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Image r-roject Well History File Cover I[' :lC XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. i ~' ~- C) .L ~ Well History~[eJdentifier RESCAN DIGITAL DATA Color items: Grayscale items: Poor Quality Originals: [] Other: [] Diskettes, No. [] Other, No/Type NOTES: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BY: BEVERLY ROBIN VINCENT ~ARIA WINDY Project Proofing Scanning Preparation ,~ x 30 = ~) ~ = TOTAL PAGES BY: BEVERL'~~VINCENT SHERYL MARIA WINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~ ' BY: . ROBIN VINCENT SHERYL MARIA WINDY DATE: Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~' YES BY: BEVERLY ROBIN VINCEN~MARIA WINDY (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL A~ENTION IS REQUIRED ON ~ INDIVIDUAL PAGE ~SIS DUE TO QUALI~, G~YSCALE OR COLOR IMAGES) NO .NO DATE: ~/~ / /SI -~,,~ °/¢3 IIIIIIIIIIIIIIIIIII ReScanned (individual page RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /S/ Quality Checked (do.e) 12/10/02Rev3NOTScanned.wpd 1l/llara#hOn MARATHON ®II COI'11al1~/ May 15, 2008 Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Mr. Tom Maunder ~ ~~-~ ~ ~j Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 ~~~~N~~ MAY ~ ~ 2008 Reference: 10-404 Sundry Submittal List Dear Mr. Maunder: Marathon and the AOGCC have had discussions on the follow-up reporting needed to close out 10-403 Sundry approved well work activities. Work has been ongoing to identify the suspect well activities and complete the appropriate reporting. Submitted for your records is a list of the completed reports along with the indicated 10-404 Sundries. am continuing to work on the remaining sundry reports and plan to submit them upon their completion. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, Enclosures: 10-404 Sundry Submittal List cc: Houston Well File Accompanying 10-404 Sundries Kenai Well File KJS M Marathon MARATHON Oil Company January 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Kenai Gas Field Well: KU 24-7 ~s~~~p MAY ~ ~ 2008 Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~Q ~,~ b 4 ~v '~~ ;!i':~ i~!! F1 '~ "a, ,~ AIaS~a ~i°{i & ~~S ~C3rla. vt~iTlfniaSit~?` Ancirarage Attached for your records is the 10-404 sundry report for well KU 24-7. This sundry covers the work over that Marathon completed under sundry #305-034. We pulled the dual 3-1/2" tubing strings and the Baker Model A-5 Dual Packer. Completed the well with a single string of 4-1/2" tubing and an injection packer. Please contact us at (907) 283 -1371 if you have any questions or need additional information. C~~~ r~ '~~ Sincerely, --- Way a E. Cissell d Well Work Over Supervisor ~~~~` `~ ~'`~ ° ~csccs\~~c~s~~Cj ~~~- ~`~~~ ~~c I~p ~ S ~ ~ '~ , Enclosures: 10-404 Sundry Report cc: Houston Well File Operation Summary Kenai Well File ~cy~n /1 KJ S ~ " KDW ~~~,°O~S e If'-O/¿O. Alaska Business Unit Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 December 27, 2005 Mr. Steve Davies Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 5G~h~ED F i '? ¿ \,; Reference: KU 24-7RD Surface Location Dear Mr. Davies: Marathon well KU 24-7RD was recently sidetracked. Upon completing the sundry forms, some surface location inconsistencies were brought to my attention. Our historical well files give the following slot location for KU 24-7: 728'FNL, 748'FEL, See 18, T4N, R11W, S.M. which appears on several old sundries and other forms. With new advances in technology and some correction to the original datum, the actual surface location is as follows: 607' FNL, 796' FEL, Sec. 18, T4N, R11W, S.M.vThis is the surface location that was printed in the permit to drill and should be considered the official updated surface location for abandoned well KU 24-7 as well as for the sidetracked KU 24-7RD. The physical location of the tree remains unchanged for the historic wellbore and for the sidetrack. If you need any additional information or have questions please contact our Drilling Engineer, Will Tank by phone at 713-296-3273 or bye-mail atwjtank@marathonoil.com. Sif'Y~ Denise M. Titus Production Engineer ) ) Alaska Business Unit Domestic Production ~ ' M MARATHON Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 September 8, 2005 (6~-vt(P S£ p §1¡ ILl /9 2005 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 Reference: KU 24-7 Abandonment Sundry Sundry Number: 305-155 Dear Mr. Aubert: Enclosed is the 10-407 Well Completion or Recompletion Report and Log to abandon the existing perfs in KU 24-7. This drill cuttings disposal well, was taken out of service due to observed lack of ~. pressure integrity in the annulus. A workover was approved to fish the existing completion and recomplete with new equipment. During the workover, we encountered casing damage severe ~ enough to require a sidetrack. Prior to drilling a replacement wellbore, the existing perfs were ~ abandoned. The attached Operation Summary Report details the attempted workover and the CIBP placement at 4360'. The plug was then pressure tested with a State witness present and topped with 75sx of / displaced abandonment cement. 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, .Iii jV/~ A I&: P)lltr Denise M. Titus Production Engineer . . ..' 'co -'~ (.)! 'lOD·~i SC#\N~E~, S L ¡ J. i- Enclosures: 10-407 Sundry Operations Summary Report Well Schematic 1 a. Well Status: STATE OF ALASKA \ ALASKA t AND GAS CONSERVATION COMMIS5'1i,'~{"'"~''ff''''' WELL COMPLETION OR RECOMPLETION REPdAlt:'Ll\ND I;QG Oil U Gas D Plugged U Abandoned 0 Suspended U WAG D 1 tfi'f!rj Cla~"s: ,'. ..,"'" 20AAC 25,105 20AAC 25,11 0 Develop~tn~;~ 121') I.)h Exploratory D No. of Completions Other 1:,RP¡~iC¡;~t~., _(. Strati~raPhic TestD 5. Date Comp., Susp., or / 12. ~~:~~Lt",~t)f,11I Numbe~~"ie" Aband.: 23-Jun-05 '1ä2~(i,rtf~f(ft;f~ f' ,\:'¡i"t' 6. Date Spudded: 13. API Number: May 12, 1982 50-133-20352-00-00 7. Date TD Reached: 14. Well Name and Number: May 22,1982 KU 24-7 8. KB Elevation (ft): 15. Field/Pool(s): 67.7' GL-MSL Kenai Gas Field 9. Plug Back Depth(MD+ TVD): Pool 3, Pool 4, Pool 5.1 4360' 10. Total Depth (MD + TVD): Zone- 4 5820' Zone- 4 11. Depth Where SSSV Set: Zone- 4 N/A 19. Water Depth, if Offshore: N/A feet MSL 16. Property Designation: A-028142 17. Land Use Permit: N/A 20. Thickness of Permafrost: N/A GINJD WINJD WDSPL0 2. Operator Name: Marathon Oil Company 3. Address: PO Box 196168 Anchorage, AK 99516-6168 4a. Location of Well (Governmental Section): Surface: 728' FNL, 748' FEL, Sec 18, T4N, R11W, S.M. Top of Productive Horizon: 11' FSL, 2552' FWL, Sec 7, T4N, R11W, S.M. Total Depth: 397' FSL, 1718' FWL, Sec 7, T4N, R11W, S.M. 4b. Location of Well (State Base Plane Coordinates): Surface: x- 275057 y- 2356013 TPI: x- y- Total Depth: x- 272265 y- 2357190 18. Directional Survey: Yes 0 No D 21. Logs Run: Temp 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 94 H-40 0 179' 0 179 Driven N/A 13-3/8 61 K-55 0 2003' 0 1849 17-1 /2 1225 sx N/A 9-5/8 43.5 & 47 N-80 0 5801' 0 4781 12-1/4 1900sx N/A 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 24. SIZE TUBING RECORD DEPTH SET (MD) PACKER SET (MD) MD 4890'-4925' 4410'-4490' 5425'-4560' TVD 4090'-4116' 3727'-3888' 3814'-3840' HPF 8 8 8 8-4 A-10 A-11 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 4250'-4360' Class G 15.8ppg, 75sx, 8bbl circulated cap 26. Date First Production: Abandoned Date of Test: Hours Tested: N/A 0 Flow Tubing Casing Press: Press. 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: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): 27. 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". None Aba Hdt:fH. ;y¡e.Jd- RBDMS BFL SEP 1 9 2n05 I:i0 · ::2J~:~:'i'i; ~ 1- ¡. "~,t'¿ < ; _? ~?cs =-C§ , V£f:';"~,\ - ~~---; .~z.._....,.._~--.:- . Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ORIGINAL NAME GEOLOGIC MARKERS ML ') TVD 29. 10RMATION TESTS ' Include and briefly sum.. .,dze test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 28. N/A 30. List of Attachments: Operations report including preparation and abandonment. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Denise M. Titus Printed Name: Deni~ M. Titus Signature: ¡@tw:/:iJ'itr- Title: Production Engineer Phone: 907-283-1333 Date: 9/7/2005 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 Injection, 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 ) ) Marathon Oil Company Page 1 of 7 Operations Summary Report Legal Well Name: KENAI UNIT 24-7 Common Well Name: KENAI UNIT 24-7 Event Name: WORKOVER Contractor Name: GLACIER DRILLLlNG Rig Name: GLACIER DRILLING Date From - To Hours Code Sub Phase Code 4/7/2005 08:30 - 09:00 0.50 SAFETY MTG - WBPREP 09:00 - 09:30 0.50 SAFETY MTG - WBPREP 09:30 - 11 :30 2.00 RURD - SLlK WBPREP 11 :30 - 12:00 0.50 TAG - PKR_ WBPREP 12:00 - 12:30 0.50 RURD - SLlK WBPREP 12:30 - 14:00 1.50 BAIL_ FILL WBPREP 14:00 - 15:30 1.50 RUNPUL VLVE WBPREP 15:30 - 17:00 1.50 TAG - BOTM WBPREP 17:00 - 17:30 0.50 RURD - SLlK WBPREP 17:30 - 18:30 1.00 TAG - BOTM WBPREP 18:30 - 19:30 1.00 RURD SLlK WBPREP 4/8/2005 07:30 - 08:00 0.50 SAFETY MTG - WBPREP 08:00 - 08:30 0.50 SAFETY MTG - WBPREP 08:30 - 10:30 2.00 RURD - SLlK WBPREP 10:30 - 12:15 1.75 BAIL_ FILL WBPREP 12:15 - 13:30 1.25 BAIL_ FILL WBPREP 13:30 - 14:15 0.75 TAG - BOTM WBPREP 14:15 - 14:30 0.25 RURD - SLlK WBPREP 14:30 - 15:15 0.75 TAG - BOTM WBPREP 15:15 -16:30 1.25 RURD SLlK WBPREP 4/30/2005 08:00 - 08:15 0.25 SAFETY MTG - WBPREP 08:15 - 08:30 0.25 SAFETY MTG - WBPREP 08:30 - 10:00 1.50 RURD - SLlK WBPREP 10:00 - 18:00 8.00 RUNPUL SLlK WBPREP 5/4/2005 06:00 - 09:00 3.00 5/5/2005 06:00 - 08:00 2.00 5/6/2005 06:00 - 09:00 3.00 Start: 4/7/2005 Rig Release: Rig Number: 1 Spud Date: 5/12/1982 End: Group: Description of Operations Arrive at gas field. Hold procedure meeting and issue permit. Arrive on 41-18, sign in and inspect area and spot equipment. Hold safety meeting making note of pad activities associated with concurrent cuttings injection. RU equipment to short string. Both strings of tubing on a vacuum. Attempt to RIH, but tag BPV. Call Vetco to remove BPV. Move over to long string. RIH wi 2.5" bailer. Tag long string at 4410'. Work bailer repeated times wtih no sample material at surface. POOH. Move back to allow Vetco to pull SS backpressure valve. RIH for additional tag wlo returns or progress. Run 2.5" LIB. See no impression at surface. RD from long string and move over to short string. Tag short string at 4398'. Bailer contains only water. RD wireline Sign in at gas field. Hold safety meeting and issue permit. Arrive at pad 41-18. Hold safety meeting wi sight supervisor. RU wireline on long string. Run pump bailer x2. Tag at 4424' Get water with little solid material both times. Run DD bailer with pointed mule shoe. Tag at 4424' Break through and fall to 4434'. Encounter large overpull coming out. Recover thick black greasy material mixed with pipe scale. No marks on bailer. PU 1-3/4" LIB. Work through tight area at 4324' to fill level at 4434'. POOH. See slight taper on edge of bailer indicating tight spot or possible split. RD from long string and over to short string. RIH wi 1-3/4" DD bailer with pointed muleshoe. RIH and tag at 4404'. Encounter large overpull out of tubing. Nothing in bailer at surface. May have been sticking against long string. RD slickline unit and depart location. Arrive at office, sign in , review work and obtain work permit. Sign in at pad 41-18, hold safety meeting. Fill out JSA. RU slickline unit to well. RIH wi plug. Unable to set due to debris in nipple. Shear off tool, but plug does not seem set. Pull plug and run wire brush through nipple. RIH wi plug and set. Debate running check-set tool, but decide not to as positive seal is not necessarily required for circulating. Run plug prong. Rig up iron and return tank. Pumped approx. 360 bbls of water down tubing taking returns on back side of well. Water produced to tank is clean. (Time estimated based upon the personnel on locatio hours entered. Unknown when during the day the work was done.) MU hard line to tank from the casing from the tubing to the flow back tank. The casing pressured up to 2100 psig. Shut down and reconnect the hard line to pump down tubing to casing tomorrow. (Time estimated based upon the personnel on locatio hours entered. Unknown when during the day the work was done.) Circulated 100bbl from the tubing to the casing wth no problem. RD hardlines. Printed: 8/24/2005 11 :44:44 AM ) ) Marathon Oil Company Page 2 of 7 Operations Summary Report Legal Well Name: KENAI UNIT 24-7 Common Well Name: KENAI UNIT 24-7 Spud Date: 5/12/1982 Event Name: WORKOVER Start: 4/7/2005 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 5/6/2005 06:00 - 09:00 3.00 (Time estimated based upon the personnel on locatio hours entered. Unknown when during the day the work was done.) 6/9/2005 07:30 - 08:00 0.50 SAFETY MTG - WBPREP Sign in at office, discuss job, issue permit 08:00 - 08:30 0.50 RURD - ELEC WBPREP Talk to T J and spot equipment. Cover cellar with grating and plywood. 08:30 - 09:00 0.50 SAFETY MTG - WBPREP Hold job sight safety meeting, noting other operations and presence of new employees. 09:00 - 10:00 1.00 RURD - ELEC WBPREP Finish equipment RU 10:00 - 10:30 0.50 PULD - PGUN WBPREP PU and arm jet cutter 10:30 -12:15 1.75 CUT_ TBG - WBPREP RIH to 4365'. Correlate depth and fire making jet cut tubing at 4370'. Had some mechanical problems with the unit while RIH and POOH. Problems were addressed. 12:15 - 13:00 0.75 RURD - ELEC WBPREP RD electric line and move off. 13:00 - 22:00 9.00 PREP - LOC_ WBPREP Install felt and liner 18:30 - 19:30 1.00 TEST_ TREE WBPREP Install BPVs 6/10/2005 12:00 - 00:00 12.00 RURD - RIG - MIRU Accept rig from KBU 22-6@ 12:00hrs 6/09/2005. PJSM prior to rig move. Complete crane pics and prep loads for transport. Split pump and pit rooms. Lower sub structure and secure. Transport and spot rig components on pad. Pull pit room and pump room together. RIU electrical and set camp units. Set mechanics office and parts trailer. Stage extra equipment on 41-7 pad. 00:00 - 06:00 6.00 RURD - RIG - MIRU PJSM. Level carrier and anchor down. R/U w/crane: Diesel tank, dog house and choke house. Sub base outriggers, stairs, landings, flowline and panic line, front and back windwalls, gasbuster and connex. Raise derrick. R/U fuel, air, hydraulic and water lines. 6/11/2005 06:00 - 12:00 6.00 RURD - RIG - MIRU PJSM:Scope derrick up, Secure guy lines, RIU Board, ExcapeLine, Snub post, Splash guards, Drillers console, Brake handle, Gas buster U-tube, Choke flow lines, Cylinder socks, Pull dog and Choke houses Electrical lines, Geolograph instrumentation, Spot in BOP, R/U Water to rig and camp, carrier mufflers, Un-load trailers,Get water circ through rig. 12:00 - 00:00 12.00 RURD - RIG_ MIRU PJSM:Spot catwalk, R/U beaver slide, stairs to BOP connex, PIU & MIU and hang torque tube and T-bar, PIU Top drive and hang and install slide and pin, Hook up service lines to top drive, Hook up mud lines, stand pipe, and cement line, R/U manifold choke, Kill, bleeder, and low torque hoses, Put water in pits test run mud pumps, Start mixing 3% KCL , Wire in cooling fans for mud pumps, Install long bails, R/U TI Pump down tubing. weld broken steps on matting boards. Repair windwalls in cellar area. 00:00 - 01 :00 1.00 RURD - EOIP WBPREP PJSM:R/U Circ lines to tree. 01 :00 - 02:30 1.50 PULL_ EOIP WBPREP PJSM: Pull BPV with Vetco gray, R/U safety valves and lines to short and long string of tbg. 02:30 - 05:00 2.50 CIRC - CFLD WBPREP PJSM: Pump 50 bbl. hec pill dn short sting and + 12 bbl. kcl water with full returns. Swith to long string and pump 50 bbl.HEC pill and 15 bbl. kcl and caught fluid, slowed rate from 4 bpm to 2 bpm and psi grew integrity from 15 psi to 90 psi, shut down for 10 min. and caught fluid with 1 bbl. psi to 96 . shut down for 15 min and caught fluid with 1.75 bbl. 05:00 - 06:00 1.00 RURD - EOIP WBPREP PJSM: Rig down circulating lines. 6/12/2005 06:00 - 07:00 1.00 NUND TREE XMBO NID Dual X-mas tree. Cut off 4 studs. 07:00 - 08:00 1.00 NUND TREE XMBO Clean and Inspect hanger threads( 3 1/2" 8rd). Threads OK. Clean TBG head flange. Printed: 8/24/2005 11 :44:44 AM ) Marathon Oil Company Operations Summary Report Legal Well Name: KENAI UNIT 24-7 Common Well Name: KENAI UNIT 24-7 Event Name: WORKOVER Contractor Name: GLACIER DRILLLlNG Rig Name: GLACIER DRILLING Date From - To Hours Code î~Je Phase 6/12/2005 08:00 - 12:00 4.00 NUND BOPE XMBO 1.50 NUND BOPE XMBO 4.00 TEST_ BOPE XMBO 1.00 NUND EQIP XMBO 2.00 RURD - CSG_ CMPPUL 0.50 WORK_ PIPE CMPPUL 4.50 CIRC_ MUD - CMPPUL 1.50 RUNPUL ELEC CMPPUL 12:00 - 13:30 13:30 - 17:30 17:30 - 18:30 18:30 - 20:30 20:30 - 21 :00 21 :00 - 01 :30 01 :30 - 03:00 03:00 - 04:00 1.00 RUNPUL ELEC CMPPUL 04:00 - 05:00 1.00 CUT - TBG - CMPPUL 05:00 - 06:00 1.00 RUNPUL ELEC CMPPUL 6/13/2005 06:00 - 07:00 1.00 CUT - TBG - CMPPUL 07:00 - 08:00 1.00 WORK_ PIPE CMPPUL 08:00 - 09:00 1.00 CIRC_ CFLD CMPPUL 09:00 - 10:30 1.50 LOG CSG - CMPPUL 10:30 - 11 :30 1.00 WAlTON EQIP CMPPUL 11 :30 - 12:30 1.00 CUT - TBG - CMPPUL 12:30 - 05:00 16.50 RUNPUL TBG - CMPPUL 05:00 - 06:00 1.00 RURD - CSG - CMPPUL 6/14/2005 06:00 - 08:30 2.50 RURD - OTHR CMPPUL 08:30 - 10:00 1.50 SLPCUT DLlN CMPPUL 10:00 - 10:30 0.50 TEST_ BOPE CMPPUL 10:30 - 12:00 1.50 TEST_ BOPE CMPPUL 12:00 - 12:30 0.50 TEST_ BOPE CMPPUL 12:30 - 13:00 0.50 RUNPUL WBSH CMPPUL 13:00 - 16:00 3.00 PULD - BHA_ CMPPUL 16:00 - 16:30 0.50 PULD - DP - CMPPUL 16:30 - 20:30 4.00 PULD - DP - CMPPUL 20:30 - 21 :00 0.50 JAR_ FISH CMPPUL Page 3 of 7 Start: 4/7/2005 Rig Release: Rig Number: 1 Spud Date: 5/12/1982 End: Group: Description of Operations PJSM: NIU 11" 5M X 13 5/8" 5M DSA. NIU 13 5/8" 5M spacer spool(H=24"). NIU 135/8" 5M A,Rd,S,R BOP. NIU Choke and kill lines. RlU scaffolding. RIU trip tank. PJSM: RlU turnbuckles on BOP. CIO top rams to 3 1/2" dual rams. CIO bottom rams to 5". Pull BPV's and set TWC's. Test 3 1/2" Dual Rams, 2-3 1/2" safety valves, 1-12 choke manifold valves, choke and kill line valves and blind rams to 250/3000psi 10min. PJSM: Remove pipeing from cellar(was going to interfere with mouseehole) and pull twc's. PJSM: RlU Weatherford Dual string tbg tools, MIU landing jts with Safety valves fill Long string, fluid level @ 1608'. PJSM: Attempt to release pkr no success after several attempts, Goal was to use 80% of tbg tensile plus 40 k for pkr set to release,(135k max pull with no success). Wait on APR. and Rig up and circ HEC pills out of both tbg strings to add value to thinner fluid getting tools down. (Long string integrity built while bullheading hec pill out to 390 psi. 75 gpm). PJSM: RlU APR and rih wi 2.7" jet cutter, Had trouble getting through connections @ 2106',2580',3512;, @ 3542' could not get through pump fluid at 3 bpm with no success. PJSM:Pooh and change out cutters F/2.7" to 2 5/8" jet cutter Rih with 2.59" Jet cutter and get on depth with CCL and Cut (SS) tbg @ 4300' (had no trouble getting down with this cutter). POOH WI spent cutter, and MIU 2.7" cutter for long string. Cont. RIH wi 2.7" TBG cutter on EL. Correlate and cut LS@4282'(good indication of cut). POOH wlAPRS and RID EL. Attempt to work TBG free(appears SS did not cut). Circ. SS B/U(there is communication between SS and LS, 5.8BPM 300psi). RIU APRS. Run 2.7" gauge to 4310' on SS. POOH. Wait on APRS to get safe detonator for 2.7" cutter. PJSM. RIH w/2.7" TBG jet cutter. Cut SS@4302'(good indication). POOH RID APRS. POOH and LID dual 3.5" 9.2PPF Butt TBG comp(check for norm) (Rec 276 jts. )Plus ,2- Sliding sleeves, and 2 - Cut jts. tbg. (1 st Jet cutter run in short string wi 2.59" cutter shot 1/3 side of tbg . both cuts made with 2.7" cutter were very good). PJSM: Rig down tbg tools. CIO bales and elevators. Adjust torque on TD and pump up compensator. CIO upper rams to 2 7/8" X 5 1/2" variables. RlU DP spinners, tongs and misc rotary tools. Slip and cut 480' of line. MIU 5" test joint and set test plug. Test annular, upper variable rams, lower 5" rams, upper and lower TD valves, TIW valve and IBOP valve to 250/3000psi 10min. PJSM. Perform koomey performance test. Set wear bushing. PIU 8 1/8" Overshot BHA. Rack and strap 5" DP. PJSM: TIH with Fta #1 on 5" DP picking up singles from racks to Fish tagged at 4278' Wts. 105 up , 85 dn, 100 rt. PJSM: Dress top of Fish, Set overshot and PIU to 95 k over Printed: 8/24/2005 11 :44:44 AM ) ) Marathon Oil Company Page 4 of 7 Operations Summary Report Legal Well Name: KENAI UNIT 24-7 Common Well Name: KENAI UNIT 24-7 Event Name: WORKOVER Contractor Name: GLACIER DRILLLlNG Rig Name: GLACIER DRILLING Date From - To Hours Code Sub Phase Code 6/14/2005 20:30 - 21 :00 0.50 JAR_ FISH CMPPUL 21 :00 - 22:00 1.00 CIRC_ CFLD CMPPUL 22:00 - 02:30 4.50 TRIP - DP - CMPPUL 02:30 - 03:30 1.00 PULD - BHA_ CMPPUL 03:30 - 05:00 1.50 PULD - PKR_ CMPPUL 05:00 - 05:30 0.50 PULD - BHA_ CMPPUL 05:30 - 06:00 0.50 TRIP - BHA_ CMPPUL 6/15/2005 06:00 - 06:30 0.50 TRIP - BHA_ CMPPUL 06:30 - 08:30 2.00 TRIP - DP - CMPPUL 08:30 - 09:30 1.00 MILL_ FISH CMPPUL 09:30 - 11 :30 2.00 TRIP - DP - CMPPUL 11 :30 - 13:30 2.00 TRIP BHA_ CMPPUL 13:30 - 14:00 0.50 SERVIC RIG - CMPPUL 14:00 - 17:30 3.50 TRIP - BHA_ CMPPUL 17:30 - 21 :00 3.50 TRIP - DP - CMPPUL 21 :00 - 22:00 1.00 WSHOVFTISH CMPPUL 22:00 - 23:00 1.00 CIRC_ CFLD CMPPUL 23:00 - 01 :30 2.50 TRIP - DP - CMPPUL 01 :30 - 03:30 2.00 PULD BHA_ CMPPUL 03:30 - 04:30 1.00 SERVIC RIG - CMPPUL 04:30 - 06:00 1.50 PULD - BHA_ CMPPUL 6/16/2005 06:00 - 07:30 1.50 TRIP - DP - CMPPUL 07:30 - 08:00 0.50 ENGAGE FISH CMPPUL 08:00 - 11 :00 3.00 CIRC - MUD - CMPPUL 11 :00 - 13:00 2.00 RURD - ELEC CMPPUL 13:00 - 14:00 1.00 RUNPUL EQIP CMPPUL 14:00 - 15:30 1.50 RUNPUL EQIP CMPPUL 15:30 - 17:30 2.00 LOG_ FRPT CMPPUL 17:30 - 18:30 1.00 LOG - FRPT CMPPUL 18:30 - 20:00 1.50 LOG_ FRPT CMPPUL 20:00 - 21 :00 1.00 LOG - FRPT CMPPUL 21 :00 - 22:00 1.00 LOG - FRPT CMPPUL 22:00 - 22:30 0.50 LOG - FRPT CMPPUL 22:30 - 01 :00 2.50 LOG_ FRPT CMPPUL 01 :00 - 03:30 2.50 TRIP - DP - CMPPUL 03:30 - 05:00 1.50 TRIP - BHA_ CMPPUL Start: 4/7/2005 Rig Release: Rig Number: 1 Spud Date: 5/12/1982 End: Group: Description of Operations wt of string and Jars went off, set jars again and repeated' fish had travel app 8" up hole, third time jars did not go off fish begin to travel fairly free. CBU 6000 STKS @ 247 gpm, 195 psi. No loss, no gain, few gas bubbles observed on bottoms up. PJSM: POOH to FTA #1 Pull and LID FTA #1 LID Packer and Tbg. (Rec. cut jt tbg, pup sub. Baker model A Pkr. 1- jt tbg below pkr, Cutjt tbg. FI LS, FI SS Recover App 5' of cutjt of tbg, 1-pup jt, Safety sub, Same pkr as above, otis XN nipple assy). Dress 8 1/8" overshot assy. PIU same. RIH w/FTA#2. Cont. RIH w/FTA#2. RIH w/DP. Engage fish @ 4365'(P/U112K S/085K). Dress off TBG. Catch TBG w/overshot and pull 120K over. Fish did not come free. Release overshot. POOH w/DP. POOH w/BHA. PJSM. LID overshot assy. Service rig. PIU 8 1/8" wash shoe and washover assy. RIH wi BHA. RIH w/DP. Tag top of fish @ 4365' , Top drive up and break circ. Wash over and tag tight FI 4380' to 4385' , Unable to make forward progress, (washover, Wt. 2k to 8k, Rpm 65, Flowrate 406 gpm, 500 psi, no loss, gain, high tq 14000 on bottom 9000 off, 120k up, 85k dn, 95 k rt). Circ Hi-Vis sweep and monitor returns ,Flow check well. POOH to Bha #3. PJSM:LlD Bha and wash pipe (Lost 81/8" wash over shoe 2.30'). Service rig. PJSM: MIU Bha #4. Cont RI H 5" DP to fish at 4365 ft. Engage I latch fish (3 1/2 tbg stub), jar twice, no movement Circ, clear floor, wait on recovery wireline unit PJSM, install top drv wireline guide, place wireline unit, R/U same, M/U 2 1/8 gauge ring RIH 2 1/8 gauge ring, can not pass 4409 ft POH gauge ring. stuck at 3600 ft, work free, cont POH constant drag, free at 100 ft, layout gauge ring, no junk top of ring. PJSM, MIU freepoint tool, RIH same, freepoint tbg, can not pass 4409 ft (1st connection blast jt), locate conn depth prepare POH wireline. POH wireline, layout freepoint tool. PJSM, M/U string shot, RIH same Align string shot, work torque to shot depth, fire shot. POH string shot (misfire), MIU new shot. RIH string shot, place shot on depth (4400 ft) work torque, fire shot, slight torque reduction, indicate back off. POH wireline, lay dn spent shot. Rig dn wireline equip. PJSM, POH 5" DP with fish Handle BHA, retrieve partial jt 3112 tbg (15.30 ft) Printed: 8/24/2005 11 :44:44 AM ) ) Marathon Oil Company Page 5 of 7 Operations Summary Report Legal Well Name: KENAI UNIT 24-7 Common Well Name: KENAI UNIT 24-7 Event Name: WORKOVER Contractor Name: GLACIER DRILLLlNG Rig Name: GLACIER DRILLING Date From - To Hours Code Sub Phase Code 6/16/2005 03:30 - 05:00 1.50 TRIP BHA_ CMPPUL 05:00 - 06:00 1.00 WAlTON EQIP CMPPUL 6/17/2005 06:00 - 07:30 1.50 WAlTON EQIP CMPPUL 07:30 - 08:30 1.00 TRIP - BHA_ CMPPUL 08:30 - 10:00 1.50 TRIP - DP - CMPPUL 10:00 - 11 :00 1.00 ENGAGE FISH CMPPUL 11 :00 - 12:00 1.00 CIRC_ CFLD CMPPUL 12:00 - 16:00 4.00 TRIP - DP - CMPPUL 16:00 - 16:30 0.50 TRIP _ BHA_ CMPPUL 16:30 - 17:00 0.50 SERVIC RIG - CMPPUL 17:00 - 18:30 1.50 TRIP - BHA_ CMPPUL 