LAYING DOWN DRILLSTRING. 08/16/95 41 9&99 FINISHED LAYING DOI4N DRILL STRING. PICK UP AND RUN IN HOLE WITH PACKER ON 3 1/2" TUBING. SET PACKER AT 7651j. PREPARE TO NIPPLE OCiWN BOP STACK. 08/17/95 42 0 INSTALLED BPV. N/D BOPE. N/U TREE AND TESTED TO 5000 PSI. RELEASED RIG FROg WELL KTU 43'6XR0 TO OEMOB AT 1400 HRS 8/16/95. OPERATION SUMMARY REPORT: POST RIG WELL: KTU 43-6Xrd 09/01/95 DEEP TYONEK D-1 SAND WAS PERFORATED FROM 9405 - 9462' MD W/ 2-1/2" HOLLOW CARRIER GUNS, 6 SPF, 60 DEGREE PHASING, 10.5 GM 31J UJ HMX CHARGES. Qi = 1190 MSCFPD, 0 BWPD, 2290 PSIG. 09/07/95 RIH W/ TANDEM ELECTRONIC GAUGES. WELL FLOWING 2660 MSCFPD, 2500 PSIG WHP @ 14.3% DD. WELL FLOWING 2000 MSCFPD, 2950 PSIG WHP @ 4.5% DD. 09/18/95 RIH W/ TANDEM ELECTRONIC GAUGES. OBTAIN FBHP AND 72 HR PBU. WELL FLOWING 2820 MSCFPD, 2420 PSIA WHP, 20% DD. 09/26/95 DEEP TYONEK D-1 SAND WAS RE-PERFORATED FROM 9405 - 9462' MD W/ 2-1/8" EJ3 NON-RETRIEVABLE STRIP GUNS, 6 SPF, 45 DEGREE PHASING OFF BOTTOM, 14 GM 30A PH EJ-E RDX CHARGES. NO CHANGE IN RATE. 10/06/95- BULLHEAD 41 BBLS OF 6% KCL. WAIT FOR FLUID TO FALL DOWN 10/8/95 TUBING. RIH W/ 2.65" IB. FLUID DID NOT FALL. BULLHEAD 60 BBLS 6% KCL DISPLACE W/ N2. RIH AND SET OWEN SURGE VALVE IN XN PROFILE AT 7724'. SURGE VALVE SET TO SHEAR AT 11,058 PSIG BHP. RU TREE SAVER AND BEGIN PUMPING N2 TO SHEAR SURGE VALVE. VALVE DID NOT SHEAR DUE TO LEAK AROUND VALVE. ABANDON EOB. RETRIEVE SURGE VALVE. ATTEMPT TO FLOW WELL. RIH W/ TANDEM AMERADA GAUGES. OBTAINED SBHP. ATTEMPT TO FLOW WELL FOR SEVERAL DAYS. WELL DAMAGED FROM EOB. LEAVE WELL SI PENDING FRACTURE STIMULATION. 10/30/95- RU FRAC EQUIPMENT AND FRAC D-1 SAND W/ 52,744# PROPPANT, (1.5% PROP NET ADDED IN FINAL STAGE), 800 BBLS FLUID PUMPED. 10/31/95 RU CT AND CLEANOUT SAND IN CASING. UNLOAD WELL W/ N2 AND BRING WELL ON LINE THROUGH TEST EQUIPMENT. WELL CONTINUEING TO CLEAN UP. Q = 4.5 MMSCFPD, 1290 PSIA WHP, 50% DD EST. 11/24/95 RIH W/ TANDEM ELECTRONIC GAUGES. OBTAIN FBHP AND 96 HR PBU. Q = 4089 MSCFPD, 1725 PSIA WHP, 0 BWPD, 48% DD. 9/1/95 9126195 KTU 43-6Xrd PERFORATION SUMMARY PERFORATIONS MD TVD SAND SPF 9405-9462' 8767-8793' D-1 6 9405-9462' 8767-8793' D-1 6 GUN TYPE 2-1/2" Hollow Carrier 2-1/8" EJ3 Strip Gun kPR 0 4 "~':" rev. 3/22/1996 -6XRD DEPTH 0.000 100.000 200.000 300.000 400.000 500.000 600.000 700.000 800.000 900.000 1000.000 1100.000 1200. 000 1300.000 1400.000 1500.000 1600.000 1700.000 1800.000 1900.000 2000.000 2100.000 2200.000 2300.000 2400.000 2500.000 2600.000 2700.000 2800.000 2900.000 30OO.0OO 3100.000 3200.000 3300.000 3400.000 3500.000 3600.000 3700.000 3800.000 3900.000 4000.000 4100.000 4200.000 4300.000 4400.000 4500.000 4600.000 4700.000 4800.000 4900.000 5000.0O0 5100.000 5200.000 5300.000 5400.000 5500.000 5600.000 5700.000 5800.000 5900.000 6000.000 6100.000 6200.000 6300.000 6400.000 SURVEY AZIMUTH 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 334.000 339.000 342.000 341.000 3392000 340.000 340.000 340.000 341.500 340.000 342.000 344.000 344.000 346.000 346.000 347.000 348.000 349.000 349.000 350.000 350.000 352.000 352.000 353.000 354.000 354.000 355.000 355.O0O 355.00O 355.50O 355.000 354.500 355.000 355.000 354.000 354.000 353.500 354.500 354.250 354.000 354.000 354.000 354.000 352.000 35O.O00 349.000 349.000 349.000 348.000 347.500 348.000 347.000 347.000 347.000 DEVIATION 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 1.000 5.000 8.500 10.250 12.000 13.750 16.000 18.000 21.250 23.750 25.000 27.000 27.250 27.000 27.250 27.250 28.000 28.750 29.000 29.500 29.750 29.000 29.000 29.500 29.500 29.500 29.500 30.000 29.750 29.000 30.000 29.500 29.000 29.750 29.750 29.500 30.000 29.000 28.750 29.000 28.150 28.150 28.000 27.150 26.000 23.000 21.000 20.000 20.000 19.750 20.000 19.500 19.500 20.000 SSTVD -114.000 -14.000 86.000 186.000 286.000 386.000 486.000 586.000 686.000 786.000 886.000 985.995 1085.838 1185.129 1283.790 1381.906 1479.389 1576.031 1671.657 1765.835 1858.216 1949.301 2039.175 2128.177 2217.178 2306.179 2395.081 2483.680 2571.666 2659.233 2746.482 2833.410 2920.552 3008.014 3095.263 3182.299 3269.334 3356.370 3443.190 3529.901 3617.043 3704.078 3790.897 3878.147 3965.289 4052.109 4139.037 4225.856 4312.891 4400.458 4488.026 4575.844 4664.016 4752.249 4840.889 4930.322 5021.308 5114.021 5207'.688 5301.657 5395.700 5489.744 5583.861 5678.125 5772.243 TVD 0.000 100.000 200.000 300.000 400.000 500.000 600.000 70O.000 800.000 900.000 1000.000 1099.995 1199.838 1299. 129 1397.790 1495.906 1593.389 1690.031 1785. 657 1879.835 1972.216 2063.301 2153. 175 2242.177 2331. 178 2420. 179 2509.081 2597.680 2685.666 2773.233 2860.482 2947.410 3034.552 3122.014 3209.263 3296.299 3383.334 3470.370 3557.190 3643.901 3731.043 3818.078 3904.897 3992. 147 4079.289 4166.109 4253.037 4339.856 4426.891 4514.458 4602.026 4689.844 4778.016 4866.249 4954.889 5044.322 5135.308 5228.021 5321.688 5415.657 5509.700 5603.74.4 5697.861 5792.125 5886.243 XOFFSET 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 -0.383 -2.423 -6.322 -11.495 -18.103 -25.902 -34.682 -44.682 -55.743 -68.367 -81.797 -94.603 -107.171 -118.971 -130.001 -140.'689 -150.723 -160.196 -169.410 -178.313 -186.897 -194.572 -201.319 -207.695 -213.269 -218.416 -223.136 -227.461 -231.802 -235.864 -239.943 -244.483 -248.955 -253.230 -257.986 -263.153 -268.556 -273.705 -278.438 -283.381 -288.381 -293.312 -298.232 -303.870 -310.863 -318.412 -325.560 -332.242 -339.061 -346.274 -353.487 -360.799 -368.309 -375.910 YOFFSET 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.785 5.606 16.694 32.141 50.269 71.142 95.265 122.740 154.449 190.573 229.596 271.517 315.345 359.382 403.621 448.143 493.412 539.982 587.385 635.429 684.110 732.555 780.564 829.008 877.933 926.906 975.921 1025.354 1074.975 1123.858 1172.931 1222.344 1271.000 1319.866 1369.259 1418.420 1467.746 1516.717 1564.774 1612.811 1660.378 1707.298 1754.103 1800.046 1844.229 1884.997 1921.766 1956.142 1989.657 2022.880 2056.103 2089.093 2121.618 2154.544 .000 .0.000 aO0.O00 6900.000 7000.000 7100.000 7200.000 7300.000 7400.000 7500.000 7670.000 7733.000 7795.000 7886.000 7948.000 8010.000 8103.000 8196.000 8289.000 8382.000 8475.000 8568.000 8661.000 8754.000 8846.000 8940.000 9033.000 9125.000 9218.000 9310.000 9364.000 9404.000 9421.000 9464.000 9504.000 9535.000 346 345 346 346 347 344 346 344 344 343 342 1 9 6 18 2O 15 12 12 7 11 13 12 12 10 11 11 12 12 12 10 10 10 10 10 10 10 .500 .500 .5O0 .000 .000 .000 .000 .000 .000 .000 .000 .900 .140 .800 .830 .000 .520 .480 ~510 .610 .550 .580 .700 .270 .800 .640 .910 .630 .950 .130 .140 .460 .460 .460 .460 .460 .460 ...... 