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199-025
i Imag~,. ,'oject Well History' File Cover R je 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. L(~?-Oc~,'~ Well History File Identifier Organizing i,~o,,~.l [] R~S~~-' Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: BY: DIGITAL DATA OVERSIZED (Scannable) [] Diskettes, No. [] Maps: [] Other, No/Type BEVERLY ROBIN VINCENT SHERY~~NINDY Other items scannable by large scanner OVE~cannable) Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Scanning Preparation ~'x 30 = l~) BY: BEVERLY ROBIN VINCENT SHERYOWINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: Y · ~ ~[~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND' __ YES (SCANNING IS coMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO ReScanned (htdividual p;.~ [~p~,cfai ,~ftcnt'io~d ,.~c~mni,'g c¢t,pt~,,~ze¢¢ RESCANNEDB~': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked 12110/02Rev3NOTScanned,wpd • c: UNSCANNED, OVERSIZED MATERIALS AVAILABLE: ~ ~~ (~, S~ FILE # ~ rn c~ 0 [-o GS '1C,' To request anylall of the above information, please contact: Alaska Oil & Gas Conservation Commission ~ 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 !Fax (907) 276-7542 • M Marathon MARATHON QI~ Company May 15, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-407 Completion Report Field: Kenai Gas Field Well: .KBU 42-7 Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~°~°~'°~ RECEIVED MAY 1 6 2008 Alaska Oil & Gas Cons. Commission Anchorage. ~NED MAY 2 2 ZU08 Dear Mr. Maunder: Enclosed please find the 10-407 Well Completion Report and Log for the Kenai Gas Field well KBU 42-7. The lower wellbore was plugged and abandoned in preparation-for sidetracking. Attached, for your records, is the operations summary along with the current wellbore diagram. The 3-1/2" tubing top depth, stated in the operations summary, on 4/10/2008 is incorrect. The measurement was corrected to 4,237'. (drill pipe measured) depth and stated in the 4/13/2008 entry. Please call me at (907) 283-1371 if you. have any questions or need additional information. Sincerely, Kevin. J. Skiba Engineering Technician Enclosures: 10-407 Completion Report cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS CLR STATE OF ALASKA ~~ RECEIVED A~A OIL AND GAS CONSERVATION COMMISSION Y 2~~0$ WELL COMPLETION OR RECOMPLETION REPOR~A~I~ LOG Oil^ Gas^ Plugged ^ Abandoned 0 /Suspended ^ 2onnc 25.1 os 20nnC 25.110 GINJ^ WINJ ^ WDSPL^ WAG ^ Other^ No. of Completions: 0 ~I~~~as Cons. 0 ve opment ~chorage Expl°rat°ry ^ Service ^ Stratigraphic Test ^ 2. Operator Name: Marathon Oil Company 5. Date Comp, Susp, Ab April 15, 2008. 12. Permit to Drill #: 199-025- Sundry#: 308-o9s 3. Address: PO BOX 1949 Kenai Ataska, 99611-1949 6. Date Spudded: January 19,.2001 13. API Number. 50-133-20488-00-00 4a. Location of Well (Governmental Section): Surface: 37' FNL, 4,118' FWL, Sec. 7, T4N, R11W, S.M. 7. Date TD Reached: February 6, 2001 14. Well Name and Number: Kenai Beluga Unit 42-7 - Top of Productive Horizon: 8. KB (ft above MSL): 8T- Ground (ft MSL): 21' 15. Field/Pool(s): „ Total Depth: 1,318' FNL, 4,843' FWL, Sec. 7, T4N, R71W, S.M. 9. Plug Back Depth(MD+TVD): 4,096' MD 3,875' ND Kenai GaS Field /Beluga POOI 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 275,023.22 y- 2,361,974.31 Zone- 4 10. Totat Depth (MD + TVD): 7,570' 7,308' 16. Property Designation: ' ,~ A - 028142 S~ 6~y TPI: x- y- Zone- Total Depth: x- 275,724.08 y- 2,360,679.84 Zone- 4 11. SSSV Depth (MD + TVD): NA 17. Land Use Permit: 18. Directional Survey: Yes No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: NA (ft MSL) 20. Thickness of Permafrost (TVD): NA 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. CASING, L INER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 20" 133 K-55 0' 11T 0' 11T Driven 13-3/8" 68 K-55 0' 1,099' 0' 1,093' 17-1/2" 734 sacks NA 13-3/8" 68 L-80 1,099'. 1,750' 1,093' 1,732' 17-1/2" NA 9-5/8" 40 L-80 0' 5,582' 0' 5,322' 12-1/4" 654 sacks NA 3-1/2" 9.3 L-80 4,236' 7,257 3,933' 6,996' 8-U2" 875 sacks NA 23.Open to production or injection? Yes ^ No ~ If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production: June 3, 2001 Method of Operation (Flowing, gas lift, etc.): Date of Test: NA Hours Tested: NA Production for Test Period Oil-Bbl: 0 Gas-MCF: 0 Water-BbL• 0 Choke Size: NA Gas-Oil Ratio: NA Flow Tubing Press. NA Casing Press: NA Calculated 24-Hour Rate ~ Oil-BbF. 0 Gas-MCF: 0 Water-8bL• 0 Oi! Gravity -API (corn): NA 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No Q Sidewall Cores Acquired? Yes ^ No Q If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ;COMPLETI(~C t. RBDMS BFL ~tiAY 2 0 2008 ~~ - l a~ Form 10-407 Revised 2/20p7~ R ~ ~, ~ ~ A ~ CONTINUED ON REVERSE 28. GHOLOGIC MARKERS (List all formations and rs encountered): 29. FORMATION TESTS NAME TVD Well tested? Yes ~ No ff yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost -Top detailed test information per 20 AAC 25.071. Permafrost -Base Middle Beluga 5,617' 5,355' Tyonek 7,436' 7,173' Formation at total depth: 30. List of Attachments: Well Schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kevin Skiba (907) 283-1371 Printed Name: Craig L. Rang Title: Senior Completions Engineer Signature: Phone: (907) 283-1372 Date: Ma 14, 2008 Q v~ Q INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on ail 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 well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for I njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Levei elevations in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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: H 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. (Submk a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). kern 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 • 50-133-20488-00-00 ertv Des: A - 028142 21' AGL (87' KB Elevation) I Date: 1/19/2001 teleased: 2/14/2001 eached: 2/6/2001 Tree cxn = 3-1/2" EUE Srd 4,096' =Bottom of Window 4,101' =Cast Iron Bridge Plug 4,125'- 4,130' =Circulation Perfs 4,208' = 9-518" EZ SV Retainer 4,215'- 4,224' =Circulation Perfs 4,229' = 9-518" Cast Iron Bridge Plug 4,236' =Excape Tubing 8 Control Lines 5,551' =Top of Tubing Cement Plug 5,586' = 2-112" Cast Iron Bridge Plug ~op of Excape Cement - 4,265' KOP: 300' Build: 2.5 deg per 100' Hold Angle: 26 deg at 2500' DOP: 3800' Drop: 0.5 deg per 100' Final Angle: <3 deg at 5720' @ 5549' MD (5289' TVD) w/ 7/16" electric cable (dual-armored, 7-strand conductor) to surface two 10K pressure sensors one temperature sensor PLT on a-line - 6;8641-2F~919~} WL tag: ~9t3A'{~/23/03) 6,464' (12/7/03) KBU 42-7 Pad 41-7 37' FNL, 4,118' FWL Sec. 7, T4N, R11 W, S.M. MARATN ON Drive Pine 20" K-55 133 ppf Tom Bottom MD 0' 117' TVD 0' 117' Surface Cas ing 13-318' 68 ppf Tom Bottom K-55 MD 0' 1,099' TVD 0' 1,093' L-80 MD 1,099' 1,750' TVD 1,093' 1,732' BTC @ 1,750' MD Cmt wl 734 sacks class G 9-5/8" L-80 40 ppf ~p tt m MD 0' 5,582' TVD 0' 5,322' BTC @ 5,582' MD Cmt w/ 654 sacks of class G 3-1/2" L-80 9.3 ppf EUE Srd with 5.25" OD slotted couplings to 7,518' Cmt wl 875 sacks of class G Excape Svstem Details - 15 Excape modules placed - Both control lines now open for methanol ~,' injection (8/30!01) -All ceramic flappers milled out with coil. 20 spf 4,125' - 4,130' (4/1 312 0 0 8) 20 spf 4,215' - 4,224' (4/12/2008) Module 15 5,636' - 5,646' (frac'd 8/30/01) Module 14 5,737' - 5,747' (frac'd 8/30/01) Module 13 5,805' - 5,815' (frac'd 8/30/01) Module 12 5,863' - 5,873' (frac'd 8/5/01) ~, ~ Module 11 5,941' - 5,951' (perfed 8/5/01) Module 10 6,123' - 6,133' (perfed 8/4/01) Module 9 6,271' - 6,281' (perfed 8/4/01) Module 8 6,366' - 6,376' (frac'd 8/4/01) Module 7 6,499' - 6,509' (frac'd 6/3/01) Module 6 6,611' - 6,621' (frac'd 6/3/01) Cast Iron Bridge Plug @ 6,706' Module 5 6,746' - 6,756' (frac'd 6/3101) Module 4 6,943' - 6,953' (perfed 6/1/01) Module 3 7,153' - 7,163' (frac'd 6/1/01) Module 2 7,319' - 7,329' (perfed 6/1/01) Module 1 7,399' - 7,409' (perfed 3/11 /01) '~" :~ -All frac'd zones were treated with 16/20 Carbolite in diesel-based Super Rheogel frac fluid. PBTD - 4,090' MD TD - 3,806' MD Well Name 8 Number: KBU 42-7 Lease: Kenai Gas Field County or Parish: Kenai Peninsula State: Alaska Country: USA Perforations (MD) : (TVD): Angle/Perfs: Angle @ KOP and Depth: Dated Completed: 211412001 Prepared by: Kevin Skiba Last Revison Date: 5115/2008 7 a '.. . • Event Name: RE-ENTRY Start: 4/4/2008 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - T~ i Hours ~ Code ~ C d Phase 23/2008 08:00 -11:30 3:50 RURD_ PIPE MIRU 11:30 -13:00 1.50 BLOWD SG OTHER 13:00 -14:00 1.00 PUMP_ WTR_ I OTHER 14:00 -14:20 0.33 SAFETY MTG_ OTHER 14:20 -14:30 0.171 PUMP_ WTR_ OTHER 14:30 -15:00 0.50 PUMP_ WTR_ OTHER 15:00 -16:00 I 1.001 RURD I ELEC I WRLN 16:00 -18:00 2.00 LOG_ CSG_ WRLN 18:00 -19:00 1.00 RURD_ ELEC WRLN 19:00 -19:30 0.50 SECUR WELL WRLN 17:30 -18:10 0.67 RURD ELEC PLUGAB Description ofi O"peratioris ASRC rig up flowback iron, tanks, containment WH pressure 1900#. Bleed back to flowback tank through gas buster. Dry gas and some mud /liquid just before well died Rig up BJ Services pump truck hard lines to wellhead PJSM. -discussed ice around wellhead and in cellar, pressure, muster point, active gas producing pad -red lights for fire, blue lights for gas, alarms Pressure test to 3000# -test good Pump 60 BBL fresh water back down 31/2" casing. Shut down to rig up Expro wireline to run CBUGR: Continue pumping water at .5 BBL / min when Expro in hole with CBL tool Rig up Expro -CBUGR Rig down Expro / BJ Services Well and location secured, tum in permit. Rig up Expro wireline to set CIBP /dump cement. Arrive at location, 18:10 - 18:44 0.57 SAFETY MTG_ PLUGAB Hold safety meeting. Topics -explosive safety, pressure, active gas production pad, red lights, blue lights, sirens, egress, cell phones etc. 18:44 - 22:30 3.77 RUNPU ELEC PLUGAB RIH w / 2.75" CIBP. Set down @ 2200' POOH. RIH with 2.75" JB / GR. Set down at 2234'. Work tool down to 2240'. POOH. RIH w/ 2.60" gauge ring. Work gauge ring down to 3730" POOH. Large pieces of 22:30 - 23:00 0.50 RURD_ ELEC PLUGAB Secure wellhead for evening, sign out and tum in work permit. 4/5/2008 09:00 -10:00 1.00 RURD_ ELEC PLUGAB Arrive at location, obtain work permit. 10:00 -10:20 0.33 SAFETY MTG_ PLUGAB Hold safety meeting. Topics -explosive safety, pressure, active gas production pad, red lights, blue lights, sirens, egress, cell phones etc. 10:20 -11:00- 0.67 PUMP_ WTR_ PLUGAB wait on vac truck w / KCL water to push coal back downhole 11:00 -12:00 1.00 PUMP_ WTR PLUGAB BJ Services pumped 35 BBI of 6% KCL water before perforations bridged off. 12:00 -12:15 0.25 RURD_ ELEC PLUGAB RU Expro, pressure test lubricator to 2000# 12:15 -17:35 5.33 RUNPU ELEC PLUGAB RIH w / 2.75" JB / GR.. Set down @ 4910' POOH. RIH with 2.295" Gauge Ring. Tag top module at 5615' POOH. RIH w / 2.75" CIBP. Hit obstruction at 4932'. POOH. Rig up 2.5" CIBP. RIH and run tie-in pass. Pull into osition and set CIBP @ 5586' POOH 17:35 -18:55 1.33 RUNPU ELEC PLUGAB RIH w / 3 ten foot sections of 2"dump i er run mp cement on top of plug 18:55 -19:48 0.88 RUNPU ELEC PLUGAB RIH w / 3 ten foot sections of 2" dump bailer (run #2 . Dump cement on top of plug 19:48 - 21:07 1.32 RUNPU ELEC PLUGAB RIH w / 3 ten foot sections of 2" dump bailer (run #3). Dump cement on top of plug 21:07 - 21:40 0.55 RURD_ ELEC PLUGAB Secure wellhead for evening, sign out and tum in work permit. 4/6/2008 18:00 - 06:00 .12.00 RURD_ RIG_ MIRU PJSM: Lay liner & matting boards. Prep to move rig. Repair hydraulic line on stabbing board & hydraulic line in sub base while waiting on daylight to move rig. 4/7/2008 06:00 - 08:00 2.00 MOB RIG_ MIRU Prep to move rig while wait on daylight. Note: Extra dirt was required to level around rig prior to laying liner and matting boards: Loads of dirt were smaller than usual due to highway restrictions due to break up. Water(due to break up season) had to be vatted off of location to inspect and install a cover on an electrical vault. 08:00 - 18:00 10.00 MOB RIG_ MIRU PJSM. Move sub base and raise. Move in pit room, pump room, generator house, boiler house, and water house. Spot in mud boat. Printed: 5/14/2008 5:58:18 PM • • Marathon Oil Company Page 2 of 13 Opera#ions Summary Report Legal Well Name: KENAI BELUGA UNIT 42-7 Common Well Name: KENAI BELUGA UNIT 42-7 Spud Date: 1/19/2001 Event Name: RE-ENTRY Start: 4/4/2008 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours ~ Co+;je I, sub Phase ,Code. Description of Operations 4/7/2008 08:00 -18:00 10.00 MOB RIG_ MIRU 18:00 - 00:00 6.00 RURD_ RIG_ MIRU 00:00 - 06:00 ~ 6.00 ~ RURD` RIG_ ~ MIRU 06:00 - 08:00 i 2.00 ~ RURD` RIG_ ~ MIRU 08:00 -10:00 2.00 REPAIR RtG_ MIRU 10:00 -12:00 2.00 RURD_ RIG_ MIRU 12:00 - 00:00 12.00 RURD_ RIG_ MIRU - 06:00 ~ 6.00 ~ RURD_ RIG_ ~ MIRU 14/9/2008 106:00 - 07:30 1 1.501 NUND 1 WLHD I MIRU 07:30 - 08:00 0.50 TEST_ CSG_ PLUGAB 08:00 -11:00 3.00 NUND TREE PLUGAB 11:00 - 12:00 I 1.001 NUND 1 BOPE 1 PLUGAB 12:00 -13:00 1.00 REPAIR RIG_ PLUGAB 13:00 -14:00 1.00. REPAIR .RIG_ PLUGAB 14:00 - 19:00 5.00 NUNb BOPE PLUGAB 19:00 - 21:00 2.00 TEST_ BOPE PLUGAB 21:00 - 00:00 3.00 TEST BOPE PLUGAB 00:00 - 01:00 I 1.001 TEST_ BOPE PLUGAB 01:00 - 05:00 I` 4.00 TEST_ ROPE PLUGAB 05:00 - 06:00 1.00 RURD ELEC PLUGAB 4/10/2008 06:00 - 08:00 2.00 PERF_ TBG_ PLUGAB 08:00 - 11:00 3.00 PERF TBG PLUGAB 1.1:00 - 12:30 1.50 PERF_ TBG_ PLUGAB Move in carrier. Move all truck loads to 41-7 pad. Move and R/U camp. Raise derrick. PJSM: Crane in 8 fill fuel tank. Remove mud pump #1 hydraulic c~oltng tower from pump house for repair. Crane in drill side grey iron, dog house, steps to from carrier, off drill side grey iron, choke house, flowline & panic line riser. Start rig generator & power up genererator house, boiler house & water tank house. PJSM: Crane in stairs, back floor plate, wind walls & set BOP connex. Pull radiator on cooling tower to repair. Plug into dog house, choke house & carrier. Replace boiler feed pump. Reassemble cooling tower. Set solids van. Hang exteriorlights on dog house and choke house. Prep derrick for scope up. Rig repair cooling tower mud pump#1. Plug in power to pits, pump room & generator house. Fire up boiler. PJSM: Set pump#3 & catwalk. Move in BOPE. PJSM: Sipe up derrick & secure guy wires. PJSM: R/U beaver slide, stairs, mud manifold & snub post. Install bows & tarps on carrier, dresser sleeves & pop-0ff lines. Run wires to pump #3. Tie back hanging line to demek. Install cylinder socks. PJSM: P/U & install torque tube. Hang "T" bar & tumbuckles. Adjust torque tube. R/U steam, water 8 air lines. Plump in cooling tower. PJSM: Inspect tugger line. P!U & hang top. drive. Inspect & prep #1 & #2 mud pumps. Mix 50 bbls brine. Bleed fuel tanks on carrier & generators. PJSM: R/U top drive & slide. Test run top drive. Hook up choke & poor boy lines to pump room. P/U & hang rig tongs & bails. Hang spinners. Test run pumps #1 & #2. Check 3-1/2" x9-5/8" annulus for pressure (negative). Rig up kill line to wing valve on production tree. Rig up shock hose to #1 & #2 mud pumps. Install new pads on draworks brakes. PJSM: Ri u & test 3-1/2" csg to 2000 psi f/ 10 min (ok). PJSM w/ Vetco: N/D production tree. a sips. isconnect control lines. Plug off control line outlet. PJSM: Install DSA. Prep BOP stack to install. All while dressing shakers w/ 165 mesh screens. PJSM: Repair bridge crane. PJSM: Rebuild brake linkage. Replace pins & bushings.. PJSM: N/U BOP stack. R/U kill line, choke line & koomey lines. Remove bell nipple. R/U panic line &tumbuckles. Plumb 15021ine to annulus. R/U suction tine, pop-off lines & shock hose to #3 mud pump. Fabricate test plug to test 3-1/2" casing. PJSM: R/U & test BOPE w/ 3-1/2" casing 8~ all related components f/ 250/2000 psi for 10 min. Witness waived by AOGCC Jim Regg @ 16:00 hrs on 4/7/08. Contacted Tim Lawler w/ BLM & gave notice. PJSM: Annular preventer not opening. Troubleshoot. Trapped pressure j beneath element. Rig down 3-1/2" test jt. Con't test BOPE w/ 5" drill pipe & all related components f/ 250 / 2000 psi f/ 10 min. Perform koomey drawdown test. Rig down test equipment. PJSM: Nipple up shooting flange w/ rig up Expro wireline. Continue R/U shooting head and expro wire line tools PJSM; R/U lubricator and test to 1500psi. make up 1 11/16X 2'/6 pert guns and RIH and set depth for peforating 3 1/2 tubing. at 4224' WLM Pressure upon tubing to 1000psi, fire guns at 4224'.WLM No pressure Printetl: 5/14/2008 5:58:18 PM Marathon Oil Company Operations Summary Report Page 3 of 13 Legal Well Name: KENAI BELUGA UNIT 42-7 Common Well Name: KENAI BELUGA UNIT 42-7 Spud Date:. 1/19/2001 Event Name: RE-ENTRY Start: 4/4/2008 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number. Date I From - To l Hours Code I Code I Phase 4/10!2008 11:00 - 12:30 12:30 -14:00 14:00 - 16:15 ~ f• ~,~ ~~ 16:15 - 19:30 19:30 - 20:30 20:30 - 06:00 4/11/2008 06:00 - 09:30 1.50 PERF TBG_ 1.50 CIRC_ CFLD 2.25 CUT TSG_ ~t 4 L3 'r~;- 3.25 NUND EOIP 1.00 PULD_ BHA_ 9.50 PULD TBG_ 3.50 RUNPU TBG_ 09:30 - 10:00 I 0.50 Description of Operations PLUGAB dro in Lubin .Increase pressure to 2000psi no change. Steed off and check lines. found valve closed on kill line side of spool. Open valve and Pressure up to 1200psi. Saw returns to shakers, confirm tubing perforated. Outlet on tubing spool leaking. Bleed off pressure and install. a blank flange. PLUGAB Pump sweep and displace out fluid in 9 5/8 X 3 1/2 annufus.with 6% KCL. Fluid displaced was 50 bbls of KCL then 185bb1s of drilling mud. PLUGAB PJSM : R!O Expro Lubricator and a-line RIHW/Titan 2.75 Jet Cutter and cut tubing at 4204'WLM.. Set down and confirm cut was made. ;, yy~ ~ POH with a-line and R/D line tools and lubricator Note Tubing stub at 4204'WLM. Note Only made one cut PLUGAB Nipple up flow nipple, flowline and trip tank lines,drip pan. PLUGAB PJSM; Measure and pick up Itco spear, dressed to latch 3 112" csg..Pull csg. slips and bowl to rig floor, laydown 31/2" csg. spear and Change. elevators. PLUGAB PJSM; POOH with 3 1/2" tubing, hang sheave and spoof control line and cable.Had trouble pulling control line thru spool outlet, at start. Note: As casing is puled out of hole, checking for NORM PLUGAB Continue to lay down 3 1/2 casing with 2control lines and 1 cable. Recovered 134jts 3 1!2 casing 100% of control lines, cable and bands. Note: last 5 jts had cement scale on pipe PLUGAB Rig down Weatherford casing tools and pollard spooter for control lines/ cable 10:00 - 11:30 ~ 1.50 ~ RURD_~ OTHR ~ PLUGAB P/U drillpipe handling tools. Set pipe racks and load drillpipe 11:30 - 12:30 1.00 SAFETY MTG_ PLUGAB Hold safety meeting both crews discuss incident (first aid on cutting banding on 3 112 casing) 12:30 - 13:00 0.50 REPAIR RIG_ PLUGAB Repair pin on brake linkage 13:00 - 14:00 1.00 TRIP_ TOOL PLUGAB Make up 8 1/2 mill ,9 5/8casing scraper boot basket and bit sub. Run in hole Strap&P/U,dnft 5" drillpipe to 4204'WLM top of 3 1/2 casing stub. 14:00 - 20:30 6.50 TRIP_ DP_ PLUGAB Measure and drift 5" drill pipe RIH to 4005'. 20:30 - 21:00 D.50 WASH FILL PLUGAB Wash down from 4005' to 4211' to to of 3 1/2 cs .stub at 4211' drill pipe measurement.Sweep bought back small amounts of cement. ~ 21:00 - 22:00 1.00 CIRC_ CFLD PLUGAB Circ. visc. sweep around, blow down mud lines. ~ 22:00 - 02:30 4.50 TRIP_. DP PLUGAB PJSM; POOH w/ 5"drill pipe SLM 02:30 - 06:00 3.50 TRIP_ bP_ PLUGAB PJSM;RIH w/5" drill pipe and drift singles. 4/12/2008 06:00 - 14:00 8.00 TRIP_ DP_ PLUGAB Continue to P/U 5"..drillpipe and RIH., POH stand back and tally Total of 288jts 144 stands. 