18:30 - 20:30 2.00 TRIP - DP CMPPUL 20:30 - 21 :30 1.00 ENGAGE FISH CMPPUL 21 :30 - 00:00 2.50 TRIP - DP - CMPPUL 00:00 - 00:30 0.50 TRIP - BHA_ CMPPUL 00:30 - 03:00 2.50 WAlTON EQIP CMPPUL 03:00 - 03:30 0.50 TRIP - BHA_ CMPPUL 03:30 - 05:00 1.50 TRIP - DP - CMPPUL 05:00 - 05:30 0.50 ENGAGE FISH CMPPUL 05:30 - 06:00 0.50 TRIP - DP - CMPPUL 6/18/2005 06:00 - 09:00 3.00 TRIP - DP - CMPPUL 09:00 - 09:30 0.50 SERVIC RIG - CMPPUL 09:30 - 11 :30 2.00 WAlTON EQIP CMPPUL 11 :30 - 14:00 2.50 TRIP - DP - CMPPUL 14:00 - 14:30 0.50 ENGAGE FISH CMPPUL 14:30 - 17:00 2.50 TRIP - DP - CMPPUL 17:00 - 18:00 1.00 TRIP - BHA_ CMPPUL 18:00 - 20:00 2.00 TRIP - DP CMPPUL 20:00 - 20:30 0.50 ENGAGE FISH CMPPUL 20:30 - 00:00 3.50 TRIP DP - CMPPUL 00:00 - 01 :00 1.00 SERVIC RIG - CMPPUL 01 :00 - 02:30 1.50 WAlTON EQIP CMPPUL 02:30 - 05:00 2.50 TRIP - DP - CMPPUL 05:00 - 05:30 0.50 ENGAGE FISH CMPPUL 05:30 - 06:00 0.50 TRIP - DP - CMPPUL 6/19/2005 06:00 - 07:00 1.00 TRIP - DP - CMPPUL 07:00 - 08:00 1.00 TRIP - BHA_ CMPPUL 08:00 - 09:30 1.50 TRIP DP - CMPPUL 09:30 - 10:00 0.50 WORK - PIPE CMPPUL 10:00 - 14:00 4.00 TRIP - DP - CMPPUL 14:00 - 15:00 1.00 TRIP _ BHA_ CMPPUL 15:00 - 16:00 1.00 SLPCUT DLlN CMPPUL 16:00 - 17:30 1.50 TRIP - BHA_ CMPPUL 17:30 - 20:00 2.50 TRIP - DP - CMPPUL 20:00 - 22:30 2.50 TRIP - DP - CMPPUL 22:30 - 00:00 1.50 TRIP - BHA_ CMPPUL 00:00 - 01 :00 1.00 WAlTON EQIP CMPPUL 01 :00 - 01 :30 0.50 TRIP - BHA_ CMPPUL Start: 4/7/2005 Rig Release: Rig Number: 1 Spud Date: 5/12/1982 End: Group: Description of Operations Lay dn same, break out fish tools. Wait on assy I arrival overshot (blast jt) Wait on arrival overshot. MIU BHA #5 (5 3/4 overshot assy), RIH same RIH 5" DP to 4381 ft Engage fish (blast jt) at 4381 ft, blind back off, pull free Circ well bore clean. LCM I sludge at shaker POH 5" DP with fish Handle BHA, retrieve 1 jt blast jt 19.65 ft, layout same. Service rig Handle BHA #6 (5 3/4 overshot), RIH same RIH 5" DP to 4395 ft at tag up. Attempt engage remaining blast jts, no latch. POH 5" DP Inspect BHA #6, no fish. Overshot shoe I extension left in hole. Wait on arrival overshot MIU BHA #7 (8118 x 5314 grapple), RIH same RIH 5" DP to tag up at 4395 ft Work over fish (overshot I extension) POH 5" DP Cont POH with overshot, no fish, lay dn overshot. Service rig Wait on magnet MIU magnet, RIH same. Work magnet top of fish at 4395 ft POH with magnet Inspect magnet, retrieve approx 41bs metal shavings MIU spear (4.476 grapple) RIH 5" DP to top of fish at 4395 ft Attempt engage fish (overshot) POH spear, no fish, spear slightly damaged, grapple sprung. Service rig Wait on arrival impression block MIU impression block, RIH same to top fish at 4395 ft Work impression block at fish POH 5" DP with impression block Cont POH with impression block Lay dn 8 1/4 impression block, MIU 5314 overshot Note ringed impression (5 3/4 overshot) outer edge of block RIH 5" DP to tag up at 4388 ft, work dn to 4396 ft Work overshot over fish (shoe I extension), latch up POH 5" DP with fish Lay dn fish (shoe I extension), recover complete shoe. Cut drlg line Re-dress, M/U 8 1/4 impression block RIH 5" DP to tag up at 4397 ft, set wt on fish, imprint block POH 5"DP with impression block Lay dn impression block, note block swedged in eliptical shape to 7 1/4 " Wait on 6 1/4 impression block Take delivery impression block, MIU same Printed: 8/24/2005 11 :44:44 AM ) ) Marathon Oil Company Page 6 of 7 Operations Summary Report Legal Well Name: KENAI UNIT 24-7 Common Well Name: KENAI UNIT 24-7 Event Name: WORKOVER Contractor Name: GLACIER DRILLLlNG Rig Name: GLACIER DRILLING Date From - To Hours Code Sub Phase Code 6/19/2005 01 :30 - 03:30 2.00 TRIP - DP - CMPPUL 03:30 - 05:30 2.00 TRIP - DP CMPPUL 05:30 - 06:00 0.50 WAlTON EOIP CMPPUL 6/20/2005 06:00 - 06:30 0.50 WAlTON EOIP CMPPUL 06:30 - 07:00 0.50 TRIP - BHA_ CMPPUL 07:00 - 08:30 1.50 TRIP - DP - CMPPUL 08:30 - 09:00 0.50 WORK_ PIPE CMPPUL 09:00 - 12:00 3.00 TRIP - DP - CMPPUL 12:00 - 13:00 1.00 TRIP - BH~ CMPPUL 6/21/2005 13:00 - 15:00 2.00 TRIP - DP - CMPPUL 15:00 - 15:30 0.50 WORK_ PIPE CMPPUL 15:30 - 18:00 2.50 TRIP - DP - CMPPUL 18:00 - 18:30 0.50 TRIP - BHA_ CMPPUL 18:30 - 19:00 0.50 SERVIC RIG - CMPPUL 19:00 - 20:30 1.50 WAlTON EOIP CMPPUL 20:30 - 21 :00 0.50 TRIP - BHA_ CMPPUL 21 :00 - 23:00 2.00 TRIP - DP - CMPPUL 23:00 - 00:00 1.00 WORK_ PIPE CMPPUL 00:00 - 02:00 2.00 TRIP DP - CMPPUL 02:00 - 03:00 1.00 WAlTON EOIP CMPPUL 03:00 - 05:00 2.00 TRIP - DP - CMPPUL 05:00 - 06:00 1.00 WORK_ PIPE CMPPUL 06:00 - 08:30 2.50 TRIP - DP - CMPPUL 08:30 - 09:00 0.50 TRIP - BHA_ CMPPUL 09:00 - 10:00 1.00 TRIP - BHA_ CMPPUL 10:00 - 12:00 2.00 TRIP - DP - CMPPUL 12:00 - 12:30 0.50 CIRC_ CFLD CMPPUL 12:30 - 15:00 2.50 TRIP - DP - CMPPUL 15:00 - 15:30 0.50 TRIP - BHA_ CMPPUL 15:30 - 16:30 1.00 RUNPUL WBSH CMPPUL 16:30 - 17:30 1.00 TRIP - BHA_ CMPPUL 17:30 - 19:30 2.00 TRIP - DP - CMPPUL 19:30 - 20:30 1.00 TEST_ CSG_ CMPPUL 20:30 - 23:00 2.50 TRIP - DP - CMPPUL 23:00 - 23:30 0.50 TRIP - BHA_ CMPPUL 23:30 - 06:00 6.50 TEST_ BOPE CMPPUL 06:00 - 07:30 1.50 TRIP - BHA_ CMPPUL 07:30 - 10:00 2.50 TRIP - DP - CMPPUL 10:00 - 17:00 7.00 MILL_ JUNK CMPPUL 17:00 - 17:30 0.50 CIRC_ CFLD CMPPUL 17:30 - 19:30 2.00 TRIP - DP - CMPPUL 19:30 - 20:30 1.00 TRIP - BHA_ CMPPUL 6/22/2005 Start: 4/7/2005 Rig Release: Rig Number: 1 Spud Date: 5/12/1982 End: Group: Description of Operations RIH 5" DP to tag up at 4400 ft, set wt on fish, imprint block POH 5" DP with block Wait on taper tap Cont WO taper tap MIU taper tap, RIH same RIH 5" DP to tag at 4393 ft Attempt work taper tap into fish POH 5" DP to BHA Inspect taper tap, 1 1/2" vertical crack at small end. Slight sign of contact with fish. MIU 5 7/8 short catch overshot, RIH same RIH 5" DP to tag up at 4398 ft Attempt work overshot over fish, no indication latched POH 5" DP to BHA Inspect overshot, overshot lost in hole, twist off at upper crossover 3 112 X 4 1/2 Service rig Wait on 5 7/8 overshot M/U overshot, RIH same RIH 5" DP to tag up at 4398 ft Attempt work overshot over lost overshot, no indication latched POH 5" DP to BHA Wait on overshot modification (weld tang to overshot) MIU overshot, RIH to tag up at 4398 ft Attempt work overshot over fish, no indication latch Cont POH with overshot Inspect Overshot, modified "tangs" worn away. Layout same. MIU bit 19518 csg scraper, RIH same RIH 5" DP to 4400 ft, no resistance Circ well bore clean, sludge I metal shavings at shaker POH 5" DP, no drag Inspect scraper, slight scale one scraper segment, layout same. Wear ring to surface with scraper, re-install, slow go, cocked in BOP. PJSM, MIU 9518 RTTS, RIH same RIH 5 " DP to 4340 ft, no dn drag. Set RTTS at 4340 ft, test 9 5/8 csg to 1500 psi I 30 min Test successful, no re-tests, release pkr POH 5" DP, slow go, swabbing with pkr. Layout RTTS, release HOWCO PJSM, test BOPE all equip to 250 I 3000 psi. Re-tests check valve, HCR valve. M/U mill assy, (8 1/8 mill, boot bskts, bumper, jars) RIH same Follow BHA with 5" DP to tag up at 4396 ft Mill junk I fish 4396 - 4402 ft. 2500 - 5000 torque 4396 - 4400 Stable torque 4400 - 4402 ft. ROP decrease to 0 fph, circ sweep (metal shavings at shaker) no loss I gain. PJSM, POH for mill. Discover lost mill assy in hole, (mill, 2 boot bskts, bit sub, Printed: 8/24/2005 11 :44:44 AM ) ) Marathon Oil Company Page 7 of 7 Operations Summary Report Legal Well Name: KENAI UNIT 24-7 Common Well Name: KENAI UNIT 24-7 Event Name: WORKOVER Contractor Name: GLACIER DRILLLlNG Rig Name: GLACIER DRILLING Date From - To Hours Code Sub Phase Code 6/22/2005 19:30 - 20:30 1.00 TRIP - BHA_ CMPPUL 20:30 - 22:00 1.50 SERVIC RIG - CMPPUL 22:00 - 06:00 8.00 WAlTON REGS CMPPUL 6/23/2005 06:00 - 17:00 11.00 WAlTON REGS CMPPUL 17:00 - 17:30 0.50 PULD - PKR_ PLUGAB 17:30 - 20:00 2.50 TRIP - DP - PLUGAB 20:00 - 20:30 0.50 SETREL PLUG PLUGAB 20:30 - 21 :30 1.00 TEST_ PLUG PLUGAB 21 :30 - 01 :00 3.50 SPOT_ CMT_ PLUGAB 01 :00 - 01 :30 0.50 TRIP - DP - PLUGAB 01 :30 - 02:30 1.00 CIRC_ CFLD PLUGAB 02:30 - 04:30 2.00 TRIP - DP - PLUGAB 04:30 - 06:00 1.50 PULD - PKR_ PLUGAB Start: 4/7/2005 Rig Release: Rig Number: 1 Spud Date: 5/12/1982 End: Group: Description of Operations partial bumper sub parted upper break) Total 15.77 ft fish, TOF 4386 ft. Lay dn BHA. Rig Service Wait on permiting for sidetrack. Cont wait on permiting I bridge plug arrival PJSM, take delivery bridge plug, MIU same Follow bridge plug with 5" DP to 4360 ft, no dn drag. Set HOWCO 9 5/8 bridge plug at 4360 ft, release plug, confirm set. PJSM, test plug I csg to 1500 psi I 30 min. Test successful, no re-test. Witnessed by AOGCC Lou Grimaldi. PJSM, Set cmt plug top of retainer, 4360 - 4250 ft. / 75 sks "G", 15.8 ppg, 8 bbls, CD-32 I FP-6L Balanced plug, 5 bbls H2o ahead I 3.5 bbls behind Displacement 71 bbls. POH 240 ft, clear plug. Circ at high rate, clear cmt from DP, insure no cmt rings at tool jts. No cmt to surface, slightly thickened drill fluids. POH 5" DP to surface. Lay dn HOWCO equip, re-install wear ring (pulled with plug) Printed: 8/24/2005 11 :44:44 AM ) ~ MARATIIO. j I,; I r)",~. .. ..'.'1' II l I !t~;',:i'< KU 24-7 Abandonment Pad 41-18 Kenai AK RT=O' Tbg Hanger @ 27.68' A B Perforation Record Date Interval Details 5/824410'-4490' A-1 0 Sd Prodn 5/824525'-4560' A-11 Sd Prodn 5/824410'-4490' Reperf A-1 0 Sd Isolated: 7/88 -1696'--1708' B-2 Sd Prdn ;;~~ ~~~~:~~~~;: ~-~ ;~: ;~~:~ ~;~~ f I ~ \I¡ :; I 1 ~\ 3 ') I 1'1 I' Drive Pipe: 1:.,1 20" 94# H-40 @ 178' I 13 3/8" 61 # K-55 Casing R @ 2003' I II Abandonment (6/23/05): A. Cement plug: 4253'-4360' B. CIBP 4360' Junk: 1. Blast joints (4-1/2" OD) 4405'-4582' 2. Otis XA Sliding Sleeve @ 4639' (ID=2.75") *PX plug (set 8/19/01) 3. Model S-2 Prodn Packer @ 4679' \.. w/ Locator Sub @ 4677' & Top of 13.72' Seal Assy @ 4678' 4. Otis X Nipple @ 4692' 5. 4694' Cut tbf (7/26/88) .~ ~ ; ETD @ 4678' · ~J---- TOF @ 4848' (30' tubing) 9 5/8" 43.5# and 47# N-80 Csg @ 5801' ~~ !Æ:?'~ June 24, 200 ) FRANK H. MURKOWSK/, GOVERNOR 333 W. lfH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279·1433 FAX (907) 276-7542 CERTIFIED MAIL - RETURN RECEIPT REQUESTED 7002 3150 0005 3521 1553 Mr. A. Ben Schoffmann Operations Superintendent Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Subject: BOPE Test Frequency Kenai Unit 24-7 PTD 182-016 SC'··"',&.N· . ~¡'.Gl':D''') JUL "iì i. 'on~ ,i'"1\ ð"'~ ...!.. .{. f- "~h!l Dear Mr. Schoffmann: The Alaska Oil and Gas Conservation Commission received a call on June 20, 2005, reporting that the required blowout prevention equipment ("BOPE") test for the Inlet Glacier Drilling 1 ("Glacier I") rig was past due. Marathon was per- forming workover operations on Kenai Unit Well 24-7 ("KU 24-7"), a waste dis- posal well. Rig personnel advised that the last BOPE test had been done on June 11, 2005, nine days prior. During the June 20 phone conversation with Commission petroleum engineer James Regg, Marathon's drilling representative was instructed to test the BOPE as soon as the current operation allowed. A test report subsequently provided to the Commission indicates the Glacier 1 BOPE was tested on June 20, 2005. Commission Inspector Lou Grimaldi wit- nessed the BOPE test and noted 2 failures. A copy of the inspection report is enclosed. There is apparently confusion among Marathon drilling personnel about the Commission's BOPE test requirements. You are reminded that Commission regulations at 20 AAC 25.285(f), 25.286(e), and 25.287(d) clearly state that BOPE for workover operations must be tested at least once a week. The Com- mission recently changed its BOPE testing requirements for drilling and com- pletion operations for development and service wells to allow BOPE testing at intervals not exceeding 14 days, but this change does not apply to workover operations. Mr. Schoffmann June 14, 2005 Page 2 of 2 ) ) Failure to test BOPE within the required weekly interval for workover opera- tions is a violation of Commission regulations, absent a variance granted by the Commission. Within 14 days of receipt of this letter, you are requested to pro- vide the Commission with an explanation of this apparent violation and what will be done in the future to prevent its occurrence in Marathon-operated fields. The Commission reserves the right to pursue enforcement action in connection with this apparent violation as provided by..,20 .MC 25.535. Should you have any questions regarding this corresponde '¡ lease contact Mr. James Regg at (907) 793-1236. Enclosure STATE OF ALASKA . 01. )ND GAS CONSERVATION COMMISSIL,. 0) . BOPE Test Report Reviewed By: P.I. Suprv Comm Contractor/Rig No.: Inlet GO 1 PTD#: 1820160 DATE: 6/21/2005 Inspector Lou Grimaldi Insp Source Operator: MARATHON OIL CO Operator Rep: Dave Morris Rig Rep: George Brewster Inspector Type Operation: WRKOV Rams: Annular: Valves: Inspection No: bopLG050621012909 Test Pressure: -,...._-," ,.-.-..--..--..-. ..,---- -_...~,...,,-_._- -'"-. Type Test: WKLY 250/3000 250/3000 250/3000 Related Insp No: MISC. INSPECTIONS: P/F __L _-P___ _,L .,~-,.-, _f__ ..X,__ .NtL ,Ni\_ Location Gen.: Housekeeping: PTD On Location -" Order Posted ~ Well Sign Drl. Ri2 Hazard Sec. Misc FLOOR SAFTY V ALVES: Quantity P/F Upper Kelly ,__..J__,,__._,_f.._ Lower Kelly ____L,___u,'R-__ Ball Type ___.l,..,__Ln_ Inside BOP ___u.l..._.____J___ FSV Misc _,_Jt..,__...,_NA_ Test Results Number of Failures: 2 TEST DATA MUD SYSTEM: Visual Alarm Trip Tank _P_,__1_n' Pit Level Indicators _X_,___,L Flow Indicator __~'____n_~__ Meth Gas Detector ._ ,R______,f.._ H2S Gas Detector _..fm__,-1___ MS Misc _M...___~A.. ACCUMULATOR SYSTEM: Time/Pressure P/F System Pressure _,_J.OO,º--.___X_ Pressure After Closure ____l4_~Q____.I?_ 200 PSI Attained_______:JZ_____R___ Full Pressure Attained _n__ 3:º~________;r__ Blind Switch Covers: )oth_.~ta~ioºL,g__ Nitgn. Bottles (avg): __A..!J 7~(L_.._f.___ ACC Misc _.______NA,,__ BOP STACK: Quantity Size P/F Annular Preventer _1__,_º~/8 __,______..e... Pipe Rams _t_~,_.7L8 ~.5.~___r_ Lower Pipe Rams _J_~_,_______"_,__f.. Blind Rams _J.._:QJinc:L__, ____J~_ Choke Ln. Valves __J-2J/8______,_,L HCR Valves _,t,_JJ.@..... .,___.____F~ Kill Line Valves ~__.1.JIª__.___, ____,p_ Check V alve__L_,~__n__"___,n.___fP BOPS Misc .._-º-__º.on~,__.,__.____.. .., NA CHOKE MANIFOLD: Quantity P/F No. Valves __ J2_..______P_..u_ Manual Chokes __._.l.___,__,.f__u_, Hydraulic Chokes _ __t_____.....f,___ CH Misc ,_______N~_. Remarks: Kill line check valve leaked (slow), flush and retest "OK", Choke line HCR leaked greased, cycled and retested "OK". Test time-4 hours. MEMORANDUIV. ) State .Jf Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, 1-:7_ 1/-1/ /ù- P. I. Supervisor 'Y11 lUof ~ DATE: June 22,2005 FROM: Lou Grimaldi, Petroleu m Inspector SUBJECT: Well Plug Verification Marathon, KU24-7 Kenai Unit PTD #182-016 Sundry #305-034 Wednesday, June 22, 2005; I witnessed setting of the bridge plug for bottom hole abandonment on KU24-7. A H.E.S. "EZDRILL" cast iron bridge plug was run to 4359+' (RKB) and set. It was tagged with drill pipe and 15K was set down with no movement observed. The pipe was pulled up and a 1500-psi pressure test was placed on the plug that held "OK". Attachments: None NON-CONFIDENTIAL 'In trl¡ ~ 2\)ü~ ~Cf\~~Et> NO~ t)! \\. 2005-0622_P&A_KU_24-7 _btm-hole_lg.doc /8 Z-Õ/b ) ) s;~pject:Ku~¿.4Ji'> ." .... ........... . .... '.' ......... ...... . ..' '. Frqrn:"Børga,Pete"<;pkberg9@OlaraíhQooU. COrn~ ~~~Zl~~~Øí5i~~~~~~~~Th{~~¿~:~; .. . .... .......:..:::..:...:. . , : ",..: ....:..,<. '·',:1:.",-.< ·>X~:·:.·:·< , . .~ . .... . ........ .... ,.."'.".. .. ...... .":: :....'.:.. ......" ................... '... .......,........".. I sent the Sundry Notices for the Abandonment of KU 24-7 and the Applications for Permits to Drill the sidetrack. They should be there by now. The rig has ended it's fishing operations and as soon as I get the approval I will do the abandonment. I hope you can both turn the dirlling permits out in a couple of days. You will notice that the drilling permit surface location is different from the past permits or sundrys. With more accurate surveying instruments now I sure you have seen this before. My question is do you want to see this change or do you want to stick with the old surface location even if you know it's wrong? If either of you have questions on the permits please call me. 565-3032. Please let me know when we can proceed with the abandonment. .,,;5¿'u-f«-e¿ ¿~c~.f:~,- ff KE zV~ 7 /U¿<-,,/ k ¿1t£tA/L:¡-d 0v s4{)&j?c:c ~ ~''pfTds ~ : &/¿H/1 ç AIL / -7Cjh I,ÇE é ~. If .-r ~Ai/ 1:: / /IV .:5, /tr I ) ./ I . . 7I:S P zo-;,·u. L/ ~cI/.~q 4s ' y ~ 2- 7.Š-- (J57 i 60 I I L¡ ::::- 2 3·-~ 0 0 1'3 . CÚ I ¥;. -..::-1 I ) ~ 1,DS ~1- ,a' ~Gù5 . . . ."f-·r·' JI'L Q l L ·...c j¡. Nr"\:.t.; U b./n ~.~ &:ï ?. fl'~"' ~.? ... ~.~' I ""'à I : [ . .. b. t~ _, ","",:::iJ (¡::'" ;,.~?.'. \ '~ "...,;)} ~ ~~~. ,"-J ) r~ Il}I 1[1 'VI ~ lh~ _~ fro ~ }~ f}~ ) AlASKA OIL.AM) GAS CONSERVATION COMMISSION FRANK H. MURKOWSK/, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Denise M. Titus Production Engineer SCANNED JUL {) ti) iOtY5 Marathon Oil Company P.O. Box 196168 Anchorage, Alaska 99516-6168 \ q{;l- öt 0 Re: Kenai KU 24-7 Sundry Number: 305-155 Dear Ms. Titus: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day followi the date of this letter, or the next working day if the 23rd day falls a _oliday or weekend. A person may not appeal a Commission d ci . on to 3uperior Court unless rehearing has been requested. DATED thiszS day of June, 2005 Encl. ) ') . , 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 June 22, 2005 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 JUI'\; 2 2 2005 f~J~ska Oil (iI, Reference: KU 24-7 Abandonment Sundry ,,~~\~ '\0() r Dear Mr. Aubert: Enclosed is the 10-403 Sundry Application to abandon the existing perfs in KU 24-7. This drill cuttings disposal well, was taken out of service due to observed lack of pressure integrity in the annulus. A workover was approved to fish the existing completion and recomplete with new equipment. In the course of this workover, we have encountered casing damage which is hindering our fishing progress. Marathon would like to abandon the existing zone, and twin the wellbore to regain access to the Pool 3 disposal zone. /"'..., ~. The attached procedure to abandon the perfs conforms to State regulation 20 MC 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 per the attached procedure. --" This work is expected to begin as soon as we receive agency approval. I have attached a procedure and a proposed wellbore 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, (/A~ þT' Ù(1;tf Denise M. Titus Production Engineer Enclosures: 10-403 Sundry Abandonment Procedure Proposed Well Schematic ORIGINAL. CflJ- ~ .1,~"~~~.. 'NG/\- ~'12~/~~o ç ALAv.1. OIL AND ~~;~g~S~~~~ON COMMI;.. J)N R. E I~~ U A~PLICATION FOR SUNDRY APPROVAL JUN 2 ~J~ 2005 / 20 AAC 25.280 Abandon ~ Suspend U Operational shutdown U Alter casing D Repair well D Plug Perforations D Change approved program D Pull Tubing D Perforate New Pool D 2. Operator Name: 4. Current Well Class: Marathon Oil Company Development D 3. Address: Stratigraphic D 1. Type of Request: Perforate Uß,\1ifi1~ktilt m1i~~~ Cþ.f~hUláí'(f:)¡sÞo~..'tj' Stimulate D Time ExtensionA~!nm~~\ð Other D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 182-016 // [] 6. API Number: 50-133-20352 / Service PO Box 196168 Anchorage, AK 99516-6168 7. KB Elevation (ft): 87 12. Attachments: Description Summary of Proposal Detailed Operations Program 0 BOP Sketch 14. Estimated Date for 16. Verbal Approval: Date: Commission Representative: W'6A c, Ill.I200,~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Denise M. Titus Title Production Engineer 8. Property Designation: Kenai Unit 11. Total Depth MD (ft): 5820 Casing Structural Conductor Surface Intermediate Production . Liner Perforation Depth MD (ft): 4410-90;4525-60;4696-108 Packers and SSSV Type: Commencing Operations: 9. Well Name and Number: KU 24-7 / 10. Field/Pools(s): Kenai Gas Field, Sterling Pool 3 and Pool 4 PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 4796 Effective Depth MD (ft): Effective Depth TVD (ft): 4878 4080 Junk (measured): Tail pipe 4848' Collapse N/A Plugs (measured): 4,639 Burst N/A Length 178 Size MD 178 TVD 178 20" 2003 13-3/8" 2003 1849 3090 1540 5801 5801 3810 9-5/8" 4781 6330 Perforation Depth TVD (ft): Tubing Size: Tubing Grade: 3726-67;3813-40;3943-51 3-1/2" 9.2ppf N-80 S-2 PRODUCTION PKR, Packers and SSSV MD (ft): Plug set in tubing at 4639' Tubing MD (ft): LS: left to 4694' Single Packer at 4679' ~ D 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil D Gas D WAG D GINJ D o Service [] 6/22/2005 ,/ Plugged WINJ D D Abandoned WDSPL [] D Denise Titus Signature rØ~ t~ ÙMr Phone 907-283-1333 Date COMMISSION USE ONLY 6/21/2005 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3oS-- I,SS- Plug Int~grity ~ Other: BOP Test D D o Mechanical Integrity Test Location Clearance RBDMS BFl JUN 2 4 2005 COMMISSIONER BY ORDER OF THE COMMISSION Date:~~ -- O R' 1 ("~\ ~. >,; " \ L \ \~..J ¡ i \J t-\ INSTRUCTIONS ON REVERSE Form 10-403 Revised 12/2003 Submit in Duplicate ) ') M MARATHON , , Marathon Oil Company Alaska Region KU 24-7 Kenai Gas Field, Pad 41-18 Abandonment Procedure History: Well KU 24-7 was previously a 3-1/2" dual string Pool 3 and Pool 4 Sterling well used for cuttings disposal. Sundry approval was recently obtained to recomplete the Pool 3 disposal ./' zone. While working over the well, excessive casing damage has created various fishing problems across the perfs in Pool 3. In order to restore cuttings disposal, the well will likely need to be sidetracked. The short string and the dual packer were already removed during the fishing operation. A PX plug installed in the long string tubing; which remains in the hole // mechanically isolates the cuttings plugged Pool 4 perfs from the uphole completion. Objective: The following abandonment is proposed to isolate the perfs prior to sidetracking operations. Procedure: 1. PU CIBP. RIH to 4360' (50' above top perf). Set CIBP and pressure test casing to 1500psi. /'" 2. Displace about 8bblNfe) 15. 8ppg abandonment cement to end of drillpipe (-110' in 9-5/8" / csg). ~¿ / 3. PU 200' and circulate. POOH. 4. PU CIBP and set at 3800'MD as a platform to run whipstock and proceed wi sidetrack. /' ) ) Attachment Cement Volumes: Cement above CIBP: Top of CIBP: 4360' Required cement: 75' Casing volume in 9 5/8", 26.4ppf: 0.4110 felft Density: 15.8 ppg, Yield: 1.1~(Nlsx Minimum Required Cement: ~J,AP /' ¡ , , J\A MARATHON ; KU 24-7 Proposed Abandonment Pad 41-18 Kenai AK RT=Q' Tbg Hanger @ 27.68' ) ~¡~ h"'~ ~" ~,q,:,i"1 I~ ~ I ;.,." ",:,"~,¡,¡,,' .. t ,¡u I. I ~1 ~I I I Perforation Record Date }ntér~al Details 5/82/4410Y-4490' A-1 0 Sd Prodn 5/8~~f5'-4560' A-11 Sd Prodn 5/824410'-4490' Reperf A-1 0 Sd Isolated: 7/88 ~696'--1708' B-2 Sd Prdn 5/82 ~890'-~905' B ~ Sd. Sqz'd 7/88 5/82 ~905' ~925' B--1 Sd. Sqz'd 7/88 3 ) 11 ~~:~~~~-~o @ 178' ~,~ .I J 133/8" 61# K-55 Casing @ 2003' .",/ ,,/ Proposed Abandonment: A. Cement plug: 4250'-4360' B. CIBP 4360' ""," 44'0 I Junk: 1. Blast joints (4-1/2" 00) 4405'-4582' 2. Otis XA Sliding Sleeve @ 4639' (10=2.75") *PX plug (set 8/19/01) 3. Model S-2 Prodn Packer @ 4679' wi Locator Sub @ 4677' &Top of 13.72' Seal Assy @ 4678' - ETD @ 4678' TOF @ 4848' (30' tubing) ) 18L-ol¿, ) t>~þj~9t:KU24~7YVorkcwør.. .. ... .. frqm: ... UTitUs,pelJis~f\t1.~'~dnltitus@rT19rathÖnQiLG9rn>' [)ð.$:F~i,f1N1ar200513:Þ7:20..09()O ... ........... rJ". i~~~mill1~~,,: J Winton, Please note that KU 24-7 will be equipped with appropriate valves and gauges on the tubing, casing-tubing annulus, and casing -casing annulus to show surface pressures and to control the well flow for the range of conditions expected in compliance with 20 MC 25.200 per Conservation Order No. 533. I have updated the procedure to reflect this in step 9. Please let me know if you have any questions or comments. Thanks, Denise Titus Marathon Oil Company «KU 24-7 WO Sundry Program.doc» Content-Description: KU 24-7 WO Sundry Program.doc KU 24-7 WO Sundry Program.doc Content-Type: application/msword Content-Encoding: base64 SCANNED MAR 112005 M MARATHON ~ 4 ) ) Marathon Oil Company KU 24-7 WO Kenai Gas Field, Pad 41-18 W orkover Procedure History: KU 24-7 is a dual 3-1/2" completion in 9-5/8" casing. This cuttings injection well must pass a regular Mechanical Integrity Test as a condition of the Disposal Injection Order. After a failed annular MIT in August '03 a sealant was pumped in the annulus which provided annular integrity. In the spring of '04, a major loss of integrity was evident based on annular pressures. Cuttings injection was voluntarily suspended. Packer failure is the most likely cause of communication. Additionally, there is known communication between the long string and the short string as of June '02, likely due to erosion of the long string tubing from solids injection. Long String: The long string provides access to Pool 4. The long string pressured up after months of injection (likely due to fill over the perfs). A PX plug was installed in the sliding sleeve profile at 4639' (8/19101) and injection operations resumed in the short string. Short String: The short string accesses Poo13 perforations. Cuttings were injected from 8/01 until packer failure. Objective: Use Glacier Rig to workover KU 24-7 recompleting to the Pool 3 zone with a single string of 4-1/2" tubing and an injection packer. Pool 4 will remain isolated by the historical drill cutting fill, the single packer, and tubing with a plug installed. Procedure: 1) Prepare wellbore. Record pressures, drift tubing, pump kill pill, and make chemical cuts. 2) Prepare wellhead by removing flowlines and control lines. Set BPV for rig mob. Inspect cellar and replace if necessary. 