000 19.000 19.000 18.750 18.500 18.000 18.000 17.500 17 · 000 16.500 15.000 15.560 15.300 15.500 15.820 15.670 16.120 16.830 15. 670 14.700 14.450 15.350 15.900 16.390 15.540 15.320 15.210 14.910 14. 680 15.180 16. 170 16.670 16.670 16.670 16.670 16.670 16.670 5866.506 5961.058 6055.609 6150.232 6244.995 6339.964 6435.070 6530.310 6625.811 6721.568 6817.811 6981.800 7042.530 7102.304 7189.926 7249.599 7309.229 7398.410 7487.693 7577.445 7667.452 7757.324 7846.887 7936.219 8025.631 8114.314 8204.998 8294.804' 8383.754 8473.614 8562.191 8613.989 8652.308 8668.594 8709.786 8748.105 8777.803 5980.506 6075.058 6169.609 6264.232 6358.995 6453.964 6549.070 6644.310 6739.811 6835.568 6931.811 7095.800 7156.530 7216.304 7303.926 7363.599 7423.229 7512.410 7601.693 7691.445 7781.452 7871.324 7960.887 8050.219 8139.631 8228.314 8318.998 8408.804 8497.754 8587.614 8676.191 8727.989 8766.308 8782.594 8823.786 8862.105 8891.803 --~3~3.560 -391.436 -399.312 -407.001 -414.457 -422.294 -430.291 -438.179 -446.353 -454.537 -462.695 -468.884 -467.275 -464.993 -459.544 -453.951 -448.777 -442.402 -436.772 -432.509 -428.616 -423.410 -417.717 -412.126 -407.009 -402.247 -397.196 -392.061 -386.861 -381.659 -376.864 -374.134 -372.051 -371.166 -368.927 -366.843 -365.229 2187.035 2218.624 2250.213 2281.636 2312.690 2343.006 2372.854 2402.300 2430.805 2458.437 2484.323 2528.469 2545.142 2561.446 2585.352 2601.219 2617.387 2642.977 2668.383 2692.359 2715.431 2738.770 2763.163 2788.412 2813.473 2837.483 2861.710 2885.322 2908.232 2931.622 2956.010 2971.029 2982.313 2987.108 2999.238 3010.522 3019.267 MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission David Joh~on, Chair~ Blair Wondzell, ~ P. I. Supervisor "//~/9~" FROM' Lou Orimaldi, .z~'~-~ SUBJECT: Petroleum Inspector DATE: July 9, 1995 FILE NO' AQ9JGICD.DOC BOP test / Rig inspection Pool Rig #122 Marathon #KTU 43-6X Kenai Gas Field PTD # 95-54 Sunday, July 9~1995: I witnessed the initial testing of the 5,000 PSI BOPE on Pool Rig #122 which was preparing to redriil Marathon #KTU 43-6X in the Kenai Gas Field. I had been on call for this test for the preceding 3 days and was called out at 0230 hrs. this morning. The test began at 0500 hrs. and was concluded at 0930 hrs. This rig is the same rig that was used on the Tyonek platform and has been converted to a land rig. i found a well prepared rig which is indicated by no failures of the equipment that I witnessed tested. I found no Hazard section in the Drilling permit package but as Pete Verga (Marathon drilling foreman) was not aware of this relatively new requirement I advised him of its necessity to be on location and received his assurance that he would advise the town engineers to include this section in their subsequent permit requests. SUMMARY: I witnessed the initial BOP test on Pool Rig #122 redrilling Marathon #KTU 43-6X in the Kenai Gas Field. Test time 4.5 hours, no failures. Attachments:. AQ9JGICD XLS CC: Mark Sinclair CO HSS O TONY KNOWLE$, (~OVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 27, 1995 Mark Sinclair Drilling Superintendent Marathon Oil Company P O Box 196168 Anchorage, AK 99519-6168 Re: Kenai Tyonek Unit 43-6XRD Marathon Oil Company Permit No. 95-54 Sur. Loc. 233'FNL, 4160'FWL, Sec. 7, T4N, RllW, SM Btmnhole Loc. 2956'FSL, 3818'FWL, Sec. 6, T4N, RllW, @ 9610'TVD SM Dear Mr. Sinclair: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout preventiOn equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting · David W. J~hnston ~ ~ Chairman ~i ~ BY ORDER OF THE SION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 .a. Type of work Drill [] Redrill I]q lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen[]1 Service [] Developement Gas I~ Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Marathon Oil Company 114' KB feet Kenai Gas Field/Tyo 3. Address 6. Property Designation P.O. Box 196168, Anchorage, AK 99519-6168 A-028142 ' 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 233' FNL ,4160' FWL ,Sec. 7,T41'.t ,R11W,S.M. Kenai Tyonek Unit At top of productive interval 8. Well nu,mber Number 5194234 2736' FSL, 3772' FWL, Sec. 6 ,T4N, R11W, S. M. @ 43-6XRD 8770 'TVD 9. Approximate spud date Amount $200,000 At total depth 2956 ' FSL'3818' FWL 'Sec' 6'T4N'R11W'S'I~CJ~0' TVD 6-1-95 ....... 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MPandTVD) property line 2344' feet 900' feet 6000 10,273 'MD,9610' TVgeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 7500 feet Maximum hole angle 15. t Maximum surface 3426 ps~g At tota, depth rrVD) 4530 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2 7" 29¢~ N-,gO BT£ L0.273 0 0 10,27: 9610 1265 l")F'rl~l%l[h " I~ LLLI V EL,/ APR 1 ~ 199§ ..... 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~.~,jl;;J Ul~ & ~ C0ii~. Present well condition summary Anchora Total depth: measured 8370 ~feet Plugs (measured) 7593 ', 7718' , 8107' true vertical 7770 'feet Effective depth: measured 7593 'feet Junk (measured) 7340' true vertical 7021 'feet · Casing Length Size Cemented Measured depth True Vertical depth Structural 113 20" Dri yen 113 113 Conductor Surface 2508 13-3/8" 1093 SX 2508 2427 Intermediate Production 8370 9-5/8 1792 8370 7770 Liner Perforation depth: measured 5118' - 5646' true vertical 4706' - 5177' 20. Attachments Filing fee IX] Property plat X] BOP Sketch ~ Diverter Sketch [] Drilling program Drilling fluid program)(] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ,:~.