14:00 - 16:30 2.50 SETREL PLUG PLUGAB PJSM: R/U expro WLS and run and set halliburton 9 5/8 EZ drily ' et mm~ing tool down to confirm setting depth. POH with a-line and rig down tools. 16:30 - 17:30 1.00 TEST_ CSG_ PLUGAB Test 9 518 casin to 1500 si for 30 min. 17:30 - 22:00 4.50 WAITON EQIP PLUGAB Wait on Shlumberger to run CBL. Work on Draw works brake, Wire MI van, Install magnets in pump strainers, service rig, PJSM; Change out saver sub on top drive. 22:00 - 00:30 2.50 RURD_ ELEC PLUGAB PJSM; Rig up Shlumberger to run CBL 00:30 - 01:30 1.00 WORK ELEC PLUGAB RIH with wireline CBL Pressure to 500 psi, retighten connections, retest. 01:30 - 02:00 0.50 WORK ELEC PLUGAB Log f/ 4199' to 3450' (WLM) Make short pass with 500 psi on csg. 02:00 - 03:00 1.00 WORK ELEC PLUGAB POOH with wireline. R/D Shlumberger. 03:00 - 03:30 0.50 TEST_ BOPE PLUGAB PJSM; Rig up to test BOP. 03:30 - 06:00 2.50 TEST_ BOPE PLUGAB Test BOP test annular to 250 psi low 3500 psi high.Test all other test " 250 psi low 5000 psi high 10 min. Test waived by Jahn Crisp AOGCC, BLM, Tim Lawlor notified 4!11/08. Printed: 5/14!2008 5:58:18 PM Marathon Oil Company Page 4 of 13 Operations Summary Report Legal Well Name: KENAI BELUGA UNIT 42-7 Common Well Name: KENAI BELUGA UNIT 42-7 Spud Date: 1!19/2001 Event Name: RE-ENTRY Start: 4/4/2008 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Code Phase 4/13/2008 06:00 - 09:00 3.00 TEST ROPE PLUGAB 09:00 - 09:30 0.50 BLOWD EOIP PLUGAB 09:30 - 10:00 0.50 TRIP_ DP PLUGAB 10:00 - 11:30 1.50 REPAIR RIG_ PLUGAB // 11:30 - 14:00 2.50 TRIP_ DP_ PLUGAB 14:00 - 17:00 3.00 PERF CSG PLUGAB 17:00 - 18:30 1.50 TEST LOT_ PLUGAB 18:30 - 19:00 0.50 CIRC CFLD PLUGAB 19:00 - 21:30 2.50 _ TRIP_ DP_ PLUGAB 21:30 - 00:00 2.50 WORK ELEC PLUGAB 00:00 -.00:30 0.50 TEST_ CSG_ PLUGAB 00:30 - 06:00 5.50 NUND BOPE PLUGAB 4/14!2008 06:00 - 08:30 2.50 NUND BOPE PLUGAB 08:30 - 09:30 1.00 TEST BOPE PLUGAB 09:30 - 13:00 3.50 TRIP DP_ PLUGAB 13:00 - 13:30 0.50 RURD PIPE PLUGAB 13:30 - 14:30 1.00 _ PERF CSG PLUGAB 14:30 - 17:30 3.00 CIRC CFLD PLUGAB 17:30 - 21:30 4.00 MIX_ LCM_ PLUGAB 21:30 - 22:00 0.50 MIX LCM PLUGAB 22:00 - 01:00 3.00 TRIP_ DP_ PLUGAB 01:00 - 01:30 0.50 RURD_ ELEC PLUGAB 01:30 - 02:30 1.00 SETREL PLUG PLUGAB 02:30 - 03:00 0.50 RUNPU ELEC PLUGAB 03:00 - 03:30 0.50 PULD_ BHA_ PLUGAB 03:30 - 06:00 2.50 TRIP DP PLUGAB Description of Operations Continue testing BOPE 250!5000 hold 10min. Peform accumulator drawdown test. All Components Passed. R/D test joint install wear bushing.' Blow down all test lines, top drive, choke and kill lines M/U 5"mule shoe and Rlh w/ 5" drillpipe Lost throttle control. Troubleshoot and repair Continue RIH W/mule shoe Tag up retainer at 4229'WLD Drill pipe Measurement 4237, POOH to 4110' (Correction on D/P depth from 4112/08) PJSM; Rig up Expro wireline RIH w/ pert. guns and misfire, POOH w/ pert guns, Pick up new set pert guns RIH, Perf. from 4214.5' to 4224' POOH ,Rig down wireline. Attempt to circ. perfs, would not circ. perfs held 1100 psi, blow down lines. Mix and Pump dry job. PJSM; POOH wl 5" drill pipe (SLM) no correction PJSM; Rig up Expro RIH w/ 9 5/8 EZ, SV retainer and set a# 4208' WLM.Rig down wireline. ~'JSM; Test css and retainer 1500 psi 10 min. held. Nipple down BOP change out 11"-500~k Cactus csg. spool to 13 5/8-5000# Vetco Grey csg. spool, test neck seal #0 2400 psi fori0 min. Nipple up BOP. Continue nipple up bop Set test plug. Test New spool and choke line 250/5000 10min, R/D test jt. Set wear busfiing Blow down test lines M/U mule shoe and rih W! 5' drillpipe to 4215' tag up on retainer, Pull up to 4095' and park drillpipe Rig up flow line from 13 3/8 annlus to rig flow line PJSM; R!U Expro WLS to run 5' 20shot pert guns. Set depth and Perforate from4125'-4130' POH witfi e-line and rig down. Well statiano losses after perforations Circulate perfs at 4125-4130 up the 13 3/8 X 9 5/8 annulus pressure inital pressure 385psi at 1.5bb1 min continue circulating at 50 bbls pumped pressure 380psi at 1 bbl per m'rn. At 100bb1s away psi=360 at 1.5bb1 per min At 120bb1s away 320psi 1.5bb1. per min at 150bb1 away 350psi at 1.8bb1 per min. At 200bb1s away 360psi 1.8bb1 min. At 250bb1 away 340psi @ 1.8bb1 per min. At 320 bbls away 295psi 1.8 bbl per min. Shut pumps down no returns to surface from 13 3/8 annulus. Hole Taking fluid at 20 bbls per hr. Note fluid was 8.6 kcl At 380psi Mix LC pi 190 ppb at. Ca .and 10 ppb G-Seal,.Pump 50 bbls. LCM pill and sgeeze 15 bbls. away pressure to 435 psi open annulas and continue pumping leaving 10 bbls. outside perfs. Monitor well losing 1 . bbl. every 5 min. Mix and spot 25 bbl LCM pill across perfs at 4124'-4130'.No gains No losses. POOH with mule shoe, to run bridge plug on wireline.No gains No losses hole static.Clean pits start mixing drillpiex mud Rig up Expro wireline R1H with 9 5/8 bridge plug on wire line. Set bridge plug at 4094' WLM. Hole static no losses POOH with wireline, rig down. Pick up 8 1/2 mill and Scraper RIH. RIH with 5" drill pipe.Cont. to mix drillpiex gel Printed: 5/14/2008 5:58:18 PM • Marathon ail Company Page 5 of 13 Operations Summary Report Legal Well Name: KENAI BELUGA UNIT 42-7 Common Well Name;; KENAI BELUGA UNtT 42-7 Spud Date:; 1!19/2001 Event Name: RE=ENTRY Stark: 4/4!2008 End: Contractor Name: Rig Release; Group:: Rig Name: Rig Number: Date From - To Hours Code Code Phase Description of Operations 4!15/2008 06:00 - 06:30 0.50 TRIP DP~ PLUGAB Continue TIH W/ Mill and scraper.Taa uo an retainer at 4101'Drilfpipe measurement. Mix Drillplex gel. 06:30- 10:30 4.00 CLEAN TANK PLUGAB Clean pltS. Complete pit cleaning,Slip and cut drilling line. 10:30.- 15:00 4.50 MIX MUD - PLUGAB Mix gel plea total. of 750bb1s mixed, with 450bb1s shipped to hanson tank. trnfiydra#ion. j 15:00 - 20:00 5.00 MIK, MUD_ PLUGAB Mix DrNpteX mud Total of 375bb1s mixed 20:00 - 21:00 L00 CIRC_ MUD_ PLUGAB PJSM;Attempt to Displace KCL with drillplex mud, Mill ptuctped presured to 1900 psi.Work pipe and reverse thru mill,-pump long way St1N plugged, pull 10 stds. pipe dry ,pump long way-got circ.,RiH with 10 etds., tied full sirs. 21:00 - 23:00 2.00 CIRC MUD_ PLUGAB Start change over to Drillpiex mud, pumped 310 bbls, 23:00 - 01:30 2.50 TRIP_ DP PLUGAB'.. PJSM;POOH with saaper and 81/2 mill. 01:30 - 02:00 0.50 PULD_„ BHA PLUGAB Lay down 81/2 mid and scraper. 02:00 -04:30 2.50 PULD $HA_ SIDET PJSM; Measuiive, delft and pick up 9 5/8 Window mill easy. 04:30 -06:00 1.50 PULD BHA SIDET :PJSM; Measure, drift and. pick up (8) 6 114 drill collars, 4/16/2008 06:00 - 07:00 1.00 TRIP_ 8HA SIDET ;Continue RiH W! BHA. Pulse test mwd. PN drift an+d rih w/ HUVDP 07:00 - 09:30 2.50 TRIP_ DP_ SIDET RIH W/ 5" drillpipe at seduced rate with whtpstodc 09:30 -10:00 0.50 SETREL TaQL SIDET Qrient Whi stock ~ 20 Right of high side tool face.Up W! 133k Dn wt 100K Set anchorwltti 900k / 20k dawn. P/U to 173k140K shear/set- whiostodc . :Printed: 51't4/2008 5:59:91 PM • SARAH PAULA, GOVERNOR ,iaA 0~ ~ ~ SSS W. 7tlt AVENUE, SUITE 100 c ~ ~~~~~'~~~~~ C~~ IQ~ ANCHORAGE, ALASKA 99501-3538 i3>~ PHONE (907) 2T9-1433 FAX (987) 27&7542 Senior Completions Engineer Marathon Ofi Company ~~~1~ APR ~ 3 200$ P.O. Box 1949 Kenai, Alaska 99611-1949 Re: -Kenai Gas Field, Beluga Gas Pool, Kenai Beluga Unit 42-? Sundry Number: 308-096 ~~ r Qtr ~ V `_` Dear Mr. Rang: Enclosed is the approved Applicx~tion for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the ComYnission to witness any required test, contact the Commission's petroleum field inspector at (90'7j 659-3607 (~gerj. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Ccnnmissi.©n giants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 2nd day of April, 2008 Encl. ,~ Marathon MARATHON Qil Company March 25, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7~' Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice Field: Kenai Gas Field Well: Kenai Beluga Unit 42-7 Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 RECEt~/IE~ MAR 2 6 2008 Alaska 0~ & Gas Cons. Commission Anchorage ~~~, o~,s Enclosed please find the 10-403 Application for Sundry Approvals for the wellbore abandonment of KBU 42-7. Marathon proposes to abandon the wellbore below 4,060' MD in preparation for redrilling the well to a new target location. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, .. ' ~~ ~ev~ Kevin J. Skiba Production Technician Enclosures: 10-403 Sundry Notice Work Scope Procedure Current Well Schematic Proposed Well Schematic cc: AOGCC Houston Well File Kenai Well File KJS CLR ~~ ~ .a'~ RECEI iv STATE OF ALASKA ~f 0`V ALASK~ OIL AND GAS CONSERVATION COMMISSION ~'^~~, MAR 2 ~~ APPLICATION FOR SUNDRY APPROVALS D~~ 20 AAC 25zso Alaska Oil & Gas Cons. Commission 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ Perforate ^ Waivep~horage Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: Marathon OII COm an p y 4. Current Well Class: 5. Permit to Drill Number: Development ^ Exploratory ^ 199-025 3. Address: PO BOX 1949 Stratigraphic ^ Service ^ 6. API Number: ~ Kenai Alaska, 99611-1949 50-133-20488-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ Kenai Beluga Unit 42-7 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): (~ycr A - 028142 87' ~ Kenai Gas Field /Beluga Pool 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7,570' 7,309' 6,706' 6,445' 6,706' 7,420' Casing Length Size MD ND Burst Collapse Structural Conductor 117' 20" 117' 117' 3,060 psi 1,500 psi Surface 1,099' 13-3/8" 1,099' 1,093' 3,450 psi 1,950 psi Intermediate 651' 13-3/8" 1,750' 1,732' 5,380 psi 2,670 psi Production 5,582' 9-5/8" 5,582' 5,322' 5,750 psi 3,090 psi Liner 7,518' 3-1/2" 7,257' 7,257' 10,160 psi 10,530 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5,636'-7,409' (Gross) 5,376'-7,148' (Gross) 3-1/2" L-80 7,453' Packers and SSSV Type: Packers and SSSV MD (ft): NA NA 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: ~ ~~ t April 7, 2008 Commencing Operations: ~ Oil ^ ~-hers-~}+ Plugged Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Craig L. Rang Title Senior Completions Engineer Signature 1 Phone (907) 283-1372 Date March 25, 2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~~ ~~ Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other. ~.0 ~ Sr ` 3~\~~ tl~.`V V'l. ~v ~ ~~'c~'~ Subsequent Form Required: ~...~~~ APPROVED BY Approved by: COMMISSIO R THE COMM SSI N Date: Form 10-403 Revised 06/2006 ~ ~ ~ ~ ~~ ~ ~ ~ ~~~~~ ~ ~~~~ ~~~ ~~ Submit in Z)uglicate • • `•: 50-133-20488-00-00 ertv Des: A - 028142 21' AGL (87' KB Elevation) I Date: 1/19/2001 teleased: 2/14/2001 eached: 2/6/2001 Top of Cement - 4,265' Tree cxn = 3-1 /2" EUE 8rd KOP: 300' Build: 2.5 deg per 100' Hold Angle: 26 deg at 2500' DOP: 3800' DfOp: 0.5 deg per 100' Final Angle: <3 deg at 5720' @ 5549' MD (5289' TVD) w/ 7/16" electric cable (dual-armored, 7-strand conductor) to surface two 10K pressure sensors one temperature sensor PLT on e-line - 6;964'-(a 2~19fA3~ WL tag: X969' {4/23/0 6,464' (12/7/03) Coil cleaned out to 7,420' CTM, (1 1 /412 0 01) ~~~ M MARATNOM Drive Pioe 20" K-55 133 ppf Tom Bottom MD 0' 117' TVD 0' 117' Surface Casins~ 13-318" 68 ppf Tom Bottom K-55 MD 0' 1,099' TVD 0' 1,093' L-80 MD 1,099' 1,750' TVD 1,093' 1,732' BTC @ 1,750' MD Cmt w1734 sacks class G 9-518" L-80 40 ppf T~ Bottom MD 0' 5,582' TVD 0' 5,322' BTC @ 5,582' MD Cmt w/ 854 sacks of class G Production Tubing 3-1/2" L-80 9.3 ppf EUE 8rd with 5.25" OD slotted couplings to 7,518' Cmt w/ 875 sacks of class G PBTD - 6,720' TD - 7,570' ih control lines now open for methanol injection 30/01) ceramic flappers milled out with coil. :: ule 15 5636' - 5646' (frac'd 8/30/01) ule 14 5737' - 5747' (frac'd 8130/01) ule 13 5805' - 5815' (frac'd 8/30/01) ule 12 5863' - 5873' (frac'd 8/5/01) ule 11 5941' - 5951' (perfed 8/5/01) ule 10 6123' - 6133' (perfed 8/4/01) ule 9 6271' - 6281' (perfed 8/4/01) ule 8 6366' - 6376' (frac'd 8/4/01) ule 7 6499' - 6509' (frac'd 6/3/01) ule 6 6611' - 6621D' (frac'd 6/3/01) f art ~ted Perfs: i ,~ '~ ~ ~J,~~~~ ~~ ,f ` ist tron Bridge Plug @ 6,720' ule 5 6746' - 6756' (frac'd 6/3101) ule 4 6943' - 6953' (perfed 6/1!01) ule 3 7153' - 7163' (frac'd 6/1101) ule 2 7319' - 7329' (perfed 6/1101) ule 1 7399' - 7409' (perfed 3/11/01) ac'd zones were treated with 16/20 Carbolite in al-based Super Rheogel frac fluid. Well Name & Number: KBU 42-7 Lease: Kenai Gas Field County or Parish: Kenai Peninsula State: Alaska Country: USA Perforations (MD) : (TVD): Angle/Perfs: Angle @ KOP and Depth: Dated Completed: 211 412 0 0 1 Prepared by: Kevin Skiba Last Revison Date: 3/24/2008 KBU 42-7 Pad 41-7 37' FNL, 4,118' FWL Sec. 7, T4N, R11W, S.M. ~ ` }.~.'~ • lit #: 199-025 t: 50-133-20488-00-00 ertv Des: A - 028142 21' AGL (87' KB Elevation) 1 Date: 1/19/2001 teleased: 2/14/2001 eached: 2/6/2001 PROPOSED KBU 42-7 Pad 41-7 37' FNL, 4,118' FWL Sec. 7, T4N, R11W, S.M. > Stock @ -4,060' ent Retainer @ -4,080' of Abandonment Cement @ -4,081' enting Perfs @ -4,110' (2') 6spf ipe Control Lines @ -4,136' !" Excape Tubing @ -4,136' ng Cement Plug @ -4,610' Iron Bridge Plug @ -4,620' Top of Excape Cement - 4,265' Tree cxn = 3-1/2" EUE 8rd KOP: 300' Build: 2.5 deg per 100' Hold Angle: 26 deg at 2500' DOP: 3800' Drop: 0.5 deg per 100' Final Angle: <3 deg at 5720' @ 5549' MD (5289' TVD) w/ 7/16" electric cable (dual-armored, 7-strand conductor) to surface two 10K pressure sensors one temperature sensor PLT on e-line - X964'-(1-21-1018 W L tag: x;869' {3/233183) 6,464' (12/7/03) Coil cleaned out to 7,420' CTM, (11 /4/2001) ~. 9' ~F i.S PBTD - 6,706' MD TD - 7,570' MD • M MARATNOM Drive Pioe 20" K-55 133 ppf Tom Bottom MD 0' 117' TVD 0' 117' Surface Casinst 13-3/8" 88 ppf Tom Bottom K-55 MD 0' 1,099' TVD 0' 1,093' L-80 MD 1,099' 1,750' TVD 1,093' 1,732' BTC @ 1,750' MD Cmt w/734 sacks class G Intermediate Casing 9-5/8" L-80 40 ppf Top Bottom MD 0' 5,582' TVD 0' 5,322' BTC @ 5,582' MD Cmt wl 654 sacks of class G Production Tubing 3-112" L-80 9.3 ppf EUE 8rd with 5.25" OD slotted couplings to 7,518' Cmt w/ 875 sacks of class G Ih control lines now open for methanol jection (8130/01) ceramic flappers milled out with coil. 15 5636' -5646' (frac'd 8/30101) 14 5737' - 5747' (frac'd 8/30/01) 13 5805' - 5815' (frac'd 8/30!01) 12 5863' - 5873' (frac'd 815/01) 11 5941' - 5951' (perfed 8!5/01) 10 6123' - 6133' (perfed 8/4101) 9 6271' - 6281' (perfed 8/4/01) 8 6366' - 6376' (frac'd 8/4/01) 7 6499' - 6509' (frac'd 6/3101) 6 6611' - 6621' (frac'd 6/3/01) Iron Bridge Plug @ 6,706' 5 6746' - 6756' (frac'd 6/3/01) 4 6943' - 6953' (perfed 6/1/01) 3 7153' - 7163' (frac'd 6/1 /01) 2 7319' - 7329' (perfed 6/1101) 1 7399' - 7409' (perfed 3/11!01) 1 zones were treated with 16/20 Carbolite in ased Super Rheogel frac fluid. Well Name & Number: KBU 42-7 Lease: Kenai Gas Field County or Parish: Kenai Peninsula State: Alaska Country: USA Perforations (MD) : (TVD): Angle/Perfs: Angle @ KOP and Depth: Dated Completed: 211 412 0 0 1 Prepared by: Kevin Skiba Last Revison Date: 3/24/2008 Revised • KBU 42-7 Pre-Sidetrack Abandonment Procedure 1. R/U Expro electric line and lubricator. 2. Test lubricator to 500 psi. 3. Run 2.75" gauge to 5,600'and POOH. 4. Run bridge plug for 3.5" 9.3# L-80 casing (2.7"OD) and set at 5,586'. Confirm plug set and POOH with setting tool. ~ 3~ x ,~, ;~~~ ~~.~ ~, ~~~ ~ t°Q P~'~ 5. Make up 2" OD dump bailer to place minimum 35' of cement on top of bridge plug @ 5586'. 6. R/D Expro EL. 7. Test 3 %2" CSG to 2000 psi. 8. Check 9 5/ " X 3 '/z" annulus for pressure. If pressure is present bleed pressure off. 9. N/D tree. ~~- ~~u~, 10. N/U BOP. 11. Test BOPE to 250/2000psi against CSG with 3 %i" test joint. 12. R/iJ Expro electric line and Run a one foot (4 spf -using tubing puncher charges) squeeze gun to 4236' and punch holes in 3 '/2" CSG. POOH. ~ T-~ C.. E5~ ~ r ~~ S~ 13. Attempt to circulate through 3 1 /2" x 9 5/8" annulus, back to surface. If unsuccessful in establishing circulation, repeat steps 12 and 13 in +/- 31' increments until successful. 14. Run Expro 3 '/2" Casing cutter. Cut 3 '/2" casing at successful circulation depth. R/D Expro. 15. N/D BOP and suspend with bridge cranes over well. 16. Remove packoff from wellhead. 17. RU casing crew. Spear 3 %2" CSG stub, pull CSG free and P/IJ to lst connection. • • 18. Pu113 '/2" CSG slips. 19. Inspect control lines and terminate at surface. RU Pollard wireline to spool up control line and electric line. 20. Set 3 %2" casing in the slips at rig floor. Release CSG spear and L/D cut joint. 21. N/LJ BOP and re-test break. 22. P/IJ 3 %2" casing with elevators. 23. Pu113 '/2" CSG and L/D same, along with spooling up control and electric lines. 24. Run test plug and test BOPS w/5" test joint to 25015,000 psi. Set wear bushing. 25. RIH with 8.5" Mill and 9 5/8" scraper on 5" DP to top of 3 %2" CSG stub. 26. Circ. hole clean and POOH with mill and scraper. 27. RiU Expro electric line and run 9 5/8" gauge ring to top of 3 '/z" CSG stub. POOH. 28. Run and set 9 5/8" bridge plug at top of 3 1/2" CSG stub. POOH. 29. Test 9 5/8" CSG to 1,500 psi. Replace top multibowl section and test. Set wear bushing. 30. R/U and run Expro CBL to compare to Schlumberger CBL dated 2-1-2001, to confirm top of cement. R/D Expro. 31. P/U 5" drill pipe and TIH open ended. 32. R/U Expro and run perf gun through 5" drill pipe. Perforate 9 5/8" intermediate casing at 4220' using Expro wireline casing guns (2 feet - 6 spf) tieing into the CBL's. Perforation depth is dependent on new CBL. 33. Establish circulation through perfs at 4220'. If needed, perforate additional holes above 4220' until perfs can be pumped into. TOOH. 34. PU and RIH with 9 5/8" cement retainer on 5" drill pipe, set at 4200'. 35. RU BJ Services. Establish circulation through perforations and place 1,000' of 15.8 ppg cement on the 9 5/8" annulus. • • 36. Sting out of retainer and dump some cement on top of retainer. PU and circulate drill pipe clean. TOOH, LD stinger for the retainer. 37. Move to sidetracking operations. • KBU 42-7 Pre-Sidetrack Abandonment Procedure 1. R/U Expro electric line and lubricator. 2. Test lubricator to SOOpsi. 3. Run 2.75" gauge to4620' POOH. 4. Run bridge plug for 3.5" 9.3# L-80 CSG(2.7"OD) and tat 4620'. Confirm plug set and POOH with setting tool. 5. Make up 2" OD dump bailer to place 10' of ceme on top of bridge plug@4620'. 6. R/D Expro EL. 7. Test 3 %2" CSG to 2000psi. 8. Check 9 5/8" X 3 '/2" annulus for pres e. If pressure is present bleed pressure off. 9. N/D tree. ~~© " `~' 10. N/LJ BOP. ~ ~~ 11. Test BOPE to 250/2000p against 3 '/2" test joint. 12. N/D BOP and suspe with bridge over well. 13. Remove packoff m wellhead. 14. Spear 3 lh" C stub. 15. Pu113 '/2" SG slips. 16.Inspe control lines. 17. R ase CSG spear and LlD. 18 /LJ overshot and overshot 3 %2" CSG. 9. N/U BOP. 20. R/U Expro electric line and Run 3 '/2" Casing Cutter. Cut 3 '/2" casing at 4136' (Tie into Expro CBL dated 3-22-2008). POOH. 21. Attempt to pull CSG free. • 22. If successful, continue with step 23. If not, shoot a one foot (4 s -using tubing puncher charges) squeeze gun at 4200 feet. Attempt to circul through 3 %2" casing back to surface. If successful, cut casing again at 417 tying into same CBL as before. Go to step 21. If unsuccessful in establish' g circulation move uphole ,shoot holes until successful in establishing circu tion then cut casing and go to step 21 23. Pull 3 %2" CSG and L/D. 24. Run test plug and test BOPE w!5" test joint. 25. Perforate 9 5/8" intermediate casing strin 110' using Expro wireline casing guns (2 feet -6spf) tying into Schlum L ted 2-1-2001. 26. RIH with 8.5" Bit and 9 5/ '1 ' ~ 5' o top of 3 1/Z" CSG stub. 27. Circ. hole clean and PO d scaper. 