3) Prep location for drilling rig. Completing dirt work and necessary modifications to the G&I plant. 4) MIRU GD #1. ND dual tree and NU BOPs to 10" 5M tubing hanger spool with dual 3- 1/2" rams and test. The single gate ram will not be used in this workover to allow more clearance. 5) Pull dual tubing strings and dual packer. a. RU to both strings in an attempt to pull dual packer (both strings are 3-1/2" 9.2ppf, N-80). If packer comes loose, TOR wi both strings (may see some seal- tite material, MSDSs will be provided). Swap dual 3-1/2" rams for single 4 12" drillpipe rams. Test doors to 250/3000psi. b. If unable to pull packer, cut tubing and fish packer per fisherman recommendation. ) ) c. If dual packer will not jar free, PU washpipe and circulate to packer. d. RIH with overshot and jar as needed to get packer. e. Ifunsuccessful, RIH wi mill and bum over packer. 6) Once dual packer is out, pull remaining long stringjblast joints. a. If long string does not come free, wash to packer as needed. 7) With casing clean, install packer at 4400' and run 4-1/2" tubing. Test casingltubing annulus to 3000psi wi brine. 8) Space out to land hanger. Run in lockscrews. ND BOP stack, NU tree and test to 250/3000psi. RDMO GD #1 9) Reconnect surface flow lines and control lines. To comply with Conservation Order No. 533, retrofit outer annulus and inner annulus valves to permit above-ground installation of pressure gauges/transmitters. Also, install tubing pressure gauge and ensure tree is compliant with 20 AAC 25.200. 10) RU wire line unit to pull plug in tubing string. 11) Resume cuttings inj ection. New perforations may be required if well pressures up beyond expected/historical injection pressure. [Fwd: FW: MIT's at Kenai Gas Field] ) . . . . . $»ÞJ~ê~:<IFWd:Jf"V\r:NIIT'~:a.tl{èIi?i9a.sfiet4] ", . '" , , ' :Frgm:,.'WihtQri i¥1.Îbert.-swìÌ1JÓ112~UQ~i1@a4#1i~.st.ate..~k.p~P; , ~,ít!lt¡,W'eli,09'tr1åi'tØ$'W$;54¡>m+08!ØØ.. ....... . ) -------- Original Message -------- FW: MITIs at Kenai Gas Field Wed, 09 Mar 2005 15:50:33 -0900 Titus, Denise M. cdmtitus@marathonoil.com> winton aubert@admin.state.ak.us 's'ÒEÒ'I{mann";""""A"""E3""''''(B'en)''''''''''~'aEs''ë}iõT"i'mann@mara thonoì 1 . com> Subject: Date: From: To: CC: Winton, Please see attached forwarded email from Wayne Cissell to Jim Regg regarding suspected loss of packer integrity in disposal well KU 24-7. Please advise as to your preferred method for notification per DIO 11 Rule 3. Thanks, Denise *From: * Cissell, Wayne E. *Sent: * Wednesday, March 09, 2005 3:41 PM *To: * Titus, Denise M. *Cc: * Cissell, Wayne E. *Subject: * FW: MITIs at Kenai Gas Field Here is the original email. *From: * Cissell, Wayne E. *Sent: * Tuesday, June 15, 2004 1:44 PM *To: * James Regg *Cc: * Cissell, Wayne E. *Subject: * MITIs at Kenai Gas Field Jim, I would like to schedule the MITIs for wells 11-17 and WD#l. I called Jeff and apparently he is back working on the slope. I would like to try and get these done Wednesday or Thursday of this week. Do you have anyone available to witness the MIT IS? To bring you up to speed on well 24-7. We have moved our injection over to 11-17 until we determine why we are unable to pressure up the back side and maintain the pressure. We believe that the dual baker packer is not holding. We plan to set plugs in the tubing and pressure up the well to see if the tubing holds and if the pressure still bleeds off as it has last week. From this testing we will try and determine what our next plan of action. wayne SC/\NNEL) MAR 1 0 2005 1 of 1 3/10/2005 8:31 AM Re: MIT on KU 24-7 ) ') ~. .,"À,.:(.,.:.r:'.02";:.!lt<'.' ~ /' ....,) . "'J . vð' \1£0"0 l~ Subject: Re: MIT on KU 24-7 From: Tom Maunder <tom_maunder@admin.state.ak.us> Date: Tue, 04 Sep 2001 08:28:53 -0800 To: "Eller, J Gary" <JGEller@MarathonOil.com> G~ . There really isn't a set pressure. Their intent is to have a positive pressure so gauges don't just read zero. In that case you don't know if it really is zero, if the gauge is broken or the valve closed. They also try to have a nitrogen or gas cushion on the annulus to allow accommodation for pressure and temperature changes. Having the cushion is not critical. My thought would be that the "hold" pressure should be less than your injection pressure. My reasoning for this is that if a leak were to develop in your SS then the pressure increase on the annulus can only be coming from one place. If your "hold" pressure is higher than your injection pressure then a pressure drop in your annulus could mean a leak in the tubing or the casing, but without further diagnostics you won't know which. In the case you describe, the "hold" pressure might be 500 psi or so. Let me know your thoughts and would you please fax a completion drawing of the well. Thanks. Tom "Eller, J Gary" wrote: There's nothing particularly crucial about holding it at 2000 psi. When we were disposing down the longstring, injection pressures there were 2000+ psi, as I recall. That was when I offered my advice to the injection guys that they hold the 2000 psi on the annulus. But we're injecting at less than 1000 psi down the short string currently. Without having done any calculations, I have no problem setting that annulus pressure lower. Do you know if there a "standard" pressure that other operators try to keep? [Eller, J Gary] -----Original Message----- From: Tom Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, September 04, 2001 7:12 AM To: Eller, J Gary Subject: Re: MIT on KU 24-7 SC¡'~NNE[) MAH 1 0 2005 Gary, Thanks for the information and your (and others) quick work to trouble shoot the well problem. Glad you had a spare tubing string. I agree with the idea of keeping positive pressure on the "annulus". That is the practice of some of the other operators. I would like to discuss your rationale for the 2000 psi. At first blush, that seems a little high. What pumping pressures are you experiencing while disposing? Give me a call and we can discuss. Tom Maunder "Eller, J Gary" wrote: Lou Grimaldi (AOGCC) came out today and passed our MIT on well KU 24-7, our class II disposal well on the 41-18 pad. You'll recall that once we recognized an MIT failure we set a plug in the longstring below the dual packer, then pressured up the longstring and casing annulus to about 2300 psi. The shortstring was left alone because it appeared to have full integrity. At first both the longstring and casing annulus held great, but then the casing began a long, slow bleed while the long string held steady. The decline on the casing was 100 to 200 psi over a 24-hour basis, but it never stabilized. 10f2 3/3/2005 4:48 PM Re:.MIT on KU 24-7 20f2 /' --YJ ý,3"f)";' Yesterday slickline set a PXN plug in the shortstring below the dual packer. Then we repressured the shortstring, longstring, and casing all to 2500 psi. All have held like a jug for the last 24 hours, which is what Lou witnessed. Our plans now are to pull the shortstring plug and resume injection down the short string. We plan to leave the slickline plug in the longstring permanently. I also recommend we leave the pressure on the longstring and casing annulus on a routine basis. While injecting, we should always try to keep the annulus pressure above 2000 psi. ') ') Please call me if you have any questions. 3/3/2005 4:48 PM ( ( FRANK H. MURKOWSKI, GOVERNOR AIIASKA. OILAlft) GAS CONSERVATION COltDlISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Denise M. Titus Pruduction Engineer Marathon Oil Company P.O. Box 196168 Anchorage, Alaska 99519-6168 \~:l- () I h Re: Kenai KU 24-7 Sundry Number: 305-034 Dear Ms. Titus: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ¥ DATED this} 7 day of February, 2005 G~ Daniel T. Seamount, Jr. Commissioner Encl. SCANNED FEB 1 8 2005 , , M Marathon MARATHON Oil Company ~ Alaska Business Unit Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 February 15, 2005 \ C6d: -b \k RË(:~Ë\\le,D FEe 1. , 'lOOS Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 'J\\lska 0\\ & I\nthmage Reference: KU 24-7 Workover Sundry Dear Mr. Aubert: Enclosed is the 10-403 Application for Sundry Approval. Marathon drill cuttings disposal well, KU 24- 7, was taken out of service due to observed lack of pressure integrity in the annulus. The dual packer is suspected to have failed and a Mechanical Integrity Test can no longer be passed per State requirements. The proposed workover would include pulling the existing dual packer and tubing strings and running a single 4-1/2" packer and string to the Pool 3 injection zone. After demonstration of mechanical integrity, the well would then be returned to disposal service. In conjunction with this work, modeling has been completed to evaluate fracture growth for existing and projected cuttings volumes. The model has been matched to historical production data and shows a fracture with very limited growth. The model information is also included for your review.--- This work is expected to begin in late March. I have attached a procedure, a current and proposed wellbore diagram, a 10-403, and a copy of the frac modeling results. If you need any additional information or have questions, I can be reached by phone at 907-283-1333 or bye-mail at dmtitus@marathonoil.com. Sincerely, ,ttWr Denise M. Titus Production Engineer Enclosures: 10-403 Sundry Workover Procedure Current Well Schematic Proposed Well Schematic Disposal Frac Modeling Summary ORIGINAL Abandon U Alter casing 0 Change approved program 0 2. Operator Name: MARATHON OIL COMPANY 3. Address: P. O. Box 196168, Anchorage, AK 99519-6168 7. KB Elevation (ft): 28 1. Type of Request: 8. Property Designation: Kenai Unit 11. Total Depth MD (ft): 5820 Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 4410-90 ;4525-60 ;4696-708 Packers and SSSV Type: ~ W6A- Z.111/1,ðO~ ALA! A OIL AND ~:~~g~S~~~ON COMl,_510N ~ ~ REe(!j\l APPLICATION FOR SUNDRY APPROVAL ~ 6- FEe 1 7 2005 20 MC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development -B- Stratigraphic 0 Suspend U Repair well 0 Pull Tubing 0 Perforate U':,W.aived~ Ø\lw'DOO~¡sij9~nbJ.ili: sim Stimulate 0 Time Extension 0 Â;n:::JmrageOther 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 ~ / ð'':;' - /J / ~ /' Service ~ 6. API Number: \ JG/Jr- 50-133-20352 / 9. Well Name and Number: KU 24-7 ./ 10. Field/Pools(s): Kenai Gas Fieldl Pool 3 PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 4796 Effective Depth MD (ft): Effective Depth TVD (ft): 4878 4080 Plugs (measured): 4,639 Junk (measured): Tail pipe 4848' Collapse N/A Length 178 Size MD 178 TVD 178 Burst 20" N/A 2003 13-3/8" 1540 2003 1849 3090 5801 9-5/8" 3810 5801 4781 6330 Perforation Depth TVD (ft): Tubing Size: 3726-67;3813-40;3943-51 Dual 3-1/2" 9.2ppf BAKER DUAL PKR Packers and SSSV MD (ft): S-2 PRODUCTION PKR Tubing Grade: Tubing MD (ft): SS: 4326' LS: 4694' N-80 Dual at 4313', Single Packer at 4679' LJ 0 12. Attachments: Description Summary of Proposal Detailed Operations Program 0 BOP Sketch 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Com mission Representative: 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Abandoned WDSPL 0 0 k.J{j~ -B- Service [B" / 4/1/2005 / 0 0 Plugged WINJ Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name De~se M Tltu~/ l Title Production Engineer Signature ~. iJj ~r Phone 907-283-1333 Date plf J COMMISSION USE ONLY Denise Titus 2/11/2005 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3ôS-- é/ 3-f Plug Integrity 0 BOP Test ~ 0 Location Clearance 0 Mechanical Integrity Test Other: T ~st ßO P ¿::. }o .~ 000 fS/ . Subsequent Form Required: lo - 4o{ . \ GI NAL BY ORDER OF THE COMMISSION Date¿jj¡¥ AppmVedbY~ Form 10-403 Revised 12/2003 Ç>riginal Signed. DAÑ SEAMnuNt COMMISSIONER INSTRUCTIONS ON REVERSE Submit in Duplicate ( M MARATHON t ~ Marathon Oil Company KU 24-7 WO Kenai Gas Field, Pad 41-18 W orkover Procedure History: KU 24-7 is a dual 3-1/2" completion in 9-5/8" casing. This cuttings injection well must pass a regular Mechanical Integrity Test as a condition of the Disposal Injection Order. / After a failed annular MIT in August '03 a sealant was pumped in the annulus which provided annular integrity. In the spring of '04, a major loss of integrity was evident based on annular pressures. Cuttings injection was voluntarily suspended. Packer failure is the most likely cause of communication. Additionally, there is known communication between the long string and the short string as of June '02, likely due to erosion of the long string tubing from solids injection. Long String: The long string provides access to Pool 4. The long string pressured up after months of injection (likely due to fill over the perfs). A PX plug was installed in thy sliding sleeve profile at 4639' (8/19/01) and injection operations resumed in the short string. / / Short String: The short string accesses Pool 3 perforations. Cuttings were injected from / 8/01 until packer failure. Objective: Use Glacier Rig to workover KU 24-7 recompleting to the Pool 3 zone with a single string of 4-1/2" tubing and an injection packer. Pool 4 will remain isolated by the historical drill cutting fill, the single packer, and tubing with a plug installed. Procedure: 1) Prepare wellbore. Record pressures, drift tubing, pump kill pill, and make chemical cuts. I 2) Prepare wellhead by removing flowlines and control lines. Set BPV for rig mob. Inspect cellar and replace if necessary. ./ 3) Prep location for drilling rig. Complet9ai dirt work and necessary modifications to the" G&I plant. 4) MIRU GD #1. ND dual tree and NU BOPs to 10" 5M tubing hanger spool with dual 3- / 1/2" rams and test. The single gate ram will not be used in this workover to allow more clearance. 5) Pull dual tubing strings and dual packer. a. RU to both strings in an attempt to pull dual packer (both strings are 3-1/2" 9.2ppf, N-80). Ifpacker comes loos, H wi both strings (may see some seal- tite material, MSDSs will be provi ed). Swap dual 3-1/2" rams for single 4 ~" drillpipe rams. Test doors to 2501 00 si. b. If unable to pull packer, cut tubing a fish packer per fisherman recommendation. c. If dual packer will not jar free, PU washpipe and circulate to packer. d. RIH with overshot and jar as needed to get packer. / e. Ifunsuccessful, RIH wi mill and bum over packer. 6) Once dual packer is out, pull remaining long stringlblast joints. a. If long string does not come free, wash to packer as needed. 7) With casing clean, install packer at 4400' and run 4-1/2" tubing. Test casing/tubing // annulus to 3000psi wi brine. 8) Space out to land hanger. Run in lockscrews. ND BOP stack, NU tree and test to 250/3000psi. RDMO GD #1 / 9) Reconnect surface flow lines and control lines. 10) RU wireline unit to pull plug in tubing string. // 11) Resume cuttings injection. New perforations may be required if well pressures up beyond expected/historical injection pressure. ~ IlARATllOII ; j I''''.'.'.,''..".,., ...,.',,'''''.,.,.'.'''''', ~" ~, ; ~ 1 , , tA~ . KU 24-7 Pad 41-18 Kenai AK RT=O' Cameron 3 1/2" Dual Tbg Hanger @ 27.68' * PX plug (refer to tubing detail)- Perforation Record Date Interval Details 5/824410'-4490' A-10 Sd Prodn 5/824525'-4560' A-11 Sd Prodn 5/824410'-4490' Reperf A-10 Sd 7/884696'-4708' B-2 Sd Prdn 5/824890'-4905' B-4 Sd. Sqz'd 7/88 5/824905'-4925' B-4 Sd. Sqz'd 7/88 C 3 8 9 Ij I~ Drive Pipe: ,,'..,',,',:, ' :, 20" 94# H-40@178' ~ i1 d iii 13 3/8" 61 # K-55 Casing @ 2003' Tubing Detail Lonq String: 3 1/2" 9.2#, N-80 Tubinq 1. Otis XA Sliding Sleeve @ 4274' (ID=2.75") 2. Baker Model A-5 Dual Packer @ 4313' (' 3. Blast Joints from 4385'-4582' 4. Otis XA Sliding Sleeve @ 4639' (ID=2.75") *PX plug (set 8/19/01) 5. Locator Sub @ 4677' 6. Top of 13.72' Seal Assy @ 4678' 7. Model S-2 Prodn Packer @ 4679' 8. Otis X Nipple @ 4692' 9. 4694' Cut tbf (7/26/88) Short Strinq: 3 1/2" 9.2# N-80 Tubinq A. Otis XA sliding sleeve @ 4268' (10=2.75") B. Baker Model A-5 Dual Packer @ 4315' C. Otis XN Nipple @ 4326' (ID=2.75", No- go=2.635") - ETD @ 4678' TOF @ 4848' (30' tubing) 95/8" 43.5# and 47# N-80 Csg @ 5801' I Lease: State/Provo Well Name & Number: County or Parish: Perforations (MD) Angle/Perfs BHP: Dated Completed: ICountry: (TVD) Angle @ KOP and Depth BHT: I Completion Fluid: ~ IlARATllOII i j KU 24-7 Pad 41-18 Kenai AK RT=Q' Tbg Hanger @ 27.68' ( I,' 'I'" 'r"'" f" ''''''' ,., I,." D. P. ~" ~.,"" ~, '. , 1I!f"" ''fit. rIve Ipe: ~. J, 0: ! I,. Cc" 20" 94# H-40 @ 178' . i ii."",~",'."',,. 0,,",.,., '.", h.,','""',"',',,~.,'.,,.i 1~ 3/8" 61# K-55 Casing e '" ,'! @2003' !u: ~ ¡,~ ;t t.Jt Ji} ¡ Ii; a ¡Ii ~~~1I ~~"",""', ~,:.,,',,' "',','. ,,',.,.,..'.",,", l ), .. 'I " ~.,. ~, ~ ti', '; ~1!!, ~' ~i ^. Perforation Record Date Interval Details 5/824410'-4490' A-10 Sd Prodn 5/824525'-4560' A-11 Sd Prodn 5/824410'-4490' Reperf A-1 0 Sd Isolated: 7/88 "1696'-"1708' B-2 Sd Prdn 5/82 "1890'-"1905' B-"1 Sd. Sqz'd 7/~ 5/82 "1905'-"1925' B-"1 Sd. Sqz'd 7/88 Well Name & Number: County or Parish: Perforations (MD) Angle/Perfs BHP: Dated Completed: 4 Tubing Detail Injection StrinQ: 4 1/2" 12.6#. N-80 Tubing 1 . X nipple @ 4350' 2. Single Injection Packer @ 4380' / 3. XN nipple @ 4395' Junk: 1. Otis XA Sliding Sleeve @ 4639' (10=2.75") *PX plug (set 8/19/01) 2. Model S-2 Prodn Packer @ 4679' wi Locator Sub @ 4677' &Top of 13.72' Seal Assy @ 4678' 3. Otis X Nipple @ 4692' 4. 4694' Cut tbf (7/26/88) - ETD @ 4678' TOF @ 4848' (30' tubing) 9 5/8" 43.5# and 47# N-80 Csg @ 5801' Lease: State/Provo I Country: (TVD) Angle @ KOP and Depth BHT: I Completion Fluid: I I I h ~ I Marathon KU 24-7 Cuttings Disposal Project Evaluation R. D. Barree Barree & Associates LLC November 21, 2004 G In 1996 a model was constructed to forecast the fracture growth resulting from injection of cuttings slurry in the KU 24-7 well. The injection project has continued through this year. A look-back model evaluation using the actual observed surface pressures from the injection project was requested by Marathon Oil Company, Anchorage. This report documents the results of that analysis. It provides an estimate of the fracture geometry resulting from the cutting slurry injected up to this time, and the effect of continued injection up to a total of 1.5 million barrels of slurry. 1 M1^ ~-~~J ;'~> > ~~g26~~processed G''-à ^'-.~, ~ ~~; ~:: 2SOI:I.œ~ 2!i5Q,OO 'I'::I: ,~' .;. = =-,!~ \~7 ""'" if1 ' :: '--!J ,.~ .'~ ::~}~ '} ií@: "'!""..'.~.' ~~... 'b.'. \:;. ~. ""'.X' 4ŒU~ ~ :,-' 'J" , ,,~.~, <," "'''OO_--'~ d: -: :: -~ - ~ :~r <+. Perforated Interval For Disposal Copyright B&A 2004 Digital log data for the KU 24-7 well were processed and used as input to the updated fracture growth model. Perforations used for injection are shown on the figure as the tan blocks at right. The perforations are listed on the following figure. Major coal seams are shown on the log in black. The coals are expected to provide substantial height containment through high in-situ stress and fracture blunting. 2 G ~~. KU 24-7 Injection Project .. Pool 3 Sterling Sands Perfs . Al0: 4410-4490' MD . All: 4525-4560' MD . Injection from 8/18/2001 - present .. Pool 4 Sands . B2: 4696-4708' MD . Injection from 4/27/2000 - 8/18/2001 .. Average rate while pumping = 6.8 bpm .. Average solids loading = .11-14°10 .. Solids pass through SO-mesh screen Copyright B&A 2004 The cuttings disposal initially began in the lower 82 perfs. After injection of about 180,000 barrels of slurry the injection was switched to the upper A-sand perfs because of rising treating pressure. Injection continued through the upper perfs to the present time. Cuttings injection was a batch process, rather than continuous injection. While pumping, the average rate was 6.8 bpm. The slurry was composed of 11-14% solids by volume and the solids were ground to pass through a 50-mesh screen. 3 G'~~' KU 24-7 Injection Disposal History 500 800000 3500 3000 700000 'iij Co € 2500 ~ I/ I/ £ 2000 s::: .2 ~ 1500 :s (I) () " ~1 000 ; ~ ' en ' 600000 ~ "Ô (I) 500000 ~ :s Copyright BM 2004 The raw injection data from the project are plotted as a function of calendar time. The "Long String" pressure curve shows the maximum measured surface pressure in the tubing connected to the 82 sand perfs during each injection cycle. The "Short String" pressure represents the maximum injection pressure to the A-sand perfs. The "Annulus" pressure represents the casing-head pressure surrounding the two strings of injection tubing. The overlay of the long and short string pressures after 6/2002 suggests that the two tubing strings are in communication, either through the fracture or through a tubing leak. 4 lM!^ KU 24-7 Continuous Injection Model G I).,\)(~c Œ 1~)(:io.\f¡':S 3500 3000 2500 "ã. ~~ l 2000 c 0 1 I 1500 g ~ III 1000 500 0 0 1600 1800 1000 1200 1400 200 400 600 800 2000 CumLllative Hour:s on Injection Copyright 8M 2004 Each injection cycle reported a total volume of slurry injected, in barrels. Using the assumed average rate of 6.8 bpm, the total volume of slurry pumped has been converted to a continuous injection model. The pressure data is plotted as a function of hours on continuous injection at constant rate. This model provides a more pessimistic result in that extended leakoff time during shut-ins is not available to dehydrate the slurry and decrease created fracture volume. This continuous injection "history" was used as input to the fracture design model. 5 ~^ KU 24-7 Disposal Model ~ 11..",""" IX ~':;'''-\t<s GR.API: 82.6< 0 VeGAl.dec = I 1.5 RH08.9/cm3 2.i I :!~ ='~ r='. ::: ~ ::~: L::.EIi!E 3993 3400 :"3 ~ 3400 4127 -c:- 3600 1'1127 ...... 3500 42-58 3600 '250 ~ .)600 : 4391 . ~ 3700 4391 :¡r- 3700 4624 ~ 3800 ~--.:: 3800 4655 ---:-- 3900 tlli -------=-- 3900 4788 ~ 4000 4788 ~ 4000 4920 ~ 4100 4920 ~ 4100 5054 A200 &0&4 - 4200 5185 ~ 4300 6186 ~300 5318 ~ 4400 5318 ----=a=l-'90 :~ ~ :::: ~= 5710 ~700 ~10 ~oo Copyright 8M 2004 The processed log data were imported to the 3-D fracture simulator GOHFER. The perforation intervals are shown in the figure. The geologic and stress model derived from the log data was used with the injection history to estimate the resulting fracture geometry. 6 .ì\ Final Model Pressure Results r 1)..\RtlCç (x i\s&)li~,n.:s V 3500 3000 2500 1000 '. 500 Hours on Continous Injection COþyright B&A 2004 The rate history was input to the model and the pressure history shown in the plot was generated by the interaction of injection and fracture propagation. While the match is not exact, some characteristic features are represented. Initially, with injection to the 82 perfs only, the treating pressure rises fairly quickly because of contained fracture height between bounding coals. When injection is switched to the A-sand perfs, after approximately 500 hours, the pressure drops, then rises more slowly to a nearly constant, or equilibrium, level that is maintained through the rest of the injection history. The equilibrium pressure is somewhat less than predicted by the model. This could results from an incorrect estimate of pore pressure or many other factors. 7 ( Model Pressure Results on (ll~~" Log-Time Seale '-V 3500 -¡. Co ~ 2000 = I!! A. .. g 1500 't: ::I II) 3000 2500 1000 500 0 100,00 1000,00 10000,00 Hours on Continous Injection Copyright BM 2004 The same model results are shown on a logarithmic time scale. The model injection was extended beyond 1.5 million barrels to address questions asked regarding future cuttings disposal. 8 Fracture Geometry V5. Slurry (I.i~~" Volume Injected 6000 1000 5000 ;: £ J 4000 ." <: .. .<: 0> ~ 3000 J ." i 2000 0 Cumulative Barrels Injected Copyríght 8M 2004 The model predicts that the bounding coals should restrict fracture height growth to approximately 350 feet. The top of the predicted fracture is at 4200' MD and the bottom at 4720' MD. This result is similar to the model results from the 1996 study. Coals in the Kenai area have repeatedly been shown to provide substantial barriers to fracture height growth and may cause fracture blunting, re-direction, and even formation of horizontal fractures. The equilibrium treating pressure established in the project is very close to 1.0 psi/ft frac gradient, which is approximately the overburden stress gradient. This is consistent with the formation of multiple horizontal fractures at formation bedding planes, along with a system of near-vertical fractures at various azimuths. The model represents the fracture primarily as a vertical planar fracture, but accounts for slurry volume stored in "transverse" fracture components. The model predicts the establishment of a stable fracture height and continued length growth. At the end of the current injection period, of about 700,000 bbls, the frac half-length is estimated to be 3100 feet. Continuing the injection to 1.5 million barrels may result in some additional length development, but the fracture is expected to remain in the same height. The added volume is expected to be taken up by "inflation" of the secondary fracture systems associated with the main vertical fracture. 