//~,~,,~' Title //~ ..~'~/~"/, Date~...~ Commission Use Only N~2tr A PInumber I Approvaldate~.~..-- I Seecover,etter Permit ~/TZ 50--/,~ ,.~ - .2. O ,.~ .2. ~'-' o I :,Z//.... 42~ '~ '"' --"-" for other requirements Conditions of approval Samples required [] Yes [] No Mud log required [] Yes ~ No Hydrogen sulfide measures E3 Yes J~ No Directional survey required ~ Yes [] No Required working pressure for BOPE []2M; [] 3M; ~5M; [] 10M; [] 15M Other: Original Signed By by order of%/,'~7/~' Approved by David W. Johnston Commissioner the commission Date ~ek Knrrn iFl.,4Fli Rev ig-i-RE Submit in triplicate DF NG AND COMPLETION PROGRAM MARATHON OIL COMPANY ALASKA REGION WELL: KTU 43-6X RD PAD: 41-7 SLOT: NA REVISION NO.: 2 SURFACE LOCATION: TARGETS: Tyonek D-1 Tyonek D-5 BOTTOMHOLE LOCATION: KB ELEVATION: 114 ft. mean GL ELEVATION: 80 ft. mean FIELD: Kenai Gas Field AFE No.: 1500893 TYPE: Tyonek Producer DATE: 4/6/95 233' FNL,4160' FWL,Sec.7,T4N,R1 lW, S.M. 2736' FSL, 3772' FWL, Sec 6, T4N, R11W @ 8770' TVD 2917' FSL, 3810' FWL, Sec 6, T4N, R11W ~ 9460' TVD 2856' FSL, 3818' FWL, Sec 6, T4N, R11W @ 9610' TVD S.L. (est.) S.L. (est.) I. IMPORTANT GEOLOGIC HORIZONS (below Side=ack Point): FORMATION DEPTH(MD) Tyonek 7840 DEPTH(TVD) 7260 II. ESTIMATED FORMATION TOPS AND CONTENT: FORMATION DEPTH(MD) DEPTH(TVD) Tyonek 72-8 Sand 7840 7260 75-8 Sand 8172 7580 D-1 Interval 9404 8770 D-2 Interval 9508 8870 D-3 Interval 9839 9190 D-4 Interval 9984 9330 D-5 Interval 10118 9460 POTENTIAL CONTENT Gas Gas Gas Gas, depleted Gas, depleted Gas, depleted Gas GaS Cons. page 1 JONTROL EQUIPMENT BLOWOUT PREVENTERS ,'~e blowout preventer stack will consist of a 13 5/8" x 5000 psi annular preventer, a 13 5/8" x 5000 psi double gate ram type preventer outfitted with blind rams in the bottom and pipe rams in the top, a 13 5/8" x 5000 psi drilling spool (mud cross) equipped with a 3-1/16" x 5000 psi outlets, and a 13 5/8" x 5000 psi single gate ram type preventer outfitted with pipe rams. The choke manifold will be rated 3-1/16" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor- boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mudpits will contain sensors to measure the volume of fluid in the sudace mud system. Both sensors will contain readouts convenient to the drillers console. WELLHEAD SYSTEM STARTING HEAD: Gray 13-5/8"-3000 psi top x 13-3/8" SOW bradenhead in place. CASING HEAD: Gray 11 "-5000 psi top x 13-5/8" bottom casing spool in place.(Will be removed) CIW 11" -5000 psi top x 13 5/8" bottom casing spool will be isnstalled. TUBING HEAD: 11" - 5000 psi bottom x 11 "-5000 psi top tubinghead with two 2-1/16" - 5000 psi studded outlets, one blind flange and one 2-1/6" - 5000 psi flanged gatevalve. (Will be refurbished.) CHRISTMAS TREE: 3-1/16" - 5000 psi single christmas tree including two master valves, one flow tee, one manually adjustable choke, and one swab valve. Existing CIW Type tree will be refurbished. IV. CASING PROGRAM: CASING DESCRIPTION SET SET TYPE SIZE WT. GRADE THREAD FROM TO PRODUCTION: 7 29 N-80 BTC Surf CASING DESIGN SETTING FRAC GRD FORM PRSS SIZE WEIGHT GRADE DEPTH,TVD @ SHOE @ SHOE MASP 7" 29.0# N-80 9610' 10273.0' 9610q-VD HOLE SIZE 8-1/2" DESIGN FACTORS TENS COLL BURST 4530 3443 2.87 1.24 1.12 RECEIVED APR 1 1995 Alaska 0ii & Gas Cons. Commission Anchora ",. page 2 dTING PROGRAM .~DUCTION: LEAD SLURRY: TAIL SLURRY: 7" @ 10273'MD Halliburton Light Premium w/.2% CFR-3, .25% HALAD-344, .3% HR-7 TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME 1870 ft. 13.6 ppg. 1.53 cu. ft./sk 7.59 gal/sk 5:04 hrs:min 0% 425 sx Halliburton Premium w/.2% CFR-3, .3% HALAD-344, .1% HR-7 TOP OF CEMENT: 7000 ft. WEIGHT: 15.8 ppg. YIELD: 1.15 cu. ft./sk WATER REQ.: 5.0 gal/sk PUMPING TIME: 5:01 hrs:min EXCESS (%): 50 % ESTIMATED VOLUME 840 sx RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3. M/U float collar. (Baker-lok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing. M/U cementing head, install bottom plug and test all lines. 6. Circulate and reciprocate until no gains in circulating efficiency is made. 7. With as little shut down as possible, drop bottom plug and begin pumping spacer. Pump spacer as follows: 40 bbls 18% NaCI 20 bbls drill water 20 bbls Super Flush 20 bbls drill water 40 bbls 18% NaCI 8. Pump 5 bbls drill water. 9. Mix and pump 115 bbls. lead slurry(425 sx). 10. Mix and pump 172 bbls. of tail slurry(840 sx). Drop top plug. 11. Displace cement. Reciprocate as long as possible. 12. Bump plug w/500-1000 psi over final circulating pressure. Check floats. 13. P/U BOP stack. Set slips. N/U tubing spool. N/U BOP stack. 1 4. WOC 12 hours. 15. Test BOPEo REC£1V£i:) APR 1 3 1995 uti & Gas Cons. Commission Anchora ~*~ page 3 PROGRAM MUD PROPERTIES DEPTH DEPTH WEIGHT VISCOSITY WATER MUD FROM TO ppg sec/qt LOSS TYPE 7500' 10273' 8.6-10 40-80 4-6cc PHPA/KCL Ventrot 401 or Liquid Casing will be used to prevent differential sticking. MUD EQUIPMENT The solids control equipment will consist of two derrick floline cleaners, a 2-cone desander, a mudcleaner, and a Swaco 518 centrifuge. VII. LOGGING, TESTING, AND CORING PROGRAMS PRODUCTION: COMPLETION: LOGGING PROGRAM AIT/SP/Cal/from 102673MD-7500'MD. LDT/CNL/CaI/SGR from 10273'MD-7500'MD. Dipole Sonic from 10273'MD-7500'MD . FMI or CBIL over cored interval and other zones to be selected by well site Geologist. CMRT from 10273' to 7500'. A TDT will be run from PBTD to 5600' MD. A Cement Bond Log (CET/GR) and a directional gyro- survey will be run prior to perforating. A VSP Icg may be run in casing. CORING PROGRAM A 60' whole core will be taken in the D~I sand at 8770'tvd. (9404'-9464'md). None planned. TESTING PROGRAM /kPF~ I 3 1995 ~,s)~ iJii & (}as Cons. Commission Anchom ~ page 4 I'OMHOLE PRESSURES AND PC. JTIAL HAZARDS ,~gen sulfide gas has not been encountered in an,/welt in the Kenai Gas Field. The T,/onek ,~e is expected to be normally pressured with the exception of the