28. R/U Expro electric lined run 5!8" gauge ring to top of 3 '/2"CSG stub. POOH. 29. Run and set 9 5/8" Ha11ib~Eon cement retainer at 4080'. POOH. 30. R/D Expro electric 31. R/U BJ Services t queeze cement behind 9 5/8" casing. Weight and volume of cement to be dete fined by drilling engineer. Rig Dow BJ. WOC 32. Proceed with si tracl~•out of the 9 5/8" CSG. KBU 42-7 Abandonment Pro~ure Revised.doc • Maunder, Thomas E (DOAj From: Maunder, Thomas E (DOA) Sent: Wednesday, April 02, 2008 2:38 PM To: 'Tank, Will' Cc: Berga, Pete; Rang, Craig L.; Skiba, Kevin J.; Rig Glacier 1, 907-283-1312 Subject: RE: KBU 42-7 (199-025) Abandonment Procedure Revised.doc Will, et al, Thanks much for reviewing the ability to test the "break" prior to pulling the 3-1/2" out of the hole. While the likelihood of having to deal with any pressure is small and the remade flange break is likely to not leak, assuring the competency of this wellhead connection is important. As I noted in our calls, I have seen tubular strings suspended using the test plug or an RTTS. Best regards for the operations. Tom Maunder, PE AOGCC From: Tank, Will [mailto:wjtank@marathonoil.com] Sent: Wednesday, April 02, 2008 12:30 PM To: Maunder, Thomas E (DOA) Cc: Berga, Pete; Rang, Craig L.; Skiba, Kevin J.; Rig Glacier 1, 907-283-1312 Subject: RE: KBU 42-7 (199-025) Abandonment Procedure Revised.doc Tom, Page 1 of ~' After I got off the phone with you this morning, we discussed the upcoming abandonment operation with the folks at the rig site. After some discussion, we believe that we can in fact test that break utilizing a test plug. We'll pull and lay down the cut joint of 3 1/2" along with the first full joint. The control lines and wireline attached to the 3 1/2" will be cut at that point, banded to the 3 1/2" stil9 in the well and secured prior to installing a test plug and lowering it into the BOP stack to re-test the bottom break. ~~RE~ APR ~ 3 2008 Thanks, Wi II From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, April 01, 2008 9:48 PM To: Tank, Will Subject: RE: KBU 42-7 (199-025) Abandonment Procedure Revised.doc Will, My questions are mostly answered. For question 6, you pointed out what you did on KBU 24-6 / 24-6RD but didn't answer my question. 1 have checked the reports for 24-6 and the break was not tested after the slips were recovered. Is it feasible to hang to LD at least 1 Joint of 3-112" and then hang off on either the test plug or RTTS? I look forward to your reply. Tom Maunder, PE AOGCC From: Tank, Will [mailto:wjtank@marathonoil.com) Sent: Tuesday, Apri101, 2008 11:30 AM To: Maunder, Thomas E (DOA) Cc: Rang, Craig L.; Berga, Pete; Skiba, Kevin J. Q,~, ~ `' fj 4/2/2008 ~.~~- ~ ~~ ~ ~~ S `D n ~~.~~ ~~Sc KBU 42-7 Abandonment Pro~ure Revised.doc • Maunder, Thomas E (DOA) From: Tank, Will [wjtank@marathonoil.com) Sent: Tuesday, April 01, 2008 11:30 AM To: Maunder, Thomas E (DOA) Cc: Rang, Craig L.; Berga, Pete; Skiba, Kevin J. Subject: RE: KBU 42-7 (199-025) Abandonment Procedure Revised.doc Tom, Page 1 of 5 Pete and I were also involved in writing the abandonment program, so ! wiA try to address these items for you. Please note that these well operations are very similar to KBU 24-6RD, which was the 1st EXCAPE well sidetracked in early 2006. Questions: 1. Kevin has given you this pressure. 2. Kevin has given you this pressure. 3. The rig will go over the well at step 8. The work for steps 1 - 7 involve wireline operations. The rig would move in and then do step 8. Once we have determined that no pressure exists between the 9 5/8" x 3 1/2" annulus, or have bled it off, we will nipple down the wellhead, nipple up the BOP and test it on the 3 1/2" string. 4. The original well KBU 42-7 was TD'd with 10.9 ppg drilling mud. The well was cemented with 15.7 ppg cement and no returns lost, so the backside should be fluid filled. At step 15 the 3 1/2" EXCAPE string is still in the well, so the 9 5/8" could not be tested. Our procedure had a casing test on the 3 1/2" EXCAPE string in step 7. Once the 3 112" is cut off, tripped out, and laid down, we need to get a CIBP in the 9 5/8"just above the cutoff 3 1/2" so that the cutoff control lines are isolated prior to testing casing. While it is quite likely the control lines wouldn't take any fluid (probably crushed), we felt we should get a CIBP aver top of it prior to testing the 9 5/8" casing itself. That test is in step 29, prior to any remedial cementing work behind the 9 5/8" casing. 5. It was our plan to use just KCI brine which would be approximately 8.6 ppg. 6. Looking at the work done on KBU 24-6RD, it would appear that we really can't retest that break, since the 3 1/2" is cut and it is suspended in the rotary table. 7. The step 24 BOP test pressure of 5,000 psi is involved in the drilling portion of the sidetrack. My MASP far the production hole is around 3,123 psi. We would then recommend testing the BOP's to 3,500 psi. For the BLM that means that the BOP stack must be a 5,000 psi stack. Their rules call fora 5,000 psi stack to be tested to 5,000 psi. This is a regulation that they haven't always been consistent on. We certainly test above the MASP, but not always to the maximum of the BOP stack. I think when we are at a MASP below 3,000 psi (which is normally where we are), we could utilize a 3,000 psi stack, but have always used our 5,000 psi stack. Below 3,000 psi MASP values we have been testing above that calculated MASP. Normally the BLM hasn't asked fora 3,000 psi test when our MASP is below 3,000 psi, they have accepted the recommended test pressure. Tom, I hope this answers your questions sufficiently. If you need any more information don't hesitate to call or e- mail me. I've had my head down working on the sidetrack sundry for this well, but I'll get you any additional info you need. Thanks, Will Tank 4/1/2008 KBU 42-7 Abandonment Pro~ure Revised.doc Page 2 of 5 From: Skiba, Kevin J. Sent: Monday, March 31, 2008 6:39 PM To: Maunder, Thomas E (DOA) Cc: Rang, Craig L; Berga, Pete; Tank, Will Subject: RE: KBU 42-7 (199-025) Abandonment Procedure Revised.doc Tom The SITP is 900#. The 9-5/8" annulus pressure is 20#. Kevin Skiba Production Technician Marathon Oil Company Office (907) 283-1371 Cell (907) 394-1332 Fax (907) 283-1350 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, March 31, 2008 1:11 PM To: Maunder, Thomas E (DOA); Skiba, Kevin J. Cc: Rang, Craig L.; Berga, Pete Subject: RE: KBU 42-7 (199-025) Abandonment Procedure Revised.doc Gentlemen, 1 have reviewed the revised procedure received on 3-28 and have some questions. I will relist questions 1 and 2 from before. 1. What is the current SITP? 2. Is there any pressure in the 9-5/8" x 3-1/2" annulus? 3. At what point is the drilling rig over the well? It would appear after step 8. 4. Is the 9-5/8" x 3-1/2" annulus fluid filled? It would seem appropriate to have that annulus filled and pressure tested early in the work process. At a minimum, the 9-5/8" casing should be tested and verified competent prior to breaking the stack in step 15. 5. What weight fluid will be used when the well is circulated (step 13}? 6. After the slips are recovered, will the "break test" be against the 9-5/8" casing or will a test plug be used? Is it feasible to hang the 3-1/2" off to accomplish the test? 7. In step 11 the BOP is tested against the 3-1/2" casing/tubing to 2000 psi. In step 24 the BOP is tested against the test plug to 5000 psi. What is the desired BOP test pressure? I look forward to your reply. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Monday, March 31, 2008 11:06 AM To: 'Skiba, Kevin J.' 4/1/2008 KBU 42-? Abandonment Pro~ure Revised.doc Page 3 of 5 Cc: 'Rang, Craig L.'; 'pkberga@marathonoil.com' Subject: RE: KBU 42-7 (199-025) Abandonment Procedure Revised.doc All, I have printed off the revised procedure that Kevin sent on Friday. The operations are more complete and make much more sense. I am still curious about the well pressures. Tom From: Maunder, Thomas E (DOA) Sent: Monday, March 31, 2008 11:00 AM To: Maunder, Thomas E (DOA); 'Skiba, Kevin J.' Cc: 'Rang, Craig L.'; `pkberga@marathonoil.com' Subject: RE: KBU 42-7 (199-025) Abandonment Procedure Revised.doc Kevin, Craig and Pete, I am reviewing the sundry for the plugging of this well and have a couple of questions. 1. What is the current SITP? 2. Is there any pressure in the 9-5/8" x 3-12/" annulus? 3. Since there is a squeeze planned, I presume the casing exit is above the 9-5/8" TOC? I will be looking at the file as my review proceeds, however I wanted to get these questions off to you all. Look forward to your reply. Call or message with any questions. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Monday, March 31, 2008 9:53 AM To: 'Skiba, Kevin J.' Cc: Rang, Craig L.; pkberga@marathonoil.com Subject: RE: KBU 42-7 Abandonment Procedure Revised.doc Kevin, et al, Thanks for the additional information. I will be back to you regarding the sundry approval. Tom Maunder, PE AOGCC From: Skiba, Kevin J. [mailto:kskiba@marathonoii.com] Sent: Monday, March 31, 2008 9:45 AM To: Maunder, Thomas E (DOA) Cc: Rang, Craig L.; pkberga@marathonoit.com Subject: RE: KBU 42-7 Abandonment Procedure Revised.doc Tom Due to the impending road weight restrictions, Marathon had to move the drill rig from Ninilchik to the Kenai Gas Field earlier than expected. This has caused us to accelerate the permitting process of KBU 42-7 well Abandonment / ReDrill. The rig should complete work on KBU 41-18x by 4/6/2008. We are hoping to have the initial part of the abandonment work completed on KBU 42-7 by this date to eliminate placing the rig on standing- bye while this preliminary work is completed. Any help that you can supply to promote this process would be appreciated. Thanks for your support, Kevin Skiba Production Technician 4/1/2008 KBU 42-7 Abandonment Pro Revised.doc Page 4 of 5 • Marathon Oil Company Office (907) 283-1371 Cell (907) 394-1332 Fax (907) 283-1350 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, March 28, 2008 11:36 AM To: Skiba, Kevin J. Subject: RE: KBU 42-7 Abandonment Procedure Revised.doc Thanks Kevin and I still haven't had a chance to see it. But I will probably be in for a while tomorrow and Monday. Tom From: Skiba, Kevin J. [mailto:kskiba@marathonoil.com] Sent: Friday, March 28, 2008 11:30 AM To: Maunder, Thomas E (DOA) Subject: RE: KBU 42-7 Abandonment Procedure Revised.doc Tom We just submitted that sundry on 3/25/2008. When i talked with you Wednesday, you said that you had not had a chance to review it yet. Kevin Skiba Production Technician Marathon Oil Company Office (907) 283-1371 Cell (907} 394-1332 Fax (907) 283-1350 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, March 28, 2008 10:55 AM To: Skiba, Kevin J. Cc: Rang, Craig L. Subject: RE: KBU 42-7 Abandonment Procedure Revised.doc Guys, Could you refresh my memory on this one? Do you already have a sundry? Abandonment takes one. Tom From: Skiba, Kevin J. [mailto:kskiba@marathonoil.com] Sent: Friday, March 28, 2008 10:26 AM To: Maunder, Thomas E (DOA) Cc: Rang, Craig L. Subject: KBU 42-7 Abandonment Procedure Revised.doc «KBU 42-7 Abandonment Procedure Revised.doc» 4/1/2008 ABU 42-7 Abandonment Pro~ure Revised.doc Page 5 of 5 Tom Here is the revised abandonment procedure for KBU 42-7. Kevin Slaba Production Technician Marathon Oil Company Office (907) 283-1371 Cell (907) 394-1332 Fax (907) 283-1350 4/1/2008 M Marathon MARATHON Oil Company October 31, 2007 ~~~~@~~~ NC?~i ~- ~ 207 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Kenai Gas Field Well: Kenai Beluga Unit 42-7 Dear Mr. Maunder: pncMorage l~~ ~ ~ Attached is a Sundry Report 10-404 for work performed on well KBU 42-7. Marathon installed a 3.5" Cast iron bridge plug @ 6706' to try and isolate water and sand producing zones from the well. If you have any questions or need additional information you can contact me at 907-283- 1308. Sincerely, ~. Wayne Ci sell Work Over Supervisor Enclosures: 10-404 Sundry Report cc: Houston Well File Well Schematic Kenai Well File Operations Summary DMD KJS • Marathon Oil Comps ny Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~~ NOV 0 ~ X007 Alaska Oil & Gas Cons. Omission RGVGt v `v STATE OF ALASKA ~~ NOV O ~. ZOO7 ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERA~`d& Gas Cons. Commission Anchorage 1. Operations Abandon Repair Well Plug Perforations ~ Stimulate Other ~ Set plug above Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Pertorations Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ at 6706' 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Oil Company Develo meat ~ p ^ E lorato ~ ry ^ 199-025 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20488-00-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 8T 21' AGL Kenai Belu a Unit 42-7 - 6. Property Designation: 10. Field/Pool(s): A - 028142 Kenai Gas Field /Beluga Pool - 11.Present Well Condition Summary: Clean out well, Set plug CIBP @ 6706', attempt to flow well to production. Total Depth measured 7,570' ~ feet Plugs (measured) 6720' true vertical 7,309' ~ feet Junk (measured) 7,420' Effective Depth measured 7,453' feet true vertical 7,192' feet Casing Length Size MD TVD Burst Collapse Structural 0 0 0 0 0 0 Conductor 117' 20" 117' 117' 3,060 psi 1,500 psi Surface 1,099' 13-3/8" 1,099' 1093 3,450 psi 1,950 psi Intermediate 651' 13-3/8" 1,750' 1,732' 5,380 psi 2,670 psi Production 5,582' 9-5/8" 5,582' 5,322' 5,750 psi 3,090 psi Liner 7,518' 3-1/2" 7518 7257 10,160 psi 10,530 psi Perforation depth: Measured depth: 5,636'-7,409' (Gross) True Vertical depth: 5,376'-7,148' (Gross) Tubing: (size, grade, and measured depth) 3-1/2" L-80 7,453' Packers and SSSV (type and measured depth) NA NA Sealbore Extension 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 75 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ~ Development ^~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil^ Gas Q WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307- 212 Contact Kevin Skiba (907) 283-1371 Printed Name Wayne Cissel Title Work Over Supervisor Signature Phone (907) 283-1308 Date October 30, 2007 Form 10-404 Revised 04/2006 ('1 ~ ` ~ ~ k~t~~~ ~ fLt~~ ~ 3 Submit Original Only RIGINA~ 71(~ 5~ b_ 50-133-20488-00-00 ertv Des: A - 028142 21' AGL (87' KB Elevation) Date: 1/19/2001 KBU 42-7 Pad 41-7 37' FNL, 4,118' FWL Sec. 7, T4N, R11W, S.M. Drive Pipe 20" K-55 133 ppf T~ Bottom MD 0' 117' ND 0' 117' Surface Casing 13-318" 88 ppf Tom Bottom K-55 MD 0' 1,099' TVD 0' 1,093' L-80 MD 1,099' 1,750' TVD 1,093' 1,732' BTC @ 1,750' MD Cmt wl 734 sacks class G Intermediate Casing 9-518" L-80 40 ppf Tom Bottom MD 0' 5,582' ND 0' 5,322' BTC @ 5,582' MD Cmt wl 654 sacks of class G Production Tubing 3-112" L-80 9.3 ppf EUE Srd with 5.25" OD slotted couplings to 7,518' Cmt wl 875 sacks of class G Excape modules placed h control lines now open for methanol injection 30/01) ceramic flappers milled out with coil. ule 15 - 5636' - 5646' (frac'd 8/30/01) ule 14 - 5737' - 5747' (frac'd 8/30!01) ~n<L ule 13 - 5805' - 5815' (frac'd 8/30/01) ~ ~' ule 12 - 5863' - 5873' (frac'd 8/5/01) ule 11 - 5941' - 5951' (perfed 8/5!01) ule 10 - 6123' - 6133' (perfed 8/4/01) ule 9 - 6271' - 6281' (perfed 8/4!01) ule 8 - 6366' - 6376' (frac'd 8/4!01) ule 7 - 6499' - 6509' (frac'd 6/3/01) ule 6 - 6611' - 6621' (frac'd 6/3!01) t Iron Bridge Plug @ 6,706' le 5 - 6746' - 6756' (frac'd 6/3/01) le 4 - 6943' - 6953' (perfed 6/1 /01) le 3 - 7153' - 7163' (frac'd 6/1 /01) le 2 - 7319' - 7329' (perfed 6/1/01) le 1 - 7399' - 7409' (perfed 3/11/01) zones were treated with 16/20 Carbolite in sed Super Rheogel frac fluid. Well Name & Number: KBU 42-7 Lease: Kenai Gas Field County or Parish: Kenai Peninsula State: Alaska Country: USA Perforations (MD) : (TVD): Angle/Perfs: Angle @ KOP and Depth: Dated Completed: 2/1412001 Prepared by: Wayne Cissell Last Revison Date: 1 013 012 0 0 7 v~,n „I~3 ~ ~~'1S1 ~ 3 ~~ I Marathon Oil Company Operations Summary Report Legal Well Name: KENAI BELUGA UNIT 42-7 Common Well Name: KENAI BELUGA UNIT 42-7 Event Name: WORKOVER Contractor Name: Rig Name: Date From - To Hours Code Code Phase 9/20/2007 09:00 - 10:00 1.00 SAFETY MTG_ IN1EVL 10:00 - 16:00 6.00 RURD COIL IN1EVL 9/21/2007 07:00 - 09:30 2.50 SAFETY MTG_ IN1 EVL 09:30 - 10:00 0.50 RURD COIL IN1 EVL 10:00-10:05 0.08 WORK COIL IN1EVL 10:05 - 10:30 0.42 WORK COIL IN1EVL 10:30 - 11:30 1.00 WASH FILL IN1EVL 11:30 - 12:00 0.50 WASH FILL IN1 EVL 12:00 - 12:30 0.50 WASH FILL IN1EVL 12:30 - 12:55 0.42 WASH FILL IN1EVL 12:55 - 13:00 0.08 WASH FILL IN1EVL 13:00 - 13:30 0.50 WASH FILL IN1EVL 13:30 - 14:05 0.58 WASH FILL IN1 EVL 14:05 - 14:15 0.17 WASH FILL IN1EVL 14:15 - 14:50 0.58 WASH FILL IN1EVL 14:50 - 16:00 1.17 RURD COIL IN1EVL 16:00 - 17:00 1.00 RURD COIL IN1EVL 9/22/2007 17:00 - 18:00 1.00 SAFETY MTG IN1 EVL 18:00 - 20:00 2.00 RURD ELEC IN1 EVL 20:00 - 20:45 0.75 RURD ELEC IN1 EVL 20:45 - 22:30 1.75 RURD_ ELEC IN1EVL 22:30 - 23:00 0.50 RURD ELEC iN1 EVL Page 1 of 3 ~ Spud Date: 1/19/2001 Start: 9/20/2007 End: 9/22/2007 Rig Release: Group: Rig Number: Description of Operations Held PJSM, discussed primary job scope and environmental issues. Contacted AOGCC, James Reggs, waived the BOP witness on 9/19/2007. PT surface lines, BOP test completed. Good test. Low pressure test 250 prig, high pressure 4500 psig. Mixed 500 bbls of 6% KCL for clean out tomorrow. Lay down for night. Held PJSM, discussed primary job scope and environmental issues. PU injector, go to well. Shell test to 1000 psig. Open well WHP= 0 psig. RIH with 1.75" coil with BHA consisting of 1.75" dimple on coil connector, 1.75" DFCV, 1.75" boss, 2.125" Vortex nozzle., coil at 100' start pumping 6% KCL at .25 BPM, PIP= 465 psig. Returns to flow back tank. Continue working coil down hole. CT at 1900' CTM, PIP= 450 psig, 0.25 PIR. Retums to flow back tank. CT @ 5685', PIP=600 psig, WHP= 0 psig, total fluid pumped = 42 bbls. PIP= 0.25 BPM. Stacked out at 5740' with coil, PU and wash down with nozzle. _` Increased pump rate to 1.5 BPM, Fluid retums dirty with some coal. Washing down with nozzle. Returns good. Lost returns when coil at 5866' CTM. PU hole until returns back. RIH with coil. Wash down to 5854' CTM, PIP= 2290 psig, WHP= 0 psig, PUW = 10, 110 lbs. Total fluid pumped 140 bbls, PIP= 2400 psig, retums muddy with small pieces of coal. WHP= 11 psig. Continue washing fill, WHP= 7 psig, PIP=2400 psig, PIP= 1.5 BPM, running weight = 1850 lbs. Total fluid pumped= 184 bbls, Check pick up weight every 200'. RIH weight back to 3000 Ibs, vortex nozzle working good. PIP= 2340 psig, WHP= 7 psig, CT @ 6670' CTM, Total bbls pumped = 235 bbls. Choke plugging from chuncks of coal. Wash down to 6751'. Coil stacked out. PU hole with coil. 10' to 6740' ATM. Pump 1.5 bottoms up (58 bbis), good returns to surface. PIP= 2400 psig, PIR= 1.5 BPM. POOH with coil, returns clean with trace of coil. Lost 1 fluid pump, reduce PIR down to 0.75 BPM while POOH with with coil. At surface with coil, shut in swab valve, verify well pressure at 0 psig. Drop walking dogs. Disconnect Bowen connection. PU injector and take to CT craddle for rig back. Secure well, secure area, lay back coil for setting plug with a-line unit. BJ personnel left lease. MI RU electric line unit, Held PJSM, discussed primary job scope and environmental issues. Move in light plant, RU lubricator. Had to go to shop to get a 5K X 10K crossover. Finish rigging up. Went to communication black out on pad 41-7 to arm setting tool on plug. MU 2.5" CIBPwith Owen setting tool. Armed tool. Go to well with plug. PT to 500 psig, WHP= 0 psig. Open well RIH with plug. Sat down at 6708'. Verifed were collar located in tubing. PU correlate depth, set plug at 6706'. POOH after setting plug. RD electric line unit. Expro leff lease. Note: CIBP set at 6706'. Printed: 10/31/2007 6:44:18 AM • • Marathon Oil Company Page 2 of 3 Operations Summary Report Legal Well Name: KENAI BELUGA UNIT 42-7 Common Well Name: KENAI BELUGA UNIT 42-7 Spud Date: 1/19/2001 Event Name: WORKOVER Start: 9/20/2007 End: 9/22/2007 'Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code ~,,,b , Phase Description of Operations 9/23/2007 08:00 - 09:30 1.50 SAFETY MTG_ IN1 EVL Held PJSM, discussed primary job scope and environmental issues. 