9 ( Fracture Geometry V5. Log Slurry n:~!~' Volume Injected T 6000 1000 5000 = .è ! 4000 ..J i l' CI ;j! 3000 f! ~ !. ¡ 2000 f! 0 Cumulative Barrels Injected Copyríght 8M 2004 The model-predicted fracture geometry is shown as a function of total slurry volume injected, on a logarithmic scale. The breaks in the growth rate are caused by spatial variations in rock properties and periods of quiescent length development probably contain periods of substantial width change or development of secondary "transverse storage". An average exponential growth rate can be estimated from the overall trend and used for approximate predictions of fracture geometry. 10 ¡ , " KU 24-7 Disposal Project ~^ Conclusions ~ r,.",,,,,, IX ,,=,,,,,,,,," , . The current "Iook-backll model åives similar results to the pre- injection model study conducte in 1996 . The fracture height is expected to be contained by a series of substantial coal seams above and below the perforated interval . A current fracture height of 300-400 feet is expected, with a length of 3000-3200 feet ~ . Extension of the injection volume up to . .8 million barrels should not result in excessive growth i r cture length or height . The two, tubing strings appear to be in communication, so accurate localization of injection is not possible . Data used to constrain the model are incomplete and the results ( presented here are based on general trends of the observed .. injection pressure and may. not be accurate Copyright 8M 2004 The results of the model are as accurate as can be, based on the available data. In-situ stresses and rock properties are based on digital log data, with poorly defined estimates of original and current pore pressures in the disposal zones and surrounding rocks. No direct measurements òf frac geometry or growth have ever been made to help constrain the model. Within these limitations, the current model predictions give results similar to the previous model study. Fracture height is predicted to be dominated by bounding coals. Continued injection of up to 1.8 million barrels of slurry is not predicted to substantially alter the current fracture geometry. 11 Alaska Oil and Gas Conservation Commisssion - Conservation Orde... ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Anchorage Alaska 99501 , :}./ D I (p ,~ 333 West Seventh Avenue, Suite 100 Re: Application by Marathon Oil Co. for Waiver of Certain Wellhead Equipment Requirements of 20 MC 25.200 for Kenai Field wells. ) Conservation Order No. 533 ) ) Kenai Field: All Pools ) ) October 4,2004 ) ) SCANNED MAR 1 0 2005 IT APPEARING THAT: 1. By letter dated August 8, 2004, Marathon Oil Company ("Marathon"), the field operator, applied to the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") for waiver of certain wellhead equipment req uirements of 20 AAC 25.200 for Kenai Field wells. 2. Notice of opportunity for a public hearing on the application was published in the Anchorage Daily News on August 6, 2004. 3. No request for a hearing was received. 4. No written comments on the application were received. FINDINGS: 1. 20 AAC 25.200 requires that wellhead equipment include valves and gauges on tubing and all well annuli. 2. An AOGCC field inspection revealed that a number of Kenai Field wellheads are not equipped with valves and gauges on all well annuli, and are thus not in compliance with 20 MC 25.200. 3. The Kenai Field is a mature gas field in which reservoir pressures have declined substantially since production commenced. Well pressures in the Kenai Field are now low relative to other Alaska fields, ranging from a minimum surface pressure of approximately 100 psi to a maximum surface pressure of approximately 1000 psi. 4. Low pressure in the inner annulus of Kenai Field wells means that there is little risk of overpressuring the outer annulus. 5. Well tubulars in Kenai Field wells are of sufficient burst pressure rating to contain the full range of reasonably anticipated well pressures. 6. The wellheads of many Kenai Field wells were installed in cellars below ground level, making access to the outer annulus difficult and somewhat hazardous. CONCLUSIONS: 1. Operation of subject Kenai Field wells without valves and gauges will not compromise well control or safety. 2. Where appropriate, during future well workovers Marathon may retrofit Kenai Field wells with equipment sufficient to bring the subject wells into compliance with 20 AAC 25.200. NOW, THEREFORE, IT IS ORDERED: 1. Pursuant to 20 AAC 25.505, Marathon's application for waiver of 20 MC 25.200, requiring valves and gauges on all well annuli, is hereby granted. This waiver applies to the following Kenai Field wells: lof2 3/10/2005 12:58 PM Alaska Oil and Gas Conservation Commisssion - Conservation Orde... ) 2. Where appropriate, as part of future well workovers, the Commission may require Marathon to retrofit the subject wells with valves and gauges so that the wells comply with 20 AAC 25,200. DON E at Anchorage, Alaska and dated October 4, 2004, John K. Norman, Chair Alaska Oil and Gas Conservation Commission Daníel T. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission '::::t::rtli.Lmmtly<:ti¥>:" Conservatìon Order Index I..tome Webrnaster 20f2 3/1 0/2005 12:58 PM ( MEMORANDUM ( State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich DATE: October 30, 2003 Commissioner -,'\0!-7 /7 II ; ü\ 1)) SUBJECT: Mechanical Integrity Tests THRU: Jim Regg \;\ rålt1 Marathon P.L Supervisor Pad 41-18 KU 24-7 FROM: Lou Grimaldi Kenai Unit Petroleum Inspector Kenai Gas Field ~ON. CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well KU 24-7 Type Inj. P TV.D, 4313 Tubing Vacuum Vacuum Vacuum Vacuum Interval V P.TD, 182-016 Type test P Test psi 1500 Casing 1000 1660 1610 1580 P/F P Notes: Initial test after "Seal-Tits" squeeze Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ, S = SALT WATER INJ, N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details I arrived to find the pump crew rigged up on the well. This well had a severe casing leak and had received an application of "Seal- Tite". Once pressure was applied I observed a 70 psi (Non-Linear) decrease in pressure over 30 minutes. It will be interesting to see how this repair stands up to time. Yearly pressure tests should be witnessed. M.LT.'s performed: One Attachments: None Number of Failures: None Total Time during tests: 4 hours cc: Denise Titus Marathon en ineer .. D" EC $ j 200'11 E",," !,:r> C' i ',," ì - ~(~A~NED t " I 1 "j MIT report form 5/12/00 loG. 2003-1 030_MIT _KGF _KU_24-7 Jg.xls 11/20/2003 KU 24-7 Disposal Well Subject: KU 24-7 Disposal Well Date: Fri, 31 Oct 2003 16:36:13 -0900 From: "Titus, Denise M." <DMTitus@MarathonOil.com> To: "Winton Aubert (E-mail)" <winton_aubert~admin.state.ak.us> CC: "Susich, Mark L." <MLSusich@MarathonOil.com> Dear Mr. Aubert, Following a sealant application, we were able to get a successful MIT for Marathon well KU 24-7 as witnessed by AOGCC Representative, Lou Grimaldi on 10/30/03. Please note that we will be resuming our disposal activities into this well. Please let me know if you require any further information. Thanks, Denise M. Titus Marathon Oil Company 907/283-1333 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner THRU: Jim Regg P.I. Supervisor DATE: October 30, 2003 FROM' Lou Grimaldi Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests Marathon Pad 41-18 KU 24-7 Kenai Unit Kenai Gas Field Packer Depth Pretest Initial 15 Min. 30 Min. We,,I KU 24-7 I~,~ Inj.I~I~.v.D. I 4313 I Tubing IVaouumlVacuumlVacuumlVacuuml IntervalI V P.T.D.I 182-00161Typetesq P ITestpsil 1500 I Casingl 10001166011610115801 P/FI P Notes: Initial test after "SeaI-Tite" squeeze Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) I arrived to fred the pump crew rigged up on the well. This well had a severe casing leak and had received aa application of"Seal-Tite". Once pressure was applied I observed a 70 psi (Non-Linear) decrease in pressure over 30 minutes. It will be interesting to see how this repair stands up to time. Yearly pressure tests should be witnessed. M.I.T.'s performed: One Attachments: None Number of Failures' None Total Time during tests: 4 hours cc:' Denise Titus (Marathon engineer) MIT report form 5/12/00 L.G. MIT KGF KU 24-7 10-30-03 LG.xIs 10131/2003 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Reudrich Commissioner THRU: Jim Regg P.I. Supervisor DATE: August 19, 2003 FROM' Jeff Jones Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests Marathon 34-31 KU 24-7 Kenai Unit Kenai Gas Field Packer Depth Pretest Initial 15 Min. 30 Min. I WellI KU 24-7 I Type Inj. I N I T.V.D.14313 ITubingI o I o I o Io I lntervall 1I .... P.T.D.I 182-016 ITypetestl P ITestpsiI 1078 I Casingl O I 2100 I 20701 20401 P/F I _F ...I I Notes: Operator rep. estimates 40 +/-BBLS to fill annulus prior to MIT. . .cm/,%-FN+-,,~ &')tz;'c/, .,J(?~j, ,,~ , I Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details August 19, 2003: I traveled to Marathon Oil Co.'s injection well KU 24-7 in the Kenai Gas Field to witness an annual MIT. Wayne Cissel was the Marathon representative for the test; which was performed in a safe and proficient manner. The pre-test pressures were observed to be stable and the standard annulus pressure test was then performed. The test pressure decreased 60 PSI over a 30 minute period and did not appear to be stabilizing. The casing pressure was observed an additional 30 minutes to allow for stabilization, which did not occur. The test pressure was reduced 500 PSI to 1500 PSI and monitored for 30 minutes and the same linear pressure loss was noted. I advised Mr. Cissel that he should allow no further injection in this well until approved by the AOGCC. Summary: I witnessed an unsuccessful MIT on Marathon's injection well KU 24-7 in the Kenai Gas Field. M.I.T.'s performed: 1_ Number of Failures: Attachments: Well bore schematic (1) Pressure chart (1) Total Time during tests: 3 hrs. ,,cc: Don Irwin (KGF Foreman MIT report form 5/12/00 L.G. MIT KGF KU 24-7 8-19-03 JJ.xls 8/19/2003 ' Date: 8/19/03 Time: 3:37:54 PM From: To: Jim Regg t'~" . . ,,~r, , - ~- ,Jr ~ · .., "'. . ' . . .... . '... ~ . ',: .... ~-': .... ,.:....... . . ~' ':: ...... '.,'~,,, , .'..' '--~.. , .., .., .. :-,~, .... ..,....:.. ..... .. /.'. .' .... ...,..~,~ ..' .. .~,' . ~' . , ,, .,-- .. . . ~- ~, :" ~ .... · , ~. · ·,. ,- '. ...."'., ' . .'~ ......... -' i'. . . -. '.'i .......... :.. · . .' ~; ', ..' . ' ' .... '". : .:.~.~.?-7" ~,.'. .... ' .... :7" :.../~;... .... ~.~i :~.' . '. ' 7"~...:~.'T'.. '. '~>.,. . 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'.. j .'..'..'. .. . . . ...... ,.,,.,,, :.::,,;; , , , ,:.:,.,,:,??,:.?,,., ;,,,,?::.,;~.:~',:.:::L~:.;~,~,~ ,:,.,.,,,,:,:.,: ~, :' .~,::'..;..~,j',,',.::,'.,.'.,,,::, Y.:Y:','.,::':"::',';', . ..' ' .j ..... :........ ,',..,,'.,?,:::::':, .,,,..,.:.;.,? .... ,. ,,,'.j.:~,..,..,,..'.:':'..,.; :.,: ,,,.;:,,,', :??::~,'.~.,,?.;?:':,'.,,::~;~. :,'.:;::;': ,:.,,,.,.,,,,.: ....' 7, ,'.'," .'," .7.' ~' ".".' ', ,,,".'.'7",:: ,'.','., ~,,',..'.: :: .::,,..,,. . :. .; ,. ;; :: :':,? ,'?:, ,,.',.,':.,','.v:: . '...':.'................'.:)>....~.:.:.....:...' ' :.:..::...:.... ~£~ILEi.~ (~OVER PAGE · To' Jim Regg Sent' 8/19/03 at 3:38:02 PM S=l~ject · Attachments to MIT KGF KU 24-7 8-19-03 JJ.xls Hello Jim, please see attachments... Thanks, Jeff 3 (including Cover) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor [~ Chair V- THRU: Tom Maunder P.I. Supervisor FROM: John Crisp Petroleum Inspector DATE: June 27, 2002' SUBJECT: Mechanical IntegritY Tests Marathon Oil Co. KU 24-7 · KU 11-17 Kenai Unit Kenai Gas Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. VVellI KU 24,7 I Type Inj. I N I T.V.D. I 4313 I TubingI o I' o I o I 0 I lntervall O P.T.D.I 1820160 ITypetestl S ITestpsiI 1500 I CasingI 1550 I 2075 I 2060 I 2050 I P/F I P Notes: Annual MIT. WelIIKU11-17 Typelnj.I N I T.v.o.I ~o~ I'TubingJ o I o I o io JlntervalI O p..'.T.D.I 1811760 TypetestI S ITestpsil 1126 I CasingI 1000 I 1700 I 1700 I 1700I p/FI_P: Notes: Annual MIT. Welll I Type Inj. P.T.D.I I Type test Notes: WellI I Type Inj. P.T.D.I I Type test Notes: Well J I Type Inj. P.T.D. I Type test Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Marathon's Kenai Gas Field to witness MIT's on disposal wells 24-7 & 11-17. A circular chart recorder was to be used to read pressures for tests on 1 l- 17. I requested Marathon Rep. Wayne Cissell to atso use a pressure gauge on each well. Zero pressure on tubing for each well was confirmed by opening each well to atmosphere during tests. No failures witnessed. Testing was conducted in a safe & efficient manner. M.I.T.'s performed: _2 Attachments: Number of FailUres: 0 Total Time during tests: 3 hrs. .cc: MIT report form 5/12/00 L.G. MIT Kenai Gas Field 06-27-02jc.xls 7/8/2002 .~HA OIL AND GAS CONSERYA~ION CO~SSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 January 11, 2002 Mr. Kyle Parker Patton Boggs LLP 1031 West Fourth Avenue, Suite 504 Anchorage, AK 99501 Re: Class II Disposal of Tracer Returns Dear Mr. Parker: %. You have asked the Commission for confirmation that your client, Marathon Oil Company ("Marathon"), is permitted to dispose of certain radioactive tracer returns in the Kenai Unit 24-7 Class II disposal well. Disposal Injection Order No. 11, issued by the Commission on November 21, 1996, authorizes the operator of the Kenai Unit 24-7 well to inject "Class II oil field fluids" in a specified interval of the well in conformance with 20 AAC 25. The Commission's regulation on underground disposal, 20 AAC 25.252, refers to 40 C.F.R. 144.6(b) for the classification of a Class II well. The latter provision, in mm, describes a Class II well, in relevant part, as a well that injects fluids that are brought to the surface in connection with.., conventional oil or natural gas production and may be commingled with waste waters from gas plants which are an integral part of production operations, unless those waters are classified as a hazardous waste at the time of injection. 40 C.F.R. 144.3 provides that the term "[h]azardous waste means a hazardous waste as defined in 40 CFR 261.3." The latter regulation excludes the following from the definition of hazardous waste: "Drilling fluids, produced waters, and other wastes associated with the exploration, development, or production of crude oil, natural gas or geothermal energy." See 40 C.F.R. 261.3(a)(1) and 40 C.F.R. 261.4(b)((5). Marathon has employed the firm ProTechnics to assist in evaluating well completions using ProTechnics' radioactive tracers known as "Zero Wash." You have informed the Commission that the tracers aid in detailing the completion placement and effectiveness of Marathon's hydraulic fracturing and acidizing treatments. You have also informed the Commission that the use and disposal of the radioactive tracers are regulated by the Nuclear Regulatory Commission. Mr. Kyle Parker January 11, 2002 Page 2 of 2 The Commission understands that sands retumed to the surface may contain some Zero Wash tracer beads and that it is such sands that Marathon wishes to dispose of in the Kenai Unit 24-7 well. Since this material has been brought to the surface in connection with conventional oil or gas production operations, it appears to qualify as Class II waste. The second criterion listed in 40 C.F.R. 144.3, concerning classification as hazardous waste, may apply only to waste waters from gas plants. However, even if this criterion applies to the Zero Wash. tracer returns, they appear to qualify as non-hazardous wastes under the exclusion for "wastes associated with the exploration, development, or production of crude oil [or] natural gas." It should be noted that the disposal of unused tracer material is an entirely different matter. Such material would not appear to qualify as a Class II waste. The Commission understands that the only tracer material Marathon proposed to dispose of in the Kenai Unit 24-7 well is material that has actually been used downhole for bona fide well completion purposes. Please note further that the Commission's authorization under Disposal Injection Order No. 11 does not relieve the operator from the responsibility to obtain any additional authorizations that may be required from federal, state, or local authorities. Sincerely, C~~y ec~sli Taylor~ Chair COT\jjc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammille Taylor~-~ DATE: September 1, 2001 Chairman .. _~,~UBJECT: Mechanical Integrity Test THRU: Tom Maunder Ma~hon Oil "~, Kenai~Gas Field, KU 24-7 Petroleum Engineer 182-016 FROM: Lou Grimaldi Kenai Unit Petroleum InSpector , Kenai Gas Field NON- CONFIDENTIAL iPre{est Initial 15 Min. 30 Min. Pa~er ~ ...... I' W.ellI KU24-7 I Typelnj. I Mud '1 T.v.D. I 43'~3 I Tubingl 25001 2,500 I 2500, I 25(X)I~.~.-.1 o. ! PTDI 189-o16 I~'petestl . IT_~_'_Psii ,o a I 2~1 2~01 2~1 e~F I e .... I Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey Interval I= Initial Test 4= Four Year Cycle V- Required by Variance W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details This well had exhibited communieafi°n with the long string. Wireline plugs had been set in the two tubing strings and a pressure test had been performed on the tubing strings and easing together. I arrived to find this pressure test applied. The PressureS held'constant for over thirty minuteS with: no loss observed. The casing exhibited integrity and during injection pressure will be held on the annulus. ~6' Well sh°Uld be observed for changes in the future. M.I.T.'s performed: ! Attachments: None Number of Failures: None Total Time during tests: 3 Hou.m cc: Gary Eller (Marathon Ellaineer) MIT rePort form 5/12/00 L.G. MIT KU 24-7 9-1-01 LGl.xls 9/4/01 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission p.T.D.I Notes: Operator noted annulus pressure drop while inj .ecfing tubing long stri'ng. TO: Julie Heusser DATE: August 23, 2001 Commissioner J) ,, ,.,,~^ _,,~,P-?SUBJECT: Mechanical Integrity Tests THRU: Tom MaunderV~y~_(~,;,lyt°'' -~''. ~,~Y Marathon Oil Co. P.I. Supervisor ~.~"'~ ~ KU 24-07 / 41-18 Pad Kenai Unit FROM: Jeff Jones Kenai Gas Field Petroleum Inspector Packer .Depth "'Pre~e~t i'niti;~l' 15 Mi'r~. 30 Min.' ' ' KU24-? 'l"i:y i,j;i" N '1 T.~/'.D.'i 4313 'l'TUbi~l 2400"1_ :i'100"1 't,i 2o.I .i . o0o 182016 IT b tl M . IT.tPSil',, !0.?,8 IC,,'%1'.' 2~ .I,, ,I 219°,,I 2150 I P/F .I E Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details .Thursday, August ~ 200.1; I traveled to Marathon Oil Co.'s Kenai Gas Field to witness an MIT on waste disposal injectiOn well KU 24-7. Wayne Cissel was the Marathon Oil representative in charge of testing today and he performed the test in accordance with AOGCC regulations. Mr. Cissel stated that during injection the operator had noticed a drop in the annulus pressure from 2100 psi to $00 psi. Well KU 24-7 is a dual string completion and has a TT plug set at 4639' KB in the long string. The pre-test pressures were monitored for 15 minutes and were observed to be stable. The tubing pressure was then lowered to 1100 psi and over the 30 minute test time this pressure increased 300 psi and did not stabilize, I returned the following day and observed the annulus and tubing pressures for 30 minutes. I noted that the tubing (1990 psi) and the annulus (1775 psi) pressures had nearly stabilized. It appears that there is communication between the tubing long string and the annulus, but that the casing may have integrity. I requested that the operator provide recorded injection pressure data from this well to the AOGCC for further evaluation. Summary; I witnessed an unsuccessful MIT on Marathon Oil Co.'s Kenai Gas Field waste disposal injection well KU 24. 7. 1 well house inspection; no exceptions noted. M.I.T.'s performed: 1_ Number of Failures: 1_ Total Time during tests: 2 hr~: Attachments: Chart Recorder Pressure, Data (1) cc; Don E.m4. 'O ( KGF Fpreman! MIT KGF KU 24-7 8-23-01 JJ.xls 9110/01 J,P~.E~image ~,ox4~u p~xe~s I of I 9/10/01 10:51 AM MEMORANDUM TO: THRU: FROM: State of Alaska Alaska Oil and Gas Conservation Commission Julie HeusserA~J~ '~.~\,7")/~ DATE: July 25, 2001 Commissioner · SUBJECT: Mechanical Integrity Tests Maunder ~.~~ Marathon Oil Co. Tom P.I. Supervisor',""-_ , ~,>~, 41-18 / 34-31 Pad ~' Kenai Unit Jeff Jones Kenai Gas Field Petroleum Inspector .......... ..... Pa~ker Depth Pretest Initial 15 Min. 30 Min. w,,,,I,. ,. v ..T;D~I,., !811070, ITyp~t~l "'lYe~{p~l ~44 I.casingi o-i ~ I .'~.~, I"~ l'_ P/F I Notes: Well has known tubi~ leak; tubing tail plug set for test. One year interval MIT i~.T.D,I '~82o!'~ ITYpete~t..M Te~.'.'p~."' 1078 I.Casingl 1i00 2i20._i.2~20 I '2i20 Pn: lB · ~: 0..ne, year interva!. MIT, pressure ,,obi, ed for 30 min. then lowered 500, psi and observed 30 min. Wall ~k~?~:~::17'~':lTypeinJ. l' ' N ":' I T-:0-D: I.'450,5. I.T...~n.I :"o .! -o !' '0'." I" o' :'.llntervall O P.T:O,I 18~760 .. IT.~"t~! "IT.m.. P*,! ~26 l c~n"I ~00. I ~?00...I..~700 I,~?00 I "~: I P_ Plob~: .one. yea'r interval, MIT, pres~, ',. re observed for 30 min. then 1,0were~,, 500 psi a,nd ,observed, .30 min. ,,, ',, Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER IN J. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey' A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test°s Details Wednesday, July 25, 2001: I traveled to Marathon Oil Co.'s Kenai Gas Field to wimess one year MIT's on waste disposal injection wells WD-1, KU 24-7 and KU 11-17. Wayne Cissel was the Marathon Oil representative in charge of testing today and he performed the tests in accordance with AOGCC regulations. Wells KU 24-7 and KU 11-17 were already pressured up on my arrival and the pressures were observed for 30 minutes with no changes noted. The pressure was then decreased 500 psi on each well and monitored for an additional 30 minutes with no changes noted. Well WD~ 1 has a known tubing/t~!~anda g~!tail~lug was: set to facilitate the test. Once pressured up, the tubing and casing pre~§~' ~u~li~ze~ '~:~:~abii~cd at'i~00 ~si, :All three Wells passed the pressure tests and are suitable for continued injection' :' :: :: ::; Summary_: I witnessed successful MIT's on Marathon Oil Co.'s Kenai Gas Field waste disosal injection wells WD-1, KU 24-7 and KU l l- 17. 3 wellhouse inspections; 0 failures. M.I.T.'s performed: _3 Number of Failures: 0 Total Time during tests: 5.houm Affachments: 0_ C.,c: Dpn Erwin, ( KG,F, Foreman} MIT KGF WD-1,KU 24-7, KU 11-17 7-25-01 JJl.xls 8/10/01 MEMORANDUM, I State of AlaSka I Alaska Oil and Gas Conservation commissiOn ' ,,. TO: Dan Seamount ~ DATE:duly 5, 2000' ,, ,Chairman . ~/ , . I SUBJECT: Mechanical IntegritY Tests 'THRU: BlairWondzell .{~__~,. Marathon . P.I. Supervisor ..li~l~[C~. :Kenai Gas Field m FROM: Lou Gri al ~.~ Kenai Gas Field : pet~)leum In~-~ector Non-Confidential ___ : · Packer Depth ~ Pretest init'iai 15 Min. 30 Min. ., ., Well WD-1 ,Typ'e Inj. F T.V.D. 2174 Tubing 250 1850 1850 1850 Interval O ,.,,P.T.D. 181-107 Type. test P Test psi 544 Casing 200 1500 1500 1500 P/F ~P Notes: Lease water injector., Yearly test Well~, 24-7 lTypelnj. I O ' T.v.D. 4313 Tubing 390 440 440 440 Interval O ,, P T.D.l~;~2~i:~l~ype test111900P , T, est psi 1078 Casing 1775 1765 1760 P/F P Notes: Mud slurry injector. Yearly test Well! 11-17 IType Inj. 1 N · I T'v'D' 4505 Tubing 0 ' 0 0 0 Interval O P.T.D.! i81-176 lTypetestl P,~Test psi 1126 Casing 2120 1820 1820 1820 P/F Notes: Mud, slurry injector, Shut in. Yearly test. _ Well Type Inj. T.V.D. Tubing Interval P.T-D.i Type testl Test Psi 0 Casing , , P/F Notes: Well ' ' Type Inj. T.V.D. Tubing ' Interval ,',P.T.D. Typ'e testl Test psi 0 Casing P/F Notes: ..... Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring I= Initial Test G = GAS INJ. ' P= Standard Pressure Test 4= Four Year CyCle · S: SALT WATER I NJ. .. R= Internal Radioactive Tracer sU~-ey .... V=, Required by Variance ,,. N = NOT INJECTING A= Temperature Anomaly Survey W= iTest during Workover O=OTHER (see notes) D= Differential Temperature Test O= ,Other (describe in notes) ['arrived at the WD-1 w~il on the main pad of the Ker~ai Gas Field to find a wireline unit rigged up on WD-1. A "PX" iwireline plug had been set in the landing nipple below the packer. The Annulus was pressured up to 1600 psi in my presence. Tubing pressure was 350 psi. The casing pressure slowly bled off with only a slight rise in robing pressure which indicated the plug was possibly not holding. A "W" circulating device was set on top of the plug. The tubing pressure was pumped up to 1850 psi and the annulus was pressured to 1500 psi. The test went well with both Tubing and Annulus remaining at these pressures for thirty minutes. Well's 24-7 and 11-17 were already pressured tiP and had been in this state for approximately 48 hours. I had Wayne' Cissel (Marathon rep.) reduce the pressures and I observed the wells in this state for thirty minutes with negligable change. All wells eXhibited casing integrity and should be "OK" for continued injection. The ~iiling rig that iS i~ 'operation in the field at this point could do a workover on WD-1 which would bring this well into full compliance without variancel and greatly shorten the test time experienced annually. ,. , .I.T.'s Performed: 3 Number of Failures: None Total Time duri g te~ts: ' ' , , Attatchments: None I [ ~ Don,E,rwin,(Marathon) I ,, Alaska He,ion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Mr. Blair Wondzell, P.E. State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 May 18, 2000 Reference: Kenai Gas Field Well KU 24-7 DIO #11 API# 50-133-20352 pr-D- [8 -ot6 Pursuant to our telephone conversation May 17, 200Q/attached is the 2200 psig annular pressure test performed on the KU 24-7 on May 02, 2000."'This is in addition to the successful MIT performed and witnessed by AOGCC inspector L. Grimaldi on July 02, 1999. At the next mutually agreeable time, Marathon will gladly provide the opportunity to witness an MIT on the KU 24-7. Sundry Form 404 was submitted May 19, 2000, notifying that waste disposal commenced into the KU 24-7L. If there is any additional information that can be provided, please do not hesitate to call 907-564-6303. Sincerely, Ralph J. Affinito Production Engineer A subsidiary of USX Corporation Environmentally aware for the long run. 25OO MARATHON OIL COMPANY ALASKA REGION Kenai Gas Fie~d Well KU 24-7 05/02/00 Pressure Test 200o 150o lOOO 5OO 0 1~ !08!00 AM 11:14:24AM 11:28:48AM 11:43:12AM 11:57:36AM 12:12:00PM 12:26:24PM 12:40:48PM 12:55:12PM I ' .... Ai~UlUS Pressure ---~ I~ng Stiing Pre~sure Shod Siring Pressure 1:09:36 PM III WELL KU 24-7 WELL SCHEMATIC CASING &::: ABANDONMENT DETAIL I. Rotary Table 0 0.0' il. Cameron 3-1/2" Dual Tbg Hanger O 27.68' III. 20" 94~ H-40 DHve Pipe 0 178' IV. 13-3/8" 61~ K-55 Casing 0 2003' V. E.T.D. 0 4878' TOF ~ 4848'(30' of Tbg.) VI. 9--5/8" 43.51~ & 47~ N-80 Csg 0 5801' A-10=__ S~nd ~ Send ~ Sqz'd,~ , TUBING ,pETAl LONG STRING: Z- 1,/2 9.2~ ]~]--80 TUalNG _ le 2. B 3. 4. 5. 6. 7. 8. 9, Otis "XA" Sliding Sleeve 0 4273.5;3' Baker Model "A-5" Dual Packer O 4312.79' .Blast Joints From 4385.29' to 4581.52' Otis "XA" Sliding Sleeve ~ 4639.47' Locotor Sub ~ 4677.12' Top of 13.72' Seal Assembly 0 4678.00' Model "S-2" Prod. Packer ~ 4679' Offs "X" Nipple {3 4691.72' 4694' Cut Tbg on 7/26/88 SHORT STRING: Z-t/'2" 9.2~ N--80 TUBING A. Otis "XA" Sliding Sleeve e 4267.57' B. Baker Model "A--5" Dual Packer 0 4314.93' C. Otis "X" Nipple ~ 4325.84' PERFORATION DA TE IN TER VA L 5/27/82 4890'-4905' 5/28/82 4905'-4925' 5/29/82 4410'-4490' 5/30/82 4525'-4560' 5/30/82 4410'-4490' 7/88 4696-4708' RECORD CONDITION B-4- Sd. Sqz'd 7/88 B-4 Sd. Sqz'd 7/88 A-lO Sd. Production A--11 Sd Proaluction Reperformte A-tO Sd. B-J, Sd. Production Checked by: NKS Drawn:10--19--S8 BAW Alaska h~gion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 May 18, 2000 Mr. Steve McMeans State of Alaska Alaska Oil and Gas Cons Comm 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: KU 24-7 Dear Mr. McMeans' Enclosed is the completed REPORT OF SUNDRY WELL OPERATIONS form for well KU 24-7L and the schematic. Please advise if additional information is required. I can be reached on 564-6303. Sincerely, Ralph J. Affinito Production Engineer Enclosure A subsidiary of USX Corporation Environmentally aware for the long run. g:~cmn\drlg~kgf~wells~ku 11-8sV~,OGCC01 a.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdownm Stimulate Plugging Perforate Pull Tubing__ Alter Casing m Repair Well__ Other X 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 728'S & 748'W FROM NE CORNER SEC. 18, T4N, R11W, SM At top of Productive Interval 142' FSL & 3,015' FEL SE CORNER, SEC. 7 T4N, R11W At Effective Depth 139' N & 3,008'W F/SE CORNER, SEC. 7 T4N, R11W At Total Depth 397' FSL, 3563' FEL SE COR, SEC. 7, T4N, R11W 5. Type of Well: Development X Exploratory Stratigraphic Service 10. Datum Elevation (DF or KB) 97 feet 7. Unit or Property Name Kenai Unit 8. Well Number KU 24-7L 9. Permit Number APl Number 50-133-20352 11. Field/Pool Sterling #4 12. Present Well Condition Summary Total Depth: measured true vertical 5820 feet Plugs (measured) 4796 feet Effective Depth: measured true vertical 4878 feet Junk (measured) 4080 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented 178' 20' DRIVEN 2003' 13-3/8" 1225 SX 5801' 9-5/8" 1900 SX A-10-4410'-4490';A-11 4525'-4560'; B-2-4696'-4708' true vertical A-10 -3726'-3767'; A-11 3813'-3840'; B-2 - 3943'-3951' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) SS: 3-1/2", n-80, 9.2# @ 4326' LS: 3-1/2", N-80, 9.2# @ 4694' BAKER DUAL PKR @4313' S-2 PRODUCTION PKR @ 4679' 0RICINAL Measured De~h 179' 2003' 5801' True Vertical Depth 178' 1849' 4780' RECEIVED Alaska 0il & Gas ~r~. Commission ~d~or~e 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) Marathon Oil Company hereby notifies that on April 27, 2000 (Conversion Date) injection commenced into the KU-24-7L wellbore. The KU 24-7 is an approved Class II waste disposal well per order DIO #11 Treatment Description Including Volumes Used and Final Pressure 14. OiI-Bbl Prior to Well Operation 0 Subsequent to Operation 0 Representative Daily Average Production or In!ection Data Gas-Mcf Water-Bbl Casing Pressure 0 0 0 0 Tubing Pressure 0 15. Attachments 16. Status of Well Classification as: Copies of Logs and Surveys run Daily Report of Well Operations __ Oil Gas 17. I hereby c~e ~~ correct to the best of my knowledge. Signed Ralph Affinito Suspended Tele 564-6303 Title Production Engineer Service Date 05/17/00 Form 10-404 Rev. 06/15/88 Submit in Dupl'hs~ WELL KU 24-7 WELL SCHEMATIC I!! CASING &: ABANDONMENT DETAIL I. Rotary Table 0 0.0' II. Cameron 3-1/2" Dual Tbg Hanger {~ 27.68' !11. 20" 94~ H-40 Drive Pipe ~ 178' IV. 13-3/8" 61~ K-55 Casing 0 2003' V. E.T.D. ~ 4878' TOF 0 4848'(30' of Tbg.) VI. 9-5//8.' 43.5~ & 47~ N-80 Csg 0 5801' A-lO----- Sand A-11~ I Sand --_---- 6, _-= gL,V ' Sand ~ Sand TUBING DETAII~ LONG STRING: ..,=-.. 1/2" 9.2~, ]~--aO TUBING 1 2. B 3. 4. 5. 6. 7. 8. 9: Otis "XA" Sliding Sleeve O 4.273.53' Baker Model "A-5" Dual Packer 0 4312.79' .Blast Joints From 4385.29' to 4581.52' Otis "XA" Sliding Sleeve ~ 4639.47' LOcator Sub ~ 4677.12' Top of 15.72' Seal Assembly ~ 4678.00' Model "S-2" Prod. Packer 0 4679' Otis "X' Nipple ~ 4691.72' 4694' Cut Tbg on 7/26/88 SHORT, STRING: .Y-1/'2." 9.2f[/N--80 TUB/ND.,. A, Otis "XA" Sliding Sleeve e 4267,57' B, Baker Model "A-5" Dual Packer ~ 4314.93' C. Otis "X" Nipple ¢3 4325,84' PERFORATION · DA T£ INTERVAL 5/27/82 4890'-4905' 5//28/82 4905'-4.925' 5/29/82 44.10'-.,~.90' 5/30/82 4525'-4560' 5/30/82 44.10'-44.90' 7/88 4696-4708' RECORD B-4 Sd. Sqz'd 7/88 B-4 Sd. Sqz'd 7/88 A-lO Sd. Production A--11 Sd Pro~luction Reperforate A-lO Sd. B-J, Sd. Production Checked ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 25, 1998 Gary Etler Production ENgineer Marathon Oil Company P.O.: Box 196168 Anchorage, Alaska 99519-6168 Re' Kenai Gas Field Well 24-7, Request for extension to DIO/gl 1 Dear Mr. Eller: The Commission has reviewed your November 20, 1998, request to approve an extension to Disposal Injection Order ("DIO") #11 which authorizes injection of Class II oilfield waste into the Kenai Unit ("KU") 24-7 well. Under 20 AAC 25.252(j), if disposal operations are not begun within 24 months after the approval date, the approval will expire unless the Commission authorizes an ex-tension. The Commission approved DIO #11 on November 20, 1996. Marathon has not yet used the well for disposal injection, but anticipates doing so within the next 24' months. The well has not been physically altered since the Commission granted DIO #11, and Marathon continues to perform yearly mechanical integrity tests ("MIT") on the well. The Commission hereby approves the requested extension to DIO #11, effective November 21, 1998. A MIT must be performed on KU 24-7 prior to initial disposal and the results forwarded to the Commission. The Commission must also be notified at least 24 hours prior to the MIT to allow a representative to witness the test. . Chairman i*-"-, /,---~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM,,JSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) UNION OIL COMi~ANY OF CALIFORNIA (UNOCAL) KB 97' Feet 3. Address 6. Unit or Property name P.O. BOX 190247, ANCHORAGE, AK. 99519-0247 KENAI UNIT 4. Location of well at surface KGF PAD #41-18 728'S & 748'W FROM NE CORNER SEC. 18, T4N, RllW, SM. At top of productive interval 142' FSL, 3015' FEL SE COR, SEC. 7, T4N, RllW At effective depth 139' N & 3,008' W F/SE CORNER, SEC. 7, T4N, RltW At total depth 397' FSL, 3563' FEL SE COR, SEC. 7, T4N, RllW 7. Well number KU 24-7L 8. Approval number 8-527 9. APl number 50-- 133-20352 10, Pool STERLING #4 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface. Intermediate Production .. Liner Perforation depth: measured 5820 feet Plugs (measured) 4796 feet 4878 feet Junk (measured) 4080 feet Length Size Cemented 178 ' 20" DRIVEN 2003' 13-3/8" 1225 SX 5801 ' 9-5/8" 1900 SX 4410'-4490'; 4525'-4560' RFClEIVEn Measured depth 179' 2003' 5801' ; 4696'-4708' T~eyertical depth 178' 1849' 4780' true vertical 3726'-3767'; 3813'-3840';3943'-3951' Tubing(size, grade and measured depth) SS: 3-1/2", N-80, 9.2# @ 4326% LS: 3-1/2", N-80, 9.2# @ 4694' Packers and SSSV(type and measured depth) BAKER DUAL PKR @ 4313' S-2 PRODUCTION PKR @ 4679' 12. Stimulation or cement squeeze summary Intervals treated (measured) CEMENT PLUG FROM 5617'-4878' (739') W/271SX OF CEMENT (3 STAGES) AND 4000 PSI. Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas~Mcf Water-Bbl Casing Pressure 1.6M Tubing Pressure SYSTEM 800 PSI 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Date //-/_.~-.~; Submit in Duplicate~ UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO. i L E A S E KENAT UNIT WELL NO. 2.4-7L .FIELD KENAT GAS FIELD DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 7/18/88 7119188 7~20~88 ., 7/21/88 7/22/88 7/26/88 8/17/88 5617' CTM 5217' 4880 ' 4880 ' 4878' Moved in rigged up Otis 1-1/4" coiled tubing unit. Bled well down from 600 psi tubing pressure. Pumped (5) bbls of formation water down coiled tubing, (10) bbls of formation water down 3-1/2" tubing. (Well static). Nipple down Larkin head and retrieved 4905' of l-l/4" coiled tubing. Rigged up injector head with BORE and pressure test same to 1500 psi with BJ equipment, ok. Ran in hole with tubing locator on l-l/4" coiled tubing. Tagged bottom at 5617' CTM. Pulled out of hole and shut in well. From 0700 hours to 1900 hours. Pumped volume of 3-1/2" tubing plus 9-5/8" rat hole (115 bbls) of formation water.. Rig up Schlumberger with lubricator and pressure test to 1500 psi. Run TDTP log from 5610' to 3600' and repeat. Rig down Schlumberger and rig up Otis coiled tubing unit. Ran in hole with l-l/4" coiled tubing with full open nozzle to 5602'. Pumped 20 bbls of water ahead 143 sx of class "G" cement plus additives at 0.5 BRM and 2550 psi. Pulled out of hole with coil tubing to 5217' while displacing. CIP at 2330 hours 7/19/88. Pulled out of hole. Estimated top of cement at 5217'. Ran in hole with coiled tubing and full open nozzle, tagged top of cement at 5214' Mixed and pumped 120 sx of class "G" cement plus additives at .75 BRM ~ 4100 psi. Pulled out of hole while displacing. CIP at 1500 hours 7/20/88. Pulled out of hole and shut well in until morning. Estimated top of cement at 4880'. Ran in hole with tubing and tagged top of cement at 4901'. Mixed and pumped 7.5 sx of class "G" cement plus additives at .75 BPM and 4000 psi. Pulled out of hole while displacing, CIP at ll30 hours 7/21/88. Pulled out of hole and shut in well. Well dead 0 psi, ran in hole with coiled tubing and tagged top of cement at 4878'. Circulate hole clean and pulled out of hole. Make up and run tubing locator with 2.7" gauge cutter stopped at 2530'. Pulled out of hole. Run a 2.25" jet nozzle to 4724'. Pulled out of hole. Run 2.55" gauge cutter to tubing tail at 4724', tag top of cement at 4875' CTM. Pulled out of hole and rig down Otis CTU. Release crews at 1900 hours 7/22/88. From 0600 hours to 1900 hours. MIRU APRS wireline unit at 1030 hours. Ran in hole with collar locator and one l-il/16" sinker bar to mule shoe at 4724_" WLM. Pulled out of hole. Made up 2.70" jet cutter and ran in hole with sinker bar. Tag "X" nipple at 4692' and jet Cut the tbg at 4694' WLM. Pulled out of hole and rig down APRS. Release crews at 1430 hours 7/26/88. Junk in hole consists of one joint 3-1/2", 9.2#, N-80 (30.85') and. mule shoe (.66'). Estimated top of fish at 4848'. MIRU Schlumberger and perforate from 4696'-4708'. ..... ' '/-'"' STATE OF ALASKA "'~ ALASr'.~, OIL AND GAS CONSERVATION COMk .3SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown '-q Re-enter suspended well .."q Alter casing Time extension ? Change approved program ~ Plugging ? Stimulate ~ Pull tubing ;-' Amend order i'- Perforate ,~ Other 2. Name of Operator 5. Datum elevation (DF or KB) Union 0il Company of Ca.].iforn±a (UNOCAL) KB 97t feet 3. Addrel~s. 0 BOX 190247, Anch, Ak ~ 995.].9-0247 6. Unit or Property name . · · Kenaz Unit 7. Well number 4. Location of well at surface 728 FSL & 748 W from NE Corner Sec. 18, 14N, RllW, SM KU 24-7L 8. Permit number 82-16 9. APl number 50-- 133-20352 10. Pool At top of productive interval .].42' FSL, 30'15 FEL SE Cor, Sec. 7 T4N, RllW At effective depth 392' FSL, 355].' FEL SE Cot, Sec. 7 T4N, R11W At total depth 397' FSL, 3563' FEL SE Cor, Sec. 7 T4N, RllW Sterling 11. Present well condition, summary Total depth: measured true vertical Effective depth: measured true vertical 5,820 ' feet 4 ~ 796 ' feet 661 ' feet ,673 feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length 178' Size Cemented Measured depth 20" Driven 179' 2003' 13 3/8" 1225 sx true vertical 5801' 9 5/8" 1900 sx 4410' -4490'; 4525 ' -4560'; 4890' -4925 ' Tubing (size, grade a~d measured depth) · Packers and SSSV (type and measured Cepth) 3726'-3787'; 3813'-3840'; 4089'-4115' SS: 3 1/2", N-80, 9.2# LS: 3 1/2", N-80, 9.2# Baker Dual Packer ® 4~13' True Vertical depth 178' 2003' 1849' 5801' 4780' RECEIVED j i.i L -- i; k--,,,, .0il & Gas Cons. Commission Anch0ra~e S-2 Production Pkr. ¢ 4679' 12.Attachments Description summary of proposal .-. Detailed operations program ~ BOP sketctq - 13. Estimated date for commencing operation July 15, 1988 14. If proposal was verbally approved ,~u~so~ueat "¢¥'or~¢ ~.eporte~ on ~ E.'orm No. ZQ-?¢/',~. Dated.Z.~/_~//~---~ Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge l,~.z-,/~/'~~Oy D. Roberts ~ Title Environmental EnoJ_neer S~gned' Commission Use Only Date -~.~' .-~ Conditions of approval Approved by Notify commission so representative may witness ~.. Plug integrity [] BOP Test [] Location clearance ORIGINAL SIGNED ,'.v '::-~NIE C. SMITH Approved O.opY ReturneO ~. Commissic~er Approval No. (~,- c,~ ¢'~ 7 by order of the commission Date Form 10-403 Rev 12-I-85 Submit in triplicate/~. KENAI UNIT 24-7LS COILED TUBING UNIT DETAILED PROCEDURE le 2. Move in & nipple down Larkin head & retrieve 4905' of 1 1/4" coiled tubing (1 1/4" run October 8, 1986). Note' Try & spool recovered coiled tubing for future use. Do not destroy, this should be good tubing. MIRU Schlumberger & run a TDTP log from + 4950' to 2500'. Rig down Schlumberger. 3. MIRU 1 1/4" coiled tubing unit & cementing unit. 4. RIH with coiled tubing & nozzle. Lay a cement plug (326 ft3) from ETD 5661' - 4870' (781') across B-4 sand. 5, 5/8" '43.5# N-80 has a volume capacity of .0744 bbl/ft Lay the cement plug in stages, each time RIH tag TOO & calculate the remaining volume of cement to place. Circulate the hole clean & displace fluid level to 3100' MD. Monitor fluid level to confirm it is static. 7. 8, Perforate the 8-3 sand (4798' - 4818' & 4840' - 4865') underOalance using 2 1/8" 0° phased 4 SPF through tubing guns. POOH & return well to production. Oil & Oas Coos ,,~,, ~ ' Codify/SS]Ort STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM,..,$1ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of ,O, pqrator,... 5. Datum el~(vl~ti~j),(DF or KB) un].on uzi Company of California (UNOCAL) 3. Address P.0. BOX 190247, Anch, Ak., 99519-0247 6. Unit or Pr. opertyr, enaz r~t 4. Location of well at surface 728' S & 748' W of' NE Co]:., Sec 18 T4N-Rll~/ SM 7. Well number KU 24-7L At top of productive interval At effective depth At total depth 11. Present well condition summary Total depth: measured .5820 ' feet true vertical 4796' feet Plugs (measured) 8. Approval number .3.38 9. APl number 50-- 133-20352 10. Pool Kenai Gas Field Stezling Pool Effective depth: measured 5661' feet Junk (measured) true vertical 467.3 feet Casing Length Structural Conductor 178 ' Surface 200.3' Intermediate Production 5801 ' Liner Perforation depth: measured true vertical Size Cemented Measured depth True Vertical depth 20" Drlven 179' 178' 13 3/8" 1225 SX 2003' 1849 8 5/8" 1900 sxs 5801' 4890'-4925'; 4410'-4490'; 4525'-4560' 4089'-4115'; 3726'-3787'; 3813'-3840' ~bing(size, grade and measured depth) .3 1/2", 9.2#, N-80 at 4724' Packers and SSSV(type and measured depth) Baker Dual at 4.31.3' 4780' RECEIVED &laska 0it & Gas Cons. O0m[ Anchorage S-2 Production Packer ~ 4679' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure ~bing Pressure 0 psi 700 psi 0 .395 psi 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ ,~ --. ( ~.,.~)~ Signed Form 10-404 Rev. 12-1-85 Environmental Engineer Date 12/11/8, Submit in Duplicate Fe4 ~:;~ issi0a Daily Drilling Report No. ~ Made at Lsc w,, Y-- U Fie d or Prospect CASING: 19 Drive Pipe TD ETD . FORM FP24H DLT VG READINGS: 600 RPM. 200 RPM 60 RPM 6 RPM MUO: 300 RPM 100 RPM Fun Plas Gel Wi. Vis. Vis. Y .P. Str 30 RPM 3 RPM APl HIP Ph Fil Fil Cake CI Conductor Protection Liner Ca Pr/mi Sd Sol 0il Cec Daily Cost: I $ O. Acc. Cost: Used BITS: No. Size Make & Type Jet Serial Depth Size No. In Depth Out Feet Hrs. Condition PUMPS: Quan. Make & Type Stroke Liner SPM Annular Jet Press GPM Vel. Vel. BHA: BHA: BHA: HOLE CONDITIONS: Length: Length: Length: WEATHER COST BREAKDOWN Drilling Wt. Drilling Wt. Drilling Wt. RPM Alaska Oil & Gas Cons. P.U. Wt. ROT. WI. S.O. Wt. Normal Torque at Max. Torque at Wind Direction Waves Direction Location Rig Charges Fuel & Wtr. Bits: -- Stimulation & Drilling & -- WO Fluid Testing C3sing Supervision Transportation- --'-' Personnel ~ Transoortation- Material 5 ~) ~'~ RPM Cement 8, '-' Services .... (Ft. #) (amps) Temperature Wt. IFt. #) amps) __wt. Production qu,pment .2,PO0 Production . Wireline & Lo~ging Fishing Contract ~q.:~D Company RPM Labor Rig Repairs Equipment Rental Miscellaneous ~ _ 6:00 AM - NOW UNION OIL COMPANY OF CALIFORNIA Daily Drilling Report No. Lsc VG READINGS: MUD: ~ FORM 200 RPM 100 RPM Fun Plas Vis. Vis. Y.P. FP24H DLT 60 RPM 6 RPM 30 RPM 3 RPM Gel APl HIP Str Ph Fil Fil Cake CI Ca CASING: Drive Pipe Conductor Surface Protection Liner Pi/mi Daily Cost: il, -/ Sd Sol Oil Cec ,Acc. Cost: ~sed BITS: Jet Size Make & Type Size Serial Depth Depth No. In Out Feet Hrs. Condition PUMPS: BHA: BHA: BHA: HOLE CONDITIONS: ) Length: WT. Liner Length: w-r. Length: WT. WEATHER COST BREAKDOWN SPM Press Annular Jet Vel. Drilling Wt. Drilling Wt. Drilling Wt. RPM P.U. wt. Wind ROT. Wt. Direction S.O.' Wt. . Waves Direction (Ft. #) Normal Torque at , (amps) Temperature _RPM Wt. Max. Torque at (amps) RPM Wt. Location Fuel & Wtr. Transportation- Rig Charges Personnel Transportation- Bits: Material -- Stimulation & Drilling & WO Fluid Testing C3sing Supervision Cement & Production Services ....... Equipment Production . Directional Facilities Wireline & Logging Fishing Contract '54~ Company Labor Rig Repairs Equipment Rental Miscellaneous DA,L~-TOTAL 2-/: /'~" ACC. TOm / - UNION OIL COMPANY OF CALIFORNIA Daily Drilling Report No. ~ Made at TO ~O , FORM FP24H DLT VG REA~I~S.~c ~ ~ 200 RPM 60 RPM 6 RPM ~ ~ 100RPM. 30 RPM F~m ~ Gel MUD: ~1.. '~;~is.,¥is. Y .P. Sir Ph , 3 RPM , APl HiP Fil Fil Cake Daily CASING: i Drive Pipe Conductor Sudace Protection Liner R/mi Acc. BITS: Size Make & Type Jet Serial Depth Depth Size No. In Out Feet Hrs. Condition PUMPS: Guam Make & Type Stroke Liner SPM Press GPM Annular Jet Vel. Vel. BHA: Length: WT Drilling Wt. [..~iiT.(J .~RPM );~; BHA: Length: BHA: Length: HOLE CONDITIONS: WEATHER COST BREAKDOWN ~ :~.~ ~ .;~ ~.,~.: Drilling Wt RPM P.U. Wt. ROT. Wt. S.O. Wt. Normal Torque at Max. Torque at Remarks: (Ft. #) (amps) RPM Wt. Ft. #) amps) RPM Wt. Wind Direction Waves Direction Temperature Location Fuel & Wtr. Transportation- Rig Charges' Personnel Transoortation- Bits: Material Drilling & __ -- Stimulation & WO Fluid Testing Casing Supervision Cement & Production Services ...... Equipment Production _ Directional Facilities Wireline & Logging Fishing Contract C~om~any Labor Mig Hepairs Equipment Rentai Miscellaneous DAILY-TOTAL ACC. TOTAL ih/'& 12:00 PM - NOW 6:00 AM - NOW /--'". STATE OF ALASKA ALASN-~ OIL AND GAS CONSERVATION COMk ,SION APPLICATION FOR SUNDRY APPROVALS feet~,~ 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator Union 0il Company o¢ California (UNOCAL) 3. Address. BOX 190247, Anch, Ak., 99519-0247 4. Location of well at surface 728' S & 748' W of NE Cor., Sec. 18, T4N, RllW, SM At top of productive interval At effective depth At total depth 5. Datum elevation (DF or KB) KB 97 ' 6. Unit or Property name Kenai Unit 7. Wellnumber ~U 2a-?L 8. Permitnumber 82-16 9. APl number 50-- 133-20352 10. Pool Kenai Gas Field ~f~rllng Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5820 feet Plugs (measured) 4796 feet 5661 feet Junk (measured) 4673 feet Casing Length Structural Size Cemented Measured depth True Vertical depth Conductor 178 ' Surface 2003 ' Intermediate Production 5801 ' Liner 20" Driven 179' 178' 13 3/8" 1225 Sx 2003' 1849 9 5/8" 1900 sxs 5801' 4780' Perforation depth: measured 4890'-4925'; 4410'-4490'; 4525'-4560' true vertical 4089'-4115 '; 3726 '-3787 '; 3813 '-3840' Tubing (size, grade and measured depth) 3 1/2", 9.2#, N-80 at 4724' Packers and SSSV (type and measured depth) RFEFIVED AUG 8 1986 Alaska Oil & 6as Cons. Commission Baker Dual at 4313' Anchorage S-2 Production Packer at 4679' 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] See Attached 13. Estimated date for commencing operation September 15, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I he,/,~by~ert~ J;hat,the foregoing is true and correct to the best of my knowledge Signe~-:)~6~.' ~:)~ ,~~ / Titl~hvironmenta]. Enqineer Commission Use Only Conditions of approval Approved by Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI Form 10-403 Rev 12-1-85 No. by order of Commissioner the commission Date~---~/~--~-~ Submit in triplicate 12. 1. RU "SX" Larkin Tubing Head Assembly over KU 24-7L. 2. RU Otis Injector Head Adaptor over "SX" Larkin Tubing Head Assembly. 3. RU Otis i 1/4" coiled tubing unit over Injector Head. 4. RIH w/ Otis "G" slim hole packer on 1 1/4" coiled tubing. Set packer at +4240' with tubing tail at +4905' (mid perf depth). 5. Hang coiled tubing and secure "SX" Larkin Head Assembly. 6. RD Otis Coiled Tubing Unit 7. Install 2 1/2" line pipe to production facilities. 8. Bring well on and turn well over to production. WELL KU 24-7 IV- A-lO Sd. CASING & ABANDONMENT DETAIL I. Rotary Table at 0.0' II. Cameron 3-1/2' Dual Tubing Hanger at 27.68' III. 20', 94~, H-40 Drive Pipe at, 178' IV. 13-3/8', 61~, K-55 Casing at 2,003' V. E.T.D. (Junk) at 5,661' VI. 9-5/8', 43.5~ & 47~, N-80 Casing at 5,801' TUBING DETAIL LONG STRING: 3-1/2~ 9.2~, N-80 TUBING 1. Otis 'XA° Sliding Sleeve at 4,273.53' 2. Baker Model 'A-5° Dual Packer at 4,312.79' 3. Blast Joints From 4,385.29' to 4,581.52' 4. Otis 'XA' Sliding Sleeve at 4,639.47' 5. LocatOr Sub at _4,677.12' 6. Top of 13.i;2' Baker Seal Assembly at 4,678.00' 7. Model 'S-2' Prod. Packer at 4,679' 8. Otis 'X"Nipple at 4,691.72' 9. Mule Shoe at 4,724.00' SHORT STRING: 3-1/2~, 9.2~, N-80 TUBING A. Otis 'XA: Sliding Sleeve at 4,267.57' " B. Baker Model 'A-5' Dual Packer at 4,314.93' C. Otis 'X' Nipple at 4,325.84' A-11 Sd. B-~, Sd. V VI- PERFORATION RECORD DA TE IN TER VA L 5/27/82 I 4,890'-4,905~. 