following intervals: TVD, ft. Est. pressure, psi Gradient, ppg. Tyonek 72-8 sand 7260 3400 Tyonek 75-8 sand 7580 3450 Tyonek D-1 interval 8770 4195 Tyonek D-2 interval 8870 785 Tyonek D-3 interval 9190 785 Tyonek D-4 interval 9330 785 Tyonek D-5 interval 9460 4530 8 88 9 00 910 1 68 1 62 1 6O 911 IX. OTHER INFORMATION DESC RKB KICKOFF, (Tie-in) END OF CURVE TOTAL DEPTH POTENTIAL INTERFERENCE: DIRECTIONAL PLAN MD TVD 0 0 7500 6931 tum @ 2.0 deg/100ft 7881 7300 tangentsection of 15.1 deg 10273 9610 WELL INCL 0.00 15.00 15.10 15.10 AZIM SOE N18W N11.69E N11.69E DISTANCE (ft.) NORTH COORD 0 2486 2582 3189 DEPTH (MD) WEST COORD 0 462 468 342 VERT SECTION 0 2522 2617 32O8 RE¢£1V£D (las Cons. Commission Anchota, ~ page 5 DI lNG PROGRAM ~DONMENT AND SECTION MILLING eve in and rig up rotary drilling rig. R/U slickline and open sleeve at 4967'. Circulate mud to kill the well. Set a two way check valve and nipple down Xmas tree. Nipple up BOPE and test. POOH and lay down tubing. RIH with packer plucker :and mill up packer at 5003'. Fish/mill 2 1/8" Halliburton strip guns on top of fill at 7340'. Clean out to EZSV at 7593'. Make bit and scraper run to 7593'. Set retainer at 5700'. Cement squeeze perforations between 5106' and 5646' by spotting cement from 5700' to 4200'. POOH to 3500' and squeeze perfs with 55 bbls. Drill out and test casing to 1000 psi. RIH with section mill and mill section from 7500' to 7550'. Lay balanced plug from 7593' to 7400'. WOC for 24 hours. While WOC RIH with RBP and set at 1000'. N/D both tubing spools and install casing head. N/U BOPE and test. Retrieve bridge plug. DRILMNG RIH with directional assembly and dress off cement plug to 7495' (directional driller to witness). Sidetrack well to core point. Cut 60' conventional core, Drill to TD and Icg. Run and cement 7" casing. COMPLETION: Cleanout casing to PBTD, Run gyro and CET/GR. Run TDT log from PBTD to 7500'. Gas Cons. Commission Anchor~ '~, page 6 MARATHON Company Structure : Pad 41-7 Field · Kenai Gas Field Well Location · · 45-6X Kenai, Alaska WELL PROFILE DATA .... Point MI) Inc D~r TVD North Eost 0e9/1 O0 KOP 7,500 16.OO 342.00 6951 2486 -462 End of guild 7880 15.O4 11.68 7299 2582 -468 2.00 Torget 10118 15,04 11.68 9460 ,I150 -350 0,00 End of Hold 1027.3 15.0& 11.68 9610 .,t189 -342 0,0( Creoted by : cheromie Dote plotted : 3-Apr-95 Plot Reterence is ~5-6X Yer~ion ~6. Coordinotes ore in feet rel'erence slot T~ue Verticol Oel~ths ore ceference RKB. --- Baker Hughes INIE0 --- 6400_ 6600_ 6800_ -- 7000_ C"' 7200_ _ (") 7400_ - 7600_ 7800 _ > - 8200_ (D _ ~ 8400_ I--- . 8600. I . I 8800. ¥ _ 9000. 9200_ 9600. 980O 2200 2400 2600 2800 3000 3200 3400 640 560 4~80 I I I .1. { .1 Tyonek Tyonek D- 1 RECEIVED APR 13 1995 0il & 6as Cons. Commission Anch0ra' ~ Wesf .~. .... ,,,, 400320 240 3280 _3200 - _3120 - _3040 ~2960 _2880 _ _2800 _2720 _2640 _ _2560 _ _2480 HYDRIL 1,3 5~8"-5000PSI GK ANNULAR BOP LATCHED HEAD ?,3 5~8"- 10, O00PS! HUB BOTFO~ CONNECTION 1/? 6"- ~ O, O00PSl SiDE OUTLETS LYNN ilV'rE'RNATIONAL HCR ITl HCR 3 ?/~6.-10,000PSi ~J~iUAJ. I I~ANUAL CHECK VALVE CHOKE WING KILL WING McEVOY 4 ~/16.-10,000PSI McEVOY 3 ~/16.-10,000PSI TYPE E GATE VALVE TYPE E GATE VALVE HYDRIL 1 $ 5/8'- 7 0,O00PSI MPL RAM BOP HUB CONNECTIONS 4 1/~ 6'- 10, O00PSI SIDE OUTLFTS ~ 3 5/8'- ~ o, oooPs~ HUB X !5 5/8 5,000 FLANGE ADAPTOR BLOW-OUT PREVENTER STACK PAA RIG 4-2g-L RECEIVED APR 1 ;b 1995 iJJi & Gas Cons. Commission Anchora-.~, TO SHAKER BOX TO FLARE PIT TO GAS BUSTER FLARE \ \ I INLET A ~cEVOY TYPE 'E"-5 1/8" - 5M CATE VALVE. B. CAI~EROiV 17PE FCC 3' 1/8' - 5M CATE VALVE C. ~cEVOY 7YPE 'E-2 1/1¢ - 51¢ CATE VALVE 0. ,¢-W.4¥ FLOW BLOCK $ 1/8" X $ 1/8" Z ,:7 fl8" X $ 1/8" 51¢1 E. 4-WAY FLOW BLOCK 2 1/16' X 2 1/1¢ X $ 1/¢ X $ 1/¢ 5M F. Z-WAr FLOW BLOCK 3 V~' X 2 1/1¢ X J I/8' 5~ Go TRI-FLO $ 1/16'-10M HYDRAULIC CHOKE H. NA1701V,4L 1YPE 'F' 2 1/16'-5M klANUAL CHOKE ~ 1/~ x ~ ~/~ 5~ SPOOL K. `7 ~/~ X `7 1/~'_5~ SPOOL L. 3 1/8' X 2 1/16'-5bl SPOOL `7 Va' x 2 1/~6'-5~ SPOOL N. `7 ~/16'-~0~ X 2 1/16--5M OOUe~ STUOOE9 AOAPTO[~ P. 5 1/16'-~0~ X 2 ~/16'-5M OOUBL~ SrUZ)OEZ) AOAPTOR `7 l/C_ X ~ V~'-5/~ SPOOL ,7 1'/.~-5M T~GET FLANGE ~ 17¢ x `7 V¢-5~ SPOOL 7'. SENSATOR BLOCK u. 2'-5~ T~[~4D~ FLANGE (2' NPT) REE£1VED APR 1 ~ lg~5 Oil & Gas Cons. Commission Anchors ~ CHOKE MANIFOLD SCHEMAtiC PAA. RIG 429-L Sec 8 Dike Sec 7 -_- Bldg~] ontractor'~-'-} Bldg ~_.1 - to 14-8 Oontrol Bldg Dik~ =- Dike KU 13-5 KU 43-6x © KU 43-8 · O KDU ~ ./ KU 41-7. ©KU 43-6A Water Well Houae mlm" KDU 2 ,/ ~ KU 24-6 Reboiler Bldg Heater Bldg ~KU 14-8 OKU' 43-7' Pad Llmita RF.¢F. IVED Gas Cons. Oommi~sion AIlchore '~ MARATHON OIL COMPANY KENAI GAG FIELD PAD 41-7 FIGURE 3. /32 · /-;;i, ! "- .'.:' /.._.... ~.~:_ // 33 ,Y 4b- · . ; l. l. T 4 N , I ~ I. I 0 ,, ?..:~ - i-:':,-:-I ! - ,?-.::.j l* [-1 o,/~"~ Well '...::! "::[ I .~ i, I . ~ . ~---' I i:'.-i :-:.~ 1..-:'i [:-:::; P, as WellS 32 33 ;' ' Unit Boundary . I I j -. we,s_ .p,,_ ./'/ .... .. 3 · · · ,,, 13 n ./ T. GN. h"r." ' Gravel Pits T. SN. 6709000m. 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Z .' / h -'" ,- :' ~ . .,' .''('" ! ~ - ~ " ': , ' ~-~-'-!,.-:::;:c:::?:.~::u.~:~:;:::/. ~, 25 ---30 .... ~ ,""';9: '-' ~- ":" ..::-'2[ 'x. :,~J.IL~ !...,.!~, ,2~ '.,' "'-: ':::' ':-":" ': ' :.':;'l \~ ~ ' ' '~- ] ' -" "' ~ I1'",,~ ~ "~- ' ~ /' I :.'. ~. "-.';'U:...C-:'.:.'~::-:~'::.:~:!. .\ I :...-- ', f-. ~-./., ~', ?'.: -.::"¢';-~".. ..... :. ' /. /A / '" ';,'-'"'~-:.~"'.: /:" t'- .~'.-.."-'~!'..:~.-.' ..... :'-.:%~ (',,\ '"- .... , ' '[.', ', : . "!', ,' ..' .: - ~' ~ '-.,,-, ,/ · - · :t ~'-:~.-.':--~.:: :::-~ ,, '-..:. ~- - "'L-' ' '" '.' ? ' ' ' ", -1 · , , .',",,~' /::'-"~ .... ':.-:?,:.,":i-:-;:: .}.~ ' ','--- ~ .-~.,oo'.-. ~h") '- ",, ', ' - ,--J ./.: :~-:--~:.:~:-:?~-:'.~ :'~:;",? \' '"-:.'.--'-.~{,_ ~ ;~-:. ":-.P'.,--~.. acl MARATHON OIL OOMP^NYJl · ' :-' . ::': ::-.". ' -'. t. ~._ .L .......... I-' ..........ii--. .... t ...... .~ ' _ L.. __ ~- .~ .~. -- ~ .-~ -- --~,- -- ~. .. .-. .... . .... .. ~ .z_ ~ ,. . .iff: %/.