09:30 - 10:00 0.50 RURD_ COIL IN1EVL Prior to rigging u blew down well from 800 psig to flow back tank. Well went to 0 psig. Monitored for 30 minutes with no change. 10:00 - 11:30 1.50 RURD_ COIL IN1 EVL MU coil with 1.75" coil with BHA consisting of 1.75" dimple on coil connector, 2.0" nozzle. PU injector, go to well. Cool down N2. 11:30 - 11:45 0.25 RURD_ COIL IN1EVL Displace fluid in reel with N2. Shell tested surface iron to 750 psig. Good test. 11:45 - 12:30 0.75 PUMP_ N2_ IN1EVL Open well, RIH with coil. Coil at 200', start N2 at min rate. 500 SCFM. 12:30 - 14:15 1.75 PUMP_ N2_ IN1 EVL Coil at 2900' CTM, no fluid to flow back tank. N2 rate at 500 SCFM. Continue down hole with coil. PIP= 510 psi, WHP= 0 psig. 14:15 - 14:30 0.25 PUMP_ N2_ IN1EVL Work coil down hole, coil tagged fill at 6665' CTM. PUH with coil, increase N2 rate up 750 SCFM. No returns to surface. PU coil 100' to 6450', PIP= 1580 psig. 14:30 - 15:30 1.00 PUMP_ N2_ IN1 EVL Continue moving pipe up hole to keep pipe from washing out across from perforations. No returns to surface. PIP= 2100 psig. WHP= 0 psig. 15:30 - 15:50 0.33 PUMP_ N2_ IN1EVL PU coil above perforations to 5600' CTM. Retums to flow back tank, very dirty, muddy and sandy. PIP= 1920 psi, N2 rate @ 500 SCFM. 15:50 - 16:10 0.33 PUMP_ N2_ IN1EVL WHP=125 psig, cut N2 rate back to 320 SCFM. Returns muddy gray water. RIH with coil to 6560' CTM. Coil well making some coal plugging up choke. 16:10 - 16:33 0.38 PUMP_ N2_ IN1 EVL PU coil PU weight increased to 18000 Ibs, continue pulling up hole through perforations losing returns at surface. Increase N2 rate up to 500 SCFM. PIP= 1028 psig, WHP= 60 psig. Coil at 5800', pick up weight down to 14, 000 Ibs, lost 4, 000 Ibs. 16:33 - 16:55 0.37 PUMP_ N2_ IN1EVL Coil at 5800' CTM, PIP=1050 psig, WHP= 66 psig. Cut N2 rate back to 300 SCFM. WHP= 600 psig. Continue POOH with coil. Choke plugged off with coal, change to other choke, flow directly to the inside of flow back tank. Hard to keep choke from plugging. Retums fluidy with gray water and silt. POOH with coil. 16:55 - 17:25 0.50 PUMP_ N2_ IN1EVL Coil at 5100' CTM, PIP= 1185 psig, N2 at 300 SCFM. PUW= 10, 000 lbs. Pulled 75 bbls off of flow back tank. 17:25 - 17:50 0.42 PUMP_ N2_ IN1EVL Plug across the flow back piping. Coil at 3600' CTM. Flow stopped to flow back tank because of plugged line. Continued pulling OOH with mil. 17:50 - 18:20 0.50 PUMP_ N2_ IN1 EVL OOH with coil. Cleared one side of choke, the well would not flow to flow back tank. WHP= 0 psig. Will let pressure build over night to determine if well will flow on its own. 16:10 - 16:20 0.17 RURD_ COIL IN1 EVL At surface with coil, shut in swab valve, well pressure at 0 psig. Drop walking dogs. Disconnect Bowen connection. PU injector and take to CT craddle for rig back. 16:20 - 17:00 0.67 RURD_ COIL IN1EVL Secure well, secure area, lay back coil for setting plug with a-line unit. BJ personnel left lease. 9/24/2007 16:00 - 16:30 0.50 SAFETY MTG_ IN1 EVL Held PJSM, discussed job outline and environmental issues. 16:30 - 16:45 0.25 WORK SLIK IN1 EVL MU tool string with dd bailer, oil jars, spangs, 1.5" tool string. PT lubricator to 1500 psig. Good test. 16:45 - 17:00 0.25 WORK SLIK IN1EVL Open well, WHP= 500 psig. RIH tagged fill at 6300' KBD. POOH with tool string. OOH with tool string. Bailer full of frac sand, mud, slit, coal and fluid. 17:00 - 17:45 0.75 RURD_ SLIK IN1EVL Close well, RD wire line equipment. Pollard left lease. 9/26/2007 07:30 - 08:30 1.00 SAFETY MTG_ CLNOUT Held PJSM, discussed job outline and environmental issues. Obtain Hot work permit. Printed: 10/31/2007 6:44:18 AM • • Marathon Oil Company Operations Summary Report Page3of3~ Legal Well Name: KENAI BELUGA UNIT 42-7 Common Well Name: KENAI BELUGA UNIT 42-7 Spud Date: 1/19/2001 Event Name: WORKOVER Start: 9/20/2007 End: 9/22/2007 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Code Phase Description of Operations 9/26/2007 08:30 - 09:00 0.50 RURD COIL CLNOUT Start equipment. Blow down well (900 psi) to gas buster. Add 09:00 - 09:30 I 0.501 RURD I COIL 09:30 - 09:45 0.25 ~ RURD_ COIL 09:45 - 10:15 0.50 RURD COIL 10:15 - 10:35 0.33 TEST_ EOIP 10:35 - 12:00 1.42 RUNPU COIL 12:00 - 12:20 0.33 RUNPU COIL 12:20 - 12:50 0.50 RUNPU COIL 12:50 - 12:55 0.08 ~ RUNPUL COIL 12:55 - 13:02 0.12 RUNPU COIL 13:02 - 13:45 0.72 RUNPU COIL 13:45 - 14:02 0.28 RUNPU COIL 14:02 - 14:05 0.05 RUNPU COIL 14:05 - 15:10 1.08 RUNPU COIL 15:10 - 15:40 0.50 RURD COIL 15:40 - 16:20 I 0.671 RURD I COIL 16:20 - 16:30 0.17 RURD_ COIL 16:30 - 17:30 1.00 RURD COIL 17:30 - 18:00 0.50 RURD_ COIL 18:00 - 18:30 0.50 RURD COIL FRW-14 friction reducer to 6% KCL water. CLNOUT MU BHA consisting of 1.75" dimple on connecter, Dual Float Check valve, Ball Operated Shear Sub., 1-3/4" X 2-1/8" XO, Down hole filter, 2-1/8" Vortex nozzle. CLNOUT Lift injecter to WH. Install walking dogs. Prime up DH pump. Tank straps: 2" mud in flowback tank, Supply tank approx 450 bbls. CLNOUT Begin pumping KCL water to fill coil. 10:05 am. Call Jim Regg with AOGCC for 24 hour advanced notice of BOP test for CLU 1. Mr. Regg waived witness. Requested follow up BOP Test Report as is required. CLNOUT Pump 27 bbls. to load coil. Test Bowens to 2500 psi. Test good CLNOUT Start RIH w/ coil. Pumping mininimum rate. CLNOUT RIH @ 5400' Pumping min rate. Sporatic returns. CLNOUT Tag up @ 6300'. Increase rate to 1.9 bpm @ 3500 psi. to begin circulating out fill. PIP 3500 psi, WHP 33 psi., Tubing rate 10 fpm. Muddy returns. CLNOUT Tubing @ 6600' CTM. PIP 3700 psi, 1.85 bpm., WHP 26 psi, Tubing rate 10 fpm. chocolate colored returns. CLNOUT 6650 CTM. returns clearing up. PIP 3960 psi. 1.85 bpm. CLNOUT Tag up on CIBP @ 6703' CTM. Returns muddy again. CLNOUT 100 bbls in the return tank. Washing pert interval. CLNOUT 5750' CTM. PIP 3900 psi. 1.86 bpm. WHP 26 psi. Returns clear. CLNOUT POOH. Reduce pump rate to 3/4 bpm. PIP 800 psi. WHP 0. CLNOUT OOH. Close swab and master valves. Release pressure on tubing. Prepare to blow down coil with N2. CLNOUT Coil blown down. Drain high pressure lines w/ vac truck. Knock out hard lines. CLNOUT Lift injector head off well head. CLNOUT Rack up iron and equipment. Lift BOP's from WH. Install tree cap and secure well. CLNOUT Load BOP and iron racks. Set gas buster on ground. CLNOUT PU duck ponds. Turn in permit. Leave location. Printetl: 1U/3V2007 6:44:75 AM . . ~V~1TŒ (ffi~ ~~fÆ~[K(fÆ / AI,ASIi& OIL A5D GAS / CONSERVATION COMMISSION / Î SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Wayne Cissell Work Over Supervisor Marathon Oil Company PO Box 1949 Kenai, AK 99611-1949 ( q~o'¡; \. . .. .,~ .... .. , ,.'..' Re: Kenai Gas Field, Beluga Gas Pool, Kenai Beluga Unit 42-7 Sundry Number: 307 -294 Dear Mr. Cissell: It~.'f.""h\/\.\MED'" SEP 2 7 Z007 \:!iUJ'\\~'eI'!- Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. £u' ~ John K. Norman ~ ~ 0 Chairman DATED thi~ ~ay of September, 2007 Encl. . . Marathon Oil Company Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone (907) 283-1371 Fax (907) 283-1350 September 19, 2007 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 RECEIVED SEP 2 0 2007 Alaska Oil & Gas Cons. Commission Anchorage Reference: 10-403 Sundry Application Field: Kenai Gas Field Well: KBU 42-7 Dear Mr. Maunder Enclosed please find the Coil Tubing procedure, form 10-403 and the associated attachments. The fill in the well bore will be cleaned out below the perforations at 6,746'. A 2.5" Owen Cast Iron Bridge plug will be set at 6,720' to isolate the lower zones. After the well is cleaned out and the plug set the well will be nitrogen lifted with assistance from the reservoir. This will cause the need to vent natural gas intermittently to a choke assisted flow back tank. Our expected gas venting should be no more than three days at less than 2.0 MMCFPD rate. Attachments include a well bore schematic, proposed well bore schematic, 10-403 Sundry form, and work scope procedure. It is my understanding that verbal approval has been given by Commissioner Forester so we can proceed with the Coil tubing work. The 10-403 is attached to cover the Sundry requirement out lined in the e-mail confirming the verbal approval. Should you require further information, I can be reached at 907-283-1308 or bye-mail at wecissell@MarathonOil.com. Sincerely, Wayn Cissell Work Over Supervisor Enclosures: 10-403 Sundry Well bore schematic Proposed Well bore schematic Procedure Summary cc: AOGCC Houston Well Files Kenai Well Files WEC KJS c\KBU 42-7 AOGCC cover letter cleanout.doc . . $:¡ R.ECEIVED ()\\"I\ STATE OF ALASKA Øt. . ~~ ~\'Q ALASKA OIL AND GAS CONSERVATION COMMISSION .........G{SE.·P 2 0 2007 ~ f. .... .)..~ ~rI rfI APPLICATION FOR SUNDRY APPROVAL~¡_ _.,1.. 11"! P. G C "'I., 20 MC 25.280 . ,.'1,\"" (,)1 lJ!. as on. om Issmn 1. Type of Request: Abandon D Suspend D Operational shutdown D Perforate D Waivé'f[g1°rage Other 0 Alter casing D Repair well D Plug Perforations D Stimulate D Time Extension D Install bridge Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D plug & vent gas 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: Development 0/ Exploratory D 199-025 .-- 3. Address: Stratigraphic D Service D 6. API Number: - PO Box 1949, Kenai Alaska, 99611-1949 50-133-20488-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Kenai Beluga Unit 42-7 " Spacing Exception Required? Yes D No 0 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): A - 028142 - 87' (21' AGL) - Kenai Gas Field I Beluga Pool / 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7,570' ; 7,309' , 7,453' 7,192' NA 7,420' Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 20" 117' 117' 3,060 psi 1,500 psi Surface 1,099' 13-3/8 " 1,099' 1,093 3,450 psi 1,950 psi Surface 651' 13-3/8 " 1,750' 1,732' 5,380 psi 2,670 psi Intermediate 5,582' 9-5/8" 5,582' 5,322' 5,750 psi 3,090 psi Production 7,518' 3-1/2" 7,518 7,257 10,160 psi 10,530 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5,636'-7,409' (Gross) 5,376'-7,148' (Gross) 3-1/2" L-80 7,453' Packers and SSSV Type: Packers and SSSV MD (ft): NA NA 13. Attachments: Description Summary of Proposal 0 14, Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development 0 Service D 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 9/19/2007 Oil D Gas 0 Plugged D Abandoned D 17. Verbal Approval: Date: 9/7/2007 WAG D GINJ D WINJ D WDSPL D Commission Representative: Tom Maunder 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283·1371 Printed Name A\~Wayne E. Cissell Title Work Over Supervisor Signature ~~AJ ~ ill i1 1)"0 P {)Phone (907) 283-1308 Date 9/19/2007 , I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: & 1 - ,çq 4 Plug Integrity D BOP Test [it Mechanical Integrity Test D Location Clearance D Other: í1. ç 00 '. \1 ü P -\-t \-- ç \"..::J '., ~7 \ - ~ ~ . û.,., Subsequent Form Required: 4 () ~ RBDMS 8Ft SEP 2 5 2D07 A.- ~~k:N~~ APPROVED BY Approvea<&:' ~1"T..1-'"7 -~ COMMISSIONER THE COMMISSION Date: Q'Zt/07 - _._ .. II. -' Form 10-403 Revised 06/2006 LJ K IlJ II\J A L ~~ b in Duplicate ~~~ Tree cxn '" 3-1/2" EUE 8rd Promore downhole sensor @ 5549' MD (5289' TVD) wi 7/16" electric cable (dual-armored, 7-strand conductor) to surface two 1 OK pressure sensors one temperature sensor PL T on e-line - WL tag: 6960' KB (1/23/03) 6464' KB (12/7103) Coil cleaned outto 7420' CTM, (11/4/2001 ) Well Name & Number: County or Parish: ations (MO) : KBU 42-7 Kenai Peninsula Dated Complèted: Prepared by: 211412001 Kevin Skiba PBTO - 7,453' TO - 7,570' Lease: State: Alaska (TVO): 20" 1(,55 133 !,pf !!;æ MD 0' TVO 0' 111' Surface Casin¡:¡ 13-318" 58 ppf !!;æ ~ 1<-55 MO 0' 1,099' TVO O' 1,093' L-BO i'IID 1,099' 1,750' TVD i,OS3' 1,732' BTe @ 1,750' MD Gmt wi 734 sacks class G L-80 40 ¡¡pf !!;æ Bottom MO 0' 5,582' TVO 0' 5,322' BTC MO Cm! wi 654 sacks of class G 9.3 ppf EUE 8rd wi!h 5.25" 00 Cm! wi 875 sacks of class G Last Reviso 911812007 Tree cxn 3-1/2" EUE 8rd TVD) wi 7/16" electric cable (dual-armored, 7-strand conductor) to surface two 1 OK pressure sensors one temperature sensor PL T on e-line - WL tag: Coil cleaned out to 7420' CTM, (11/4/2001 ) Well Name & Number: County or Parish: Perforations KBU 42-7 Kenai Peninsula 211412001 Kevin Skiba 20' 1{-55 133 ppf I.2I2 MO 0' TVO 0' 117' 13-318" 6S ppf I.2I2 K-55 MO ()' TVO 0' L-80 MO 1,099' TVD 1,093' aTC@ 1,750' Cm! wi 734 sacks class G 41! ppf 0' 5,322' STC @ 5,582' MD EUE lire! slotted coupJings tQ 7,518' Cm! wi 875 sJ!cks of cla$$ G 9/1912007 (fIJ. ') . . Marathon Oil Company Alaska Region Well KBU- 42-7 Kenai Gas Field, Pad 41-7 Coil Tubing Cleanout and plug setting Procedure WBS # WO.07.16138.EXP OBJECTIVE: Clean out fill down to or below Module #5. After clean out of well. Stand back coil tubing and rig up Expro America E-line services to set 2.5" cast iron bridge plug @ 6720'. POOH. Flow the well unassisted to flow back tank. Ifwell will not unload, run in hole with coil, unload well with Nitrogen and produce well to sales. Tree flange is 4 o/.¡" Otis tree connection, 5 M. Tubing ID is 2.992" and tubular capacity is 0.0087 BBL/FT. HISTORY: Well KBU 42-6 - the well was fracture stimulated in 15 zones from 5,636' to 7,409'. The well produced to sales at 4-4.5 MMSCFD until it started flowing mud and sand up to the production flow lines and equipment. The well was cleaned out on 2-17-2007 and produced around 2.5 MMCFPD at 500 psig, 150 bbls of H20 per day. The well has been shut in most of the time since the cleanout because of produced mud and sand. On 09/13/2007 wire line tagged fill between modules#14 and #15 at 5712' KBD with a 2.65" GR. PROCEDURE 1. Perform joint safety and environmental meeting with all personnel involved in well work, obtain work permit for work to be performed on well. 2. Deliver and fill Rain-for-Rent tank with about 500 bbls. 6% KCL water. ASRC to lay liner and berm under flow back tank, choke skid, and around wellhead. 3. Notify the AOGCC, James Reggs of BOP Test schedule. 4. MIRU BJ CoilTech Services with 1.75 inch coil tubing, BOPE stack, and Nitrogen pump. a. NU BJ Services 3-1116" 10K flange to the top ofthe tree. Install BJ flow cross to top of3-1I16", 10K flange. Connect BJ pump suction line to 500 bbl. Rain-for Rent water tank. b. RU MOC flow back equipment including flow back tank with gas buster, choke skid, chicksan. MU chicksan connections between BJ flow cross and choke skid. MU BJ pump line connection to flow cross. . . c. Have Peck crane pick up BJ coil tubing BOP. Flange up BOP to top of flow cross. Install coil tubing in injector head. MU and pull test coil tubing connector suited for coil tubing wall thickness. Pick up injector head and lubricator with crane. Make PU test between checks and hydraulic disconnect. d. Make up CT injector head and lubricator to BOP's. Displace coil tubing with 6 % KCL water. e. Pressure test BJ Services pump lines to 4500 psi. Pressure test CT BOP pipe and blind rams, test tree, and production string with 6 % KCL water to 250/4500 psi max pressure. Pressure test Well Tester's lines to 250/4500 psi with 6% KCL water using BJ pump 5. Open well and RIH with coil tubing and pump in nozzle circulating 6% KCL water through nozzle at 0.5 BPM to flowback tank. RIH and cleanout fill. Note: (wire line tagged fill between modules #14 & #15 @ 5712' KBD). Iflose fluid returns or have partial returns, start pumping nitrogen up to 30% by volume with the KCL water for a total rate through the nozzle at 1.3 BPM or recommended rate ITom BJ CT operator. Clean well bore down to the top of Module #5 @ 6756' KBD. PUH 10' and circulate 1-112 bottoms up or until returns are clean. POOH circulating at minimum rate with 6% KCL water. Stop pumping water about 300' from surface. When coil out of well SWI and displace water in CT to flow back tank with nitrogen. Bleed off pressure and LD CT and BHA. 6. Stand back BJ Coiltech. 7. MIRU Expro wire line Unit with 0.125" OD wire to run 2.5" Cast Iron Bridge plug at a setting depth above Module #5, set plug @ 6720' at joint #19.. a. Hold pre-job safety and environmental awareness meeting. b. PU tool string consisting of CCL, weight bars, baker setting tool, Owen 2.5" cast iron bridge plug. Note: prior to arming setting tool go to communication black out on pad. c. Ann setting tool. Install lubricator. Pressure the test lubricator to 2,500 psig with test pump using 50/50 methanol. Bleed back fluid to returns tank, open well and drop methanol into well bore. d. Open well. e. RIH, correlate to setting depth, set plug at 6720'. f. PU hole 50', RIH tag top of plug to verify setting depth. . . g. POOH h. RDMO Expro Wireline. 8. Have operators flow well to production prior to rigging down coil unit. Ifwell will not flow plan to pickup the coil. RIH with I %" coil and jet well dry to flow back tank with Nitrogen.. 9. POOH with coil. 1 O. RD coil unit, clean up around well head. KBU 42-7: PTD #199-025 . . Page 1 of2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, September 07,20077:58 AM To: Walsh, Ken Subject: RE: KBU 42-7: PTD #199-025 Ken, Yes and Yes. You have approval to proceed, however a sundry is needed. The situation with regard to when you need to file and not file a sundry is at best confusing right now. There are 5 stated "work types" in 25.280. The matrix you have seen provides some detail regarding actual operations. The matrix was developed to guide paperwork flow for the pools where an exemption to submitting sundries has been granted. No order has been issued granting Marathon relief, in fact some time ago when Marathon applied for relief it was specifically denied. As I wrote yesterday, I think it best to discuss the matter and get a protocol/process sorted out. Call or message with any questions. Tom Maunder, PE AOGCC From: Walsh, Ken [mailto:kdwalsh@marathonoil.com] sent: Friday, September 07,20077:25 AM To: Maunder, Thomas E (DOA) SUbject: RE: KBU 42-7: Pro #199-025 Tom, Are you saying that Marathon has verbal approval to proceed with the work but we need to follow-up with a 403 sundry? Is the sundry required just because of the possible methane venting? We have not been required in the past to file the sundry to cIeanout fill or set a temporary plug for diagnosis purposes. %en Ken D. Walsh Senior Production Engineer Marathon Oil Company-Alaska Asset Team 907-283-1311 (office) 907 -394-3060 (cell) .