5/28/82 ~ 4,905'-4:925' 5/29182 4,410'-4,490' 5/30/82 4,525'-4,560' 5/30/82 4,410'-4,490' ; CONDITION B-4 Sd. Production B-4 Sd. Production A-lO Sd. Production .., A-11 Sd. Production Reperf. A- 10 Sd. RECEIVED AUG 1 8 ]986 Alaska 011 & G~s C~n~. Commission F[LL TAGGED @ 5628' - 4/10/86 OAT [ WELL KU 24-7 WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA DR,~W~ BAW_ APl)tO. ~CALE NONE O',T~ 8120/8e SCALE 1" " 300' -( Center of Well Ce?,lar Lat. 60°26' 35.216 Long. 151°14'43.944'' y , 2,356,013.69 7 fiE: Cor. Sec.lO// Lat. 60~26'42.38-)'' '" LOnq.151°14'29.027" X = 275,819.31 Y = 2,356,727.16 748' 8 L~GEt(D ANd NOTES: Found GLO brass cap monumemt. Top Welt cellar elevation is 78.8 feet above MLLW of Cook Inlet or 67,7 feet above Mean Sea Level. , Bas($ of coordinates and bear(n.q$ is USC~GS Tr( Station AUDRY in ASP Zone and related A~imuth ~rk. yCq AUDRY Lat. 60°30.50.559 iq tonq. '151'16'37.4q5 W X = 269,866.75 Y · 2,382,045,45 KU 24-7' PREPAREO FOR UNION OIL COMPANY OF CALIF. OPERATOR ,.a ............... i .~. ...... .-.. _ SURFACE LOCATIOH' 728 Ft. South and 7~8 Ft. West from the NE corner of Section TeN, Rl lW, S. M., Alaska, Surveyed by' HcLane arid A$$octate'~ Inc, Oate of Survey; 4/20/82 ~ ~,~'.- '~ ,~,. ~ .~ ,o. RECEIVED JUL ..... 4lask~ Oii .m Gas Cons. Co~issio. Anchorage , TUBING DETAIL ZO,4/G I. :31/2" OTIS "XA" SLEEVE AT 427:3.5:3' 2_. A-5 DUAL PACKER AT 4:312..79' 3. BLAST ,JOINTS FROM 4,:385.29' TO 4,5@t.52' 4. :31/2" OTIS "XA" SLEEVE AT 4.639.47' 5 LOCATOR AT 46,77.12' 6. BAKER SEALS AT 4678.00' 7. :31/2" OTIS "X" NIPPLE AT 4691.72' 8. MULE SHOE AT 4724.00' A. 31/2" OTIS "XA" SLEEVE AT 4267.57' B: A-5 DUAL PACKER AT 4314.93' C. 3 I/2" OTIS "X" NIPPLE AT 4:325.84' PERFORATION RECORD D, dTEi/I/TE/FZ4L £OIVDITIOIV 512718::) 4890' - 4905' OPEN B-4. SAND 5/28/82 4905' -- 4925 .... ' " 5/2-9/82 4410' -- 4490' " A-lO SAND 5/30/82 4525' -- 4560' " A-II SAND " 4410' ~ - 4490', REPERFED A-lO SAND '! KU 24-7 B 2- O' 27.70' II 20,94~H-40 AT 178' 13 3/8",61~ K- 55 CASING AT 2,003' 9 5/8'i 43.5 & 47~ N-80 AT 5,801' KU 2_.4-7 WELL SCHEMATIC COMPLETED: 6/5/82.. Well KU 24-7 I Field KENAI GAS County KENAI [Date 11//29/82_ Drawn By B.. W. JChecked By Approved By Scale NONE ] Page I Of I IMCO Services A Division o! HALLIBURTON Company 2400 Wesf Loop South. ~ O. BOX 22605 Houstor,. Texas 77027 A,C 713 671-4800 WELL DATA SUMMARY COMPANY UNION OIL COMPANY OF CALIFORNIA ADDRESS Anchorage, Alaska REPORT FOR MR. WELL NAME & NO. KU 24-7 STATE ] COUNTY Alaska Kenai IMCO WAREHOUSE X-KENA I CONTRACTOR BRINKERHOFF ADDRESS REPORT FOR MR. FIELD Kenai Gas Field DESCRIPTION OF LOCATION Sec. 18 T-4N R-11W SM WELL DATA DATE SPUDDED CSG. SIZE FROM TO HOLE SIZE FROM TO 5-11-82 20 O.D. 0 _ 178 17~ 178 _ 2003 TO O.D. TOTAL DEPTH 5,820 ' DATE TD REACHED 5-22-82 CSG. SIZE FROM 13 3/8 0 CSG. SIZE FROM 9 5/8 0 TO 2003 HOLE SIZE FROM TO 12{ 2003 _ 5820 HOLE SIZE FROM TO O.D. 5741 _ -- TOTAL DAYS CSG. SIZE FROM TO HOLE SIZE FROM TO O.D. 11 _ - BITS: NUMBER AND SIZE MUD LIP DEPTHS 178 TYPE MUD IMCO GEL,/GELE,.X & DRZSPAC- COMMENTS Please see summary of drilling mud tests. _ -- Dennis R. Lundquist/mn IMCO REPRESENTATIVE ["RT'O IN U..':;.A, 5M COST SUMMARY IMCO SERVICES A Division of HALLIBURTON Company 2400 West Loop South, P. O. Box 22605 Houston, Texas 77027 A/C 713 622-5555 DATE PRODUCT ~MCO~.~AR':~B' SUPEBCO'DRZBPA¢ GAUBT.ZC:.;SODA, COUNTY ,~PAR~81'ii, BO.R. OUOH SALES UNITS 801 '/40 · ,103 ~ '~-;00 · SIZE ~OOLB ~6o~8 tO0~B tOOLB :~5LB ;50LB '66LB' '50L0 50LB DAY AMOUNT '?7.0:00 1oa3~56 .850i5 ~3aOJO I I I I I. . ~ o~oo ,, ~ ~ ~:oo I I i ...... 8 8 0 &. 0 DATE DEPTH 1982 , 5/11 - SUMMARY OF DRILLING FLUID OPERATIOH OPERATOR[]nion Qi ] SECTION [TOWNSHIP WELL FIELD KU 24-7 Kenai Gas Field CONTRACTOR COUNT Y/PARISH Brinkerhof f Kenai ENGINEERS STATE _ Shambo/Lundquis t I Ala_ska _ MUD ] VIS' ] MUD I I ]GELS I pHI Ap, IHT.HP-~ I ALKALINITY [~PpGWT' SEC/Q TEMP. ~iu 'I~STnlPI FLUID I FLUID ~ ~co©r / rm r,,~ IS PAGE i OF 2 ----*tMUD TYPE CONDUC'TOR SIZE DEPTH BIT ~'IZE I 20 178 ---/~--~' -~), T E SURFACE ] 5/12Z82 133/8 2003 17% .... -i~~ DAT¥-- 5> ......... INTERMEDIATE 9 8 5820 12¼ ...... .~A'~:C-:~-T. D. LINER(S) ..... ~ SALT CALCIUM SAND OIL WATER / ['] NaCI J~PPM % VOL. % VOL. % VOL. / ~-1 el- D~ON ~,n I ~,~ ['PM CEC ' O -,'4 IRANGE Ri r~ nD s/~_"i ]_oo I ~s I 18o:1 - i 2]. I 38 I'~T~i:J~_.,_ol - J,-., J ~ J_ '.2" I .4 J [~~Q~__..j- tr J Nil l - J97. 22'.5 J3 'J j ...... Build mud, spud. .. ' ('/~-~~ I..~ ! 8~....I-:I~-~F~T-I~-O'~:L"I-':~--:-~~]~'I 4 I-.z I .....~-'l---::~l,~-o-?--l-~r Iz I -194 122.5 ~ I 1 s/z4! zzso I ~9 I ~01 ~gr~13~o/40_.~~z~.;~l- I 4 J. .esl .:sl_._~~~ '1 ~= Iz.:sl- I~ I~:.~".l I '1' 5/zsl 2030 1"7~ I 661 eol 20135'1z2~-I e.s. lz;,ol- I 4 I ';0'~'1 .z. I' .~~'~q~ '"1~= !~ I- 192 12s.. I~ I ':'[' ~Siti~n m~ f~ cs~ ................ s/~i ~o I :~ ! 5o-i .aolzsl~l ~ I ~.skz.~l - I 4 I .z I .~ I_~ / ~ .1 ~ lz I -,l~'l~s h I I Run [33/8 csa. ePmen~ ~mP,~~~Lp~[~ea~ ~.ceme~. . . , _ , _ , . ...... ~. , ~ ~ ...... _ 5/17 ! 2fl~n I ~ I 49 ! B9 I[S I 22 I B AB./ 8.5 1~2.2 I - I 3 / .[ I .9 I - I 50O I u I ,/~ [ -. ~ .~ ~z:.. 5/~81 22~5 1"'69I s~...I :o 1 zZ"l z:l ~ a~ Izz.olz~.:l -I ~ I z.oI~.~ I'- I :oo I o ...... I.751 - 193 125 D~L[Led ou~ cemen[ - '. 5/201 44~7 I ~8 I 46...I 7~1~0 !~7t 6~ 19.518.4 1~8.81 2 / .4 I ...8 I :___1 ~0~ I 0 I .751 - 194 125 ~ 1~20~ ; ~./:]1~4~ I ~+1 4~1 ~l]ziz?l~4~ 1'9.51a.o I~.~1 2 q .4 i'.9 I - I 600 I 0 .... 1,5 I - 193.5J25 ~.51~20~ ~n]P a hit tight ~n t~i~s, 40~ ana]e ~_.Swe~~ys ..... 5/23 I ~2~ I 72 I 52l 7~ I ~51 2~ I 5 ,Z,t_ I 9~ZB_~,o/ 2 / .4 I .8 I - I ~ ~ 0 J ,5 [ - I 9~..5~30. ~8.5l~40~ ~/~1 ~0--I 5~ r 5zl 7s I-zs'l ~'~ I--T?,-~~q~:~l~:'~'_~3 .~. I .:' I ~L:~_~_0~~ ~'1 .s I - I 9z.'sl:f:.s IMCO FORM NO. 131 (Rev. 1179) J ..... ~;~n~i__G. as_J?~ .... [ COUN r Y/PAR ISI-t PAGE 2 OF 2 .iUD TYPE CONDUCTOR $1Z£ DEPTH '[?,IT SIZ[ ~'/" " I':'~ 20 178 I.D. [),~ ~-f INTERMEDIATE ___5/;'.?,/_..[J.?, ...... 133/8 2009 i7-~ DAYS IO T.O. LINER($) 11 95/8 5820 12% SALT CALCIUM SAND OIL WATER ['.] N,,CI ~<PPM % VOL. % VOL. % VOL. ~'j C~- [iJ iON .,H ~PPM CFC ,--I 4J 0 I~J Gr./Gal __ .~.p_0_____ tr ,5 - 8.5 25 ~1. 140-. SUMMARV OF DRILI_It'JG FLUID OPERATiO:.',!S OPERATOR ,./~ Union Oil ~' ~'" ~' ~ "" '"'~ BriQkerhof f ENGINEERS [STATE Shako/Luna.!it l_.~.~ska __ MUD I VIS. MUD I / L GEL~~]HT'I'IP I ALKALINITY ] WT, I SEC/ TEMP. I / /~~l~sT~ml FLUID I FLUID I I~ DATE DEPTH ] ~PCF. ~DSMPL[ PV IX. I / lo I ~/TEMP--I CAKE I Pf I M~ I ,',,, s/261.~7__z4 I 64 I Kcl_[~_a_~J I I / _l ,1 I_ I--1---, l ~___--_~i~Ii~20~ii-_---__L I I I --'1' I I' 1-' _.~srllac_a~ud w/ 4% K~i..._~! ........................................... __ T ~ t , ..... 5z~__3 ~ ~4 I 6~ I ~,~~ ........ ~1.__~ ....... L.~~I~I ... L__I- I ~~f~400--] I I I I I I I 2qmp safie sea~ p~, ~OH ~ay~nq ~o~_ ~J~" ~r~ ~ge ............. , , , 5 / 31 ! 5714 [ 64 ] [ I F [ - ~---_[[-J~"~-']- ' --E~ ........ [ .. [ . ] ' {2]~0~.0 { .. I I I I I l_ ~ is:~4 I ~4 I I "'1 I I / '~-I'-~,-~'I I I L. I~~- I I I I I I 1":' ~/~ I s:~4 I ~ ! I ','1 I I ~__ I I I ,I I I I --~'~ I I "1 I I., "¥1I-~ Displaced hole ~ith packez fluid. f I I -I I I I / I I I I I l. I I I I I I I I I I ! I ' I I ! ! I '/ I "1 I I I I I .. I I I I i I I I I ! I I I "1 '1 I ,'/ I I I I I I ! I I I I I I" I I 1 I 'i "' I I I I '1 /- '1' '1 1 I ] I I _.1- ' I I I I I. i ! IL I ! . 1 I i I I / '--]---T---I---I---I' I I.-'E-_J .... -i I, ,1 I I I t IS IMCO FORM No. 131 (Rev. 1/79) ,. SUMMARY OF MUD MATERIAL USAGE PAGE1 OF 1 IMCOServlces Union Oil ....... Keqa~ Gas Field ........ '~--~°'~ KU 24-7 Kenai Alaska Kenai DATE DEPTH DAILY CUMULATIVE COST COST 5"~11 - 430.0C 430 O0 '] 1 5/12 100 3439.5E 3869 58 131 15 4_ 1 5/13 675 3739,4C 7608 98 150 20 1 5/]4 1150 1633.32 9242 30 50 11 5/]5 2030 4554.2C 13796 20 210 .. 6. .. 1 ........... ~/]6 2000 1760.0~ ~5556 28 40 5/1~ 2000 430.00 15986 78 ,, 1 5/18 2517 2831.94 18818 72 55 36 12 11 1 5/]9 3241 6279.9£ 25098 62 75 80 16 10 3 1 5/~ 44~7 49~4.4~ 3n00~ 04 5~ 64 15 6 ]~ 2 1 5/2] 54~3 5459.3~ 35462 39 48 8 ]~ ]3 .... 2 1 5~221 58~017674.82 43137 22 322 1 5 5 2 1 ..... 5/23 5820 1374.96 44512 18 30 22 ... 1 5/24 5820 957.40 454~9 58 30 1 5___~/~5 5820 954.08 46423 66 20 4 .... 1 .... 5/26 5714 4016.80. .. 50440 46 .... 122 1 5/27 5714 430.00 50870 46 1 __5/~ ~7~4 ]~_~n 5~]9~ 66 .................. 5/29 5714 450.00 52622 66 __ 1 5/30 5714 %400,04 54022 70 ..... 3 14 1 5/31 5714 430.00 54452 70 1 6/1 5714 430.00 54882 70 1 6/2 5714 430.00 55312 70 __ 1 · , .... ..... , Tnta]s ~22.._861 104 34 38 19. 6 122 9 26 _. --, ,, .... IMCO FORM NO. 132 {Rev. 11/79} :' Document Transmitta' - Union Oil Company of Califc .a union HAND DF~i-V-ER DATE SUBMITTED ACCOUNTING MONTH 7/28/82 TO FROM lVk-...:,,' William Van Alert R.C. Warthen Alaska Oil & Gas Conserva-~ P.O. Box 62.47 AT tion Con]nission AT Anchorage, AK 99502 3001 Porcupine Drive ~nchorage, ~ut 99504 TELEPHONE NO. TRANSMITTING THE FOLLOWING: UBTION KU 24-7 1 ea of: Tang, Angle Ave, and Radiu of Curv. Dir. SUrveys 1 ea Mag ~pe #65122 1 ea of blueline and sepia as folio ~s: FDC-CNL-GR 5,, (raw data) FDC-CNL-GR 5,, (porosity) BHC-sonic 2" BHC sonic 5" DIL 2 ,, DIL 5" ~"% F% ~ Open Hole VDL 5" I~U~ A~L-VDL-GR 5" Please aclmowle~g/~ re~elot Alaska Oil S Gas CoD: Commls ~ior~ , hqphnrafl FORM 1-2M02 (REV. 11-72) PRINTED IH U.S.A. ~"' "~' -- STATE OF ALASKA ALASKA/~_ AND GAS CONSERVATION CC~V/ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION _ · Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. UNION Oil COMPANY OF CALIFORNIA 82-16 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 133-20352 4. Location of Well at surface 728'S & 748'W of NE corner, Sec. 18, T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. GL 67.7' MSLI A-028142 9. Unit or Lease Name KENAI UNIT 10. Well No. KU #24-7 11. Field and Pool KENAI GAS FIELD STERLING POOl For the Month of 3une ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 5820' TD, 5661' ETD Completed well w/ dual 3 1/2" comp assy. Released rig ~ 24:00 hfs 6/5/82 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None 1 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby ce,~"~/that the foregoing is true and correct to the best of my knowledge. SIGNED DIST DRLG SUPT 7/14/82 DATE NOTE--R _ n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and G~"onservation Commission by the 15th of the succeeding month unless otherwise directed. Form 10~,04 Submit in duplicate STATE OF ALASKA ALASKA G ...... AND GAS. CONSERVATION CO~.._JlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG -1. Status.of Well . . . Classification of Service Well OIL [] GAS'1~ SuspENDED [] ~ABAN'DONED [] , SERVICE [] 2.'Name of Operator ' 7. Permit Number UNION OIL COHPANY OF CALIFORNIA 82-16 3. Address 8. APl Number pn nnx g247 ANCHORAGE AK 99502 50-133-20352 4. Location of well at surface 9. Unit or Lease Name 7~t8'S & 748'W of NE Cor, Section 18, T4N, RllW, SM. KENAI UNIT Top Producing Interval 10. Well Number 1Alt'N & 2728'W of SE Cor, Section 7, T4N, RllW, SM. KU ~24-7 TotalDepth 11. Field and Pool 397'N & 3562'W of SE Cot, Section 7, T4N, RllW, SM. 5. Elevat.ion in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KENAI GAS FIELD GL 67.7' MSLI A-028142 Sterling Pool f2. DateSpudded 13. DateT.D. Reached 14. DateComp.,Susp. orAband. ,15. WaterDepth, ifoffshore ,16. N~ofCompletions 5/12/82 5/22/82 6/5/82I I------ feet MSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)i 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 5820, & 4796' ___ YES [~ NO []I .... feet MD ..... 22. Type Electric or,Other Logs Run D!L-BHC--Rnni o-VDL-GR, FDC-CNL-GR, CBL-VDL-GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94 H'40' ' 0 ~' 179 Driven 1 ~ ~/n 61 K-55 0 2003 17 1/2 122~ sxs --- ? 5/8 /,3.5&47 N-80 0 5801 , 12 1/4 1900 sxs --- 24. Rerforations open to Rroduction (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) . SIZE DEPTH SET (MD) PACKER SET (MD) r6¥- MD TVD HPF 3,31/2"1./?,, ------ 4317'4679 ' ~ 489~'-4925 ' 409-~-4116 ' 8 B-4 :~ ........ "~-~0-4490 ' 3727-3888 ' 8 A-10 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED !~° 45~5-4560' '3814-3840" : 8 .~ A.11 -. ,- ~ TEsT 27. Date E'irst Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-DEL CHOKE SIZE IGAS-OILRATI° 5/28/82 . 13 TEST PERIOD ~. . - . 23102 - I Flow .T,, ubj. ng, Casi0g pressure . CALC~ULATED I~ OIL-BBL GAS-MCF WATER-DEL OIL GRAVITY-APl (corr) Press.. 738,.. . ,: 24-~O~JR R~TE-~ ' . .." '. 16200 - 28. CORE DATA Brief description of lithology, porosity, fractures, apParent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .. 29. 30. GEOLOGIC MARKERS FORMATION TESTS ~ NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Radioactive 3759' 3243' B-4 4890-4925' = 6.07 MMCFD $ 768 psi w/ Sand 0 BWRD A-8 Equivalent 4310' 3662' A-10 4410-4490' = 9.43 MMCFD ~ 730 psi w/ Sand 2.4 BWRD A-9 Equivalent 4361' 3700' A-10 & A.11 4525-4560' = lO.13 MMCFD ~ 738 Sand psi .w/ 0 BWRD A-10 Sand 4404' 3733' ' ' A-11 Sand 4508' 3812 ' I : , 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge /- - ,<.. ....d / .,./ // /¢/,,"? INSTRUCTIONS General: This form is designed for submitting a complete and ccrrect well completion report and .log on all types of lands and leases in Alaska. Item- 1: Classification of Service Wells: Gas injection, w~ter injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for imsitu 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' Indicati~ whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show tl~'d~tails of any multiple stage cement- ing and the location of the cementing tool.~ Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water I.n- iection, Gas Injection Shut-in: Other--e×...n!~i..~ UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE A-028142 FIELD Kenai Gas Field WELL NO. KU #24-7 LOCATION: KGF Pad #41-18~ 728'S & 748'W from the NE corner~ Section 18~ T4N~ RllW~ SM. SPUD DATE 5/12/82 CONTRACTOR Brinkerhoff TYPE UNIT SHEET A ~ PAGE NO. 1 COMP. DATE 6/5/82 RIG NO. 59 DRILL PIPE DESCRIPTION 5" 19.5# "E" PERMIT NO. 82-16 SERIAL NO. A-028142 TD 5820' TVD 4800' DEVIATION (BHL) COMPANY ENGINEER $ohn R. Underhill, Watson, Graham, Abernathy ELEVATIONS: WATER DEPTH RT TO OCEAN FLOOR - RT TO MLLW 67.7' MSL RT TO GL ...... . 27' RT TO PROBATION DE~'-'~ _ . APPROVED ~/'~//~/_~x.,~/~/7 ~/ /, ......... CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 20" 94# Drive Pipe H-40 179' Driven 13 3/8" 61# Buttress K-55 2003' 975 sxs "G" w/ 2.5% prehyd §el & 2% CaCL2 & 250 sxs "G" w/ 2% CaCL2 9 5/8" 43.5# Buttress N-80 1900 sxs "G" w/ 3% kcl, 1.2% D-19, , 47# Buttress N-80 5796' 3 1/2" LS 9.2# Buttress N-80 4725' 0.1% A-2~ 0.1% R-5, 0.2% 2% .qel . A-5 pkr ~ 4315' (Top) SS 9.2# Buttress N-80 4328' PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 5/27/82 4890-4905' 5714' DST #1/Upper B-4 sds Open to Production Il Il Il 5/28/82 4905-4925' 5/29/82 4410-4425' 4700' DST #2/A-lO sds " 5/29/82 4425-4445' " " " 5/29/82 4445-4465' " " " 5/29/82 4465-4490' " " " 5/30/82 4525-4560' " A-il sds " 5/30/82 4525-4560' " Add 4 more HPF (8 HPF Total) " 5/30/82 4410-4490' " " " INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS 727 4210 5/28/82 B-4 sds (4890-4905') LS 0 BWPD " " (4905-4925') LS 768 6070 " 5/29/82 A-lO (4410-4425') SS 716 5570 " " " (4410-4445') " 830 7240 " " " (4410-4465') " " " " A-10 (4410-4490')" 730 9430 2.4 BWPD 5/30/82 A-Il & A-10 sds " 738 10130 0 BWPD WELL HEAD ASSEMBLY TYPE: CASING HEAD: Cameron SOW to 13 3/8" .csg x 12" 3000 psi .~ TUBING HEAD: TUBING HANGER: TUBING HEAD TOP: MASTER VALVES: CHRISTMAS TREE TOP CONN: CASING HANGER: 9 5/8" CIw type "AW" 12" 3000 X 10" 5000 CIW "DCB" Dual 3 1/2" CIW "DCB-B" 8rd 3 1/2" Buttress 8rd EUE 3 1/16" 5000 psi 3 1/2" 8rd UNION OIL COMPANY OF CALIFORNIA · WELL RECORD LEASE A-028142 WELL NO. KU #24-7 FIELD SHEET D PAGE NO. KENAI GAS FIELD DATE ETD DETAILS OF ORERATIONS, DESCRIPTIONS & RESULTS A 5/9/82 DAILY COST: $ 32,395 ACC COST: $ 32,395 AFE AMT: $2,000,000 B 5/10/82 DAILY COST: ACC COST: $ 105,624 $ 138,019 AFE AMT: $2,000,000 C 5/11/82 DALLY COST: $ 33,370 ACC COST: $ 171,389 AFE AMT: $2,000,000 1 5/12/82 76/76' 20" O. 179' 65 PCF 30 SEC DAILY COST: $ 20.6,318 ACC COST: $ 377,707 AFE ANT: $2,000,000 2 5/13/82 635'/559' 20" O. 179' 67 PCF 81 SEC DALLY COST: $ 27,873 ACC.COST: $ 405,580 AFE AMT: $2,000,000 5/14/82 '1135'/500' 20" O. 179' 69 PCF 80 SEC DALLY COST: ACC COST: $ 63,638 $ 469,218 AFE AMT: $2,000,000 4 5/15/82 2020'/885' 20" D. 179' 71 PCF 66 SEC DALLY COST: ACC COST: $ 29,655 $ 498,873 Commenced operations ® 00:01 hrs 5/9/82 on moving rate. Moving rig to 24-7 location & RU. Rigging up on KU #24-7. Rigging up on KU #24-7. Drove 20" to 179'. Installed 20" diverter system. Spud 0 23:30 hrs. CO 20" drive pipe w/ 17 1/2" bit to 76'. CO 20" cond w/ 17 1/2" bit to 179'. Orld 17 1/2" hole to 300' KOP. Trip for dyna-drl. Orient dyna-drl w/ SDC steering tool. Dyna-drl 17 1/2" hole f/ 300' to 635'. Dyne drld 17 1/2" hole f/ 635'-816'. Trip for bldg assy. Reamed dyne dr1 run. Drld 17 1/2" hole f/ 816' to 1135'. Dir drld 17 1/2" hole f/ 1135' to 2020'. Short trip to 550'. C&C mud hole for 13 3/8" csg. AFE AMT: $2,000,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #24-7 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5 5/16/82 DAILY COST: ACC COST: AFE AMT: 6 5/17/82 2020'/0' 20" D. 179' 13 3/8" C. 2003' 70 PCF 50 SEC $ 49,757 $ 548,630 $2,000,000 2020'/0' 20" D. 179' 13 3/8" C. 2003' 70 PCF 49 SEC DAILY COST: $ 135,050 ACC COST: $ 683,680 AFE AMT: $2,000,000 7 5/18/82 DAILY COST: ACC COST: AFE AMT: 8 5/19/82 DALLY COST: ACC COST: AFE AMT: 2517'/497' 20" D. 179' 13 3/8" C. 2003' 69 PCF 56 SEC $ 39,895 $ 723,575 $2,000,000 3332'/815' 20" D. 179' 13 3/8" C. 2003' 69 PCF 61 SEC $ 38,548 $ 762,123 $2,000,000 Cond mud & hole for 13 3/8" csg. POOH. Ran 13 3/8" 61# K-55 butt csg to 2003'. RIH w/ DP & stinger. Eh- gauged FC $ 1960' & cmtd 13 3/8" csg w/ 975 sxs "G" w/ 2.5% pre-hydrated gel & 2% CaCL2 tailed in w/ 250 sxs "G" w/ 2% CaCL2. Had very good cmt returns to surf. CIP @ 20:25 hrs. WOC. Cut off 13 3/8" csg. Install- ed 12" 3000 psi SOW csg head. Comp installing & testing 13 5/8" 5M BOPE. All tests WAA by USGS. PU 12 1/4" BHA #6 (slick assy). TIH. Tagged cmt $ 1941'. CO cmt to 1951' - test 13 3/8" csg to 2500 psi - drlg cmt & FC 8 1960' & cmt to 1993. Retest 13 3/8" csg - ok to 2500 psi. Drld cmt & FS @ 2003'. C0 cmt & open hole to 2015'. Tested 13 3/8" csg seat equiv to 90 PCF or .625 psi/ft grad - ok. ROOH - LD BHA #6. PU BHA #7 (locked assy) & TIH. CO 12 1/4" hole f/ 2015' to 2020'. Drld 12 1/4" hole f/ 2020' to 2517'. Angle not holding as desired - POOH for angle bldg assy. POOH w/ BHA #7. Surveys: 2136' 39° N68 1/2W 2289' 37° N69 1/2W 2442' 34 3/4° N69 1/2W 2600' 33 3/4° N70 1/2W 2753' 34° N67 1/2W 2873' 33 3/40 N68 1/2W Comp POOH w/ BHA #7 (locked BHA). PU BHA #8 (30' belly). TIH. Drld 12 1/4" dir hole f/ 2517' to 2934'. Hole angle not bldg as desired. POOH. PU BHA #9 (60' belly). TIH- CO bridge ® 2885' Drld f/ 2934' to 3179'. Hole angl~ incr as required- reamed out angle bldg run f/ 2934' to 3179'. POOH. PU BHA #10 (30' belly). TIH. Rereemed angle bld f/ 2800 to 3179'. Drld 12 1/4" hole f/ 3179' to 3332'. Drilling © 3332' at midnight. Surveys: 2873' 33 3/4° N68 1/2W 2969' 33° N67 1/2W UNION OIL COWPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #24-7 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 9 5/20/82 DAILY COST: ACC COST: AFE AMT: 10 5/21/82 DAILY COST: ACC COST: AFE AMT: 11 5/22/82 DAILY COST: ACC COST: AFE AMT: 12 5/23/82 DAILY COST: ACC COST: AFE AMT: 4407'/1075' 20" D. 179' 13 3/8" C. 2003' 68 PCF 46 SEC $ 28,677 $ 790,800 $2,000,000 5489'/1082' 20" D. 179' 13 3/8" C. 2003' 69 PCF 47 SEC $ 30,255 $ 821,055 $2,000,000 5820'/331' 20" D. 179' 13 3/8" C. 2003' 72 PCF 44 SEC $ 30,754 $ 851,809 $2,000,000 5820'T.D. 20" D. 178' '13 3/8" C. 2003' 72 PCF 52 SEC $ 81,250 $ 933,059 $2,000,000 Dir drld 12 1/4" hole f/ 3332' to 4407' w/ BHA #10 (30' belly). POOH w/ bit #5PR. Tight hole f/ 3394' to 3026'. Change NB stab & RIH w/ bit #6 & BHA #11 (30' belly). Surveys: 3679' 40 1/2° N65 1/2W 3803' 40 1/2° N65 1/2W 3954' 40 3/4° N65 1/2W 4352' 40 1/2° N63 1/2W 4505' 40 1/4° N63 1/2W RIH w/ bit #6 on BHA #11 and worked thru tight spots F/ 3306' to 3396', 3908' to 3928', and 4008' to 4120'. Reamed down F/ 4274' to 4407'. Directionally drilled 12 1/4" hole F/ 4407' to 5433'. Trip for bit change-had tight hole F/4764' to 4429'. RIH w. bit #7 on BHA #11 and reamed 20' to btm. Directionally dmilled 12 1/4" hole F/ 5433' to 5489'. SURVEY: 5368' 40 1/4° N 63 W Directionally drilled 12 1/4" hole F/ 5489' to 5820'. Circ and made short trip to csg shoe. RIH-had tight spots $ 5050',5220', and 5560'. Circ and raised mud wt to 72 pcf. Wade short trip to csg. shoe-no tight spots. Circ and POOH for logs. SURVEY: 5760' 39° N 61W Ran DIL/BHC-Sonic/~GR log-Sonic tool failed. POOH and repaired same. RIH and ran log F/5820' to 2000'. POOH. Ran FDC/CNL/GR log F/5820'to 2000'. P.D. Schlumberger. RIH w/ 12 1/4" bit on 5" d.p. Circ and cond. mud. POOH. RU and began running 9 5/8" 43 1/2# & 47# csg. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #24-7 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 13 5/24/82 DALLY COST: ACC COST: AFE AMT: 14 5/25/82 5820' TD 5720' ETD (FC) 13 3/8" C. 2003' 9 5/8" C. 5796' 72 PCF 51 SEC $ 392,433 $1,325,492 $2,000,000 5820' TD 5714' ETD (FC) 13 3/8" C. 2003' 9 5/8II C. 5796' 72 PCF 43 SEC DAILY COST: $ 58,260 ACC COST: $1,383,752 AFE AMT: $2,000,000 15 5/25/82 5820' TD 5714' ETD (FC) 13 3/8" C. 2003' 9 5/8" C. 5796' 64 PCF 30 SEC DAILY COST: $ 29,003 ACC COST: $1,412,755 AFE AMT: $2,000,000 16 5/27/82 GAILY COST: ACC COST: AFE AMT: 5820' TD 5714' ETD (FC) 13 3/8" C. 2003' 9 5/8" C. 5796' KCL FLUID $ 23,166 $1,435,921 $2,000,000 Comp running 9 5/8" 43.5# & 47# N-80 butt csg to 5796'. Broke circ& worked pipe. Cmtd 9 5/8" csg w/ 1900 sxs cl "G" w/ 3% KCL, 1.2% D-19 .1% A-2, .1% R-5, .2% D-6 & .2% gel. Dropped plug & displ w/ 433 bbls of mud to bump plug w/ 2300 psi. Floats held ok. CIP ~ 15:10 hrs. Note: Reciprocated csg thruout most of job. However, lost comp returns after stopping reciprocation w/ +200 bbls of displ left. Removed B--ORE & landed csg in slips. Cut off excess csg & installed CIW 12" 3M X lC" 5M DCB spool. Tested spool to 2000 psi - ok. Installed & tested BORE. Installed wear bushing. RIH w/ bit #8 on 9 5/8" csg scraper & tagged FC ~ 5714'. C&C mud. POOH. RU SDC & ran gyro survey f/ surf to 5700'. RD SDC. RU DA. Ran CBL-VDL-GR log f/ 5704-1800'; RD DA. LD 30 jts of HWDP. RIH w/ 8 1/2" bit on 9 5/8" csg scraper to 5714'. Circ & cleaned mud tanks. Mix KCL fluid.. Comp chnging hole over to 3% KCL fluid. Tested 9 5/8" csg to 3000 psi - ok. POOH. RIH w/ 9 5/8" RTTS pkr & tbg tail while PU 3 1/2" DP. Located tail ~ 4750', pkr ~ 4720'. Displ DP w/ N2 & set pkr. RIH w/ 15' of 2 1/16" link cone guns w/ 4 HPF on 0° phasing. Had 2 misfires. Finally perfed upper B-4 sd f/ 4890' to 4905' DIL for DST #1. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #24-7 FIELD KENAI GAS FIELD DATE ETD DETAILS OF ORERATIONS, DESCRIPTIONS & RESULTS 17 5/28/82 DAILY COST: ACC COST: AFE AMT: 18 5/29/82 DAILY COST: ACC COST: AFE AMT: 19 5/30/82 5820' TD 5714' ETD (FC) 13 3/8" C. 2003' 9 5/8" C. 5796' KCL FLUID $ 32,816 $1,468,737 $2,000,000 5820' TD 4700' ETD (RET) 13 3/8" C. 2003' 9 5/8" C. 5796' KCL FLUID $ 33,296 $1,502,033 $2,000,000 5820 ' TD 4700' ETD (RET) 13 3/8" C. 2003' 9 5/8" C. 5796' KCL FLUID DAILY COST: $ 63,550 ACC COST: $1,565,583 AFE AMT: $2,000,000 2O 5/31/82 5820' TD 5661' ETD (JUNK) 13 3/8" C. 2003' 9 5/8" C. 5796' KCL FLUID DAILY COST: $ 20,994 ACC COST: $1,586,577 AFE AMT: $2,000,000 21 6/1/82 DALLY COST: ACC COST: AFE AMT: 5820' TD 5661' ETD (JUNK) 13 3/8" C. 2003' 9 5/8" C. 5796' KCL FLUID $ 199,179 $1,785,756 $2,000,000 Tested upper 8-4 sd f/ 4890-4905' DIL f/ DST #1. Had a rate of 4.21 MMCFD 8 727 psi w/ 0 BWRD. Rerfed remainder of upper B-4 sd f/ 4905- 4925' DIL & flowed well. Had a final rate of 6.07 MMCFD 8 768 psi w/ 0 BWRD. Rump a 20 bbl safe-seal pill across perfs. Rev circ to kill well. ROOH w/ RTTS. Ran & set Baker omt ret on DR & set 8 4700'. POOH. RIH w/ RTTS on 3 1/2" DP & set ~ 4317', tail ® 4359'. Test equip to 3000 psi. Opened bypass & displ DP w/ N2. Closed tool. RU DA & perfed A-lC sd f/ 4410-4425' DIL for DST #2. Had rate of 5.57 MMCFD ~ 716 psi w/ 0 BWPD (shot well w/ 500 psi underbalance). Perfed A-lC sd f/ 4425' to 4445' DIL. Had total rate of 7.24 MMCFD ~ 830 psi. Parred A-lC sd f/ 4445' to 4465' DIL - had rate of 7.24 MMCFD ~ 830 psi. Parred remainder of A-lC sd f/ 4465' to 4490' DIL - had rate of 9.43 MMCFD 8 730 psi w/ 2.4 BWPD. Rerfed A-il sd f/ 4525' to 4560' DIL & tested in comb w/ A-lC sd. Had a final rate of lO.13 MMCFD ~ 738 psi w/ 0 BWRD. Rumped 20 bbl safe-seal pill across perfs. Rev circ clean & ROOH. LD 3 1/2" DR. RU DA & reperf A-11 sd f/ 4525-4560' DIL & A-lC sd f/ 4410-4490' DIL w/ 4" osg guns ~ 4 HRF. RD DA. RIH w/ 8 1/2" bit & drld ret $ 4700. RIH & tagged junk G 5661'. POOH. RIH w/ 8 1/2" bit on 9 5/8" csg scrpr to 5653'. Rulled up to 4388' &oirc clean. ROOH. RIH w/ Baker "S-2" pkr on 5" DR & set pkr ~ 4679. Tested pkr - ok. ROOH & LD 5" DP. Rulled wear bushing & changed rams. RU & began running dual 3 1/2" comp assy. Cont running dual 3 1/2" tbg assy. Stabbed into "S-2" prod pkr S 4679' & attempted to test. LS circ'd freely. RIH in LS & discovered "XA" sleeve ~ 4274' was open. Closed sleeve and tested stab-in - ok. Spaced Out & landed on tbg hanger. Tested hanger to 300 psi.