-: ~ I I-'1 ~.'~ .: .' .':":-' '/i'.:.?'.:':-::::?:-'".~ ?:/'; ~ :' - ' ': " .. . ' .: ...... '.0.-- I '~' · --"--':-~'-<-:-::'~'~?--~::~?~ :.::i:o \. , ,....~ tl -......:zJ. _..,.,, :..~ ,IK,=N^, e^~ F~ELD 1,1- · '" :': '::' ........ .... "'? ::'""" '1 I- : '-:: :'F-:-:c: '-...:..:.:.: ' ""~ ~"' I '" I '-' '( '- -' ~' : -J.~'"~ ' ' ..... : .-....-. -..;..:-. : .. , . .. ~/--.._1~- . . :' -."L-::'".:.-'-:!:'?:i'?'~':.:':'.?':'' ' 36 ~ 31 ~ 32 "~ f'. ~'3"L~A:e ,--~ ~::'J. , ..... / ~ : ]-- "~:""~ - " " / ' '- '.-' ' " /'"I - ' ,: " ......... - .-- ·:. ~ ' - :,---~ -~ ~4-,~, '-~/--~ :-~,-~.,~ --~ ":-'~::':i' i'--. ':-. '.~ "i: ! '. . '-- :- ._ · , r"~%. c :. ' ', /~.-~-------.~'--.--*° ' T. SN ...Ii. aN '..j PIPELINE 25 ...... 60'30' J- 25 · ~ 370 000 22 27 34 t I I 1 4 II 9 ~ . ' ' . ; . .,' . ..... . ' /'r~\ KU 14-4 PROD. EGUIP. , .~ ~ ' ' ' · .' ..'" . '. '":-,.".-..' .'.'.:,....'.';' ".'L~/TUD=,2= IOUUCF.E^T=. '"" '"J ' ' '":" ":'' '"':::"' t:' ':"" '" ::' ;":' "|.4'4` ':'·:~."" ' "..""".:'"' :. :'-~. . : i '.' ' .." ...".-..:,.' .:.;'" :.::...!-..~.,'........~. :-....:'! ...::..- .'......: .... ...:..\.'-....i,....:.:.--:-'; :: ' <' ' ' ! ': x2 RECEIVED APR 1 ~ 1995.' .... ! ~,,~ PROD. £qblP. "~'--12"~' "f APL( TO ANCHORAGE ' 1050 PSI) · -s~u .5 U-M KDU 3 TDM 11.518 8 43-6^ 'TMD 5300 KU , KDU 2 ~ 21 - i PROD. EGUIR U-I~ ' .. · ' 120'MMCF GLYCOi~ .... '-.--Ku. 45-? D~;HY & HTRS-SRU! TMD 5707 41-18, 'i" .. ' '. ' /,~" .u-~ . · ~'.: ::"'. '... ": '.'. ' .' ~, : I~/ .~",,., 6 f:~,,,,~ , , z ,8 ~ ."- ': ... '.. '. .. ', ; ! :~ ;~ !il' u-, ' ? -- ............ :-. ...................... ....... , :" '" ·' '. ." · ~ PROD. E~UIP : 12~ :i ~ '~ ~/I KU ~1-7 ~_ ' ' ' ) ' , . . ..................................... ~..H~,~..P~., . :~..U.~.U .................... [~ .... I '~ ~ ,~,~"¥' . ~ ....... :: .... : -"7'".':-. ....... . : ~ . ~-' KU.,4-~O i~! / / U-~ ~~', .~' ~4.~ ~.~ U-M · ' ;' ~~ ,~..' ' ."" " ;. ', ¢~': TUD STO0 ~ ,- u~ KU I1-~_ IlG'~'~' ' Tun,~ n47 "~ KDU 4 ~'. · ~%- -,,-r~-~ ' .. , . ' ~ ~' ~ u-~,~ ./ TUD44~e /~4~. - ...... '- ;~' ~-7 , ' .... ' , : ~ :,, ' KU 34-31~- '~ ~ ~ :~ ':~ '~ '; ' 'i" -'~ .,,~--.. ...... ___ c~._s.o~ ~. /, . ~;'..~.~=,,, ~ ~ ~.~ ~4-~ ~?~:.,. ~ ~ TUo ~O,S~O . . - ~ ~ : "~-,~",,: : ~ ~"~i t .:::~ ~- . ' . ' -- -- -- I ~, ' -~O" ;~=':.,~,~';:'~ , .: i~ ~.~ ~ z'.';; -:" ~ KU 43-12 . - _ I ~~'-" ................. " ~ . '~'~. /~ ; ARCO : ~ . ~ ...................... ~ ........... ~ ....... . ~.~'~ ........._~e.- .~ · ~,,~ , ' ~~ . ~,.. ,~..._ . . ~ : ........... ~~ ~ , - ..... , , . ~ · ~ ~ -- ~~ --- ~~-~ ~ ~ ~ .... ~ ':~ ' i'~ · , , .... , ......... ~ ~,.-'- ~ ....~-~ .... ," ~ -- ;133-t [ ' -- '~ ~,; L~i~ -~ - ?' ....... ~'--tF:~ ....................... :'- .................... M~RATHON OIL COmPaNY : SERVICE ~ KU 3~-i I ~ KENAI GA8 FIELD ............................ ~ ~ .............................................................. ~, . t COOK INLET-~ ... ~ ' t ~ .... ] L ................................................ n-~ ...... F t ,.,:'41-19 ...' KU44~-18 Du~,~:at,u Production Marathon OilCompan¥ RO, Bo)< 190168 ,~nchorage, AK 995 lg-0168 Telephone 9071§61-5311 FAX COVER LE'ITER PLEASE DELIVER TI-Iii FOLLOWING DOCUMENTS TO: Department/Location _. _ Facsimile Number ~ ?& - 75'-//~ N'umher of pages (including this cover page) ' i ,11 i1 '1 in FROM: .... ii I' , I , " _. Facsimile Number ,i NOTE: 8 o RECEIVED A su~Idiary ol USX Comoration APR 1 7 1.995 Alaska 0il & Gas Cons. Com~'ts$~°t~ Anchorage Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 April 12, 1995 Mr. David W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: Re: Kenai Gas Field Well 43-6XRD Enclosed is an application for a permit to redrill Well 43-6X in the Kenai Gas Field. Also enclosed is an application for Sundry Approval of the abandonment required prior to sidetracking the well. If further information is required, please contact me at 564-6450. Sincerely, Mark F. Sinclair Drilling Superintendent MFS:kgh Enclosures H:\WP\Oper95\0412.3 RECEIVED APR 13 1995 Uti & Gas Cons. Commission ~ ~chora~,~ A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1 Type of Request: Abandon __ Suspend __ Operation shut~own __ Re-enter susoended well __ Alter casing __Repatr wel~ ~ Plugging .2[._ Time extension ~ Stimulate __ Change approved orogram __ Pull tubing m Vanance __ Per'orate __ Other 2. Name of Operator j 5. Type of Well: Marathon 0i1 Compan,y ' DevelopmentX ' l Exploratory __ 3. Address Stratigraph~c __ P.O. Box 196168 Anchorage, AK 99519-616 Serv, ce__ 4. Location of well at surface """ '-"- '"-- -"- - - --" ---'- - --;/~.~'~-FIL,q-J-bU'I-WL,Sec./,T4N,RllW,S.M. At top of product,ve interval ~l~ 2736'FSL,3772'FWL,Sec.6,T4N,R11W,S.M., 08 At effective depth At total dePth 2956'FSL,3818'FWL,Sec.6,T4N,R11~,S.M. @9610'TVD 6. Datum elevation (DF or KB) KB 100 feet Z Unit or Property name Kenai T,yonek Unit 8. Well number KTU 43-6X 9. Permit number 79-3O 10. APl number 5o- 133-20328 11. Field/Pool Kenai Gas F~eld/Tyonek 12. Present well condition summary Total deptn: measured true verbcal 8370 feet Plugs(measured) 7593, 7718, 8107' 7770 feet Effective depth: rneasured 7593 feet true vertical 7021 feet Casing Length Size Structural 113' 20" Conductor Surface 2508' 13-3/8" Intermediate Production 8370' 9-5/8" Liner Perforation depth: measured 5118' - 5646' true vertical 4706' - 5177' Tub,ng (size, grade, and measured depth) See schematic Packers and SSSV (type and measured depth) See schematic Junk(measured) 7340' Cemented Measured depth True vertical depth Driven 113' 113' 1093 SX 2508' 2427' 1792 SX 8370' 7770' Alaska 0il & Gas Cons. Commission /Imchora :,- 13. Attachments Description summary of proposal ~ Detailed operabons program -X- BOP sketch 14. Estimated date for commencing operation 6-1-95 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classihcation as: Gas X__. Suspended __ Oil ~ Service 17. I hereby certify that the foregoing is true and correct to the best o! my knowledge. FOR COMMISSION USC: ONLY Signed Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10-,.. , v %',,,J'~ J Approval N o. ~..