------- _____~_N From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] sent: Thursday, September 06, 2007 4:53 PM To: Walsh, Ken SUbject: RE: KBU 42-7: Pro #199-025 Ken, I have spoken with Commissioner Foerster. She has indicated that you may proceed with the work planned for KBU 42-7, however a sundry should be prepared and submitted. You should describe all the possible work including the bridge plug, cleanout, vent, etc. Although the enforcement matter is still to be resolved, I think the possibility of scheduling meeting separate from that process should be considered. There is value in my time and Marathon's in reducing the paperwork exchange where possible. Absent some "agreement", I see the default 9/24/2007 KBU 42-7: PTD #199-025 . . Page 2 of2 situation being that sundries should be submitted. Speak with Lyndon and lets talk tomorrow. Tom Maunder, PE AOGCC -~,-- From: Walsh, Ken [mailto:kdwalsh@marathonoil.com] Sent: Thursday, September 06,20073:50 PM To: Maunder, Thomas E (DOA) Cc: Ibele, Lyndon; Cissell, Wayne E.; Donovan Jr, Dennis M.; Grant, Patrick; Mullin, Mickey; Rang, Craig L.; Skiba, Kevin J.; Sulley, Michael; Walsh, Ken Subject: KBU 42-7: PTD #199-025 Tom, KBU 42-7 is an EXCAPE (casing-conveyed perforating) well that was completed in 2001. This well has been shut in since February 2007 after three separate attempts to clean out Carbolite proppant sand bridges with coiled tubing. Marathon believes that the source of the proppant flowback is below our Module #5 perfs at 6746-6756' KB. We wish to set a cast iron bridge plug above this interval to shut off the proppant flow and return the well to production. From our telephone conversation this afternoon, it is understood that Marathon would not be required to file a Form 10-403 sundry request to perform this work. We did not specifically discuss the possibility of having to clean out the proppant fill one more time with coiled tubing to clear the way for the bridge plug, if a slickline tag deems that this would be appropriate. I ask that Marathon only file a Form 10-404 for this work and that the AOGCC grants approval to begin this work immediately. Best Regards, %en Ken D. Walsh Senior Production Engineer Marathon Oil Company-Alaska Asset Team 907-283-1311 (office) 907 -394-3060 (cell) «kbu42-7.xls» 9/24/2007 • • Marathon Oil Company Marathon Alaska Asset Team P.O. Box 1949 MARATHON ~~~ ~ampany Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 September 18, 2007 ~'~~ Mr. Tom Maunder ~ ~. ~' 2 0 2007 Alaska Oil & Gas Conservation Commission 333 W 7th Ave laslca Oil ~ Gas Ctan~. Ccrmmissiort Anchorage, Alaska 99501 ~~~~~~~' Reference: 10-404 Report of Sundry Well Operations -Add Perforations -Sundry #304-018 Field: Kenai Gas Field, Pad 41-7 Well: Kenai Beluga Unit 42-7 (PTD- 199-025) Dear Mr. Maunder: Enclosed is the 10-404's for sundry 304-018. This Sundry reports that we did not add perforations in this wellbore. This should be reported as Non-Work. Attached with the 10-404 is the current wellbore diagram. Please send any sundries or pertinent documentation to Kevin Skiba at the above address listed. If you have any questions or need further information please call me at (907) 398-1362. Dennis Donovan Production Engineer Enclosures: 10-404 Sundry of Well Ops 304-018 cc: AOGCC Current Well Schematic Houston Well File Kenai Well File DMD KJS 1S V~v, h~ 9v3~,9~ • STATE OF ALASKA ~~P ~ ~ ZQ~7 ALASKA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPE~AkTDGD~is ~s~sis. Cttmmis~ion Ararl~r3r~r~ 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ NO WORK Pertormed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Did NOT Add Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ PerFs 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development ~ Exploratory^ 199-025 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO BOX 1949, Kenai, AK 99611 50-133-20488-00-00 7. KB Elevation (ft): 9. Well Name and Number: 87' 21' KB Kenai Belu a Unit 42-7 8. Property Designation: 10. FieldlPool(s): 37' FNL, 4118 FWL, Sec 7, T4N, R11W S.M. Kenai Gas Field, Belu a Pool 11. Present Well Condition Summary: Total Depth measured 7570 feet Plugs (measured) true vertical 7309 feet Junk (measured) 7420' Effective Depth measured 7453 feet true vertical 7192 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 20" K55 117' 117' 3060 1500 Surface 1750' 13-318" K55/L80 1750' 1732' 3450/5380 1950/2670 Intermediate 5582' 9-518" L80 6582' 6322' 5750 3090 Production 7518' 3-1/2" L80 7518 7257' 10160 10530 Liner 5636-46', 5737-47', 5805-15', 5863-73', 5941'-51', 6123-33', 6271-81', 6366-76', Perforation depth: Measured depth: 6500-10', 6612-22', 6747-57', 6945-55', 7153-63', 7320-30', 7400-10' 5375-85', 5476-86', 5544-54', 5602-12', 5680-90', 5862-72', 6010-20', 6105-15' True Vertical depth: 6239-49', 6351-61', 6485-95', 6682-92', 6893-03', 7059-69', 7139-49' Tubing: (size, grade, and measured depth) 3-112" 9.3# L-80 7453' Packers and SSSV (type and measured depth) N/A and N/A 12. Stimulation or cement squeeze summary: Interva{s treated (measured): N/A (~ ~* ®~~ ~~~ ~ g ~OD~ ~7 I~ Treatment descriptions including volumes used and final pressure: N!A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A N/A N/A 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ^ Development 0 Service ^ Daily Report of Well Operations NONE (Did not Add Perfs) 16. Well Status after work: Oil ^ Gas ^ WAG ^ GINJ ^ WiNJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 304-018 Contact Kevin Skiba Printed Name Dennis M D novan Title Production Engineer I ~ (907)-283-1333 W Signature ._ _ ~ Phone (907)-398-1362 C Date 18-Sep-07 Form 10-404 Revised 04/2006 (3'w i~~~`~Original Only ORIGINAL ~_ • is 50-133-20488-00-00 e Des: A - 028142 21' AGL (87' KB Elevation) I Date: 1 /19/2001 teleased: 2/14/2001 KBU 42-7 Pad 41-7 37' FNL, 4,118' FWL Sec. 7, T4N, R11W, S.M. • Ma~rroM Drive Pioe 20" K-55 133 ppf Tom Bottom MD 0' 117' TVD 0' 117' Surface Casino 13-318" 88 ppf Tom Bottom K-55 MD 0' 1,099' TVD 0' 1,093' L-80 MD 1,099' 1,750' TVD 1,093' 1,732' BTC @ 1,7 50' MD Cmt wl 734 sacks class G Intermediate Casino 9-5/8" L-80 40 ppf TSp Bottom MD 0' 5,582' ND 0' 5,322' BTC Q 5,582' MD Cmt wl 654 sacks of class G Production Tubing 3-112" L-80 9.3 ppf EUE 8rd with 5.25" OD slotted couplings to 7,518' Cmt wl 875 sacks of class G Excape System Details - 15 Excape modules placed - Both control lines now open for methanol injection (8/30/01) - All ceramic flappers milled out with coil. Perfs: Module 15 - 5636' - 5646' (frac'd 8/30/01) Module 14 - 5737' - 5747' (frac'd 8/30101) Module 13 - 5805' - 5815' (frac'd 8/30/01) Module 12 - 5863' - 5873' (frac'd 8/5/01) Module 11 - 5941' - 5951' (perfed 8/5/01) Module 10 - 6123' - 6133' (perfed 8/4/01) Module 9 - 6271' - 6281' (perfed 8/4!01) Module 8 - 6366' - 6376' (frac'd 8/4101) Module 7 - 6499' - 6509' (frac'd 6/3/01) Module 6 - 6611' - 6621' (frac'd 6/3101) Module 5 - 6746' - 6756' (frac'd 6/3/01) Module 4 - 6943' - 6953' (perfed 6/1/01) Module 3 - 7153' - 7163' (frac'd 6/1/01) Module 2 - 7319' - 7329' (perfed 6/1/01 } Module 1 - 7399' - 7409' (perfed 3/11/01) All frac'd zones were treated with 16/20 Carbolite in diesel-based Super Rheogel frac fluid. Well Name & Number: KBU 42-7 Lease: Kenai Gas Field County or Parish: Kenai Peninsula State: Alaska Country: USA Perforations (MD) : (TVD)~ Angle/Perfs: Angle @ KOP and Depth: Dated Completed: 2114!2001 Prepared by: Kevin Skiba Last Revison Date: 911 812 0 0 7 • • Marathon MARATHON O[ Company September 18, 2007 ~ ~ - Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 N_. .~~ Noa~ ~ ~` ~°~7 Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 t~3:F~ '~~P ~ U 2007 ~'ti~~s~~ Oi! Gay ~ean~rt C~rrlmissi~~ ~:r~w~~ Reference: 10-404 Report of Sundry Well Operations - Cleanout with Coil Tubing - Sundry #301-296 ~ ,~,~..; Field: Kenai Gas Field, Pad 41-7 Well: Kenai Beluga Unit 42-7 (PTD- 199-025) Dear Mr. Maunder: Enclosed is the 10-404's for sundry 301-296. This Sundry reports the milling of a composite bridge plug set at 5820' KB. The well operation successfully milled the plug down to 7420' KB and then jetted the well with N2. Attached with the 10-404 are operations summary reports for the work that was completed and a current wellbore diagram. Please send any sundries or pertinent documentation to Kevin Skiba at the above address listed. If you have any questions or need further information please call me at (907) 398-1362. Sincerely, Dennis Donovan Production Engineer Enclosures: 10-404 Sundry of Well Ops 301-296 cc: AOGCC Operations Summary Report 10/19/01 .Houston Well File Current Well Schematic Kenai Well File DMD KJS ~~~ STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMISSION SEP REPORT OF SUNDRY WELL OPERATIONS ~ ®2007 Alaska Oil ~ 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ~~ eanout with Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ Coil Tubin 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development ^~ Exploratory^ 199-025 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO BOX 1949, Kenai, AK 99611 50-133-20488-00-00 7. KB Elevation (ft): 9. Well Name and Number: 87' 21' KB Kenai Belu a Unit 42-7 8. Property Designation: " 10. Field/Pool(s): ~r„`w ~ ~+~-~~~~ ~~' 3T FNL, 4118 FWL, Sec 7, T4N, R11W S.M. Kenai Gas Field, B Pool 11. Present Well Condition Summary: Total Depth measured 7570 feet Plugs (measured) true vertical 7309 feet Junk (measured) 7420' Effective Depth measured 7453 feet true vertical 7192 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 20" K55 117' 117' 3060 1500 Surtace 1750' 13-3/8" K55/L80 1750' 1732' 3450/5380 1950/2670 Intermediate 5582' 9-5/8" L80 6582' 6322' 5750 3090 Production 7518' 3-1/2" L80 7518 7257' 10160 10530 Liner 5636-46', 5737-47', 5805-15', 5863-73', 5941'-51', 6123-33', 6271-81', 6366-76', Perforation depth: Measured depth: 6500-10', 6612-22', 6747-57', 6945-55', 7153-63', 7320-30', 7400-10' 5375-85', 5476-86', 5544-54', 5602-12', 5680-90', 5862-72', 6010-20', 6105-15' True Vertical depth: 6239-49', 6351-61', 6485-95', 6682-92', 6893-03', 7059-69', 7139-49' Tubing: (size, grade, and measured depth) 3-1/2" 9.3# L-80 7453' Packers and SSSV (type and measured depth) N/A and N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A ~~ - ~~~ ~~P 2 g 2~~7 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2600 0 0 1450 Subsequent to operation: 0 5200 71 0 1450 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ^ Development Q Service ^ Daily Report of Well Operations Included 16. Well Status after work: Oil ^ Gas ~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 301-296 Contact Kevin Skiba Printed Name , Dennis M Don an Title Production Engineer I (907)-283-1333 W a ~ ~°~ ~ ~ ~ (907)-398-1362 C Si t ~~~ ~ , gna ure ~, ~ a Phone Date 18-Sep-07 Form 10-404 Revised 04/2006 ~ R ~ G i N A L ~~i ~` ~ i~nal Only ~ ,~` t. ~-`~ • MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 10/19/2001 FIELD: Kenai Gas Field WELL #: KBU 42-7 FILL DEPTH/DATE: TUBING: 3 1/2" CASING: 9 5/8" DATE LAST WL WORK: TREE CONDITION: Good 3 1/2" 8rd WORK DONE: BENCHES OPEN: PRESENT OPERATION: Clean out with coil WIRELINE CREW: OTHER: Hrs. SUMMARY OF OPERATIONS 1-3l4" BJ coil tubing unit and nitrogen. Test BOPE to 250/3000 psi using 3% KCI water. Held safety and operations meeting. 51TP =1900 psi. Attempt to bleed off wellhead pressure to open top tank, but choke is froze up. Aiso, coil is tagging up in the swab valve (ice?), and master valves are partially frozen. Circulate water through choke and past swab valve, remove ice plugs. Bullhead 20 bbl of 3% KCI water down the tubing and RIH with coil. Pumping at 0.5 bpm while RIH. At about 1000' open up the backside to establish circulation, but having much difficuly controlling we11 with the choke. Shut in returns to inspect choke while continuing to R1H. Choke is wiped out, and unable to find a ready replacement. Had coil POOH from 4000', blow reel dry, and secure well. SDFN. DAILY COST: CUM: REPORTED BY: Gary Eller .] MARATHON OIL COMPANY DATE: 10122/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: DAILY WELL OPERATIONS REPORT FIELD: Kenai Gas Field TUBING: 31/2" Clean out with coil PAGE 1 OF 1 WELL #: KBU 42-7 CASING: 9 5/8" TREE CONDITION: Good 3 1/2" 8rd BENCHES OPEN: WIRELINE CREW: Hrs. SUMMARY OF OPERATIONS 1330 1830 2030 2330 MIRU Steam-on-Wheels to thaw out tree and heat up KCI water. Tree valves operating freely after heating operation. RU 1-3/4" BJ coil tubing unit and nitrogen. Jug test lubricator and returns line to 5000 psi using 3% KCI water. Held onsite safety and operations meeting. Tool string has 2.58" 3-blade junk mill, 2.82" tapered string mill, 2-1l8" Mach-1 motor, BJ phase seperator, filter, ciculating sub, hydraulic diconnect, and check valve. TP = 2000 psi. RIH without circulating to 5600'. Establish circulation at 1.1 bpm and 600 SCFM per phase seperator recommendation. RIH. Tag composite bridge plug. at 5810' CTM. Attempt drill up bridge plug for the next hour or more, but unable to drill through. With nitrogen and phase Aerator tool it is difficult to determine when we reach stall out. POOH to swap tool .string. k mill and string mill look unworn. Lay down phase separator, change out motors for one that will ept nitrogen. RIH. Establish circulation at 1.0 bpm at 5600'. RIH, tag up at 5646' CTM in the city of the#15 flapper. Work past and continue in hole, No trouble at the #14 flapper, RIH. ~en-e slight obstruction at the #13 flapper at 5805' CTM. Tag up on composite plug at 5820' JI. Mill on the plug for about 20 minutes, then break through for about 3'. Work mill at 5823' v(, but unable to get any deeper. It appears that the string mill is unable to pass by the area .re the composite plug was set. PU to 5600' while circulating. Drop a 0.5" ball to open the circulating sub. Circulate sufficient nitrogen to purge reel. POOH. Finish purging lines and tree. RD coil, discover that junk mill had backed off. SDFN. Note: In the morning, plan to pick up a coil tubing overshot and jars to fish the mill and crossover. Detail offish faxed to Anchorage office and Baker Oil Tooi. Length of fish = 10.8'75", fishing neck OD = 2.23", mill OD (max) = 2.58". Vendor Equipment Daily Cosi Cumulative Cost Steam-on-Wheels steam Veco crane, vac truck BJ Coiltech coil tubing, pump Baker Oil Tools motor, mills Other DAILY COST: CUM: REPORTED BY: Gary Eller MARATHON OIL COMPANY DATE: 10/24J2001 FILL DEPTH/DATE: DATE LAST W L W ORK: WORK DONE: • DAILY WELL OPERATIONS REPORT FIELD: Kenai Gas Field TUBING: 3112" CASING: TREE CONDITION BENCHES OPEN: PAGE 1 OF 1 WELL #: KBU 42-7 9 SJS" Good 3 1J2" 8rd PRESENT OPERATION: Fish 2.58" junk mill WIRELINE CREW: OTHER: Hrs. SUMMARY OF OPERATIONS 1100 1530 1800 1930 0130 0300 Get fishing tools shipped in from Baker Oil Tool shop on N. Slope. Pick up fishing tools at airport, make modifications to overshot at machine shop. Tools arrive on location. MU toolstring with a 2.84" OD overshot with spiral grapple, hydraulic disconnect, and Bowen hydraulic jars. Pressure test lubricator #0 3000 psi. Held safety meeting. SITP = 2000 psi. RIH with fishing string on 1.75" coil tubing. Note some fluctuations on the weight indicator around the #15 and #14 flapper assemblies {5626' & 5727' CTM) but able to get past without difficulty. Stop at 5775' CTM, circulate 60 bbl of 3% KCI to load the hole. Establish circulating pressure of 785 psi at 1.0 bpm after hole is fully loaded. Shut down pumps and close in returns RIH. Set down at 5799' CTM, which corresponds to the top of the fish compared to where the flapper assemblies were noted. Set overshot down on top of fish with 6000 to 8000 Ibs several times. After each time, PU 15' without noting any additional weight or drag. PU to 5775' CTM again and attempt to re-establish circulation at 1.0 bpm. Pumped total of 5 bbl and pump pressure increased to 850 psi without getting any returns, so ii appears we have our fish. Shut down pumps, POOH. Inspect overshot - no recovery. No wear marks inside overshot. Circulate through the coil to the pits with the swab valve closed at 850 psi at 1.0 bpm. RIH to 5775' CTM. Circulate at 1.0 bpm to reload the hole. Reduce rate to 0.5 bpm, RIH. Tag bottom at 5820' CTM this time. Continue circulating at 0.5 bpm while stacking out on fish. Hit fish with several downward jar licks, and each time pump pressure would increase from 70 psi to 300 psi. But every time we picked up, the pump pressure returned to 7D psi. After about 10 downward licks, began having trouble getting the jars to fire. Shut off pumps and closed off returns, continued trying to jar down. Occasionally getting jars to fire bui not regularly. Decide to POOH. Begin to POOH, but we're stuck! Pull 16K to 18K over string weight, unable to move. Work pipe, but can't get jars to fire. Resume pumping at 0.5 bpm, and as soon as we achieved circulation we came loose. Slopped pumping, closed returns, POOH. Inspect overshot - no recovery. Marks inside of overshot show that fish made it inside about 2" to the retainer ring on the grapple, but not into the grapple itself. Blow reel dry, secure well, SDFN. Vendor Equipment Daily Cost Cumulative Cost Steam-on-Wheels steam Veco crane, vac truck BJ Coiltech coil tubin ump Baker Oil Tools motor, mills Other DAILY COST: CUM; REPORTED BY: Gary Eller MARATHON OIL COMPANY DATE: 10/26/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: • DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 FIELD: Kenai Gas Field WELL #: KBU -42-7 TUBING: 3 1.12" CASING: 9 518 " TREE CONDITION: Good BENCHES OPEN: PRESENT OPERATION: Mill out bridge plug WIRELINE CREW: OTHER: TIME: SUMMARY OF OPERATIONS 10700 11500 11530 1730 11800 2000 12230 RU CT unit. Held safety and environmental meeting. Discussed procedure with crew. Problem with freezing across the tree and blow down lines. Had to get steam on wheels out to thaw out lines. PT lines to 3000 psig prior to running in hole with CT. RIH with 1 314" CT with Cut lip guide with screw-in sub, motor, check and crossover. PIP=34, WHP = 127, ct at 5798' Liquid retums to tank. At 5800' start pumping at .5 BPM, PIP increased to 173 psig. WHP=83 psig, returns to tank.. RIH with CT to 5811', PIP = 830 psig, PUH to 5803' RIH to 5811' PIP=244 psig, .5 BPM. WHP = 100 psig. Pumped a total of 81 bbls. PIP = 1450 psig. CT @ 5812' PU hole to 5798'. Shut down pumping to see if pressure falls off on PIP. Pressure dropped to 85 psig, WHP=78 psig, CT at 5798'. RIH with CT Increase PIR to 1 BPM. PIP increased to 2365 psig., WHP=97 psig. CT @ 5812'. Sat down on fish. PIP = 2970 psig. WHP =97 psig., Shut down pumping. appears pressure higher while pumping down coil . POOH with CT. with CT, Blow down tree, Recovered fish. RIH with mill, motor, and rest of BHA, When CT at 5797' PIP=1050 psig, WHP= 429 psig, pumping at 1 BPM. Tag bridge plug @ 5812.12', PIP = 1084 psig, WHP=400 psig. Continue to work CT up and down on top of bridge plug. Increased Pump in rate from 1.0 BPM to 1.5 BPM. monitored returns to tank during Pump in process to try and mill through the bridge plug. Tried to stall motor but could not get the motor to stall. PUH to 50' 5760' RIH @ 1.50 BPM, PIP = 2000 psig, WHP= 78 psig, Tried to stall the motor but could no# get it to stall. Not making much progress milling the plug. POOH with CT to check the bit to verify that the motor is still working properly. OOH with CT, verified the bit turned at surface. No wear on the face of the bit. The sides are polished smooth but not tear marks on sides. Does not appear that the bit is making contact with the bridge plug. Will change out the motor and RIH tomorrow. BJ DAILY COST: CUM: REPORTED BY: Wayne Cissell • • MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 1012912001 FIELD: FILL DEPTH/DATE: TUBING: DATE LAST WL WORK: WORK DONE: Kenai Gas Field 31/2" CASING: TREE CONDITION: BENCHES OPEN: Good PRESENT OPERATION: Mill out bridge plug WIRELIKE CREW: OTHER: TIME: SUMMARY OF OPERATIONS 10900 11715 11810 1850 1950 2100 2400 10!30 0100 0200 RU CT unit. Problem with freezing across the tree and blow down lines. Swab valve had problem with pressure locking across the valve. Had to get steam on wheels out to thaw out lines and heat up tank. Ordered out 2 pallets of KCL for mixing additional H2O. Held safety and environmental meeting. Discussed procedure with crew. PT fines to 3000 psig prior to running in hole with CT. Lubricator leak replace o-ring on lubricator. PT lines to 3200 psig. RIH with 1 3/4" CT with BHA, 2.65" {more aggressive) 3 bladed junk mill. Added a 4' weight bar to change the mill depth on the BHA. Maintain 1400 psig at surface while running CT in well by bleeding off through the gas buster. Dry tag the plug at 5819.4' KB. PU to 5787' KB, start circulating the hole with 3% KCL WHP=1440 psig, PIP =102 psig. 1 BPM rate. Pumped 32.5 bbls away, pump caught a rock under valve, had to shut down the pump, re prime. WHP=1284 psig. PIP= 615 psig. Resume pumping into well with KCL. swapping hole volume with KCL caught returns after 57 bbls pumped. WHP=43 psig, PIP=996 psig, 5815.44 KB. RIH with CT to 5820.36 KB stacked 3200 Ibs of weight on top of mill. 1 BPM. PIP=2163 psig. ,WHP=170 psig, 70 bbls away. good returns to tank. no sand. Continue to set on plug and try and get the mill to cut, PIP = 1796 psig, WHP=53 psig., 5820.37' KS Increased PI rate to 1 1/4 BPM, 2534 Ibs on coil, PIP= 2400 psig, 91 bbls pumped. good returns. PU weight on coil 14417 Ibs., WHP=59 psig, PIP =1679 psig, 5812' KB RIH with CT 1 1/4 BPM, WHP=53 psig, tag plug at 5820. 