- ok. Pres up on SS & set dual "A-5" pkr ~ 4317'. Tested pkr - ok. Installed BPV's. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #24-7 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 22 6/2/82 DAILY COST: ACC COST: AFE AMT: 23 6/3/82 DAILY COST: ACC COST: AFE ANT: 24 6/4/82 DAILY COST: ACC COST: AFE AMT: 25 6/5/82 DAILY COST: ACC COST: 5820' TD 5661' ETD (JUNK) 13 3/8" C. 2003' 9 5/8" C. 5796' PKR FLUID $ 34,251 $1,820,007 $2,000,000 5820' TO 5661' ETD'(JUNK) 13 3/8" C. 2003' 9 5/8" C. 5796' $ 17,663 $1,837,670 $2,000,000 5820' TD 5661' ETD (JUNK) 13 3/8" C. 2003' 9 5/8" C. 5796' $ 20,776 $1,858,446 $2,000,000 5820' TD 5661' ETD(JUNK) 13 3/8" C. 2003' 9 5/8" C. 5796' $ 25,237 $1,883,683 Installed CIW dual 3 1/2" 5M# tree & tested to 5000 psi. RU Otis on LS & opened sleeve 8 4274'. Displ ann above "A-5" pkr w/ pkr fluid. Closed sleeve in LS ~ 4274'. Knock out guide shoe w/ sinker bars. Opened sleeve in LS ~ 4640'. Displ N2 down SS while taking returns up LS - lost returns shortly after clearing tbg. Closed sleeve in LS ~ 4640'. Opened LS to clean up - LS was dead. Shut in LS & opened SS to clean up. Flowed SS. Opened sleeve in LS ~ 4274' & displ LS w/ N2. Closed "XA" sleeve $ 4274'. Opened LS & flowed to clean up, Installed BPV's, Released rlg to move rate e 15:00 hrs. Cont to RD & prep to move rig to KU #13-6. Continued to rig down Rig #59. Continued to rig down Rig #59. Re- leased rig $ 24:00 hrs 6/5/82. AFE ANT: $2,000,000 LEASE A-028142 UNION OIL COMPANY OF CALIFORNIA NELL RECORD NELL NO. KU #24-? FIELD SHEET D PAGE NO. Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS JTS 13 3/8" CASING DETAIL DESCRIPTION LENGTH BTM TO.~. 1 5O Mule Shoe 1.95' 2003' 2001.05' 13 3/8" K-55 61# 39.20' 2001.05' 1961.85' Float Collar 2.10' 1961.85' 1959.75' 13 3/8" K-55 61# 1959.75' 1959.75' Cmt'd w/ 975 sxs "G" cmt w/ 2.5% prehydrated gel and 2% CaCL2. Tail slurry w/ 250 sxs "G" cmt w/ 2% CaCL2. Good returns to surface. CIR © 20:25 hrs 5/16/82. JTS 9 5/8" CASING DETAIL DESCRIPTION LENGTH BTM Tqp 13 ll 19 1 10 1 89 B&W 9 5/8" Float Shoe Jts 43.5# N-80 Butt B&W 9 5/8" Float Collar Ots 43.5# N-80 Butt \ Pup Jt 47.0# N-80 Butt Jts 43.5# N-80 Butt Jts 47# N-80 Butt Pup Jt 47# N-80 Butt Jts 47# N-80 Butt Pup Jt 47# N-80 Butt Jts 47# N-80 Butt Pup Jt 47# N-80 Butt Jts 47# N-80 Butt RT 1.68' 5796.41' 5794.73' 77.35 ' 5794.73' 5717.38' 1.38 ' 5717.38 ' 5716.00' 525.5' 5716.00' 5190.50' 14.03' 455.24 ' 75.91 ' 11.73' 5190.50 ' 5176.47 ' 5176.47' 4721.23' 4921.23' 4645.32' 4645.32' 4633.59' 734.59' 4633.59' 3899.05' 19.75' 3899.05' 3879.30' 393.07' 3879.30' 16.88' 3486.23' 3442.75' 3469.35' 27.60' 27.60' 3486.23' 3469.35' 27.60' Cmt'd w/ 1900 sxs cl "G" cmt w/ 3% kcl, ].2% D-19, 0.1% A-2, 0.1% R-5, 0.2% D-6 and 0.2% gel. Displaced w/ 433 bbls of mud. CIR ~ 15:10 hrs 5/24/82. LEASE A-028142 SHEET D PAGE NO. UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. KU #24-7 FIELD Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS JTS 13 13 SHORT STRING TUBING DETAIL DESCRIPTION Otis X-Nipple A-5 Pkr 3 1/2" Pup N-80 Butt 9.20# 3 1/2" N-80 Butt Tbg 3 1/2" Pup N-80 Butt Otis XA Sleeve 3 1/2" N-80 Butt Tbg 3 1/2" Pup N-80 Butt 3 1/2" N-80 Butt Tbg 3 1/2" Pup N-80 Butt 3 1/2" N-80 Butt Tbg 3 1/2" N-80 Butt Tbg 3 1/2" Pup N-80 Butt 3 1/2" N-80 Butt Tbg 3 1/2" Pup N-80 Butt 3 1/2" N-80 Butt Tbg 3 1/2" N-80 Butt Tbg 3 1/2" Pup Butt N-80 3 1/2" N-80 Butt Tbg 3 1/2" Pup N-80 Butt 3 1/2" N-80 Butt Tbg 3 1/2" Pup N-80 Butt 3 1/2" N-80 Butt Tbg 3 1/2" N-80 Butt Tbg LENGTH BTM 1.75' 4327.59' 10.91' 4325.84' 10.00' 4314.93' 31.11' 4304.93' 2.20' 4273.82' 4.05' 4271.62' 176.39' 4267.57' 5.05' 4091.18' 391.67' 4086.13' 5.10' 3694.46' 395.25' 3689.36' 913.03' 3294.11' 4.16' 3081.08' 178.60' 3076.92' 5.07' 2898.32' 122.48' 2893.25' 241.59' 2770.77' 4.98' 2529.18' 88.31' 2524.20' 4.45' 2435.89' 120.00' 2431.44' 4.11' 2311.44' 148.82' 2307.33' 181.57' 2158.51' TOP 4325.84' 4314.93' 4304.93' 4273.82' 4271.62' 4267.57' 4091.18' 4086.13' 3694.46' 4689.36' 3294.11' 3081.08' 30?6.92' 2898.32' 2893.25' 2770.77' 2529.18' 2524.20' 2435.89' 2431.44' 2311.44' 2307.33' 2158.51' 1976.94' LEASE A-028142 UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. KU #24-7 FIELD SHEET D PAGE NO. Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS JTS 1 15 4 1 18 1 21 SHORT STRING TUBING DETAIL (oont) DESCRIPTION 3 1/2" Pup N-80 Butt 3 1/2" N-80 Butt Tbg 3 1/2" Pup N-80 Butt 3 1/2" N-80 Butt Tbg 3 1/2" Pup N-80 Butt 3 1/2" N-80 Butt Tbg 3 1/2" Pup N-80 Butt 3 1/2" N-80 Butt Tbg 3 1/2" Pup N-80 Butt 3 1/2" N-80 Butt Tbg 3 1/2" Pup N-80 Butt 3 1/2" N-80 Butt Tbg 3 1/2" Pup N-80 Butt 3 1/2" N-80 Butt Tbg 3 1/2" Pup N-80 Butt 3 1/2" Pup N-80 Butt Cameron 3 1/2" Dual Hanger RT to Hanger LENGTH 4.18' 453.11' 4.18' 58.11' 3.60' 58.77' 4.07' 117.50' 4.08' 549.29' 4.06' 639.10' 4.02' 29.82' 10.04' 4.31' 1.O0' 27.68' BTM 1976.94' 1972.76' 1519.65' 1515.47' 1457.36' 1453.76' 1394.99' 1390.92' 1273.42' 1269.32' 720.03' 715.97' 76.87' 72.85' 43.03' 32.99' 28.68' 27.68' TOP , . 1972.7~' 1519.65' 1515.47' 1457.36' 1453.76' 1394.99' 1390.92' 1273.42' 1269.32' 720.03' 715.97' 76.87' 72.85' 43.03' 32.99' 28.68' 27.68' 0 LEASE A-028142 SHEET D PAGE NO. UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. KU #24-7 FIELD Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS JTS 10 2 132 1 LONG STRING TUBING DETAIL DESCRIPTION Mule Shoe 3 1/2" N-80 Butt Tbg Otis X-Nipple Baker Seals Locator 3 1/2" Pup N-80 Butt 3 1/2" Tbg N-80 Butt Otis XA Sleeve 3 1/2" Tbg N-80 Butt Baker Blast Jts 3 1/2" Tbg N-80 Butt A-5 Dual Pkr 3 1/2" Pup N-80 Butt 3 1/2" Tbg N-80 Butt Otis XA 3 1/2" Tbg N-80 Butt 3 1/2" Pup N-80 Butt 3 1/2" Tbg N-80 Butt 3 1/2" Pup N-80 Butt 3 1/2" Pup N-80 Butt Dual 3 1/2" Cameron Hanger RT to Hanger LENGTH BTM ,,, 0.66' 4724.66' 30.85' 4724.00' 1.43' 4693.15' 13.72' 4691.72' 0.88' 4678.00' 3.10' 4677.12' 30.55' 4674.02' 4.0' 4643.47' 57.95' 4639.47' 196.23' 4581.52' 60.05' 4385.29' 12.00' 4324.79' 4.20' 4312.79' 31.06' 4308.59' 4.00' 4277.53' 184.85' 4273.53' 3.08' 4088.68' 4044.30' 4085.60' 9.80' 41.30' 2.80' 31.50' 1.00' 28.70' 27.70' 27.70' TOP 4724.00' 4693.15' 4691.72' 4678.00' 4677.12' 4674.02' 4643.47' 4639.47' 4581.52' 4385.29' 4324.79' 4312.79' 4308.59' 4277.53' 4273.53' 4088.68' 4085.60' 41.30' 31.50' 28.Y0' 27.70' 0 CONTRACTOR Brinkerhoff Signal Inc. OIL COMPANY Union Oil Company TOOL PU.S.HER. DR RIG MAKE & MODEL /"q. 1 PUMP \".,.,AKE & MODEL NO. 2 PUMP MAKE & MODEL Emsco F-lO00 Liner 6 1/2 Oilwell lO00P Liner RUN NO. SIZE MAKE] ,.1ETS 32ND TYPE I 2 3 · . . 'RIG NO. 59 LEASE/WELL NO. DR BIT RECORD KU #24-7 COUNTY Kenai FIELD/TOWN STATE Alaska RECORD NO. SPUD DATE 5/12/82 SHEET NO. DR SEC/TSHIP/ RANGE 728'S & 748'_W f/ NE corner, Se.c. 1~, T4N, RllW,.. SM. TOOL $OINTS MAKE IF SIZE TYPE 4 1/2 OD 6 1/4 INTER .. BIT DEPTH FOOT- SER No. OUT AGE HOURS UNDER SURF DRILL COLLARS NO OD 8" ID 2 7/8 LENGTH TD ACCUM HOURS ..... DRILL COLLARS NO OD ID LENGTH WT 1000 VERT LB RRM DEV. PUMP No 1 No. 2 MUD DULL COND REMARKS _PRESS ..... SPM LIN SPM _L.I.N_ WT VIS T. ..... B G ...(FAILURE, E. TC.) 1 Sec 17 1/2 S350 1PR " " 2 II 11 3 HTC 12 1/4 X3A 5 II Il 8 Reed 8 1/2 S13G$ 20 20 20 16 16 13 12 12 12 13 13 B ---do--- ---do--- ---do--- ---do--- 130488 II 130487 LM 283 MM867 MM697 RA344 RA343 930266 300 .300 .... 3 - 816 516 2020 1204 2015 74 2517 497 2934 417 4407 1473 5433 1026 5820 367 5716 0 3 25- 60/80 13 10/ 7.5 10.5 15 0 11 19 1/4 19 1/4 15/20 80/100 39 2.5 2.5 3 3 3 5.5 15.5 15.5 11 11 c/o 500 65 55 1000/ 1200 42 1200 43 5O 52 20 60 1100 85 50/70 80/100 35 2400 100 45/50 70 34 2100 90 40/60 70 40.5 2100 90 50 llO 40.25 2200 90 50 llO 39 2200 90 69 200 2 3 I Gravel & Sand 66 75 69 75 69 56 69 56 69 61 68 46 69 47 72 44 72 43 3 4 I Dyna drlg 1 4 I 1 1 I Cmt 4 4 I S, Gl, Coal 3 3 I " 6 4 1/8 S, Sh, Gl, Coal 6 5 1/8 " 2 2 I " 1 1 I Drlg FC AMF' SCIENTIFIC DRILLING INTERNAI'IONAL 1111 E. AoT 801'H STREET GYROSCOPIC DIRECTIONAL SURVEY FOR *UNION OIL OF CALIFORIA* ************************ JOB NUMBER: 1359 WELL NAME: LOCATION: oURVEY DATE: DRILLPAD 41-18 WELL 24-7 KENAI GAS FIELD 0~/~.~/8~. oURVEY ENGINEER: PHIl_ GRAFFT MAGNETIC DECLINATION: AT .gO E GYRO REFERENCE BEARING: o 87-' 0 W METHOD OF [~AL. CUi...ATION: THE RADIUS OF CURVATURE VERTI[,A[. ,::~.~, ION: [.,Oi'~MEN1 S: GAL6ULA[ED USING PROPOSAL OF.N 83 ~.,., W THANK YOU * THIS SURVEY IS GORRECT TO THE BEo! OF MY 'x'KNOWLEDGIE AND IS SUPP[IR'i"ED BY ACTUAL F'IEI_D DATA,'x' , .x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x. ~. ~ ~..x..x..~ .x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x. .x. .x. COMPANY REPRESEN'rATIVIE .x. .x..x..x..x- .x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..~ .x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x..x. AMF SCIENTIFIC DRILLING INTERNATIONAL 1111 EAST 80TH STREET PAGE 1 (' JOB NUMBER: 1359 MEAS, VERT, VERT, I)EPTH DEPTH SECT, 100,00 100.00 200 , O0 200 . O0 300 . O0 299,99 400 . O0 399,88 500, O0 499,50 .00 ,44 1 .71 5.93 14.62 600.00 598.75 26.72 7(30.00 697,48 42.42 800,00 795,59 61,25 900,00 1992.97 83.38 1000.00 989,21 110.00 INRUN SURVEY BY THE RADIUS OF CURVATURE COURSE INC BEARING DEV, D M D M DATE: 05/25/82 ,00 O- 0 N / A .44 0-30 N 62-18 W .31 1- 0 N 41-15 W ,36 4- 0 N 57-14 W .72 6-..0 N 71- 9 W 12,19 8- 0 N 69~- 7 W 15,86 10-15 N 73-59 W 19.29 12-- 0 N 77-49 W 22.71 14-15 N 74-45 W 27.14 17-15 N 74.-34 W COORDINATES LATITUDE DEPARTURE D--LEG PER 100 .O0 N .00 E ,00 ,20 N ,39 W .50 1.01 N 1.41 W ,56 3,85 N 4,70 W 3,05 7,63 N 12.53 W 2,32 11.77 N 23,99 W 16,79 N 39,03 W 21,49 N 57.74 W 26,88 N 79,79 W 34,06 N 105,96 W 11(30.00 1083,96 141,4(3 31,93 20'- 0 N 73-17 W 42,90 N 136,65 W 1200,00 1176,99 177,51 36.65 23- 0 N 73- 4 W 53,51) N 171,73 W 1300.00 1267.98 218.40 41.46 26- 0 N 72-50 W 65,65 N 211.36 W 1400,00 1356.57 264,16 46,36 29-15 N 72-33 W 79,45 N 255,62 W 1500,00 1442,27 315.03 51,50 32""45 N 72-12 W 95.05 N 304.71 W 2.02 2,38 2,35 3,00 2.78 3.00 3,00 3.25 3.5(I AMF SCIENTIFIC DRILLING INTERNATIONAL 11'11 EAST 80TH STREET PAGE 2 JOB NUMBER: 1359 MEAS. VERT. VERT, DEPTH DEPTH SECT. INIBUN SURVEY BY THE RADIUS OF CURVATURE COURSE INC BEARING DEV, D M D M 1600,00 1526.14 368.92 54.46 33-15 N 71-17 W 1700.00 1608,92 424,44 56,10 35- 0 N 71-56 W 1800.00 1689.81 482.58 58.78 37- 0 N 71-42 W 1900.00 1769.15 542,85 60.88 38- 0 iN 71--,37 W 2000,00 1846,44 605,65 63.43 40-45 N 71-20 W 2100,00 1922,91 669,44 2200,00 2000,89 731,42 2300,00 2080,49 791.37 2400,00 2161.64 849.25 2500.00 2243,56 906,11 2600,00 2325,97 962,26 2700.00 2408,87 1017.79 2800.00 2491,78 1073,34 2900,00 2574.68 1128.86 3000,00 2657,09 1185.14 DATE: 05/25/82 COORDINATES LATITUDE DEPARTURE 112,10 N 356.43 W 129,80 N 409.65 W 148.14 N 465.49 W 167,31 N 523.29 W 187.46 N 583.43 W 64,44 39-'30 N 71-30 W 207,99 N 644,49 W 62.59 38- 0 N 71-40 W 227.77 N 703.89 W 60,53 36-"30 N 71- 2 W 247.12 N 761,24 W 58',42 35-. 0 N 71-12 W 266.02 N 816.51 W 57,36 35- 0 N 71'-14 W 284,51 N 870,84 W 56,64 34-. 0 N 70.-36 W 303.02 N 924,37 W 55,92 34-- 0 N 69.-48 W 321,96 N 976,98 W 55,92 34'- 0 N 69.-49 W 341.26 N 1029.44 W 55.92 34- 0 N 70-.41 W 360,15 N 1082,07 W 56,64 35-0 N 68-59 W 379,68 N 1135.23 W D-'LEG PER 100 .71 1 ,79 2.00 1.00 2.76 ,25 .50 ,55 .50 ,02 1,06 ,45 .01 .49 I .39 AMF SCIENTIFIC DRILLING INTERNATIONAL 1111 EAST 80TH STREET PAGE 3 JOB NUMBER: 1359 MEAS, VERT. VERT, DEPTH DEPTH SECT, 3100,00 2737,07 1844,88 3800,00 2813,81 1308,68 S300,00 2889,28 1374,02 3400,00 2964,75 1439,45 3500,00 3040,23 1504,94 3600,00 3115,55 1570,58 3700,00 3190,74 1636,40 3800,00 3266,07 1702,02 3900,00 3341,54 1767,53 4000,00 3417,[)1 1833,06 41()0,00 3492,419 1898,56 4200,00 3567,95 1964,08 4300,00 3643,42 2029,64 4400,00 3719,18 2(194,87 45(10,00 3794,94 2160,14 INRUN SURVEY BY THE RADIUS OF CURVATURE COURSE INC BEARING DEV, D M D M 'COORDI LATITUDE 60,00 38'-45 N 68-46 W 401 ,31 N 64,11 41- 0 N 69-24 W 424,20 N 65,61 41- 0 N 67.-54 W 448,09 N 65,61 41- 0 N 67-10 W 473,16 N 65,61 41- 0 N 66-.85 W 499.01 N 65,77 41.-.15 N 66-86 W 525,28 N 65,93 41.-15 N 67:-13 W 551,;_~3 N 65,77 41-. 0 N 67.-.14 W 576,69 N 65,61 41.- 0 N 65.-.45 W 602.85 N 65.61 41- ~) N 66-31 W 629,39 N 65,61 41.- 0 N 66-.39 W 655,46 N 65,61 41.- 0 N 65-54 W 681,86 N 65,61 41-. 0 N 65-.10 W 709,02 N 65,27 40-30 N 65-12 W 736,40 N 65,27 41..-() N 65.-.13 W 763~79 N DATE: 05/25/82 NATES D-LEG DEPARTURE PER 100 1191,21W 3,75 1251,10 W 2,29 1312,20 W ,98 1372,83 W ,48 1433,12 W ,48 1493,37 W ,25 1553,99 W ,51 1614,62 W .25 1674,78 W ,98 1734,78 W ,51 1794,98 W ,08 1855,04 W ,48 1914,76 W ,48 1973,99 W ,50 2033,28 W ,50 AMF SCIENTIFIC DRILL. lNG INTERNATIONAL 1111 EAST 80TH STREET PAGE 4 JOB NUMBER: 1359 MEAS, VERT, VERT, DEP TH DEP TH SECT, 4600,00 3870,55 2225,51 4700,00 3946,16 2291,02 48(10,00 4021 ,63 2356,57 4900.00 4097.10 2421,97 5000,0(I 4172,57 2487,61 5100,0 5200.0 5300,0 54(10,0 5500.0 5800,0 5700,0 0 4248,04 2553,17 0 432;~,51 2618,61 0 4398,98 2684,29 0 4474.74 2749,36? O 4551.06 2814,15 0 4627,66 2878,41 0 4704,27 2942,69 DATE: 05/25/82 INRUN SURVEY BY THE RADIUS Of CURVATURE COURSE INC BEARING I)EV, D M D M COORDINATES D-LEG LATITUDE DEPARTURE PER 100 65,44 40'-.45 N 65-.14 W 791,20 N 2092,65 W ,25 65,44 41- 0 N 65'-15 W 818,65 N 2152,17 W ,25 65,61 41- 0 N 66.- 0 W 845,72 N 2211,~3 W ,50 65.61 41'-' 0 N 65'-'5~ W 872,35 N 2271,73 W ,01 65,61 41- O N 65-58 W 8~,11N 2331,74 W ,01 65,61 41.- 0 N 65.-12 W 926,23 N 2391,48 W ,51 65,61 41- 0 N 65~I1 W 953.68 N 2450,92 W ,01 65,61 41- 0 N 65-10 W 981,28 N 2510,54 W ,01 65,27 40-30 N 65- 9 W 1008,66 N 2569,64 W ,5(1 64,61 40.-. 0 N 65-' 8 W 1035,90 N 2628,43 W ,50 64,28 40'- 0 N 64-14 W 1063,39 N 2686,53 W ,58 64,28 40- 0 N 64.-13 W 1091.35 N 2744,42 W ,O1 AMF SCIENTIFIC DRILLING INTERNATIONAL 1111 EAST 8OTH STREET PAGE JOB NUMBER: 1S59 MEAS, VERT, VERT, DEP TH DEP TH SEC]", 57A 0 , 00 INRUN SURVEY BY 4750,23 2981,27 THE RADIUS OF CURVATURE COURSE INC BEARING DEV, D M D M S8,57 40- 0 N 64-12 W DATE: COORDINATES LATITUDE DEPARI'URE 1108,1S N 2779,16 W 1'HE HORIZONTAL DISPLACEMENT Al' THE DEPTH OF 5760 00 FEET E. QUAL,~ 8991 ,94 FEET Al' N 68-16 W, 05/'25/82 D-LEG PIER 100 ,02 AMF SCIENTIFIC DRILLING INTERNATIONAL. 1111 EAST 8QTH STREET GYROSCOPIC DIRECTIONAL SURVEY FOR ~UNION OIL OF' CALIFORIA* JOB NUMBER: 1357 WELL NAME: DRILLPAD 41'-18 WELL 24-7 LOCATION: KENAI GAS FIELD oURVEY DATE: 05/85/88 SURVEY ENGINEER: PHIL GRAFFT MAGNETIC I)E. CLINATION: Al' ,00 El GYRO REFERENCE; BEARING: S 87 .... () W METHOD [)F CAI..CUI..ATION: 't'HE TANGENTIAl_ METHOD VERTICAl_ ('' " ' ,:)E(.,T I (:IN: CAi_CUi..ATED USING I")R(]POSAL OF N 6J**"2,.~ W COMMENTS: 'i'HANK YOU BEo'F OF MY .x. · x- T H I S S U R V E Y I S (2. O R R E C.T T O T H Il:.' ' · x. KNOWI...EI,~GE AND IS SUPPORTED BY ALl'UAl... I:'"IEi_D DATA,.x. .~ .......... --- -X, · ×. .×..X..×..X' '×' '×' 'X' .×. -×..×. -×..×' '×' '×' .×. .x. COMP ANY REP R E[ENTAT I VE .x. .×..x..x..×- .×..×..x..x. -x..×..×..x..x..x. -×..x..x..x..x..x- .x..x..×..~ .x..×..x..x. ~ .x..x. * .x..x..×..×..x. * .x- .×..x..×. -x..x..x..x..x..x. AMF SCIENTIFIC DRILLING INTERNATIONAL 1111 EAST 80TH STREET PAGE 1 JOB NUMBER: 1S59 MEALS, VERT, VERT, DEPTH DEPTH SECT, 100,00 100,00 200 , O0 200 , O0 300. O0 299,98 400 . O0 399.74 500. O0 499.19 ,00 ,87 2,49 9,42 19.78 600 , 00 598,22 33,63 700 , 00 696,62 51 , 12 800, O0 794,44 71 , 26 900, O0 891 , 36 95,40 000 , O0 986,86 124,49 1100,00 1080,83 158,19 1200, O0 1172,88 196,71 1300, O0 1262,76 239,96 1400 , 00 1350 , O1 288,20 1500 . O0 1434 , 11 341 , 67 INRUN SURVEY BY THE TANGENI'IAL METHOD COURSE INC BEARING C DEV, D M D M LATI . O0 0"- 0 N / A ,87 0-30 N 62.-18 W 1,75 1- 0 N 41-15 W 1 6,98 4'- 0 N 57-14 W 5 10,45 6- 0 N 71-' 9 W 8 13,92 8- 0 N 69-' 7 W 17,79 10-15 N 73-59 W 18 20,79 12"- 0 N 77-49 W 23 24,62 14-15 N 74-45 W 29 29,65 17-15 N 74-.34 W 37 34,20 20- 0 N 73-17 W 39,07 23- 0 N 73-' 4 W 43,84 26- 0 N 72-50 W 48,86 29-15 N 72-33 W 54,10 32-45 N 72-12 W DATE: 05/25/82 (]ORDINATES TUDE DEPARTURE D-LEG PER 100 , 00 N , 00 E . O0 ,41 N ,77 W ,50 ,72 N 1,92 W ,56 ,49 N 7.79 W 3,05 ,87 N 17,68 W 2,S2 ,83 N 30.69 W 2,02 ,74 N 47,79 W 2.38 ,13 N 68,11 W 1,90 ,61 N 91,86 W 2,35 ,50 N 120,44 W 47,33 N 153,20 W 58,71 N 190,58 W 71,65 N 232,47 W 86,31N 279.08 W 102,84 N 330,59 W 2,78 3, O0 3,00 3,25 3,50 AMF SCIENTIFIC DRILLING INTERNATIONAL 1111 EAST 80TH STREET PAGE JOB NUMBER: 1559 MEAS, VERT, VERT, DEPTH DEPTH SECT, 1600 , 00 1517,74 I700,00 1599,66 1800, O0 1679,52 1900,00 1758,32 2000 , I) 0 1834,08 2100,00 1911 ,24 2200, O0 1990 , 04 2300,00 2070,43 2400 . O0 2152,34 2500, O0 2234,26 2600,00 2.317,16 2700,00 2400,07 ;?.800,00 2482,97 ;.:.).900 , 00 2565,87 3000, O0 2647,79 395,98 452,71 512,26 573,20 637,85 700,83 761,76 880,72 877,55 934,37 989,85 1045,43 1101,00 1156,47 1213,56 THE COURSE DEV, INRUN SURVEY BY TANGENTIAl_ METHOD INC .BEARING DM D M I)ATE: 05/25/82 COORDINATES LATII'UDE DEPARTURE 54,83 33-15 N 71-.17 W 120,43 N 382,52 W 57,36 35-' 0 N 71-56 W 138,22 N 437,05 W 60,18 37-. 0 N 71-42 W 157,12 N 494,19 W 61,57 38'- 0 N 71-37 W 176,54 N 552,61 W 65,28 40-45 N 71-20 W 197,43 N 614,45 W 63,61 39-30 N 71 .... 30 W 61,57 38..- 0 N 71-40 W 59,48 36-30 N 71.- 2). W 57,36 35- 0 N 71-12 W 57,36 35'-' 0 N 71-14 W 55,98 34- 0 N 70-36 W 55,98 34"- 0 N 69-48 W 55,92 34 .... 0 N 69.-49 W 55,92 34- 0 N 70---41 W 57,36 35- 0 N 68'-59 W 217,62 N 674,77 W 236,98 N 7~J3,21 W 256,30 N 789,47 W 2).74,79 N 84:~,77 W 293,2).4 N 898,07 W 311,81 N 950,82 W 331,12 N 11)03,30 W 350,42 N 1055,78 W 368,91 N 1108,56 W 389,49 N 1162,10 W D-...L. EG PER 100 .71 1,79 2,00 1 , 00 2,76 1 , 25 1 ,50 1 ,55 1,50 ,02 1,06 ,45 ,01 ,49 1 AMF SCIENTIFIC DRILLING INTERNATIONAL 1111 EAST 80TH STREET PAGE JOB NUMBER: 1359 MEAS, VERT, VERT, DEPTH DEPTH SECT, 31 O0, O0 3200, O0 3300. O0 3400.00 3500, O0 3600.0 3700,0 3800,0 3900,0 4000,0 4I O0,0 4200.0 430 0,0 4400,0 450 0,0 2725,78 1275,88 2801,25 1341,13 2876,72 1406,53 2952,19 1472.00 3027.66 1537.51 0 3102,85 1603,36 0 3178,03 1669,15 0 3253,50 1734.61 0 3328,97 1800,16 0 3404,44 1865,67 0 3479,91 1931.17 0 3555.39 1996,72 0 3630,86 2062,29 0 3706,90 2127,21 0 3782,37 2192,78 INRUN SURVEY BY THE TANGENTIAL METHOD COURSE INC BEARING DEV, D M D M 62,59 38..-45 N 68--46 W 65,61 41- 0 N 69-24 W 65,61 41- 0 N 67-54 W 65,61 41'" 0 N 67'-10 W 65,61 41-' 0 N 66'"'25 W 65,93 41-15 N 66-26 W 65,93 41"-15 N 67-13 W 65,61 41- 0 N 67-"14 W 65,61 41- 0 N 65--45 W 65,61 41"' 0 N 66'"'31 W 65,61 41'- 0 N 66-39 W 65,61 41'-' 0 N 65'"'54 W 65,61 41'- 0 N 65 .... 10 W 64,94 40-30 N 65'-12 W 65,61 41'- Q N 65'-'13 W DATE: 05/25/82 COORDINATES LATITUDE DEPARTURE D-LEG PER 100 537,99 N 1523,67 W ,25 563,53 N 1584,45 W ,51 588,91 N 1644,95 W ,25 615,86 N 1704,77 W ,98 641,99 N 1764,94 W ,51 668,00 N 1825,17 W ,08 694,79 N 1885,06 W ,48 722,33 N 1944,60 W ,48 749,58 N 2003,56 W ,50 777,08 N 2063,12 W ,50 412,15 N 1220,44 W 3,75 435,24 N 1281,85 W 2,29 459,93 N 1342,64 W ,98 485,39 N 1403,10 W ,48 511,63 N 1463,23 W ,48 AMF SCIENTIFIC DRILLING INTERNATIONAL 1111 EAST 80TH STREET PAGE 4 JOB NUMBER: MEAS, VERT, DEPTH DEPTH 4600,00 3858 4700,00 3933 4800 , O0 4(1 (19 4900,00 4084 5000 . 00 41 60 5100, O0 4235 52. 00 , 00 4310 5300, O0 4386 5400 , 00 44612 551) 0, OO 4539 5600, O0 4615 5700,01) 4692 1359 VERT, SECT, ,12 8258,02 ,60 2323,60 .07 238~,14 ,54 2454,68 ,01 2520,22 ,48 2585,79 ,95 2651,37 ,42 2716,94 ,46 2781,86 ,07 2846.11 ,67 2910,38 ,28 2974,65 DATE: 05/25/82 INRUN SURVEY BY THE TANGENTIAL METHOD COURSE INC BEARING DEV, D M D M COOR D I NATES D'"L. EG LATITUDE DEPARTURE PER 100 65,28 40'-45 N 65.-.14 W 804,43 N 2122.39 W ,25 65,61 41- 0 N 65.-15 W 831,89 N 2181,97 W ,25 65,61 41.-- 0 N 66-0 W 858,57 N 2241,91W ,50 65,61 41- O N 65~5~ W 885,27 N 2301,84 W ,01 65,61 41.- 0 N 65-58 W 911,~8 N 2361,76 W ,01 65,61 41.- 0 N 65-12 W 939,51 N 2421,31 W ,51 65,61 41 .... 0 N 65'-11 W 967,05 N 2480,86 W 65,61 41'- 0 N 65'-10 W 994,61N 2540,~9 W ,01 64,94 40-30 N 65,- 9 W 1021,90 N 2599,32 W ,51) 64,28 40- 0 N 65-' 8 W 1048.V3 N 2657,64 W ,50 64,28 40-- 0 N 64-14 W 1076.87 N 2715,53 W ,58 64,28 40'- 0 N 64-13 W 1104,83 N 2773,41 W ,01 AMF SCIENTIFIC DRILLING INTERNATIONAL 1111 EAST 80TH STREET PAGE 5 JOB NUMBER: 135~ DATE: 05/25/82 INRUN SURVEY BY THE TANGENTIAL METHOI) MEAS, VER T, DEP'lr'H DEPTH VER l' , COUR SE I NC BEAR I NG SECT, DI-'_V. D M D M COOR D I NATES D-LEG LATITUDE DEPARTURE PER 100 5760.00 4738,24 3013,22 38,57 40'- 0 N 64-12 W 1121,61 N 2808,14 W ,08 THE HORIZONTAL. DISI:>LACEMENT AT THE DEPTH Of 5760,00 F'IEET EQUALS 30~3,85 FEET AT N 68-14 W, AMi: SCIENTIFIC DRILLING INTERNATIONAL 1111 EAST 80TH STREET GYROSCOPIC DIRECTIONAL SURVEY FOR · X..X. -X- .X- * .X. * .X..X..X..X- 'X. -)~ * * 'X..X' -X- .X' .X' 'X- .X- -X' 'x- · x. UNION Oil_ OF CALIFORIA* · ~ .X- -X, * .X- .X..X..X. 'X. * 'X. -X. -X. -)~ -X' -~ 'X' 'X- 'X' -X' -X' 'X' 'X- 'X' JOB NUMBER: 13;59 WEL..L NAME: LOCATION: SURVEY DATE: oURVEY ENGINEER: MA(.-]NET IC DECL. INATION: DRILLPAD 41-18 WELl. 24-7 KENAI GAS FIELD 05/25/88 PHIL GRAFFT AT .0 0 E GYRO REFERE~NCE BEARING: S 87- 0 W METHOD [)F. CALCULATION: THE ANGLE-AVERAGED METHOD .............. 83"'2,~ W VtERTICAI_ SE.(.,IION: CAL.(.,UI..A~ED tJSING PRC)POSAI.. (DF N .... COMMENTS: THANK Y(]U * 'IFHIS SURVEY IS CORRECT TO THE BE.o! OF MY * '" ' ('" ('" 3 ' " '" .......... , .x. KNOWLEDGE AND Io ,.~tJr~(,lUAl.. i-.[EI.D DA1 A * .X- 'X~ C'-c~~~ .X' .X. * .x. .x..x..x..x. .x. ~..x..x..x..x, .x- .x..x., .x..x., .x..x..x..x..x..x..x., .x. .x. COMP ANY REP R IESIENTAT I VIE .x. ,.x..x..x.,.x..x.,, .x. **.×,,, ,.×..x.,,,, .x..x-, .x., .x. **, **,, .x., .x.** .x. **.x.-x. ,.x..x..x., AMF SCIENTIFIC DRILLING INTERNATIONAL 1111 EAST 80TH STREET PAGE 1 JOB NUMBER: 1359 MEAS, VERT, VERT, DEPTH DEPTI-i SECT, 10(1,00 100,00 2(10, O0 800, (10 ,44 300 , O0 299.99 1 , 72 40(I, O0 399,90 5,95 50(I, 00 499,51 14,66 600 , O0 598,77 700 , O0 697,50 80(I , O0 795,62 900 , O0 893, O1 000,00 989,2(.) 11 O0 , O0 1 084.02 1200, O0 1177,06 1300 , O0 1268,06 '1400 , O0 1356,66 '15(10, O0 '1442,31'3 26,77 42,47 61 , 30 83,44 110,07 INIBUN SURVEY BY THE ANGLE-AVERAGED METHOD COURSE INC BEARING DEV, D M D M ,OO O.- 0 N / A ,44 (!-30 N 62.-119 W ,31 1'- 0 N 41.-15 W ,36 4'- 0 N 57,-.14 W ,72 6- 0 N 71- 9 W 12,19 8'- 0 N 69- 7 W 15,86 1(3-15 N 73....59 W 19,3(1 12 .... 0 N 77-49 W 22,71 14-.15 N 74-...45 W 27,14 17-15 N 74.-34 W DATE: 05/25/82 COORDINATES LATITUDE DEPARTURE I)-.-.LEG PER 100 .(30 N ,(1(3 E ,00 ,20 N ,39 W ,50 1,01 N 1,41 W ,56 3,86 N 4,72 W 3,05 7,65 N '12,57 W 2,32 11,80 N 24,03 W 16,82 N 39,07 W 21,52 N 57,78 W 26,90 N 79,84 W 34,09 N 1(36,02 W 141,47 31.94 20- 0 N 73-17 W 42,93 N 136,71W 177,59 36,65 23 .... 0 N 73- 4 W 53,53 N 171,79 W 218,49 41,47 26'- 0 N 72-50 W 65,69 N 211,44 W 264,25 46,37 29-15 N 72-33 W 79,49 N 255,71 W 315,13 51,5(3 32'-45 N 72-18 W 95,08 N 304,79 W 2, (32 2,38 1 ,90 2,35 3 ,' (30 2,78 3.00 3.00 3,25 3,5(3 AMF SCIENI'IFIC DRILLING INTERNATIONAL 1111 EAST 80TH STREET PAGE 2 JOB NUMBER: 1359 MEAS. VERT, DEPTH DEPI'H 1600,00 1526,24 1700,00 1609,02 1800,00 1689,93 1900 , O0 176(?, 26 2000.00 1846,56 2100.00 1923.03 2200, O0 2001, O1 23(30 , 0(3 2080 . 62 2400 . O0 2161 , 77 2500,00 2243,69 2600, O0 2700.00 2800,00 2900.00 3000,00 VERT, SECT, INRUN SURVEY BY THE ANGLE-AVERAGED METHOD COURSE INC BEARING DEV, D M D M DATE: 05/25/82 COORDINATES LATITUDE DEPARTURE 369,02 54,46 33-15 N 71-.17 W 112,14 N 356,5,~ W 424,54 56,10 35'- 0 N 71 .-56 W 129,84 N 409,75 W 482,69 58,78 ,37- 0 N 71.-42 W 148,19 N 465,59 W 542,94 60,88 38.- 0 N 71..-37 W 167,34 N 52`3,38 W 605,75 63,44 40.-45 N 71-20 W 187,50 N 583,53 W 64,45 39-30 N 71--3() W 62,59 38.- 0 N 71--.40 W 60,53 36-30 N 71- 2 W 58,42 35'- 0 N 71'-12 W 57,36 ,35 .... 0 N 71-.14 W 56,64 34- 0 N 70-,36 W 55,92 34.- O N 69.-48 W 55,92 34 .... 0 N 69-49 W 55,92 34- 0 N 70..-41 W 56,64 35-' 0 N 68-59 W 669,57 731,53 791,48 849,38 906,21 2326,10 962,36 2409,00 1017,89 2491,91 1(373,47 2574,81 1128,99 2657,22 1185,27 208,04 N 644,61W 227,82 N 704,00 W 247,17 N 761,`35 W 266,07 N 816,63 W 284,54 N 870,94 W 30`3,06 N 924,47 W 322,00 N (?77,08 W 341,`30 N 1029,56 W 360,20 N 1082,19 W 37(?,72 N 1135,36 W D..-LEG PER 100 ,71 2, O0 1 , 00 2,76 ,50 ,55 ,50 ,02 ,06 ,45 ,01 ,39 AMF SCIENTIFIC DRILL. lNG INTERNATIONAL 1111 EAST 80TH STREET PAGE JOB NUMBER: 1359 MEAS. VERT, VERT. I)EP TH DEP TH SECT, 3100,00 2737,22 1245,01 3200,00 2813,96 1308,81 3300,00 2889.43 1374,14 34(10,00 2984,91 1439,58 3500,00 3040,38 1505,07 3800,0(I 3115,70 1570,75 37(10,00 3190,89 1636,57 380(1,00 3288,22 1702.20 3900,00 3341,69 1767,71 4000,00 3417,16 1833,24 INRUN SURVEY BY THE ANGLE-AVERAGED METHOD COUR SE I NC BEAR I NG DEV, D M D M 8O,O1 38.-45 N 68-48 W 84,11 41- 0 N 89-24 W 85,81 41--. (1 N 87-54 W 65,61 41- 0 N 87-10 W 65,61 41- 0 N 66-85 W 85,77 41.-.15 N 88-28 W 85,93 41'.-15 N 87-13 W 85,77 41.- 0 N 87-.14 W 65,81 41.- 0 N 65-45 W 85,81 41- 0 N 88-31 W 410Q,O0 3492,63 1898,75 65,61 41- 0 N 86-.39 W 420O,OO 3588,10 1984,27 85,81 41.- 0 N 65--54 W 4300,O0 3643,57 2029,83 65,81 41- 0 N 85 .... 10 W 44(~0,0(~ 3719,33 2O95,08 85,28 40-30 N 85-12 W 4500,00 3795,08 2180,32 85,28 41- 0 N 85 .... 