~,,~,. ~ ~__ II' Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATr' ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 23, 1995 Mark F Sinclair Marathon Oil Company P O Box 196168 Anchorage, AK 99519-6168 Re: Kenai Tyonek Unit Well 43-6X Kenai Gas Field Dear Mark: Enclosed are the original permit to drill for the subject well, as submitted to the Commission on March 8, 1994, and Marathon Oil Company check #000730 dated 2/25/94 in the amount of $100.00. ! am returning these to you in response to your request by letter dated February 16, 1995. Yours very truly,' Blair E Sr Petr Engineer /jo encl Marathon Oil Company February 16, 1995 Alaska an Domestic r'roduction P.O. Box 1~1~6.1~ Ancho rage ~,&~lS) 9.,.~168 Telephone Alaska Oi! & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Attention' Blair Wondzell Reference: Kenai Tyonek Unit Well 43-6X Kenai Gas Field Dear Blair: t # Marathon's plans to sidetrack the referenced well have significantly changed. Please cancel the Permit to Drill submitted in March, 1994 by Unocal on behalf of Marathon. Marathon will submit a new Permit to Drill that accurately reflects our current plans. Additionally, please return the check issued last year to Dave Boelens at the letterhead address. Your assistance in this matter is appreciated. Sincerely, M. F. Sinclair Drilling Superintendent /nr~ H:\WP\DRILL95\MFS216 RECEIVED FEB 2 1 1995 Aisska Oil & Gas Cons. Commission Anchora ~' A subsidiary of USX Corporation Environmentally aware for the long run. YELL PERMIT CHECKLIST WELL NAME ~.,~? ~ ~°J~'~ PROGRAM: exp 0 der 0 redrll ,,~ 0 ~o~ ~ ~ ~,. ~11~o o~/o~ sao~ O~ DMINISTRATION ENGINEERING 1. Permit fee attached .................. .[Y 2. Lease number appropriate ............... ~Y 3. Unique well name and number .............. ./Y 4. Well located in a defined pool ............. I.Y 5. Well located proper distance from drlg unit boundary..tY 6. Well located proper distance from other wells ..... .IY ' 7. Sufficient acreage available in drilling unit ..... .{Y 8. If deviated, is wellbore plat included ........ .)Y 9. Operator onlY affected party ....... ....... 10. Operator has appropriate bond in force ......... tY 11.. Permit can beissued without conservation order ...... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... GEOLOGY 14. Conductor string provided ................ Y N) 15. Surface casing protects all known USDWs ......... Y 16. CMT vol adequate to circulate on conductor & surf csg.. Y 17. CMT vol adequate to tie-in long string to surf csg . . -O N 18. CM~ will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... .~ N 20. Adequate tankage or reserve pit ............ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. N 22. Adequate wellbore separation proposed ......... N 23. If diverter required, is it adequate ........... Y N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~d~ psigJY~V N 27. Choke manifold complies w/API RP-53 (May 84) ....... ~---N~J~ 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............. Y ~ / 30. Permit can be issued w/o hydrogen sulfide measures .... Y ~ 31. Data presented on potential overpressure zones. .... Y/N 32. Seismic analysis 9f shallow gas zones .......... ~ N 33. Seabed condition survey (if off-shore) ........ /J Y N 34. Contact name/phone for weekly progress reports . ./ . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: ~ ,~'J~2 q l ~ o wJ C~mments/Ins~ructions: IOW/lo - A:~FORMS~cheklist rev 03/94 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. COMPANY NAME : MARATHON OIL COMPANY WELL NAME : 43-6XED FIELD NAME : KENAI GAS FIELD BOROUGH : KENAI STATE : ALASKA API NUMBER : 50-133-20328-01 REFERENCE NO : 95305 Date _ LIS Tape Verification List|ng Schlumberger Alaska Computing Center 6-SEP-~995 ~2:~8 **** REEL HEADER SERVICE NAME : SPEA DATE : 95/08/11 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION # : 1 PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY PaGe: · ,~. TAPE HEADER ,~** SERVICE NAME : FSPEA DATE : 95/08/11 ORIGIN : DLIS TAPE NAME : DEFAULT CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY **** FILE HEADER FILE NAME : SPEA .122 SERVICE : PLAYBA VERSION .: 7C0-427 DATE : MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 79 516 4 66 5 66 6 73 0 7 65 IN 8 73 60 9 65 .lIN 11 66 15 12 68 -999. 13 66 14 65 .lIN 15 66 73 16 66 0 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center SET TYPE - CHAN ** 6-SEP-~995 12:08 PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TENS SPEA LBF 99 635 21 0 111 1 1 4 68 00~0000000 SP SPEA MV 99 010 01 0 111 1 1 4 68 0~000~0000 PR SPEA 99 000 00 0 111 1 ~ 4 68 0000000~00 CHR2 SPEA 99 000 00 0 111 1 1 4 68 00000~0~00 DT2 SPEA US/F 99 520 80 0 111 I I 4 68 ~000000000 DT4P SPEA US/F 99 520 8~ 0 111 I I 4 68 0000000000 HTEN SPEA LBF 99 000 ~0 0 111 I I 4 68 0000000000 SPR2 SPEA 99 e00 00 0 111 1 101 404 68 Oeoooooe00 GR SPEA GAPI 99 000 00 0 111 1 1 4 68 oeoe000000 AIBD SPEA IN 99 0e0 ~0 e 111 2 1 8 68 eooeoooooe AT20 SPEA OHMM 99 ~00 ~ 0 111 2 I 8 68 ~0~000000 AT3e SPEA OHMM 99 ~00 ~0 0 111 2 I 8 68 0000~00000 AT60 SPEA OHMM 99 000 ~0 0 111 2 1 8 68 00000~ee0 AT90 SPEA OHMM 99 0~0 0~ 0 111 2 I 8 68 ~000000~00 ATD1 SPEA IN 99 e00 Oe 0 111 2 1 8 68 0000e00000 ATD2 SPEA IN 99 000 ~0 0 111 2 I 8 68 000~00000~ ATRT SPEA OHMM 99 000 00 0 111 2 1 8 68 00e0000000 ATRX SPEA OHMM 99 0~0 00 0 111 2 I 8 68 ~000~0000~ ATVM SPEA G/FT 99 0~0 ~0 ~ 111 2 I 8 68 ~00000~00 ** DATA DEPTH = 9552.e00 FEET ** TENS.SPEA 2555.e00 SP.SPEA 0.0~0 PR.SPEA 0.406 CHR2.SPEA DT2.SPEA 225.588 DT4P.SPEA 89.773 HTEN.SPEA -339.258 SPR2.SPEA GR.SPEA 22.910 AIBD.SPEA -999.25e AT20.SPEA -999.250 AT$O.SPEA AT60.SPEA -999.250 AT90.SPEA -999.250 ATD1.SPEA -999.250 ATD2.SPEA ATRT.SPEA -999.25~ ATRX.SPEA -999.250 ATVM.SPEA -999.250 ** DEPTH = 9500.0e0 FEET ** TENS.SPEA 5110.e0~ SP.SPEA -11.688 PR.SPEA e.4e6 CHR2.SPEA DT2.SPEA 