18' KB. 110 bbls pumped. good returns to tank. Small trace of sand in returns. Slow down pump in rate to 314 BPM. PIP=1640 psig, WHP = 61 psig, 5821.11' KB, Weight on coil al 1614 Ibs. returns good. PUH to 5712' KB to verify PI rate @ 314 BPM, PIP =620 psig, WHP=29 psig, RIH with CT to tag plug tagged plug at 5820.5' KB, 128 bbls pumped No progress on plug 'POOH to check the junk mill OOH with CT checked the bit for wear and damage. No wear on the bit, all pieces back to surface. MU a jet nozzle to RIH with CT to wash out any sand on top of plug. jRIH with 2.125" wash tool, spacer, Girt-tool tagged up at 5820' KB, Start pumping at 1.5 BPM after 6 'bbls pumped broke circulation to surface. PU and down washing down to the plug at 5819.7 KB Circulated the hole with 130 bbls of water to surface, 3 hole volumes. total pumped on this trip in the hole. No sand returns to tank. POOH with CT, no progress depth at 5820'KB OOH RD CT Vendor Equipment Daily Cost Cumulative Cost BJ services WELL #: KBU -42-7 9 5/8 " DAILY COST: CUM: REPORTED BY: Wayne Cissell • MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 11!112001 FIELD: Kenai Gas Field WELL #: 42-7 FILL DEPTH/DATE: NIA TUBING: 3 1J2 CASING: 9' 5/8 DATE LAST WL WORK: COIL TUBING FISHING TREE CONDITION: FAIR WORK DONE: GR ! CCL BENCHES OPEN: NtA PRESENT OPERATION: NIA WIRELINE CREW: HOWARTH/GRAVES OTHER: Hrs. SUMMARY OF OPERATIONS 08:30 09:15 10:00 12:30 ARRIVE MOC -SAFETY MEETING START RIG - UP. CHANGE FLANGE ON COlL TBG .BOP. TO R/U. W/L WAIT ON PDS TOOLS RIN wi PDS. GR /CCL SET DOWN ON FISH AT 5808' WLM OOH WAIT ON DATA FROM PDS TOOLS. RIG DOWN FUEL EQUIPMENT. Vendor Equipment Daily Cast Cumulative Cost PWL W1L UNIT W/CREW PWL FUEL DAILY COST: $1,930.00 CUM: N/A REPORTED BY: WAYNE CISSELL MARATHON OIL COMPANY DATE: 11!312001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: • DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 FIELD: Kenai Gas Field WELL #: KBU -42-7 TUBING: 3112" CASING: 9 5/8 " TREE CONDITION: Good BENCHES OPEN: PRESENT OPERATION: Mill out bridge plug WIRELINE CREW: OTHER: TIME: SUMMARY OF OPERATIONS 0730 1300 155fl 1700 1810 1830 2130 140 RU CT unit.WHP= 300 psig, Held safety and environmental meeting. Discussed procedure with crew. PT lines to 3000 psig prior to running in hole with CT. RIH with 1-3/4" CT with BHA, 2.8 "Chumps mill. Bleed off gas through the gas buster to maintain the 300 psig on WH . Tagged the plug at 5822.88' CTM. PU hole to 5696' , Open choke to buster, Start circulating the hole with 3°I° KCL while dropping WHP @ surface. 1 BPM rate. PIP=1113 psig. After 31 bbls pumped, RIH with BHA to 5821.36' CTM, module #12, PIR= 1.5 BPM, stalled motor. PUH to 5816.0'CTM, shut back PIR to 0.5 BPM. Increase PIR to 1.5 BPM, PIP=2529 psig, WHP= 170 psig, CT weight @ 8580 lbs. 59 bbls pumped. RiH to 5824.81' CTM. PIP = 2488 psig, WHP= 78 psig,PlR= 1.5 BPM, Work mill, stalled rnoior. Shut back PIR to 0.5 BPM, PUH to 5816.6' CTM. shut back PIR to 0.5 BPM. Increase PIR to 1.5 BPM, PIP=2529 psig, WHP= 170 psig, CT PU weight @ 16080 lbs. RIH with BMA to 5824.28. PIP=2612 psig, WHP=180 psig, continue to work tool string, stall motor. shut back PIR to 0.5 BPM. Increase PIR to 1.5 BPM, PIP=2505 psig, WHP= 91 psig, CT weight @65501bs. RIH to 5824' CTM, Broke through plug. lost circulation. Stalled motor, PUH to 5815' CTM, Continue to work tools string for several hours. Working tools till motor stalls above the mill, chased the plug and its pieces down hole. Each time motor stalls we would shut back the. pump from 1.5 BPM to 0.5 BPM ,then back up to 1.5 BPM drill until the motor stalled and repeat the above scenario. RIH with BHA to 6034' CTM. PIP=2556 psig, W HP=156 psig, stall motor, PUH to 6029' CTM. CT PU weight @16000 lbs., RIH to 6129' CTM, PIP = 2556 psig CTW = 9.'138 Ibs:, StaAed motor, PU CT to 6125' CTM, RIH to 6280' CTM, Module #9, Stall motor, PU hole to 6275' CTM. Good returns to the flow back tank. RIH to 6346' CTM, sat down PUH , CT PU weight = 200001bs. PIP= 233 psig, W HP= 34 psig, 214 bbls pumped. Stalled motor, PUH with CT. Rubber and trash showing up in the flow back liquids. RIH to 6375.5' CTM, Module #8, CT weight = 9763.5' CTM, PIP = 2554 psig, W HP= 48 psig. Ordered out 2 pallets of KCL for mixing up KCL wafer. Good returns to flow back tank. RIH to 6506' CTM, Module #7, CT weight = 6506 Ibs ,PIP = 2350 psig, WHP= 48 psig. work tool string, Stalled motor. RIH to 6556' CTM, Module #6, CT weight = 9607 Ibs., CTM, PIP = 2440 psig, WHP= 51 psig. CT PU weight = 17,700 Ibs. Good returns to flow back tank. RIH to 675.5' CTM, Module #5, CT weight = 10168 Ibs, PIP = 2355 psig, WHP= 48 psig (CONTINUED) Vendor BJ services DAILY COST: CUM: REPORTED BY: Wayne Cissell MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 11/3 & 4 /2001 FIELD: Kenai Gas Field WELL #: KBU -42-7 FILL DEPTH/DATE: TUBING: 3112" CASING: 9 5t8 " DATE LAST WL WORK: TREE CONDITION: Good WORK DONE: BENCHES OPEN: PRESENT OPERATION: Mill out bridge plug WIREL{NE CREW: OTHER: TIME: SUMMARY OF OPERATIONS 2300 11 /4/0 1 0100 0120 0140 0300 (CONTINUED FROM PREVIOUS} Stalled motor, PU hole to 6742' CTM, R1H stalled motor, PU hole. CTW=12924 Ibs, good returns to flow back tank. RIH to 6757' CTM, Module #4, CT weight = 9198 Ibs, CTM, PIP = 2260 psig, WHP= 131 pstg. work tool string to 6921.98' CTM, stalled motor PU H to re start the motor. RIH to 6930' CTM, stalled PUN, RIH to 702T CTM, Module #3, CT weight = 9989 Ibs, PIP= 2310 psig, WHP=136 psig, stalled motor, PUH, continue to work tool string down well RIH to 721T CTM, Module #2, CT weight = 6906 Ibs ,PIP = 2291 psig, WHP=156 psig. stalled motor, PUH to re start the motor. Work tools down to 7228' , CT PU weight = 17800 Ibs R1H to 7400' CTM, Module #1, CT weight =10253 Ibs, PIP = 2377 psig, WHP= 170 psig. work tool string to 7424' CTM, stalled motor, PU H to re start the motor. RIH to 7420' CTM, stalled motor, .PUW =18500 Ibs, RIH to 7420' CTM. Good returns to flow back tank, total bbls pumped = 948 bbls. ,Start N2 pump warm up, Start pumping N2 ,PIP = 3000 psig, 750 SCFM, Returns have slowed down. total water pumped 1013 bbls, POOH W/coil. PUW= 13364 Ibs. WHP= 48 psig, ACT @ 6000' CTM, WHP= 131 psig, N2 PIP= 2160 psig, CT PUW= 14744 Ibs. RIH to 7420' CTM, 10 bbls away on 40 bbls stage before N2 around end of CT. PU weight = 17620 Ibs, PU to 7279' CTM, 40 bbls away this stage. Dropped ball ,restage 21 bbls till the ball reaches the end of the coil. WHP=185 psig, PIP= 2479 psig, CTW = 12543 Ibs, CT @ 7420' CTM, 16 bbls away, pump pressure increased to 3400 psig and fell off to 1150 psig, indicating the ball has seated. small returns to tank. POOH with CT CT @ 5699' PUW= 36,000 Ibs, RIH with CT released weight on CT, POOH PU weight to 28, 000 lbs. continue up hole with coil. WHP= 737 psig, no returns to tank. Flow back line plugged up with stuff. unable to clear the line. no returns to tank. Increased N2 rate to 1500 SCFM, PIP= 2548 psig,, CT at 5482' CTM, PU weight increased to 34, 000 Ibs, RIH with CT to 5498' CTM, POOH with coil Shut off N2 no returns to flow back tank, WHP = 1210 psig. OOH with CT, i.e., It has been a long hard ride... Put night. cap on well head and secured the CT. Blew down the GT with N2. Left location. Note: total KCL lost to the formation 380 bbls. Milled plug out but chased the plug parts down the hole and was pulling heavy on the CT when coming out of the well. The plug parts caused the flow back iron to plug which did not allow me to blow down the well. Vendor Equipment Daily Cost Cumulative Cost DAILY COST: CUM: REPORTED BY: Cissell • MARATHON OIL COMPANY DATE: 11/5!2001 FILL DEPTH/DATE: DATE LAST W L W ORK: WORK DONE: • DAILY WELL OPERATIONS REPORT FIELD: Kenai Gas Field TUBING: 31/2" CASING: TREE CONDITION BENCHES OPEN: PAGE 1 OF 1 WELL #: KBU -42-7 9 5/8 " Good PRESENT OPERATION: Mil{ out bridge plug WIRELIKE CREW: OTHER: TIME: SUMMARY OF OPERATIONS 0700 1030 1415 1435 1630 Had steam on wheels out at 0400am to heat up tree and KCL water. RU CT unit.WHP= 1850 psig, Held safety and environmental meeting. Discussed procedure with crew. Tested BOPS to 3000 psig, Tested good. PT lines to 3000 psig prior to running in hole with CT. Open well to Coil. Coil had ice plug in reel. Applied steam on wheels steam to coil. Was able to thaw out the coil. RIH with 1 3/4" CT with same size nozzle as CT. Continue to bled down CT on way in well with CT. WHP= 555 psig, CTM = 578' . Water in tank after coil at 1710' CTM. CTM= 3510' KB, WHP = 1088 psig, good returns to tank. Start N2 at 750 SCFM, When CT @ 7399" KB, Promore gauge= 2068 psig, PIP= 1538 psig. PUH to 6793' KB. PIP = 1894 psig, good returns to tank. Set on bottom at 6560' KB and pump N2, check returns with small amount of frac sand. '"'"' 45 bbls flowed back to the flow back tank. WHP= 522 psig PIP= 1821 psig, CT=6380' KB, Continue OOH with coil at 25' FM. WHP = 737 psig, PIP = 1772 psig, CT = 6090' KB, promore= 2007 psig Continue out of hole with coil while pumping N2. WHP= 996 psig, PIP= 1538 psig, CT=4120' KB, good returns to tank. S/D N2 when CT @ 2988' KB, WHP= 1113 psig, good returns to tank continue to POOH with the coil good returns all the way out of the well with coil. Flow well to open to top tank for 1 hour when coil at the surface. well making 500 bbl day ra#e of water. Shut in the well to finish Rigging down the coil. finish rigging down CT. Note: total water flowed back to flow back tank 200 bbls. BJ services DAILY COST: CUM: REPORTED BY: Wayne Cissell • 50-133-20488-00-00 Des: A - 028142 ' AGL (87' KB Elevation) gate: 1 /19/2001 ceased: 2/14/2001 KBU 42-7 Pad 41-7 Sec?7F T4N4R11W, SLM. • M M~w-rnoM Drive Pioe 20" K-55 133 ppf Tom Bottom MD 0' 117' ND 0' 117' Surface Casino 13-3/8" 68 ppf Tom Bottom K-55 MD 0' 1,099' ND 0' 1,093' L-80 MD 1,099' 1,750' ND 1,093' 1,732' BTC @ 1,750' MD Cmt wl 734 sacks class G Intermediate Casino 9-518" L-80 40 ppf T~ Bottom MD 0' 5,582' ND 0' 5,322' BTC @ 5,582' MD Cmt wl 654 sacks of class G Production Tubing 3-112" L$0 9.3 ppf EUE 8rd with 5.25" OD slotted couplings to 7,518' Cmt w/ 875 sacks of class G - 15 Excape modules placed - Both control lines now open for methanol injection (8/30/01) - Afl ceramic flappers milled out with coil. Module 15 - 5636' - 5646' (frac'd 8/30101) Module 14 - 5737' - 5747' (frac'd 8/30/01) Module 13 - 5805' - 5815' (frac'd 8/30/01) Module 12 - 5863' - 5873' (frac'd 8/5/01) Module 11 - 5941' - 5951' (perfed 8/5/01) Module 10 - 6123' - 6133' (perfed 8/4!01) Module 9 - 6271' - 6281' (perfed 8/4/01) Module 8 - 6366' - 6376' (frac'd 8/4/01) Module 7 - 6499' - 6509' (frac'd 6/3/01) Module 6 - 6611' - 6621' (frac'd 6/3/01) Module 5 - 6746' - 6756' (frac'd 6/3/01) Module 4 - 6943' - 6953' (perfed 6/1/01) Module 3 - 7153' - 7163' (frac'd 6/1/01) Module 2 - 7319' - 7329' (perfed 6/1 /01) Module 1 - 7399' - 7409' (perfed 3/11/01) 's were treated with 16/20 Carbolite Super Rheogel frac fluid. Well Name & Number: KBU 42-7 Lease: Kenai Gas Field County or Parish: Kenai Peninsula State: Alaska Country: USA Perforations (MD) : (ND): Angle/Perfs: Angle @ KOP and Depth: Dated Completed: 2N4/2001 Prepared by: Kevin Skiba Last Revison Date: 911 812 0 0 7 Re: Pending 403s] , , 99-0~ ~ It { Subject: Re: Pending 403s] From: sarah palin <spalin@mtaonline.net> Date: Fri, 23 Jan 2004 11 :40:08 -0900 To: Dan Seamount <dan_seamount@admin.state.ak.us> looks great - here's my approval. Sarah Palin ----- Original Message ----- From: "Dan Seamount" <dan seamount@admirl.state.at."\.,ls> -"---- To: "Sarah H Palin" <spalin@mtaonline.net> Sent: Friday, January 23, 2004 10:36 AM Subject: [Fwd: Pending 403s] Here are the 403's. the 401's will come later. thanks, dan -------- Original Message -------- Subject: Pending 403s Date: Fri, 23 Jan 2004 10:04:31 -0900 ! From: Winton Aubert <winton aubert@admin.state.ak.us> i Organization: State of Alaska To: Daniel Seamount <dan seamount@admin.state.ak.us> Dan, Pending 403s are Forest Oil well RU #7 - operations shutdown (received 1/15/04), BP well 03-33A - add perforations to existing injection zone (1/21/04), Marathon well KBU 42-07 - add perforations to existing producing zone (1/22/04). WGA 1 of 1 , " " ' .', (l 0 fì E 1/23/2004 1: 11 PM ~SþÇ;8;N~E~:' Jß;\N ~¿ ~ II u4 . (' ( Alaska Business Unit ~ Domestic Production M lV!arathon P.O. Box 196168 MARATHON 011 Company Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 January 22, 2004 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: KBU 42-7 Dear Mr. Aubert: / Enclosed is the 10-403 Application for Sundry Approvals for Marathon well KBU 42-7. The proposed work is to target additional pay by adding perforations to the wellbore. The perfs to be added are included in the enclosed procedure. This work is expected to begin Tuesday, January 27th. If you need any additional information, I can be reached at 907-283-1333 or bye-mail at dmtitus @ marathonoil.com. Sincerely, ~ø Denise M. Titus Production Engineer Enclosures RECEIVED JAN 2 2 2004 Alaska Oil & Gas Cons. Commission Anchorage nDth1f\'l1t n:\drlg\kgf\43-6xrd\AOGCC 10-403 Add Perfs 42-7.xls ,( (y..¡c:'Æ I /'1..,,/ 1.-00<f STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend - Operation Shutdown - Re-enter Suspended Well- Alter Casing - Repair Well- Plugging - Time Extensior - Stimulate - Change Approved Program - Pull Tubing - Variance - Perforate - Other X 2. Name of Operator 5. Type of Well: 6. Datum Elevation (OF or KB) MARATHON OIL COMPANY Development~ 87 feet 3. Address Exploratory - 7. Unit or Property Name P. O. Box 196168, Anchorage, AK 99519-6168 Stratigraphic - Kenai Unit 4. Location of Well at Surface Service 8. Well Number - ./ KBU 42-7 At top of Productive Interval 9. Permit Number 37'FNL, 4118'FWL, Sec. 7, T4N, R11W, S.M. 99-25/ At Effective Depth I Add P f t. I 10. API Number / er ora Ions 50-133-20488 At Total Depth 11. Field/Pool 1318'FNL, 4843' FWL, Sec. 7, T4N, R11W, S.M. Kenai Gas Field / Beluga 12. Present Well Condition Summary Total Depth: measured 7570 feet Plugs (measured) None true vertical 7309 feet Effective Depth: measured 7453 feet Junk (measured) None true vertical 7192 feet Casing Length Size Cemented Measured Depth True Vertical Depth Structural Conductor 117 20" Driven 117 117 Surface 1750 13-3/8" 734 sks 1750 1732 Intermediate 5582 9-5/8" 654 sks 5582 5322 Production 7518 3-1/2" 875 sks 7518 7257 Liner Perforation Depth: measured 5636-46,5737-47,5805-15,5863-73,5941-51, 6123-33, 6271-81,6366-76,' RECE IVE D 6500-10,6612-22,6747-57,6945-55,7153-63, 7320-30, 7400-10 true vertical 5375-85, 5476-86, 5544-54, 5602-12, 5680-90, 5862-72, 6010-20, 6105-15 ß¡ 2 004 6239-49,6351-61,6485-95,6682-92,6893-03, 7059-69, 7139-49 JAN &¡ 2 Tubing (size, grade, and measured depth) 3-1/2",9.3#, L-80, 8rd @ 7453' cemented in place \ .. Alaska Oil & Gas Cons. CommlSSIO Packers and SSSV (type and measured depth) N/A Anchorage 13. Attachments Description Summary of Proposa~ Detailed Operations Progra~ BOP Sketch - 14. Estimated Date for Commencing Operation 15. Status of Well Classification as: 1/27/2004 16. If Proposal was Verbally Approved Oil- Gas X Suspended- Name of Approver Date Approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Denise M. Titus Title Production Engineer Date 1/22/2004 FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness Approval No. v Plug Integrity BOP Test Location Clearance 30 -!) / ð Mechanical Integrity Test -Subsequent Form Required 10-- 4- 0 'I- Approved by Order of the Commission Commissioner Form 10-403 Rev. 06/15/88 ~(ÇÁiI!~H J \i' 2 ¡P 2004. 0 R \ G \ N A L.. .-9fl l . \ ( Marathon Oil Company Alaska Region KBU 42-7 Kenai Gas Field, Pad 41.7 Add Perforations Procedure WBS # WO.03.09900.EXP History: KBU 42-7 is a cemented 3-1/2" Beluga Excape completion. Additional pay has been identified in the wellbore. Objective: Perforate additional pay. Procedure: 1. Ensure location and tree are prepped for wireline including liner installation and house removal if necessary. 2. MIRU wireline unit. 3. Perforate the following zones with 2-3/8" 4SPF, retrievable guns: KBU 42-7 Top Bottom Footage Comment L3 6388 6414 26 1350 BHP 6364 6376 12 Reperf Mod. 8 6336 6342 6 6107 6143 36 Reperf Mod. 10 6004 6037 33 M8/M9 2597 BHP 5933 5971 38 Reperf Mod. 11 5708 5719 11 M3 1090 BHP 5681 5688 7 M2 1641 BHP 4. Clean up location. RDMO eline, and return well to system per instruction of production engineer. Flow back to open top tank if necessary. ( ( MEMO TO EACH WELL FILE LISTED BELOW Date January 7, 2004 Two previously undefined intervals, the Dl sand of the Tyonek Formation and the Beluga Formation in the Kenai Unit of the Kenai Gas Field, have been combined into a single defined pool the Kenai, Beluga/Tyonek Gas Pool, field & pool code number 448571. This change was effective in January 2004. Production from these two intervals had previously been reported to production codes 448569 Kenai, Beluga Undefined Gas and 448570 Kenai, Tyonek Gas. These codes have been deleted from some of the wells listed below. The wells listed below have had their production records modified reflecting this change. 184-109 KBU 23X-06 200-023 KTU 32-07 181-153 KBU 31-07 168-049 KDU 2 195-055 KBU 31-07RD 184-108 KTU 13-05 174-050 KU 14-06RD 199-024 KBU 33-06 178-055 KDU 5 195-054 KTU 43-06XRD 177 -029 KBU 13-08 203-066 KBU 43-07X 185-181 KBU 33-07 199-073 KTU 24-06H 202-043 KTU 32-07H 195-054 KBU 43-06XRD 1 79-029 KBU 41-07 169-012 KDU 4 184-108 KTU 13-05 179-030 KBU 43-06X 199-024 KBU 33-06 199-025 KBU 42-07 200-188 KBU 24-06 202-025 KBU 41-07X 200-179 KBU 44-06 (¡'"'. (('-l:~¡~\.Jj~~,\¡lt::ttl~\ \i~.~~\\1 c~ 0' 200,~. ~3>vtr1A~~ü~tÇ;,lL "-.JÏHiJ~ (:.... I!Jj Permitto Drill 1990250 MD 7570 '~ TVD DATA SUBMITTAL COMPLIANCE REPORT 61412003 Well Name/No. KENAI BELUGA UNIT 42-07 Operator MARATHON OIL CO 7309 ~- Completion Dat 6/3/2001 j Completion Statu 1-GAS Current Status APl No. 50-'133-20488-00-00 1-GAS UIC N REQUIRED INFORMATION Mud Log No Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type ~.dia Fmt (data taken from Logs Portion of Master Well Data Maint) Log Log Run Name Scale Media No Interval Start Stop OH I Dataset CH Received Number Comments Mud Logging Report FINAL .9834 FINAL ~ FINAL 1760 1760 1760 1760 1760 7570 7570 7570 7570 7570 Open 3/1/2001 r_~9935 1760-7570 Open 3/1/2001 ce9934 1760-7570 CH 3/1/2001 1760-7570 Bound Report CH 3/1/2001 ~9934 1760-7570 Digital Data CH 3/1/2001 z~33-5 1760-7570 Digital Data Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? Analysis ~Y-/-N~ R P.c.