13 W DATE: 05/25/82 (](]ORDINATES LATITUDE DEPARTURE 401,35 N 1191,33 W 424,24 N 1251,22 W 448,13 N 1312,32 W 473,21N 1372,95 W 499,06 N 1433,24 W 525,38 N 1493,53 W 551,31 N 1554,14 W 578,77 N 1614,78 W 6O2,93 N 1674,94 W 629,48 N 1734,94 W 855,55 N 1795,14 W 681,94 N 1855,21 W 709,11 N 1914,92 W 738,51 N 1974,17 W 763,88 N 2033,43 W D....LEG PER lOO 3.75 2,29 ,98 .48 ,48 ,25 ,51 ,25 ,98 ,51 ,08 ,48 .48 ,5O ,50 AMF SCIENTIFIC DRILLING INTERNATIONAl. 1111 EAST 80TH STREET PAGE JOB NUMBER: 1359 MIEAS, VER T. VE:R T, DE:PTH DEPTH SECT, 4600,00 4700, O0 4800,00 4900. O0 5000,00 5100,00 5200,00 5300,00 5400, O0 5500,00 5600, O0 5700,00 3870,70 2225,73 3946,31 2291,14 4021,78 2356,69 41) 97,25 2422,23 4172,73 8487,77 4248,20 2553,33 4323,67 8618,91 4399,14 2684,48 4474,89 2749,73 4551,22 2814,31 4627,82 2878,58 4704,43 2942,85 INRUN SURVEY DATE: 05/25/82 BY THE ANGLE-AVERAGED METHOD COURSE INC BEARING DEV, D M D M COOR D I NATES D'-'-L. EG i_ATITUDE DEPARTURE PER 100 65,44 40-45 N 65--14 W 65,44 41- 0 N 65-15 W 65,61 41- 0 N 66- 0 W 65,61 41-' 0 N 65 .-.59 W 65,61 41 .... 0 N 65-58 W 791,31N 2092,85 W 818,71 N 2152,27 W 845,78 N 2212,07 W ,50 872,47~N 2271,97 W ,01 899,18 N 2331,89 W ,01 65,61 41"" 0 N 65,61 41-0 N 65,61 41-0 N 65.28 40""30 N 64,61 40- 0 N 65-12 W 926,30 N 2391,63 W ,51 65-11 W 953,83 N 2451,18 W ,01 65-11) W 981,38 N 2510,72 W ,01 65- 9 W 1008,81 N 2569,95 W ,51) 65'- 8 W 1035,97 N 2628,58 W ,50 64,28 40- 0 N 64-14 W 1063,46 N 2686,68 W ,58 64,28 40 .... 0 N 64-13 W 1091,40 N 2744,57 W ,01 PAGE AMF SCIENTIFIC DRILLING INTERNATIONAL 1111 EAST 8QTH STREET JOB NUMBER 1359 INRUN SURVEY DATE: 05/25/82 BY MEAS, VER T. VER T DEP TH DEPTH SECT 5760,00 4750.39 2981,41 THE ANGLE-AVERAGED METHOD COURSE INC BEARING COORDINATES DEV, D M D M LATII'UDE DEPARTURE 38,57 40- 0 N 64-12 W 1108,18 N 2779,30 W D..-'LEG PER 100 , O2 THE HORIZONTAL.. DISPLACEMENT AT THE DEPTH OF 5760,Q0 FEET EQUALS 8~98,08 FEET AT N 68 16 W, Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. - - Oper~tor~ WAil-N~~and Number Reports and Materials to be received by: ?-~' -- Date Required Date Received Remarks Completion Report Yes · '::~i~_P- .... ~_ ,~ ...... ~.-~o.-,~ .. ~I~ _~.., :"'~11 .His~ Yes ~ , .... . .... Mud L~ ~... ._ , ......~ - ~ , ~re ~ips .,,.,,...Registered ~ey Plat '-~ Inclination .Su~ey ~ ,. , Drill St~ Test Re~s ~D ,~--, ..Di~itiz..ta ...... .~~ :-Xr__~> Z.~,'f~..'.. '~" -- ~ STATE OF ALASKA L AND GAS CONSERVATION C~'~MISSION ALASKA MI}NTHLY REPORT OF DRILLING AND WORKOVER OPERATION · Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 82-16 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 133-20352 4. Location of Well at surface 728'S & 748'W of NE corner, Sec. 18, T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. GL 67;7' MSL A-n2Rla2 9. Unit or Lease Name KENAI UNIT 10. Well No. KU #24-7 11. Field and Pool KENAI GAS FIELD STERLING POOl For the Month of MAY 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced operations ® 00:01 hrs 5/12/82 Spud ~ 23:30 hrs 5/12/82 TD ~,5820' 5/22/82 13. Casing or liner run and quantities of cement, results of pressure tests Drove 20" csg to 179' Ran 13 3/8" 61# K-55 butt csg to 2003' cmt w/ 1225 sxs & tested to 2500 psi - o~ Ran 9 5/8" 43 1/2# & 47# osg to 5801' cmt w/ 1900 sxs & tested to 3000 psi - ok 14. Coring resume and brief description None 15. Logs run and depth where run DIL-BHC-Sonic-VDL-GR f/ 5820-2000' FDC-CNL-GR f/ 5820-2000' CBL-VDL-GR f/ 5704-1800' (cased hole) 1 6. DST data, perforating data, shows of H2S, miscellaneous data Perfed 4890-4925' 4410-4490, & 4525-4560' 17. I hereby~e/tify that the foregoing is true and correct to the best of my knowledge. ' ~SIGNE iTLE ~ DRLG SUPT DATE 6/15/82 NOT~-Report on tJ~is form is required f ~e~ac~o~~~tUs of operations, and must be filed in duplicate with the Alaska Oi~hd Gas Conser/~tion Commission by~i"~t/l~"c=~'~'c~.e'~nth, unless otherwise directed. F/drm 10-404 / /~' Submit in duplicate February 2, 1982 Hr. Robert T. Anderson District Laud Hanager Union 0ti Company of Cali/~ornla P. O. Box 62,~7 Anchorage, Alaska 99502 Kena. t Unit KU NO. 2&-7 un/on Oil Company of California Permit No. 82'-!6 Sug, Loc. 745'S, 775'W of NE cr Sec 18, T4N, RIiW, SM, Bottomhole Loc~ ~90~, 1730'E of S~ cr Sec 7, TiN, RII~, Dear Hr. Auderson~ Enclosed is the approved application for permit to drill the above referenced well. ~ell samples and a mud log are not required. A continuous directional survey ts required as per 20 AAC 25.050(b)(5). available, a tape contain/n/ the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys anti dtpmeter surveys. Hany rivers in Alaska and their drainate systems have been classified as important for the spawning or migration of anadromous fish, Operations in these areas are subject to AS 16.05,870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code), Prior to commencing operations...you may be contacted by the habitat Coordinator*s Office, Department of dish end Game. Pollution of any waters of the State is prohibited by AS 66. Chapter 3, Artiale 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Hr. Robert T, -2- ~'..-~"e~ruary 2, 1982 To aid us in schedultn$ field work, we would appreciate your notifyins this office within 48 hours after the veil is spudded, We would .also like to be notified so that a representative of the Commission may b.e present to witness testing of bl0vout preventer equip~ent before surface castn~ shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present, Very truly yours, Alaska Oil and Gas Conservation Commission Eno Io sure Department of Fish & Game, Habitat Section v/o encl, Department of Environmental Conservation v/o anti. CVC~be union Oil and Gas E'"~on: Western Region Union Oil Company of California P.O. Box' 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unlen Robert T. Anderson District Land Manager '$anuary 22~ 1~82 Hr. Chat Chatterton Ak. Oil & Gas Conservation Committee 3001Rorcupine Drive Anchorage, Alaska 99504 KENAI SOLDOTNA AREA State of Alaska Kenai Gas Field Kenai Unit, KU #24-7, A-028142 (8-86-71-5390-600972) Dear Hr. Chatterton: Enclosed for your approval are three (3) fully executed copies of the above captioned Rermit to Drill KU #24-7 in the Kenai Gas Field. Also enclosed is our Check No. 19179 in the amount of $100.00 to cover filing fees. Very truly yours, sk Enclosures (4) cc: $. R. Callender A. Lannin-LA Office RECEIVED JAN 2 6 ]982 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ?-X ALASKA ~.,tL AND GAS CONSERVATION CO.,~MISSION I='ERMIT TO DRILL 20 AAC 26.005 la. Type of work. DRILL REDRILL DEEPEN 1 b, Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS J~ SERVICE [] STRATIGRAPHIC SINGLE ZONE [] MULTIPLE ZONE 2. Name of operator UNION OIL COMPANY OF CALIFORNIA 31 Address PO BOX 6247~ ANCHORAGE, ALASKA 99502 4. Location of well at surface +745'S & +775'W of NE Corner, Section 18, T4N, RllW, SM. At top of proposed producing interval +~50'N & +_2450'E of SW corner, S.7 T4N RllW SM. At total depth +590'N & +1730'E of SW corner, S.7 T4N RllW SM. i 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. KB +100' MSL I A-028142 . m 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/or number 9. Unit or lease name KENAI UNIT 10. Well number KU f124-7 11. Field and pool KENAI GAS FIELD National Fire Insurance Company of Hartford (B5534278) Amount $200,000.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 7 mi South miles 590 feet well 1900 feet 16. Proposed depth (MD & TVD) 1~. Number of acres in lease 18. Approximate spud date +7000' MD & +5700' TVD feet 2560 2/15/82 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures ~l~00 psig@~Surface KICK OFF POINT +500 feet. MAXIMUM HOLE ANGLE +31° l (see 20 AAC 25.035 (c) (2) **1800 psig@ 5000 .ft. TD (TVD) 21 *Max possib-le surf press uszng wt ofg'~s **Based on KU Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 20 ~4f~ H-4O I Plainl lDO' Surt' I --- +lOO~ --- Driven 17 1/21 i3 3/8 61fl K-55 I Butt-I 2000' Surf ' --- ~000! ¢-~1 1100 sxs 12 1/41 95/8 47¢t N-80 I Butt.16000' Surf I --- +6000[-~7E! +14OO sxs °r as ' ~ -- I r--equired by callper ~ ~ log t'or lOO0' t'illup 22. Describe prOposed program: ' I I . ~-Y-~ in 1~ ~/8'" csg. 1. Move in and rig up Brinkerhoff Rig f~58. 2. Drive 20" to refusal ~ +100' & install 20" diverter. 3. Drill 17 1/2" directio~l hole to +2000'. . 5. 6. 7. 8. 9. 10. 11. Run & cmt 13 318" csg ~ +2000' Install 12" 3000 psi starting ~ead, install & test BOPE. Drill 12 1/4" directional hole to +6000' TMD. Run and cement 9 5/8" csg 6 +6000'7 Remove BOPE, install tubing head, install and test BOPE. Clean out to TD and run CBL & gyro. Squeeze and test Sterling gas sands as required. Complete well ad dual 3 1/2" Sterling gas producer. RECEIVED JAN 2 6 ]982 Alaska 0il & Gas Cons. Commission Anchorage 23. I hereby c~._~e~ true a/correct to.~e best of my kn(~ge TheSiS'/~~space below for Commislion use . ~(~,~C ~TiT~LE Dzs'trz'ct Land Mgr DATE 1/22/82 CONDITIONS OF APPROVAL Samples required Mud Icg required []YES ~NO []YES [~NO Permit number Approval date APPROVED BC~ ~~ Form 10~,01 Directional Survey required I APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE by order of the Commission Februar~ 2, 1982/~, Submit in triplicate' r-~_.. ~ ~ ~ · i RECEIVED JAN ~ (~ 1982 ~as'l(a Oil & Gas Cons. commissiu. Anchorage H¥ 13R:l;Ut.. I~...~ · JAN2 6 1982 oil & Gas ¢o~$. Anchorage lift i ' 3.000 ps; 50t,O RECEIVED JAN2 6 ]982 Alaska Oil & Gas Cons. Commission Anchorage .. ! . : ~,t ..'. ~ ~,, ' . ' . ' , . . ..... .. .,,. .,~ . · ...... . ...... ......,,,,... ............. .:.... - ,.. . - " , & - . . '.. ' ,' .. ' ' '-. ...... ' ',;'.e 'C:.:?' ','::~4:."" · .... . " · , , .,... .,.-, .....~ . '~tt¢~E~'. .'-" . . JAN 2 '6 19B2 , . · : ,. ~.:~ ~ D~~~D.. .... , Il I ..... '" "S~ ......... - . . ~ .. ...... _ ~ - DA~ - .. : . _ .-, .~, , ....... " ' ...... i Ill Botto~ Top · DESCRIPTION WEIGHT ~ENSION M/NI.~J~4 TDF COLLAPSE COLLAPSE OD~ ~UBST Wt. Grade o_ L J i ! L' L i i IIiTERi~T., :BDF PP~ fiO BF __ -top of ' 8TRENG2%I ' P~SS. ~' ~IST. P~SS~ 1.~l.~{ PER Thread BF~ section TE~ION ~ott~ tension Y~LD ~. , , lbs , , i~S 1000 lbs ,, psi , y$,i~, , ~si , psi ....... . ~ ~2 M ~ }x~'+.<" ~x ?g~_ .,~7~ /s~./~ /~_ , ~' ~ g.¢o 7,?. ~ ,,, , , B . J 1' L ' __ 11 i -- 11 . Fonuulae: ' Calculations: Collapse resistance in tension = X (Collapse pressure ratin~) Burst Pressure = ~mP +. ~pta ( It,va. Or. II --,5) ~F (Bouyancy F&c'ior) = l.~- (o.~3 x Ma w~. ~) · . . i i , ~ ~ ....... ., .......... c~sn~G s~= 71~. '.,-:o~ ~= ~..'~" ~ ~. ~ ~?'.'~. f~/~ ~ o~. ~.~ .~/f~.- ~ w. ~~ ~. oa. ~z_~ .~/r~.. ms.~.~ . ~. WI ~ -top of 'ST~NG~ P~S8. ~ ~StS~. -~8~ 1,~!.Y2~ PER ~ttom. '~ Wt. Grade ~nzea& W/O ~ sectiom TERB'ION bott~ tensiom ~LD ............ lbs lbs .... lO00.1~s ~, _psi. psi _- psi .... psi . _ . , -- , -- IlJJ Il _ . ~ _ _ -- _ - _ - ~ . ~ _ -- 1, , , _1,1 ~ , , , ~ i, ....... _ - ~- ~ 0~ - _ ~,, ~ ., - ~ ..... _ _ _z _ _ i ,, ,, , . ~ ........ ,1 , , 1, , . _ ~ , Y=Tensile ~pad/Pi. pe Yield Strength ..~ 0 2 ~'. 6 '~~ 0 Fo~ulae: ~ Calculations O, . ,' ...... ~ , ' - '~~' ~ , . .: ~ ............ . ... ~, ....j..lj .... ,J~.jl.d .....~1. ..~ .. .... '.,.......-... , ...t,. ~-..~.~... ...~ ~ ..t..~... .~t...~. · ,. . . ~ i::~:::~:~l:{i:{;fi~l~i~l:[i~{i~l};~.il~:.{:7{~I Collapse ~e~i~nce in tension = · ...... '3. t...J,.'., ..,., .... , ........ [~ ,;... ...,i ........; . .......,..,.J ,.. ,,.. · · ,~ ,I I ~., ,., · '''. "'* 'j e~. ...... }~.:~-:': :.::,::~.'J::::: ::~: ;~.; .~ ~'... .... i__. ;,.~., ...I.J..~. ,,.,. . ~ ,I.. .81 .... ~-.1 ...... ~,., ...... ' - -I'- '- ..... *. .. -i.m. ~.,~ 4 i' '*' '"~ ". ~ If ..: ..~, ~... ,~,~., I'., 'm. a J ...... ~..l. ,.,-.,I.,...,.,~i .... l.,..! :':.1: ..... J ....... {% . i.. ~ ,~,~ . ].~ '.';.. ?~.:~ '.::,: ...... '. ',,. .:i . .~. . ~. :.. .. .. l ! I I 1 ! ! ! ! ! I ! ! I ! l ! ! __._J _ ~ J I I ~ I//L \ ~, u-,, 33 -I CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc 1 3 4. 5. 6. 7. 8. (3) Admin ~'jL.. !~' 'bk~'~l-. 9 ~ (9/thru 11) 10 11 (4) Casg ~ /~z7-~12 ~2 thru 20) 13 · 14. 15. 16. 17. 18. 19. 20. (5) BOPE~ /'--~:~;~-&g._ 21. ~.(~-1 thru ~4) 22 23 24 25. YES NO Is the permit fee attached ......................................... ~_~ Is well to be located in a defined pool ............................. Is well located proper distance from property line ........ ..........7 Is well located proper distance from other wells .................... ~ Is sufficient undedicated acreage available in this pool ............ ~ Is well to be deviated and is well bore plat included ............... ( Is operator the only affected party ................................. ~ Can permit be approved before ten-day wait .......................... C REMARKS Does operator have a bond in force ........................ Is a conservation order needed ... i ........ i'ii'[''~' Is administrative approval needed .............. Is conductor string provided ..................................... Is enough cement used tO circulate on conductor and surface ...... Will cement tie in surface' and intermediate or production strings Will cement cover all known productive horizons .................. Will surface casing protect fresh water zones ...... ~ ............. Will all casing give adequate safety in collapse, tension and burs Is this well to be kicked off from an existing wellbore .......... Is old wellbore abandonment procedure included on 10-403 ......... Is adequate well bore separation proposed .......................... ~ . Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ...... .~'~ Does BOPE have sufficient pressure rating - Test to ._~_.~..z~.~_ psig . .~ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. ~'~ Additional requirements ............................................. Additional Remarks: Geology: Engin, e e~ring: H L C S'V C5/ : WV~ JK~ R~~ rev: 01/13/82 INITIAL GEO. UNIT ON/OFF · POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. ,, No special'effort has been made to chronologically organize this category of information. LIS TAPE VERIFICATION LISTING LVP 010 HO1VERIFICATIO~.. LISTING ** REEL HEADER ** SERVICE NAME :SERVIC DATE ~82/05/26 ORIGIN : REEL NAME :REEL ID CONTINUATION # PREVIOUS REEL COMMENTS :REEL COMMENTS ** TAPE HEADER ** SERVICE NAME :SERVIC DATE :82/05/26 ORIGIN :1070 TAPE NA~E :65122 CONTINUATION # :01 PREVIOUS TAPE : COMMENTS :TAPE COMMENTS ** FILE HEADER ** FILE MANE :SERVIC,O0! SERVICE NAME : VERSION # : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE : INFORMATION RECORDS ** MNEM CONTENTS CN : UNION OIL OF CALIFORNIA WN : KU-24-7 FN : KE~AI GAS FIELD RANG: IlW TOWN: 4N SECT: 18 COUN: NORTH SLOPE STAT: ALASKA CTRY: U,S,A, ~NEM CONTENTS PRES: DILOO1E ** RECORD TYPE 047 ** UNIT TYPE CATE SIZE CODE 000 000 024 065 000 000 008 065 000 000 016 065 000 000 00] 065 000 000 002 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 006 065 UNIT TYPE CATE SIZE CODE 000 000 007 065 LVP OIO,HO1 VERIFICATIO~ LISTING PAGE 2 ** RECORD TYPE 047 ** ** RECORD TYPE 047 *~ ** CO~MENTS ** SCHLU,~BERGER ALASKA COMPUTING CENTER COMPANY WELL FIELD COUNTY STATE UNION OIL OF CALIFORNIA KU-24-7 KENAI GAS FIELD KENAI ALASKA JOB NUMBER AT ACC: RUN #1, DATM LOGGED: BOTTO~ DEPTH TOP DEPTH CASING BIT SIZE TYPE FLUID DENSITY VISCOSITY 5708 FT, 2003 NA ~2.25 IN. GEL/GELEX 9,6 LB/G 44,0 S LVP 010.HOi VERIFICATION LISTING PAGE 3 PH FLUID LOSS R~ RMF R~C R~ AT BMT 9,5 8.0 C3 4.860 OHMM ~ 74.0 DF 4.240 OH~M ~ 74,0 DF 4.200 OMniS 0 74.0 DF 56.23 OHM @ NA MATRIX~ SANDSTONE TAPE DE~SITY= 1600 BPI ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 4 1 66 8 4 73 60 9 ~ 65 ,lin 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API API API API FILE SIZE PROCESS SAMPLE REPR ID ORDER # LOG TYPE CLASS MOD NO. DMPT FT 0 0 0 0 0 4 SFLU DIL OHMS 7 0 0 0 0 4 ILM DIL OH~ 7 0 0 0 0 4 ILD DIL OHMS 7 12 46 0 0 4 SP DIL MV 7 1 0 0 0 4 GR DIL GAPI 7 31 32 0 0 4 NPHI FDN PU 42 68 2 0 0 4 RHOB FDN G/C3 42 ]5 1 0 0 4 GR FDN GAPI 4~ 31 3~ 0 0 4 CAbI FDN IN 42 28 3 0 0 4 DRHO FDN G/C3 42 44 0 0 0 4 NRAT FDN 42 42 1 0 0 4 NCNL FDN 42 34 92 0 0 4 FCNL FDN 42 34 93 0 0 4 DT BHC US/F 60 5~ 32 0 0 4 bEVEL CODE 0 1 68 0 1 68 0 1 68 0 ! 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 I 68 0 1 68 0 1 68 0 1 68 0 I 68 0 1 68 LvP OIO.HOI VERIFICATION LISTING GR BHC GAPI 60 31 32 0 0 4 0 SP BHC MV 60 1 0 0 0 4 0 PAGE ! 68 ** DATA DEPT NCNb SP DEPT SP NCNb DEPT GR NCNb SP DEPT SP GR NCNL SP DEPT SP NCNb SP DEPT SP DEPT SP NCNb SP DEPT SP NCNb SP -999. -~99, 580O -62 67 1903 -62 44 2554 -43~ 5600, -44. 46. 2280. -44. 5500. -57. 43 2306: -57. 5400. -56. 61 -56, 5]00. 50, 47. 2080, -50. 5200 '57i 2140, -57. 5000 5625 250O 2500 5625 0000 125 625 0000 8125 00o0 2813 7188 0000 2813 o000 7813 1562 0000 7813 0000 2813 5000 0000 2813 0000 8437 4375 0000 8437 0000 8125 78!3 0000 8125 0000 0313 7188 0000 0313 SFLU GR CALl FCNb SFbU GR CALI FCMb SFLU GR CALI FCNL SFLU CALI FCNL SFbU G~ CALl FCNL SFLU GR CALl FCNL SFLU GR CALI FCNL SFLU GR CALI FCNL 51,2500 ILM 40.5938 NPHI -999,2500 DRRO -999,2500 DT 12,8828 ILM 40 8437 ~,PHI !2.8828 DRMO 488.2500 DT 9,0938 IbM 48.1562 NPHI 12 125 DRHO 8,6953 IbM 37,6250 NPHI 12,1328 DRMO 737.5000 DT 14.2266 IbM 40,0625 NPMI 11.7969 DRHO 687.0000 DT 14.3594 IbM 47.8437 NPHI 12 9062 DRHO 383:7500 DT ' 8.6484 IbM 33.6875 NPHI 12,0859 DRHO 528,5000 DT 10.6328 IbM 36.5625 NPHI 11.9687 DRMO 556.5000 DT 44,7813 ILD -999,2500 RHOB -999.2500 NRAT -999.2500 GR $,2 031 ,1680 RMOB 0,0952 NRAT 92.5625 GR 9.3516 30.3223 0005 NRAT 10:3750 GR 10.2031 IbD 30,1270 RHOB 0,0366 NRAT 115.0000 GR 15.7556 29,7363 RHOB 0,0117 NRAT 124,0000 GR 13.2500 ILD 52.9785 RHOB 0.0571 NRAT 92.0000 GR 8.4922 45.2148 RHOB 0,0361 NRAT 89.7500 GR 9,6875 ILO 39.3555 RHOB 0,0703 NRAT 108.3750 GR 40 78013 -999 25 0 -999 2500 40 5938 19,6875 2,4629 3.9434 40.8437 9.3750 2.2129 2,9824 48,I562 I0,~234 2, 133 2.9668 37,625O 16,7500 2.0859 2,9297 40.0625 12.3984 2,3242 4 2656 47:8437 8 2500 3.8125 33.6875 9.2422 2,2090 3.4824 36.5625 VERIFICATION DEPT 5~00,0000 SFLU SP 18,5469 GR GR 47.7168 CALI NCNb 2442.0000 FCNL SP -18.5469 DEPT 5000.0000 SFLU SP -51.7813 GR GR 41 6875 CALI NCNb 2166:0000 FCNL SP -51.7813 DEPT 4900 0000 SFLU 5P -55i2~13 GR GR 39 5000 CALI NCNb 2172.0000 FCNL SP -55.2813 DEPT 4~00.0000 SFLU SP 49.0313 GR GR 41.4063 CALI NCNb 1~71,0000 FCNL SP 49.0313 DEPT 4700 0000 SFLU SP 54' - ,0625 GR GR 52,5938 CALI NCNb 2148.0000 FCNL SP -54,0625 DEPT 4600 SP -29 GR 48 NCNb 1942 SP -29 0000 SFLU 2813 G~ 0938 CALI 0000 FCNL 2813 DEPT 4500. SP -25. NCNL 1661: SP -25. 0000 SFLU 7813 GR 3125 CALI 0000 FCNL 7813 DEPT 4_4~0 0000 SFLU Gn 53.7500 C Ll NCNb '.774 0000 SP -25:7813 DEPT 4=~0010000. 8FLU SD 35 0313 GR GR 35 5625 CALl NCNb I875 0000 FCNL SP 35 0313 LISTING 6.9531 45.1875 1~.0938 711.5000 11.3516 38.7500 12,0313 685.0000 1.7,6094 35.2187 11.9297 620.5000 14.5078 39.2813 12 3906 25ooo 18.6094 39 6563 633.0000 5.2109 38 5625 1 2 797 523.0000 27 3!25 29:5000 11 7656 4 5: 5oo 6 0742 12.5391 409.5000 6.8047 41.2500 12.0625 453.0000 NPMI DT IbM NPHI DRHO DT NPHI DRHO DT NPMI DRHO DT NPHI DRHO DT NPHI DRHO DT ILM NPHI DRHO DT NPHI DRHC DT IbM NPHI DRHO DT 7.0430 34.2773 0.0254 103.7500 12.2578 33.2031 0.0200 126.1875 18.0i56 35.5469 o o o Oo o:oo 15.1484 43.1641 0.0376 127.5625 19.1562 35.8398 0.0459 131.1250 12.1484 41.8945 0.1416 122.5625 23.8906 47.1191 0.1436 I19,0000 6,5859 47,2168 0.1602 137.0000 11.9609 45,5078 0.1226 I~1,7500 RHOB NRAT GR ILD RHOB NRAT RHOB NRAT GR ILD RHOB NRAT GR ILD RHOB NRAT GR RHOB NRAT GR RHOB NRAT GR RHOB NRAT GR RHOB NRAT GR AGE 7.6641 2 1777 3!2031 45 1875 3' 1680 38.7500 18.9844 2,0742 2695 3:2187 1387 3.705t 39.2813 17 625O 211309 3 2930 39 6563 I .1.328 3 6426 38~5625 26.2031 2,0625 3,9102 29,5000 6.9258 2.3086 3.9355 41.6250 14.2266 2,1328 3.8281 41.2500 bVP OIO,HO1 VERIFICATIO~¢ DEPT 4200.0000 SFLU SP -56 0313 GR GR 45 3125 CALl NCNb 1695 0000 FCNL SP -56 03!3 DEPT 4,1~0.0000 SFLU 8P 0.0625 GR GR 46,6875 CALI NCNb 1979. 0000 FCNL SD -70.0625 DEPT 4000 SP -27 GR 46 NCNb 1692 SP -27 0000 SFLU 7813 GR 2500 CALI 0000 FCNL 7813 DEPT 3900 0000 SFLU SP -25:0625 GR GR 44.4063 CALl NCNb 1778.0000 FCNL SP -25.0625 DEPT 3_~00 0000 SFLU SP -26:2813 GP, GR 45,0625 CALI NCNb 1,672,0000 FCNL SP 26.2813 DEPT 3!00.0000 SFLU SP 50.7813 GR GR 44.9375 CALl NCNb 1919.0000 FCNL SP -50,7513 DEPT 3~00 0000 SFLU sp -39:5313 oR GR 48.1875 CALI NCNL 1~,89.oooo FC~L SP -29.5313 DEPT 3500.0000 SFLU SP -58,5313 GR GR 45.9062 CAL, I NCNb iS07 0000 FCNL sp -5~:5313 DEPT NCNb SP 3400 0000 SFLU -59:2813 GR 47.6553 CALI 1812,0000 FCNL -59.2~13 LISTING 14.8984 35.6563 12.5391 364.0000 21,7656 41.4375 11,6641 519.5000 5.8594 46,8437 12.7500 380.750O 8.5234 40.2813 !2.3984 407.0000 6 64B4 4.2:7813 12,7266 347,0000 15.3359 45,8125 12,3438 419,5000 5.9492 45.7500 11.7656 423.7500 13.4375 36.9375 11.4688 417.5000 16.8125 45.2500 11.5781 613.0000 IbM NPHI DRMO DT IbM NPHI DRHO DT IbM NPHI DRHQ DT MPHI DRHO DT IbM NPMI DRHO DT Ib~ NPHI DRMD DT IbM NPHI DRHD DT IbM NPHI DT IbM NPHI DRHO DT t7,4688 58.1055 0.0654 128.5000 20.9062 42.9687 0,0874 130,1250 6,2227 48.584O 0,1982 118. 750 9,0547 52.7832 0.1147 120.18'15 7.5625 56.4453 0.1631 126.7500 1i.9141 51,4160 0.0835 133.3750 8,8984 49.3652 0.1362 121.7500 15.3594 47,0215 0.1343 119.7500 17.1094 33,1055 0,2236 I23.3750 ILD RHOB NRAT G~ ILD RHOB NRAT GR ILD RHOB NRAT GR RHOB NRAT IbD RHOB NRAT GR ILD RHOB NRAT G~ IbD RHOB NRAT GR ILD RHOB NRAT GR ILD RHOB NRAT GR PAGE 14.8125 ,9502 5391 35'6563 . 20,7813 2.1367 3.6777 41,4375 5,2773 2,2148 4,0156 46.8437 9.4688 2,0664 2813 7,7500 2.0664 4,4531 42.7813 12 5078 2:1523 4.1641 45,8125 8.5625 2.0039 4.0313 45.7500 15.4688 2.0488 3 8945 17,2813 2,2910 3.1484 45.2500 5VP DEPT GR NCNb SP DEPT SP GR NCNb SP DEPT SP GR NCNb DEPT SP GR NCNL SP DEPT SP GR NCNb SP DEPT SP NCNb SP DEPT SP NCNL SP DEPT SP NCNb SP DEPT SP NCNb Ol0.H0! VERIFICATION 3300 0000 SFLU -46:7813 GR 43,5313 CALI 1927.0000 FCNL -46,7813 ~ 0000 SFLU 3 '2813 GR . 49.8437 CALI 1~92.0000 FCNb 35.2813 3100.0000 SFLU -34.5938 GR 23.5000 CALl 1321,0000 FCNL -34.5938 3~.0000 SFLU .0313 GR 45.9062 CALI 000 FCNL ~20' o 34.0313 2900 0000 SFLU -67i8125 GR 444375 CALI 1941,0000 FCNL -67,8125 2800 0000 SrbU -4:5:3125 GR 53,0625 CALI 1681.0000 FCNL -45.3125 2700.0000 SFLU -63 78~3 GR 37:6250 CALl 1995.0000 FCNL -63.7813 2600.0000 SFLU -67.0625 GR 37,3125 CALl 2128.0000 FCNL -67.0625 2500.0000 SFbU -48.0313 GR 40.1250 CALl 1876,0000 FCNL -48.0313 LISTING 18.5469 40.0OO0 11.3594 504.5OOO 8.7422 37.7500 11,7656 361.7500 7.6992 40.9062 12.2813 260,5000 8.2969 40.6563 12.2656 391.2500 14 1484 32i2813 12 2~91 469 5000 9.7734 40.2813 12.7188 400.2500 13. 6563 38.4063 12 1016 512:oooo 19.4063 31.5938 11.7891 532.0000 10.9844 41.8750 12.5625 457.5000 IL~ NPHI DRHO DT IL~ NPHI DT NPHI DRHO DT IL~ NPMI DRMO DT IbM NPHI DRHO DT NPHI DT NPHI DRHO DT ILM NPHI DRHO DT Ib~ NPHI PT 16.8125 42.7734 0,1646 122.~875 9.6875 51.7090 0.1479 126,3750 9,0000 65.8203 0.0078 126.1~75 8,4375 52.9297 0.0674 123.0000 14.5234 46.2402 143.0000 12.2500 48.0957 0,1030 136.3750 15.2969 44.8730 0.1440 132.3750 18.4688 42.2852 0.1323 ~24,3750 8.8516 46.5332 0.i304 138.1250 ILD RHOB NRAT IbD RHOB NRAT GR ILD NRAT GP ILD RHOB NRAT ILD RHOB NRAT GP ILD RHOB NRAT ILD RHOB NRAT GR RHOB NRAT GR ILD RHOB NRAT GR PAGE 16.3125 2.0895 3.6582 40.0000 1~,70 4.1641 3'7,7500 9,5000 .4199 .9609 40,9062 8.9297 2.0918 4,246! 4 . 6563 14.2813 2,0703 3,8750 32.2813 1~,5469 .0859 3.9902 40,2013 15.2578 2,1152 3.7930 38.4063 17,7344 2.1621 3.6426 31.5938 8.6563 2,1055 3.8984 41.8750 LVP OIO,MO1 VERIFICATION LISTING DEPT 2400,0000 SFLU SP -70 8125 GR R 36!4658 CALI ~CNL 1913 0000 FCNL -70.8125 DEPT 2300,0000 SFLU SP -71.3125 GR GR 37,8125 CALI NCNL 2~36'0000 FCNL SP 71,3125 DEPT SP NCNL SP 2200 0000 -77 5625 35 5000 1986 0000 -77 5625 oooo GR 43.7158 NCNL 1.802,0000 SP 43.7813 DEPT 2000.0000 SP -39.2813 GR 28,3750 NCNL 1307,0000 BP -39.2813 CALI FCNL SFLU CALI FCNL SFLU CAL! FCNL DEPT 1969.0000 SFLU SP -999.2500 GR GR -999.2500 CALI NCNL -999.2500 FCNL SP -999.2500 12,0234 35.0000 NPHI II.9766 485.0000 DT 14,2578 39.1250 NPHI 11.7031 495.2500 DT 16,1250 40,8750 NPHI 11.8594 471,0000 6.5781 4~:0625 NP,I 3281 DRHO 413~7500 DT 2000.0000 IbM 27.2344 NPHI 11,6641 DRHO 296.5000 DT 2~99 2500 IbM 99:2500 NPHI -999.2500 DRHO -999.2500 DT ** FILE TRAILER ** FILE NAME :SERVlC,O01 SERVICE NA~E VERSION ~ : DATE : ~AXIMU~ LENGTH : 1024 FILE TYPE NEXT FILE NAME : EOF ********** 11.i016 42.1875 0.0728 NRAT 136.7500 GR 13.2813 43.7988 R}~OB 0.1333 NRAT 130.3750 GR 13.9922 ILD 48,828! RHOB 0,~260 NRAT 139. 000 GR 7,8789 ILD 46.9727 RHOB 0,1611 NRAT 129.0000 GR 2000. 0000 !LD 59,7165 RHOB 1450 NRAT i;~'7500 GR -999.2500 ILD -999.2500 RHOB -999.2500 NRAT 61.5938 GR PAGE 10,9219 2.0625 3.6406 35.0000 13,0391 1152 39.1250 ~,1094 40,08078 750 8,4453 2.0430 3,94~4 42.0625 2oo :oooo 344 '999.2500 '999,2500 '999.2500 '999.2500 ** TAPE TRAILER ** SERVICE NA~E :SERVIC DATE :~2t05t26 ORIGIN ~1070 TAPE NAME :65122 LVP 010.H01 VERIFICATIOS LISTING PAGE 9 CONTINUATION # NEXT TAPE NA~E COMMENTS :TAPE ** REEL TRAILER ** SERVICE NAME :SERVIC DATE :82/05/26 ORIGIN ~ REEL NAME :REEL ID CONTINUATION # :01 NEXT REEL NAME : ********** EOF