225.588 DT4P.SPEA 89.773 HTEN.SPEA 973.31e SPR2.SPEA QR.SPEA 22.91e AIBD.SPEA 8.5~0 AT2e.SPEA 4.411 AT30.SPEA AT60.SPEA 7.879 AT90.SPEA 7.885 ATD1.SPEA 8.500 ATD2.SPEA ATRT.SPEA 7.969 ATRX.SPEA 39.932 ATVM.SPEA o.eoe ** DEPTH = 9242.500 FEET ** TENS.SPEA 5040.0e0 SP.SPEA 7.250 PR.SPEA 0.388 CHR2.SPEA DT2.SPEA 188.907 DT4P.SPEA 82.967 HTEN.SPEA 984.482 SPR2.SPEA GR.SPEA 67.759 AIBD.SPEA 8.5e0 AT20.SPEA 4.033 AT30.SPEA AT60.SPEA 4.813 ATge.SPEA 5.911 ATD1.SPEA 8.500 A'rD2.SPEA ATRT.SPEA 5.859 ATRX.SPEA 10.129 ATVM.SPEA 0.000 0.412 22.729 -999.250 -999.25e 0.412 22.729 6.745 8.500 0.312 18.294 4.471 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-SEP-1995 12:08 PAGE: ** END OF DATA **** FILE TRAILER **** FILE NAME : SPEA .122 SERVICE : PLAYBA VERSION : 7Ce-427 DATE : 95/08/11 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : **** FILE HEADER FILE NAME : SPEA .126 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/08/11 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 520 4 66 5 66 1 6 73 0 7 65 IN B 73 60 9 65 .lIN 11 66 15 12 68 -999. 13 66 14 65 .lIN 15 66 73 16 66 0 66 LIS Tape Veri~icaf,|on Lis~,ing Schlumberger Alaska Compuf, ing Cen~er SET TYPE - CHAN ** 6-SEP-1995 12:08 PAGE: NAME SERV UNIT SERVICE API AP1 API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TENS SPEA LBF 99 635 21 0 107 1 1 4 68 0000~0~000 SP SPEA MV 99 010 01 0 107 1 1 4 68 00~00e~000 PR SPEA 99 000 00 0 107 1 1 4 68 000~00000 CHR1SPEA 99 00~ ~0 0 107 1 1 4 68 00000000~0 DT1 SPEA US/F 99 520 80 0 107 1 I 4 68 00~000090~ DT2 SPEA US/F 99 520 80 0 107 1 1 4 68 000~00~0~0 DT4P SPEA US/F 99 520 80 0 107 1 1 4 68 00eoOOooeg HTEN SPEA LBF 99 0~0 ge 0 lg7 1 1 4 68 00~00000~0 SPR1SPEA 99 ~00 0~ 0 107 1 101 494 68 00~000~0eg GR SPEA GAPI 99 00g gg g lg7 1 1 4 68 ggggggOggg AIBD SPEA IN 99 ggg gg g lg7 2 I 8 68 gggggggggg AT2g SPEA OHMM 99 ggg gg g lg7 2 1 8 68 gggggggggO AT3g SPEA OHMM 99 ggg gg g lg7 2 1 8 68 gggggggggO AT6g SPEA OHMM 99 ggg gg ~ 107 2 1 8 68 gggggOgggO ATgg SPEA OHMM 99 ggg gg 0 1~7 2 1 8 68 gggggggggO ATD1 SPEA IN gg ggg gg g 1~7 2 1 8 68 gOgggggOgg ATD2 SPEA IN 99 ggg ge ~ lg7 2 1 8 68 gggogogggo ATRT SPEA OHMM 99 gOg Og g 107 2 I 8 68 Oggggggg~O ATRX SPEA OHMM 99 ggg 00 0 lg7 2 1 8 68 gOggggOggO ATVM SPEA G/FT 99 00g gg 0 lg7 2 1 8 68 gOgggggggO ** DATA DEPTH : 9552.5gg FEET TENS.SPEA 3465.ggg SP.SPEA g.g~O PR.SPEA g.273 CHR1.SPEA DT1.SPEA 158.493 DT2.SPEA -999.25g DT4P.SPEA 88.517 HTEN.SPEA SPR1.SPEA 28.564 GR.SPEA 63.gg4 AIBD.SPEA -999.250 AT2g.SPEA AT30.SPEA -999.25g AT6g.SPEA -999.250 AT9g.SPEA -999.25g ATD1.SPEA ATD2.SPEA -999.25g ATRT.SPEA -999.25g ATRX.SPEA -999.25g ATVM.SPEA ** DEPTH = 95~g.gOg FEET ** TENS.SPEA 5105.0gg SP.SPEA -lg.563 PR.SPEA g.273 CHR1.SPEA DT1.SPEA 158.493 DT2.SPEA -999.25g DT4P.SPEA 88.517 HTEN.SPEA SPRI.SPEA 28.564 GR.SPEA 63.~4 AIBD.SPEA 7.996 AT20.SPEA AT3g. SPEA 6.053 AT60.SPEA 6.754 AT9g.SPEA 6.783 ATD1.SPEA ATD2.SPEA 9.297 ATRT.SPEA 6.848 ATRX.SPEA ~g.275 ATVM.SPEA ** DEPTH = 900g.ggg FEET TENS.SPEA 4815.eeg SP.SPEA 9.563 PR.SPEA g.332 CHR1.SPEA DTI.SPEA 181.721 DT2.SPEA -999.250 DT4P.SPEA 91.187 HTEN.SPEA SPR1.SPEA 39.913 GR.SPEA 74.987 AIBD.SPEA le.951 AT20.SPEA AT3e. SPEA 5.832 AT6g.SPEA 6.297 AT90.SPEA 6.565 ATD1.SPEA ATD2.SPEA 10.e45 ATRT.SPEA 6.524 ATRX.SPEA 195g.egg ATVM.SPEA 0.866 -393.453 -999.25g -999.25g -999.25g ~.866 964.196 4.581 9.297 0.0gg g.972 979.717 5.093 lg.045 LIS Tape Ver|fica~;|on L|s~;ing Schlumberger Alaska CompuS~ng Cent;er 6-SEP-1995 12:~8 PAGE: ** DEPTH = 8500.~00 FEET TENS.SPEA 4615.0e0 SP.SPEA DTI.SPEA 280.981 DT2.SPEA SPR1.SPEA 22.042 GR.SPEA AT30.SPEA 28.976 AT60.SPEA ATD2.SPEA 10.669 ATRT.SPEA DEPTH = 8000.000 FEET TENS.SPEA 4320.000 SP.SPEA DT1.SPEA 210.229 DT2.SPEA SPRI.SPEA 26.446 GR.SPEA AT3e.SPEA 10.783 AT6e.SPEA ATD2.SPEA 12.243 ATRT.SPEA DEPTH = 7500.e00 FEET TENS.SPEA 4090.000 SP.SPEA DTI.SPEA 238.888 DT2.SPEA SPR1.SPEA 27.e60 GR.SPEA AT30.SPEA 4.746 AT60.SPEA ATD2.SPEA 18.364 ATRT.SPEA DEPTH = 7312.5e0 FEET TENS.SPEA 4000.0e0 SP.SPEA DTI.SPEA 177.226 DT2.SPEA SPR1.SPEA 25.787 GR.SPEA AT30.SPEA 5.582 AT60.SPEA ATD2.SPEA 8.369 ATRT.SPEA 7.500 PR.SPEA -999.250 DT4P.SPEA 37.580 AIBD.SPEA 24.855 AT90.SPEA 24.366 ATRX.SPEA 0,445 88.765 !8.637 25.391 23.212 16.875 PR.SPEA 0.383 -999.250 DT4P.SPEA 91.700 39.814 AIBD.SPEA 10.758 17.016 AT9~.SPEA 15.208 14.531 ATRX.SPEA 1950.000 56.125 PR.SPEA -999.250 DT4P.SPEA 81.922 AIBD.SPEA 6.670 AT90.SPEA 6.720 ATRX.SPEA 123.625 PR.SPEA -999.250 DT4P.SPEA 53.507 AIBD.SPEA 1950.000 AT90.SPEA 2.302 ATRX.SPEA 0.380 105.142 i5.101 6.990 6.446 0.442 57.221 8.369 2.302 2.039 CHR1.SPEA HTEN.SPEA AT20.SPEA ATD1.SPEA ATVM.SPEA CHRI.SPEA HTEN.SPEA AT20.SPEA ATD1.SPEA ATVM.SPEA CHR1.SPEA HTEN.SPEA AT20.SPEA ATDI.SPEA ATVM.SPEA CHR1.SPEA HTEN.SPEA AT20.SPEA ATD1.SPEA ATVM.SPEA 0.595 978.811 14.650 10.669 0.000 0.870 994.307 8.544 12.243 0.0~0 0.721 1000.890 3.684 18.364 0.000 0.982 1005.588 2.e77 8.369 0.0~0 ** END OF DATA ** **** FILE TRAILER FILE NAME : SPEA .126 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/08/11 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE HEADER **** FILE NAME : LDTD SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/08/08 MAX REC SIZE : 8[92 FILE TYPE : DL LAST FILE : 6-SEP-[995 12:08 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 2 3 4 5 6 .7 8 9 [2 0 66 0 66 0 79 72 66 66 73 0 65 IN 73 60 65 .liN 66 113 68 -999. 66 65 .lIN 66 73 66 1 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BS LDTD IN 45 282 01 0 75 1 1 4 68 0000000000 TENS LDTD LBF 45 635 21 0 75 1 1 4 68 9000090000 CGR LDTD GAPI 45 319 91 9 75 1 1 4 68 9e99e99e99 POTA LDTD 45 719 59 9 75 [ 1 4 68 9999999999 SGR LDTD GAPI 45 $19 91 9 75 [ 1 4 68 9999999999 THOR LDTD PPM 45 799 59 9 75 1 1 4 68 9999999099 URAN LDTD PPM 45 792 59 9 75 1 1 4 68 9999999e99 CDF LDTD LBF 45 999 99 9 75 1 1 4 68 9999999999 DRHO LDTD G/C3 45 356 91 9 75 ! I 4 68 9999e99999 RHOB LDTD G/C3 45 359 92 9 75 I 1 4 68 9999999999 CALl LDTD IN 45 289 91 9 75 [ 1 4 68 9999999999 KCMR LDTD MD 45 999 99 9 75 [ 1 4 68 9999999999 T2LM LDTD MS 45 999 99 9 75 ! 