~.ivP. d ~ Daily History Received? Formation Tops (~)/N Comments: Compliance Reviewed By: Date: · g:\cmn\drlg~kgflwells\kul 1-8s~OGCC03a.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate X Plugging Perforate X Pull Tubing Alter Casing Repair Well Other .. 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface At top of Productive Interval 37'FNL, 4118'FWL, Sec. 7, T4N, R11W, S.M. At Effective Depth At Total Depth 1318'FNL, 4843' FWL, Sec. 7, T4N, R1 lW, S.M. 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum Elevation (DF or KB) 87 feet 7. Unit or Property Name Kenai Unit 8. Well Number KBU 42-7 9. Permit Number 99-25 10. APl Number 50-133-20488 11. Field/Pool Kenai Gas Field / Beluga 12. Present Well Condition Summary Total Depth: measured true vertical 7570 feet Plugs (measured) None 7309 feet Effective Depth: measured true vertical 7453 feet Junk (measured) None 7192 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented Measured Depth 117 20" Driven 117 1750 13-3/8" 734 sks 1750 5582 9-5/8" 654 sks 5582 7518 3-1/2" 875 sks 7518 true vertical 6239-49, 6351-61,6485-95, 6682-92, 6893-03, 7059-69, 7139-49 Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80, 8rd @ 7453' cemented in place True Vertical Depth 5636-46,5737-47,5805-15,5863-73,5941-51,6123-33,6271-81,6366-76, 6500-10,6612-22,6747-57,6945-55,7153-63,7320-30,7400-10 5375-85,5476-86,5544-54,5602-12,5680-90,5862-72,6010-20,6105-15 117 1732 5322 7257 Packers and SSSV (type and measured depth) N/A RECEIVED ~ilaska Oil & Gas Co~s 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) 5636-46, 5737-47, 5805-15, 5863-73, 5941-51,6123-33, 6271-81, 6366-76, Treatment Description Including Volumes Used and Final Pressure Stimulated using 220,000 lbs of 16/20 carbolite in 2600 bbl of diesel-based Super Rheogel frac fluid. Average treating pressure = 4500 psi. 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation 0 0 0 0 (Note: Prior/subsequent volumes are for the specific intervals treated, not the well as a whole.) Subsequent to Operation 0 2700 190 0 1420 15. Attachments 16. Status of Well Classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil Gas x Suspended__ 17. I here ,~ t ~,,~,~ oregoin[3,~xcertify ~he f d correct to the best of my knowledge. Signed '~..,~..~_ ~ ~,~,,., J.Gary Eller Title Production Engineer Form 10-404 Rev. 06/15/8~ '~ Service Date 10/16/01 Submit in Du~"~'"olicate<~' APl: 50-133-20488 KBU 42-7 RT-GL: 20.50' 37' FNL, 4118' FWL, Sec. 7, T4N, R11W, S.M. Tree cxn = 3-1/2" EUE 8rd ITOC (est.)- 5000' Promore downhole sensor @ 5549' MD (5289' TVD) w/7/16" electric cable (dual- armored, 7-strand conductor) to surface two 10K pressure sensors one temperature sensor Note: Composite bridge plug seI at 5830' (8/27/01 ) I KOP: 300' Build: 2.5 deg per 100' Hold Angle: 26 deg at 2500' DOP: 3800' Drop: 0.5 deg per 100' Final Anqle: <3 deg at 5720' Coil cleaned out fill to 7434' MD 8/7/2001 ~:i~:: ::}ll~l:!. ~l:::s: :~ :4:.'. ISurface Casing: 13-3/8", 68 ppf, L-g0 & K- · i~..~.-: .~ ': .::i:: .<,:'": ":: :~; 155, BTC @ 1750' :':~ :: ': ~: ::~ ~;.',.~!~-~;."~;:'ii~ :.[ ~}~ '~:": I 1099' - 1750' - L-80 I ~!~..,. :.1> :M ............ ~ IInL Casing: 9'5/8"' 40 ppf' k-80, BTC @ I Cmt w/654 sks of class G I · h,~'' i"[:' ,¥ PBTD - 7453' TD - 7570' Well Name & Number: County or Parish: Perforations (MD) Angle/PerfSBHP: I KBU 42-7 Lease: Kenai State/Prov. Angle @ KOP and Depth Dated Completed: Prepared By: IProd. Tubing: 3-1/2", 9.3 ppf, L-I 80, EUE 8rd with 5.25" OD slotted couplings to 7518' Cmt w/875 sks of class G Exca.De System Details - 15 Excape modules placed - Both control lines now open for methanol injection (8/30/01) - All ceramic flappers milled out with coil. Perfs: Module 1 - 7399' - 7409' (perfed 3/11/01) Module 2 - 7319' - 7329' (perfed 6/1/01) Module 3 - 7153' - 7163' (frac'd 6/1/01) Module 4 - 6943'- 6953' (perfed 6/1/01) Module 5- 6746'- 6756' (frac'd 6/3/01) Module 6 - 6611'- 6621' (frac'd 6/3/01) Module 7- 6499'- 6509' (frac'd 6/3/01) Module 8 - 6366'- 6376' (frac'd 8/4/01) Module 9 - 6271'- 6281' (perfed 8/4/01) Module 10 - 6123' - 6133' (perfed 8/4/01) Module 11 - 5941'- 5951' (perfed 8/5/01) Module 12 - 5863'-5873' (frac'd 8/5/01) Module 13 - 5805' - 5815' (frac'd 8/30/01) Module 14 - 5737'- 5747' (frac'd 8/30/01) Module 15- 5636'-5646' (frac'd 8/30/01) All frac'd zones were treated with 16/20 Carbolite in diesel-based Super Rheogel frac fluid. Kenai Gas Field Alaska IC°untry: (TVD) BHT: I 2/14/2001 Completion Fluid: J.G. Eller I Last Revison Date: 10/16/2001 010725.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 7/25/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9207601 FIELD: Kenai Gas Field WELL # KBU 42-7 TUBING' N/A CASING: 3.5", 9.3#, N-80 TREE CONDITION: good BENCHES OPEN: Set composite bridge plug to isolate existing perfs SUMMARY OF OPERATIONS MIRU electric line. Conduct prejob safety and operations discussion. Pressure test lubricator to 2500 psi. SITP = 1800 psi. RIH with Halliburton 5K Fasdrill composite bridge plug. Plan is to set BP at 6410', below module #8. RIH to 6650' to tie in, plug is stuck. Make several attempt to move plug without success. Set composite BP at 6640' MD (tied into correlation log of 2/13/01). Setting tool released as designed. POOH, RDMO electric line. Vendor Equipment Daily Cost Cumulative Cost Schlumberger electric line $10,000 $10,000 'Halliburton Fasdrill bridge plug $6,000 $6,000 Misc other $1,000 $1,000 DALLY COST: $17,000 CUM: $17,000 REPORTED BY: G. Eller 010727.X~ MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 7/27/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9207601 FIELD: Kenai Gas Field WELL # KBU 42-7 TUBING: N/A CASING: 3.5", 9.3#, N-80 TREE CONDITION: good BENCHES OPEN: Set composite bridge plug to isolate existing perfs SUMMARY OF OPERATIONS MIRU electric line. Conduct prejob safety and operations discussion. Pressure test lubricator to 2500 psi. SITP - 1800 psi. RIH with Halliburton 5K Fasdrill composite bridge plug. CCL not working, POOH. Replace CCL. RIH. Tied into TCP correlation Icg of 2/13/01. Set composite bridge plug at 6410' between modules #7 and #8. Setting tool released as designed. POOH, RDMO electric line. Vendor Equipment Daily Cost Cumulative Cost Schlumberger electric line $15,000 $25,000 Halliburton Fasdrill bridge plug $6,000 $12,000 Misc other $1,000 $2,000 DALLY COST: $22,000 CUM: $39,000 REPORTED BY: G. Eller 010803.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/3/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9207601 FIELD: Kenai Gas Field WELL # KBU 42-7 TUBING: N/A CASING: 3.5", 9.3#, N-80 TREE CONDITION: good BENCHES OPEN: RU frac iron, load hole and minifrac module #8 SUMMARY OF OPERATIONS MIRU frac iron and tree saver. Strap frac tanks of #2 Williams diesel (3559 bbl). Load 400,000 lbs of 16/20 Carbolite proppant into Sand King. Test frac lines to 8500 psi. Test flowback lines to 4000 psi. Held safety and operations meeting. Open well, SITP = 1900 psi, hole is gas-filled. Pump 30 bbl of diesel until pressure reached 4000 psi. SD, fire module #8 (6366' - 76'). Continue pumping to fill hole with diesel then SD. Perform 15 bbl minifrac with diesel + 1.0 gpt NE-1 lOW at 10 bpm. ISIP = 1983 psi = 0.69 psi/~ Minifrac data not very conclusive, but best interpretation is a highly depleted, highly permeable formation. Secure well, SDFN. Vendor Equipment Daily Cost Cumulative Cost BJ frac equipment $0 $0 Stinger/Onsite tree saver & fire protection $0 $0 Protechnics RA tracer $0 $0 Promore downhole pressure sensor $0 $0 Tripoint Excape guns $0 $0 Veco vac truck, crane, loader $0 $0 DALLY COST: $0 CUM: REPORTED BY: G. Eller OI0804.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE I OF 1 DATE: 8/4/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9207601 FIELD: Kenai Gas Field TUBING: N/A Frac Modules 8-15 WELL # KBU 42-7 CASING: 3.5", 9.3#, N-80 TREE CONDITION: good BENCHES OPEN: SUMMARY OF OPERATIONS Conduct safety and operations meeting. Open well. Promore = 1989 psi after having module #8 open all night. SITP = 30 psi. Frac schedule called for 71 bbl of Super Rheogel 5/5 pad in #2 Williams diesel, 32 bbl of 1 ppg proppant (16/20 Carbolite), 32 bbl of 2 ppg, and 112 bbl of 4 ppg (design = 19,000 lbs). Pump pad at 15 bpm. Start into proppant stage traced with Sb-192 (antimony) Zerowash tracer. Blender having much difficulty meeting schedule, and proppant concentration fluctuating wildly. Perfs took the first 7100 lbs of proppant just fine but screened out at perfs when an unscheduled 10 ppg slug hit. Design called for 4 ppg proppant at this point. Left 7600 lbs of proppant in the wellbore. Immediately attempted to backflow, and got some small amount of proppant to flow back. Tried again to pump in and backflow without success. Fired modules #9 (6271' - 6281 ') and #10 (6123' - 6133') to encourage backflow of proppant. (Both modules #9 and #10 were intended as strictly diesel breakdowns anyway.) No success in getting well to unload. Bled well to zero, RD tree saver. Circulate lines clean after screenout. MIRU 1-3/4" coil tubing. Mix 210 bbl of 3% KCI water. Held operations and safety meeting. Test BOPE to 250/3000 psi. RIH circulating 3% KCI at 0.5 bpm. Getiing just a little proppant in returns, and did not encounter firm fill until 5700'. Increase rate to 0.75 bpm and continue to wash. Wash to 6131' CTM and tag up; presumably it is the flapper assembly for module #10. Increase pump rate to 1.0 bpm (AV = 175 ft/min). Circulate two annular volumes before returns clean up. Circulate 40 bbl of diesel to fill the annulus, then start to POOH. While POOH purge the reel with 3?/0 KCI, leaving the hole filled with diesel. RD coil tubing. Vendor Equipment Daily Cost Cumulative Cost BJ frac equipment, coil $0 $0 !Stinger/Onsite tree saver & fire protection $0 $0 Protechnics RA tracer $0 $0 Promore downhole pressure sensor $0 $0 Tripoint Excape guns $0 $0 Veco vac truck, crane, loader $0 $0 DALLY COST: $0 CUM: REPORTED BY: G. Eller 010805.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/5/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9207601 FIELD: Kenai Gas Field TUBING: N/A Frac Modules 8-15 WELL # KBU 42-7 CASING: 3.5", 9.3#, N-80 TREE CONDITION: good BENCHES OPEN: SUMMARY OF OPERATIONS MIRU tree saver and frac iron. Test lines to 8500 psi. Took several hours to get a pressure test due to leaking valves and pump problems, which is likely a repurcussion of yesterday's screenout. Held prejob safety meeting. Open well, SITP = 30 psi. Load hole and perform 10 bbl minifrac with diesel on module #10. Beautifull looking falloff data for module #10. Calculate a closure pressure of 0.65 psi/fi, G=0.75, calculated permeability of 0.4 md. Not fracturing this zone as per recommendation of Reservoir Dept. for fears of water production. Prepare to perforate module #11. Discover that our lines cleanup from yesterday's screenout was not adequate. Still have extensive amount of frac sand in the pumps, blender manifold, lines, etc. Shut down to clean up. Everything clean now. Perforate module #11 (5941' - 5951 '), obvious indications of firing. Performed 10 bbl minifrac with diesel. Calculate a closure pressure of 0.615 psi/fi and G=0.6. Not fracturing this zone as per recommendation of Reservoir Dept. for fears of water production. Prepare to perforate module #12. Perforate module #12 (5863' - 5873'), obvious indications of firing. Performed 10 bbl minifrac with diesel. Calculate a closure pressure of 0.63 psi/fi, G=1.0. Some sign of height recession. Pump frac as follows: 119 bbl of pad (Super Rheogel in diesel), 25 bbl of 1 ppf proppant (16/20 Carbolite), 26 bbl of 2 ppg, 54 bbl of 3 ppg, 70 bbl of 4 ppg, 88 bbl of 5 ppg, 91 bbl of 6 ppg, and 94 bbl of 7 ppg. Proppant traced with Ir-192 ZeroWash tracer. Placed 70,000 lbs of proppant (97% of design), flushed to top perf with diesel. ISIP = 2500 )si. Load to recover (module #12) = 642 bbl. Vendor Equipment Daily Cost Cumulative Cost BJ frac equipment, coil $0 $0 Stinger/Onsite tree saver & fire protection $0 $0 Protechnics RA tracer $0 $0 Promore downhole pressure sensor $0 $0 Tripoint Excape guns $0 $0 Veco vac truck, crane, loader $0 $0 DALLY COST: $0 CUM: REPORTED BY: G. Eller 010805.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/5/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9207601 (continued) FIELD: Kenai Gas Field TUBING: N/A Frac Modules 8-15 WELL# KBU 42-7 CASING: 3.5", 9.3#, N-80 TREE CONDITION: good BENCHES OPEN: SUMMARY OF OPERATIONS Perforate module #13 (5805' - 5815'), but it's not clear that it fired. Performed 10 bbl minifrac with diesel. Showing identical behavior to module #12 minifrac with identical closure pressure and G-function. Begin pumping 119 bbl of pad. Approximately 20 bbl into the pad (total of 68 bbl pumped into perfs), the well plugged off and we could no longer inject. It behaved as if sand plugged off the perfs, but there was no sand yet pumped and no indication of sand passing the wellhead as per the inline densometer. Pressured up again. Well is leaking off, but can't break down perfs. Attempt to backflow well for 1 minute. Attempt injection again, but now is completely plugged with no leakoff. Determine we must have pulled in sand from module #12 when we backflowed. Decide to move on to module #14. Perforate module #14 (5737' - 5747'). Very obvious firing. Perform 10 bbl minifrac with diesel. Behavior nothing at all like previous minifracs. Showing severe near-wellbore friction (1000+ psi) and other signs of poor access to the formation. Bottomhole treating pressure very erratic due to an unknown restriction at the perfs. Calculate a closure pressure of 0.67 psi/ft, G=1.1. Decide to pump a 48 bbl pad, a 24 bbl slug of 1 ppg or lower proppant, 10 bbl of pad, and straight diesel to overdisplace the perfs by 20 bbl. Bottomhole treating pressure jumped 150 psi when the slug hit the perfs but appeared to clean up. At shut down, the near wellbore fiction was vastly reduced to about 200 psi. Shut down about 25 minutes while we discuss what to do next. Elect to send down another 48 bbl pad and another proppant slug displaced with 1.5 tubing volumes of gel. If things look good, we would elect to frac, and if things look bad we would flush the wellbore. Attempted to pump in, but the perfs are plugged off and again we are unable to pump in. Shut down frac operations. RD tree saver. Total fluid to recover = 1100 bbl. SITP = 200 psi. Attempt to flow well. Well dead, no production to report. Vendor Equipment Daily Cost Cumulative Cost BJ frac equipment, coil $0 $0 Stin~ledOnsite tree saver & fire protection $0 $0 Protechnics RA tracer $0 $0 Promore downhole pressure sensor $0 $0 Tripoint Excape ~luns $0 $0 Veco vac truck, crane, loader $0 $0 DALLY COST: $0 CUM: REPORTED BY: G. Eller OI0807.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/7/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9207601 FIELD: Kenai Gas Field WELL # KBU 42-7 TUBING: N/A CASING: 3.5", 9.3#, N-80 TREE CONDITION: ~]ood BENCHES OPEN: Clean out flapper and plugs with coil, unload SUMMARY OF OPERATIONS 8/6/01 MIRU 1-3/4" coil tubing unit and nitrogen. RDMO frac iron. 8/7/01 Finish RU. MU tool string with 2.58" metal-muncher junk mill, 2-1/8" motor rated for nitrogen applications, and circulating sub. Test BOPE to 250/3000 psi. Held prejob safety and operations meeting. RIH with coil without circulating, displacing diesel to returns tank. Promore gauge = 2234 psi. While RIH, well was trying to start flowing on it's own. Dry tag at 5740' CTM. (Note: Pipe correlation suggests coil tagged up on the #14 flapper assembly without any sand fill.) Start circulating 3% KCI at 0.75 bpm but no nitrogen. Drill through flapper valves without hardly noticing them. Getting a large amount of proppant in our returns. Promore varying from 2300 psi to 2800 psi, but not losing any returns. Wash to 6352' CTM in the vicinity of module #8. Showing signs of losing partial returns, so star pumping nitrogen at 500 SCF/min. Regain full circulation. RIH to composite bridge plug at 6392' CTM. Drill on bridge plug, but motor keeps stalling out. Returns have cleaned up, so decide to quit pumping nitrogen to assist in drilling up bridge plug. Increase liquid rate to 1.£ bpm. Finish drilling through bridge plug and RIH. Required 1.35 hours to drill through bridge plug #1. Tag up on bridge plug #2 at 6623' CTM. Drill through bridge plug #2 in 25 minutes. RIH. Encounter junk at 7084' CTM. Mill on it several minutes before getting through. Continue in hole to 7416' CTM (7434' MD), unable to make any more progress. Circulate bottoms up at 1.3 bpm, then drop a ball to open the circulating sub. Pump pressure increased substantially verifying that sub opened. Displace hole with nitrogen. POOH, RDMO coil. Turn well over to PTS for flowback throughout the night. Diesel recovery via coil operations = 60 bbl. Load to recover = 1040 bbl. Produce well to surface flowback facilities. Vendor Equipment Daily Cost Cumulative Cost BJ frac equipment, coil $0 $0 PTS flowback personnel $0 $0 Veco va¢ truck, crane, loader $0 $0 $o $o DALLY COST: $0 CUM: REPORTED BY: G. Eller MARATHON OIL COMPANY !" ,. DALLY WELL OPERATIONS RE~,.. ,r PAGE 1 OF 1 DATE: 8/14/2001 FIELD: Kenai Gas Field WELL #: KBU 42-7 FILL DEPTH/DATE: TUBING: 3 1/2" CASING: 9 5/8" DATE LAST WL WORK: unknown TREE CONDITION: Good WORK DONE: Dummy Guns/Completion Profile Survey BENCHES OPEN: PRESENT OPERATION: Incomplete WlRELINE CREW: WhitakedBelden OTHER: Wire test - 22 turns AFE # 9203799 Hrs. 15 SUMMARY OF OPERATIONS Arrive @ MOC Office, discuss job w/Foreman, hold safety meeting Check equipment R/U Pressure test BOP's & Lub to 1300 # PSI (well bore pressure) RIH w/25' x 1 11/16" Dummy Guns w/2.50" GR on bottom to 5963' MD, sat down, worked tool, couldn't pass, discuss w/Foreman, told to work tool more, did, couldn't pass, POOH RIH w/25' x 1 11/16" Dummy Guns w/2.25" GR on bottom to 6636' MD, sat down, worked tool, couldn't pass, POOH RIH w/1.75" DD Bailer to 6636' MD, worked through to 7330' MD (Modules hanging up Tool String) RIH w/25' x 10" Completion Profiler Tool (Protecnics) to 6623' MD @ 40 FPM - Logged from 5400' to 6623' @ 70 FPM - Logged from 5400' to 6623' @ 100 FPM - Logged from 5400' to 6623' OOH w/Logging Tool, stand-by for download, secure well for night Tool Cost: Dummy Guns $150.00 2.50" Gauge Ring $50.00 2.25" Gauge Ring $50.00 Anti-blowup Tool $50,00 1,75" DD Bailer $150.00 Weighted Stem $150.00 Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. Tools $600.00 $600.00 Pollard Wireline Inc. 12 hr min / 2 man crew $1,830.00 $2,430.00 Pollard Wireline Inc. 3 add hrs $375.00 $2,805.00 DALLY COST: $2,805.00 CUM: $2,805.00 REPORTED BY: cannot read signature MARATHON OIL COMPANY DALLY WELL OPERATIONS RE~,,.. ,i' PAGE 1 OF 1 DATE: 8/15/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: Unknown FIELD: Kenai Gas Field WELL #: KBU 42-7 TUBING: CASING: 9 5/8" 8/14/2001 TREE CONDITION: Good Gamma Ray Survey BENCHES OPEN: Complete WIRELINE CREW: Whitaker/Belden Wire test - 22 turns Hrs. 12 SUMMARY OF OPERATIONS Arrive @ MOC Office, discuss job w/Foreman, TGSM Check equipment, stand-by for (Protecnics) to Program tool R/U W/L RIH w! Gamma Log to 6966' MD, pull up to 5400' @ 30 FPM, back down to 6754' MD, pull up to 5400' @ 30 FPM, continue up OOH w/Gamma Log, stand-by for download of Data - Data good R/D W!L, secure well, turn over to Production, make report, travel to MOC Office Depart MOC Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. 12 hr min w/2 man crew $1,830.00 $1,830.00 DAILY COST: $1,830.00 CUM: $4,635.00 REPORTED BY: Wayne Cissell 010827.