1 4 68 9999999999 PHIX LDTD PU 45 899 31 9 75 1 1 4 68 9999999999 LIS Tape Verii'icai;ion Listing Schlumberger Alaska Compu~,|ng Cent, er 6-SEP-1995 12:08 PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DPHI LDTD PU 45 890 01 0 75 I I 4 68 ~000000000 NPHI LDTD PU 45 ~ 00 0 75 1 I 4 68 0242000000 CMRP LDTD PU 45 000 00 0 75 I I 4 68 000~000000 CMFF LDTD PU 45 0e0 00 0 75 I I 4 68 0000000000 DATA ** DEPTH = 9545.090 FEET ** BS.LDTD 8.599 TENS.LDTD 4255.999 CGR.LDTD 173.218 POTA.LDTD SGR,LDTD 83,955 THOR,LDTD 9,892 URAN,LDTD -19.489 CDF,LDTD DRHO,LDTD 9.953 RHOB,LDTD 2,519 CALI,LDTD 3,148 KCMR,LDTD T2LM,LDTD -999.259 PHIX.LDTD 17,959 DPHI,LDTD 7,933 NPHI,LDTD CMRP.LDTD 12.266 CMFF.LDTD 12.254 DEPTH = 9599.999 FEET BS.LDTD 8.599 TENS.LDTD 5925.999 CGR.LDTD 82.979 POTA.LDTD SGR.LDTD 95.459 THOR.LDTD 4.714 URAN.LDTD .~.449 CDF.LDTD DRHO.LDTD -9.992 RHOB.LDTD 2.439 CALI.LDTD 8.726 KCMR.LDTD T2LM.LDTD -999.259 PHIX.LDTD 16.722 DPHI.LDTD 13.359 NPHI.LDTD CMRP.LDTD 12.266 CMFF.LDTD 12.254 DEPTH = 8993.999 FEET BS.LDTD 8.599 TENS.LDTD 5955.999 CGR.LDTD 91.235 POTA.LDTD SGR,LDTD 92,593 THOR.LDTD 6.751 URAN,LDTD 9.158 CDF,LDTD DRHO,LDTD 9,918 RHOB,LDTD 2.438 CALI.LDTD 19.476 KCMR,LDTD T2LM,LDTD -999.259 PHIX,LDTD 19,567 DPHI,LDTD 12,876 NPHI,LDTD CMRP.LDTD 68.914 CMFF.LDTD 68.092 END OF DATA 9.971 84.116 -999.259 29.157 9.934 1186.584 -999.259 21.497 9.934 1337.788 -999.259 27.795 **** FILE TRAILER **** FILE NAME : LDTD .991 SERVICE : PLAYBA VERSION : 7C9-427 DATE : 95/e8/98 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE HEADER **** FILE NAME : LDTD .095 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/e8/08 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : 6-SEP-1995 12:08 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 72 4 66 5 66 1 6 73 0 7 65 IN 8 73 60 9 65 .liN 11 66 113 12 68 -999. 13 66 14 65 .lin 15 66 73 16 66 1 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SiZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BS LDTD IN 45 282 01 0 79 1 1 4 68 0000000ee0 TENS LDTD LBF 4,5 635 21 0 79 1 1 4 68 000000~000 CGR LDTD GAPI 45 310 el ~ 79 1 1 4 68 0000~0~0 POTA LDTD 45 719 5~ 0 79 1 1 4 68 000~00~00 SGR LDTD GAPI 45 310 ~1 0 79 1 I 4 68 00000000~0 THOR LDTD PPM 45 790 50 0 79 1 1 4 68 0000000000 URAN LDTD PPM 45 792 5e 0 79 1 1 4 68 000000e0~0 CDF LDTD LBF 45 000 00 0 79 1 1 4 68 0000e0~000 DRHO LDTD G/C3 45 356 el 0 79 1 1 4 68 0000000000 RHOB LDTD G/C3 45 350 02 0 79 1 1 4 68 0000000000 CALl LDTD IN 45 280 el 0 79 1 1 4 68 0000000000 KCMR LDTD MD 45 000 00 0 79 1 1 4 68 0000000000 T2LM LDTD MS 45 000 ~0 0 79 1 1 4 68 000000000e PHIX LDTD PU 45 890 31 e 79 1 1 4 68 00e0000000 LIS Tape Verification Li$t~ing Schlumberger Alaska Computing Cent~er 6-SEP-~995 ~2:08 PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOQ TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DPHI LDTD PU 45 890 01 0 79 I I 4 68 0~00000000 NPHI LDTD PU 45 000 00 0 79 1 1 4 68 0242000000 CMRP LDTD PU 45 000 00 0 79 I 1 4 68 ~000000000 CMFF LDTD PU 45 ~0~ 00 0 79 1 1 4 68 0000000000 DATA DEPTH = 9552.000 FEET BS.LDTD 8.500 TENS.LDTD 308e.000 CGR.LDTD 94.245 POTA.LDTD SGR,LDTD 92.285 THOR,LDTD 15,014 URAN.LDTD -0,228 CDF,LDTD DRHO,LDTD 0,248 RHOB,LDTD 2.737 CALI,LDTD 3.217 KCMR.LDTD T2LM,LDTD 14,923 PHIX,LDTD 9.924 DPHI.LDTD -5,255 NPHI.LDTD CMRP,LDTD 1,534 CMFF,LDTD 0,263 ** DEPTH = 950~.000 FEET ** BS.LDTD 8.500 TENS.LDTD 5915.000 CGR.LDTD 69.673 POTA.LDTD SGR.LDTD 86.975 THOR.LDTD 3.395 URAN.LDTD 2.011 CDF.LDTD DRHO.LDTD 0.e04 RHOB.LDTD 2.443 CALI.LDTD 8.739 KCMR.LDTD T2LM.LDTD 12.365 PHIX.LDTD 16.163 DPHI.LDTD 12.533 NPHI.LDTD CMRP.LDTD 7.655 CMFF.LDTD 1.373 DEPTH = 9000.000 FEET BS.LDTD 8.50e TENS.LDTD 5710.e00 CGR.LDTD 82.610 POTA.LDTD SGR.LDTD 88.128 THOR.LDTD 6.037 URAN.LDTD e.641 CDF.LDTD DRHO.LDTD 0.~17 RHOB.LDTD 2.433 CALI.LDTD le.831 KCMR.LDTD T2LM,LDTD 11,982 PHIX,LDTD 20,082 DPHI,LDTD 13,127 NPHI,LDTD CMRP,LDTD 11,661 CMFF,LDTD 1,299 ** DEPTH = 850~.~00 FEET ** BS.LDTD 8.500 TENS.LDTD 5555.000 CGR.LDTD 58.294 POTA.LDTD SGR.LDTD 49.894 THOR.LDTD 2.06e URAN.LDTD -0.976 CDF.LDTD DRHO.LDTD -e.e64 RHOB.LDTD 1.516 CALI.LDTD 19.404 KCMR.LDTD T2LM.LDTD 10.951 PHIX.LDTD 63.303 DPHI.LDTD 68.730 NPHI.LDTD CMRP.LDTD 14.820 CMFF.LDTD 1.761 DEPTH = 800~.e00 FEET BS.LDTD 8.500 TENS.LDTD 4985.000 CGR.LDTD 75.514 POTA.LDTD SGR.LDTD 78.116 THOR.LDTD 4.644 URAN.LDTD ~.302 CDF.LDTD DRHO.LDTD 0.007 RHOB.LDTD 2.119 CALI.LDTD 12.184 KCMR.LDTD T2LM.LDTD 9.609 PHIX.LDTD 33.482 DPHI.LDTD 32.199 NPHI.LDTD CMRP.LDTD 18.332 CMFF.LDTD 2.699 ** DEPTH = 750e.000 FEET ** 0.015 135.496 0.000 25.576 0.03e 1359.808 0.021 21.137 0.031 1262.920 0.106 28.480 0.027 1348.064 0.231 54.731 0.030 1475.780 0.417 35.718 LIS Tape Verification L|sting Schlumberger Alaska Comput|n9 Center 6-SEP-~99~ ~2:08 BS.LDTD 8.50e TENS.LDTD 4895.000 CGR.LDTD SGR.LDTD 97.373 THOR.LDTD 6.583 URAN.LDTD DRHO.LDTD 0.030 RHOB.LDTD 2.249 CALI.LDTD T2LM.LDTD -999.250 PHIX.LDTD 34.550 DPHI.LDTD CMRP,LDTD -99925.~00 CMFF.LDTD -99925.000 ** DEPTH = 7441.000 FEET ** BS.LDTD 8.500 TENS.LDTD 4680.00e CGR.LDTD SGR.LDTD 89.977 THOR.LDTD 4.851 URAN.LDTD DRHO.LDTD -0.688 RHOB.LDTD 1.818 CALI.LDTD T2LM.LDTD -999.250 PHIX.LDTD 45.743 DPHI.LDTD CMRP.LDTD -99925.eoe CMFF.LDTD -99925.00~ 95.645 0.201 14.e66 24.310 86.642 0.388 9.044 50.423 POTA. LDTD CDF. LDTD KCMR. LDTI) NPHI. LDTD POTA.LDTD CDF.LDTD KCMR.LDTD NPHI.LDTD PAGE: 0.037 1784.060 -999.250 45.261 0.036 1284.940 -999.250 36.913 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : LDTD .095 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/o8/e8 MAX REC SIZE .: 8192 FILE TYPE : DL LAST FILE : **** TAPE TRAILER SERVICE NAME : FLDTD DATE : 9S/eS/e8 ORIGIN : DLIS TAPE NAME : DEFAULT CONTINUATION # : ! PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY **** REEL TRAILER **** SERVICE NAME : LDTD DATE : 95/es/e8 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION ~ : 1 PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY