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE I OF 1 DATE: 8/27/2001 FI LL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9207601 FIELD: Kenai Gas Field TUBING' N/A Set composite bridge plug WELL# KBU 42-7 CASING: 3.5", 9.3#, N-80 TREE CONDITION: good BENCHES OPEN: SUMMARY OF OPERATIONS MIRU Schlumberger. Test lubricator and BOPE to 3000 psi with methanol. PU Halliburton 5K composite bridge plug and RIH. Correlate to TCP log of 2/13/01, drop down to 5830' MD to set plug. Could not fire setting tool. POOH. Repair faulty setting tool, RIH with plug. Correlate, set composite bridge plug at 5830' MD. PU, then set back down on plug to verify it is set. POOH, RDMO electric line. SDFN. Vendor Equipment Daily Cost Cumulative Cost Schlumberger electric line $14,600 $14,600 Halliburton bridge plug $6,200 $6,200 Misc. $500 $500 DALLY COST: $21,300 CUM: $21,300 REPORTED BY: G. Eller OI0830.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/30/2001 FI LL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9207601 (continued) FIELD: Kenai Gas Field TUBING: N/A Frae Modules 13-15 WELL # KBU 42-7 CASING: 3.5", 9.3#, N-80 TREE CONDITION: good BENCHES OPEN: SUMMARY OF OPERATIONS (continued from previous page) Perforate module #15 (5636' - 5646'). Prior to perforating Promore gauge was 2400 psi. Observed firing via several indicators. Immediately began pumping with straight diesel, and broke down perfs at 2380 psi surface pressure at 1 bpm. Began pumping gel pad and increased rate to 15 bpm. Fracturing well at 15 bpm with 4200 psi stable pressure on the Promore gauge. When the leading edge of the new fluid hit the perfs, the perfs abruptly plugged off. Were unable to inject at frac rates. Backflowed well and re-pressured up three times, but only succeeded in completely plugging off the perfs. Shut down fracturing operations. MIRU coil tubing. Test BOPE to 3000 psi. RIH without circulating. Tag at 5627' CTM, which correlates closely to the module 15 flapper based on previous runs in the hole. Circulate 3% KC1 at 2.0 bpm. Make two bottoms-up circulations with the KC1 fluid, but get minimal amount of sand in returns. POOH, leaving hole full of 3% KC1. RDMO coil tubing. Note: During circulation was unable to build more than 2200 psi on Promore gauge due to choking at surface. Must have been leaking off excess to the formation. Vendor Equipment Daily Cost Cumulative Cost DALLY COST: $0 CUM: REPORTED BY: G. Eller 010830.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE I OF 1 DATE: 8/30/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9207601 FIELD: Kenai Gas Field TUBING: N/A Frac Modules 13-15 WELL # KBU 42-7 CASING: 3.5", 9.3#, N-80 TREE CONDITION: good BENCHES OPEN: SUMMARY OF OPERATIONS 8/29/01 MIRU tree saver and frac iron. Test lines to 8500 psi. 8/30/01 Held prejob safety meeting. Open well, SITP = 1900 psi. Load hole with diesel. Module 13/14 perfs broke back at 4300 psi (Promore) at 3 bpm. Increased rate to 15 bpm, switched to pad. Pump frac as follows: 119 bbl of pad (Super Rheogel 5/5 system in diesel), 52 bbl of 2 ppf proppant (16/20 Carbolite), 54 bbl of 3 ppg, 70 bbl of 4 ppg. During 4 ppg, briefly lost prime on blender and had to shut down less than 1 minute. Got back into, perfs taking slurry without any apparent penalty. About the time that the "bobble" hit the perfs, we screened out abruptly. Immediately backflowed well. When returns fell off, pumped a 3/3 gel system to displace the sand from the pipe. Successfully displaced all sand into perfs plus 10 bbl overflush. Placed estimated 20,000 lbs of sand in the formation with 472 bbl of diesel (total). SD to regroup. Decide to repump the same design again in modules 13/14. Begin pumping pad, running at same surface and BHP as previous while pumping 15 bpm. Pump 119 bbl of pad, 52 bbl of 2 ppf proppant), 54 bbl of 3 ppg, 70 bbl of 4 ppg, 88 bbl of 5 ppg. Perfs taking proppant easily. Pumped 75 bbl of planned 182 bbl of 6 ppg proppant when burned up the packing on #1 pump. Cut rate to 12 bpm with two pumps left. Second pump packing burning up also, so cut to flush. Successfully flushed to top perf. Placed 52,000 lbs of proppant in formation (design = 71,000 lbs) with another 468 bbl of diesel to recover. Total proppant = 72,000 lbs, total diesel to recover = 960 bbl. ISIP = 2579 psi. Shut down to replace pump packing. Also investigate blender pumping problems. Discuss possibility of flowing well, but decide we can get back to fracturing relatively quickly. (continued) Vendor Equipment Daily Cost Cumulative Cost BJ frac equipment, coil $0 $0 Promore downhole pressure sensor $0 $0 Stinger/Onsite tree saver & fire protection $0 $0 Veco vac truck, crane, loader $0 $0 $o $o $o $o DALLY COST: $0 CUM: REPORTED BY: G. Eller 010831.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/31/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9207601 FIELD: Kenai Gas Field TUBING: N/A Frac Module 15 WELL # KBU 42-7 CASING: 3.5", 9.3#, N-80 TREE CONDITION: good BENCHES OPEN: SUMMARY OF OPERATIONS RU tree saver for fracture operations and pressure test to 8500 psi. Held prejob safety meeting. Open well, SITP = 200 psi. Attempt to frac module 15 perfs, but unable to pump in. Pressure up to 7000 psi three separate times, and while it is leaking off fairly quickly the perfs will not break down. Suspend frac operations. RD tree saver. Waiting on electric line. MIRU Schlumberger. Pressure test lubricator to 2000 psi. SITP = 100 psi. RIH with 10' of 2-1/2" hollow carrier guns loaded with 6 spt Power Jet charges. Tie into CCL/GR log of 2/13/01. Drop down, tag bottom at 5593' MD, which is 43' above the desired top perf. Surmise that it must be sand fill. POOH, RDMO Schlumberger. SDFN. Vendor Equipment Daily Cost Cumulative Cost BJ frac equipment, coil $0 $0 Promore downhole pressure sensor $0 $0 Stinger/Onsite itree saver & fire protection $0 $0 Veco vac truck, crane, loader $0 $0 Schlumberger electric line $0 $0 $o $o DAILY COST: $0 CUM: REPORTED BY: G. Eller O10901 .XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE I OF 1 DATE: 9/1/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9207601 FIELD: Kenai Gas Field TUBING: N/A Frac Module 15 WELL # KBU 42-7 CASING: 3.5", 9.3#, N-80 TREE CONDITION: ~ood BENCHES OPEN: SUMMARY OF OPERATIONS RU 1.75" coil tubing. Test to 5000 psi. RIH without circulating. Tag up at 5571' CTM, which correlates very closely to where Schlumberger sat down last night (5593' MD). Circulate 3% KCI at 1.75 bpm and wash to bottom. Tag up at 5635' CTM, which is within 3' of previous tag on previous coil run (8/30). Circulate up crushed proppant then clean proppant. Increase rate to 2.0 bpm. Have to circulate three annular volumes with 3% KCI before returns clean up adequately. Close off returns and attempt to break down module 15 perfs. Pump in at 2.0 bpm with 1650 on the tubing and 4000 psi on the Promore gauge, which is comparable to the injection pressures observed prior to the perfs plugging. POOH while continuing to pump at 0.75 bpm while POOH to constantly over-pressure perfs. When OOH, perform another injection test at 2.0 bpm. Injection pressure has climbed to 2100 psi at the surface and 4300 psi on the Promore gauge. Pump an entire tubing volume of 3% KCI plus 5 bbl into the perfs, and get some slight cleanup in injection pressure. Surmise that some proppant has fallen back across perfs and is plugging some of them. Discuss possibility of cleaning out wellbore again, but decide instead to try to frac as is. Cease pumping, isolate well, and RD coil tubing. RU tree saver and frac lines. Pressure test to 8500 psi. Pump into module 15 perfs with straight diesel, then gradually increase the gel concentration. Downhole Promore gauge and control-line deadstring confirms that perfs are partially plugged, but gradually cleaning up. Pump 100 bbl pad, then ramp proppant from 2 ppg to 7 ppg. Had not initially planned to go to 7 ppg, but elected to do so due to fears of running short of fluid before all proppant pumped. Displaced frac with 2/2 gel. Placed 63,000 lbs of proppant (design = 62,000 lbs). Have 581 bbl of diesel to recover from this stimulation. Opened well to flow within 45 minutes, but surface leak caused it to have to be shut back in for another hour. When re-opened, flowed weakly to surface flowback equipment. Vendor Equipmenf Daily Cost Cumulative Cost BJ frac equipment, coil $0 $0 Promore downhole pressure sensor $0 $0 Stin~er/Onsite tree saver & fire protection $0 $0 Veco vac truck, crane, loader $0 $0 Schlumber~ler electric line $0 $0 $o $o DALLY COST: $0 CUM: REPORTED BY: G. Eller 010902.XLS MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 9/2/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9207601 FIELD: Kenai Gas Field TUBING: N/A Jet Module 13, 14, & 15 WELL # KBU 42-7 CASING: 3.5", 9.3#, N-80 TREE CONDITION: good BENCHES OPEN: SUMMARY OF OPERATIONS 9/1/01 Well produced liquid weakly until about midnight when it died altogether. 9/2/01 0700 RU coil tubing and nitrogen. Pressure test to 3000 psi. RIH without circulating, dry tag at 9311' CTM indicating much fill. Standby to build gel pills. Begin circulating at 1.75 bpm anc wash down to module 15 flapper at 5636' CTM. Getting full circulation, and getting heavy sand returns at surface. Sweep hole with a 5 bbl HEC pill. The pill itself was clean, but the returns got somewhat dirty again after the pill was displaced. Proppant feeding in from perfs? 1430 Break #15 flapper by setting down 1600 lbs. Wash to composite bridge plug at 5804' CTM. Send around a couple more viscous pills, and begin pumping nitrogen at 500 SCFM when the pills turned the corner. When these pills had almost been fully displaced, got indications that we were plugged off in the flowline upstream of the choke. Able to move coil without difficulty. Decided to shut down pumping, POOH with coil to shut-in well and clean out flowline. Continued to pressure up at the surface whille POOH, reaching maximum pressure of 1500 psi. Plug appears to have been proppant packed off around the coil in the tree, because when the coil passed through the tree this plug broke loose and blew through our surface flowback iron with much force. Shut down to clean out and retest flowback iron to 3000 psi, : i 0300 Open up well; no flow. RIH with coil to 3000' circulating nitrogen at 500 SCFM. Getting good fluid returns. Continue jetting until well is capable of independent flow. Shut down nitrogen, POOH. RDMO coil tubing. Produce well to surface testing equipment. Vendor Equipment Daily Cost Cumulative Cost BJ frac equipment, coil $0 $0 Promore downhole pressure sensor $0 $0 Stinger/Onsite tree saver & fire protection $0 $0 Veco vac truck, crane, loader $0 $0 Schlumberger electric line $0 $0 $o $o DALLY COST: $0 CUM: REPORTED BY: G. Eller OI0910.XLS MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 9/10/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9207601 FIELD: Kenai Gas Field TUBING: N/A Produce to sales WELL # KBU 42-7 CASING: 3.5", 9.3#, N-80 TREE CONDITION: good BENCHES OPEN: SUMMARY OF OPERATIONS 9/3/01-9/10/01 Produced well to temporary surface flowback facilities. Final rate = 2.5 MMCFD (based on choke calculations), 1400 psi FTP on a 18/64" choke, 1955 psi on Promore, 250 BWPD. Well is 3roducing from modules 13-15 with a composite bridge plug at 5830'. ,9/10/01 Shut-in well, RD flowback iron. Attempt to minimize downtime, but the wing valve is "froze up" and cannot be opened. Drop out wing valve and send out to get repaired. Vendor Equipment Daily Cost Cumulative Cost BJ frac equipment, coil $0 $0 Promore downhole pressure sensor $0 $0 Stinger/Onsite tree saver & fire protection $0 $0 Veco vac truck, crane, loader $0 $0 Schlumberger electric line $0 $0 $o $o DALLY COST: $0 CUM: REPORTED BY: G. Eller 0ct-16-01 11:1Sam F rom-MARATHON O I L +g15564648g T-$01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS P.03/05 F-085 ,..)...~///r 1, Type of Request; Abandon -~uspend~ Operation ShutUown Re-enter Su~,pended WelL_._ Alter Casing ~ RepairWellm Plugging~ Time ExtensiorI Stlmulate~ Change Approved Program ~ Pull Tubing~ Variance~ Perforate~ Other._~.X 2. Name of Operator MARATHON el L COMPANY s. Address P. O. Box 196168, Anchorage. AK 99519-6168 4. LocalJon of Well at Surface 5. Type of Well: Development~X Explo rato~.~ Stratigraphi~ Service At top of Productive Interval 37'FNL, 4118'FWL, See. 7, T4N, R1 lW. S,M. At Effective Depth [Clean out with coil tubing I. At Total Depth 1318'FNL, 4843' FWL, Sec, 7. T4N, RI 1W, a.M. 6. Datum Elevation (DF or KB) 7. Unit or Property Name Kenai Unit Well Number KBU 4~-7 Permit Number 99-25 87 feet lO, APl Number 50-133-2,0488 1 t. Field/Pool Kenai Gas Field / Beluga 12, Present Well Condition Summary Total Depth; measured true vertical 7570 feet Plugs (measured). None. 750g feet Effective Depth: measured true vertical Casing Length Structural Conductor 117 Surface 1750 Intermediate 5582, Production 7818 Liner Perforation Depth: Tubing (size. grade, and measured depth) Packers and SSSV (type and measured depth) 745,3 feet Junk (measured) None 7192 1eot 8i:;e Cemented Measured Depth 20" Driven 117 13-3/8" 734aka 1750 9-5/8' 654 sks 5582 3.1/2" 876sks 7518 measured 5636-46, 57,q7-47, 5805-15, 5863-73, 5941-51, 6123-,33, 6271-81,6366-76, 6500-10, 6612-22,, 6747-57, 6945-55, 7153-63, 7320-,30, 7400-1o true vertical 5375.85, .~476.86, ~B44.64, B602-12. 5680-90, §862,72, 6010-20, 6105-15 0239-49, 6:3,51-61,648S-95, 6682-92, 6893-03, 7059-69, 7189-49 3-1/2", 9.3t¢, L-80, Srd @ 7453' oemented In place True Vertical Depth 117 1792 8322 7267 13. Attachments Description Summary of Proposal...~X 14, Estimated Date for Commencing Operation lO/19/2OOl 16. If Proposal was Verbally Approved OII Detailed Operations Program,.,__ 15, Statue of Well Classification aa; Gas X BOP Sketch Suspended._.__ Name of Approver Date Approved Service 'i"~'-I hereby c~ that the (or rue and correct to the beat c3f my knowledge. Signed .'.~ ~~ ~ Ga~ Eller Title Production Engineer Date 1~16/2001 '~ ....... - FOR COMMISSION UsE ONLY , Plug Integri~ BOP Test~ Location Clearance .._ Mechanical Integri~ Te~ Subsequent Form Required t 0-~~ Approved by OMer of the Commission Original S~ed By co.~i.~,o.., Date Form 1O-4Oa Rw. 0~1~88 Cammy 0echs~ Submlf RECEIVED ORIGINAL 0C~ '~ ~2001 Alaska Oil & Gas Cons. Commission Anchorage 0ct-18-01 ,~, il :1Sam From-MAI~ATHON OI L APl: 50-13,3-20488 RT-GL: 20.50' 37' FNL, 4118' F'WI., Sec. 7, T4N, R11W. S.M. Tree cxn -- 3-1/2' EUE 8rd ITOC (est.) - 5000' =remote downholo sensor @ 5549' MD (52l~9' TVD) w/7/16" electric cable (dual- armored, 7-strand conductor) to surface ~vo 1OK pressure sensors one temperature sensor INote: Composite bridge plug seI at 58a0' (8/27/01) iKOP_.: ,300' ' ' BulIM: 2.5 deg per 100' Held Anale: E6 de9 at 3500' Doe: mOO' Drop: 0.5 deg per 100' Final AnQle'. <3 deg at 572o' Coil cleaned out fill to 7434' M D 6/7/2001 KBU 42-7 IPB?D - ?455' ,, TD - 7570' +9155548489 T-501 P.04/0~ F-066 ID._r~ve P!pI~; 20', 133 ppf, K-SS to 1 iT iSurfaee Casing: 13-3/8", 68 ppf, L-80 & K- 5~, BTC O ~75o' O' - 1099' - K-55 1099'- 1750'- L-80 Cmt w! 734 &ks of class (3 lint. Ca,i~g: 9-5/8", 40 ppii-~'~0, BTC'@ ........ 5582' Cmt w/654 sks of class Q I P~ed. Tubing,. 3-1/2", 9.3 ppf, L-I 180, EUI~ etd with 5.28" OD I lslot~d couplinge to 7518' ICmt w/875 eks of claes G I I~xoape ~ystem D~,teils 15 Excspe modules placed Both control lines now open for methanol ~jeclion (a/so/01) - All ceramic flappers milled out with coil, Module 1 - ModUlO 2 - Module 3 Module 4- Module 8- Module 6 - Module 7- Module 8 - Module 9 - Module 10 Module 11 Module 12 Module 13 Module 14 Module 15 7:~99' - 7409' (perfed 3'11/01) 7319' - 7329' (parred 6/1/Ol) 7153' - 7163' (frac'd 6/1/01) 6943' - 89~3' (perfed 6/1/01) 6746'- 67~6' (frac'd 6611'- 6621' (fra~'d 6/3/01) 6499'- 6509' (frac'd 6/3/01) 6366'- 6376' (frac'd 8f4/01) 6271' - 6281' (per,ed 8/4/01) · 6123'. 6133' (parred 8/4/01) - 5941' - S9s1' (parred 8/5/01) - 5863' - 5873' (f~ac'd a/5/01) ,5805'. $81~' (frac'd ~30/01) · 5737' · ~747' (frac'd 8/30/01) - 5636'- 5646' (frac'd 8/30/01) All frac'd zones were treated with 16/20 Carbolite in diesel-based Super Rheogel frac fluid, IWell Name & Number: c~o-un~ or Parish: 'PeHoratlone (MD) Angle/Pe~s IBHP: Dated Completed: Prepared By: "' KBu 42-7 Ke~aj State/Prey. Angle ~) KOP and Depth CrVD) BHT: I 2/14/;~001 _ ,, IL. C om plow ,Ui.d.: :. J.G. IEIler I Last Revleon Date; Kenai Gas Field Alaska ,I lO/16/3oo I ::L 11:19am From-MARATHON OIL f~,, +9156646489 i' Well KBU 24-6- AFE 9205801 Coil Tubing Cleanout October 5, 2001 T-$01 P.05/05 F-085 PUrPOSe: Clean out well KBU 24-6 to PBTD, including a composite bridge plug isolating module #1. Return to flowing condition. Procedure: 3. 1. Produce well to diffuser tank as per Production Engineer's instrucdon until coil tubing unit arrives on location. 2. Shut in KBU 24-6. MIRU 1.75" coil tubing unit and nitrogen pump. MU three- blade junk mill (1.5"- 1.75" OD) on 2-1/8" motor with phase separator tool. Test BOPE and flowback lines to 4000 psi with 3% KC1. Test nitrogen lines to 4000 psi. Hold onsite safety meeting. Reopen well to diffuser tank on same choke size as was flowing thc well previously. RIFI with coil tubing without circulating. Adjust surface choke to maintain constant surface pressure while RIH, (Note: If thc Promote gauge display is installed, maintain constant Promore pressure instead of constant surface pressure.) Be cautious around 5940' MD, where coil had difficulty getting through during the previous coil operation on 10/3/01. 4. Dry tag fill. PU 20', begin circulating at 1.0 bpm. Adjust nitrogen rate as needed to maintain strong returns. Mill through composite bridge plug at 7215' CTM. Continue in hole to PBTD of 7376' MD. Circulate clean with 3% KC1. When returns are adequately clean, stop pumping KCI water and jet hole dry with nitrogen. PU to 5200'. 5. Shut off nitrogen and monitor well. Once well is coming around strong, RIH "i without circulating. Dry tag fi [1. Contact Production Engineer if it appears that fill needs to be washed out again. 6. POOH, RDMO coil tubing. Continue to produce well to diffuser tank. 3'GE - October 5, 2001 00t-16-01 (June 1990) !1 :lSam From-U^R^THOH 0IL +9166646489 UI~~ %~ ~ m AR, I r..~.~ SUBMIT Ill DEPARTM[{ 3F THE INTERIOR BUREAU OF LAND MANAGEMEN'[ re~eme sloe) SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry fl3 a different reservoir. Use 'APPLICATION FOR PERMIT--" for such proposals. SUBMIT IN TRIPLICATE 1. Type of Well r'~ Well [~ Well ~ Other 2. Name of Operator Marathon Oil Co, 3. Address alld Telephone No. P.O. Box 196168, Anchorage, AK 99519, (907)561-5311 4. Location of Well (Footage, Sec,. T,. R., M,, or Suvey Description) 12. Interval: -FD: 37' FNL, 4118'FWL, See. 7, T4N, R11W, S.M. 12~37'1=NL, 4BO8'FWL, Sec. 7, T4N, R11 W, a.M. T-SO1 P.OZ/O$ F-OBS , BUDGET BUREAU NO. ~x~res. M,~rch $'L 5, Le~se De~ignslion 8nd Serial No. A~8142 6. If Indian, AIIo~ee orT~be Name 7. If Un~ or CA. Agree~nt D~Ignatlon Kenai Beluga Unit 89100~67C 8. Well Name and No. KBU 42-7 g, APl Well No, ~-133-~488 10. Field an~ Pool, or Exp[orato~ Area ~nai Gas Field 11. County or Palish, Kenai Peninsula, Alaska i CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION [~] Notice of Intent ['~ ~ubsequent Report r'""] Final Abandonment Notice TYPE OF ACTION r~ Abandonment r-=! Change of Plans r~ Recompletion ~] New Construction r-"] Plugging Back r--] Non-Routine Fracturing I--'] Casing Repair r""l Water Shut-Off r-'"] Altering Casing r"-] Conversion to Injection [~ Other CJean out with coil tubing r-"] Dispose water (NOTE: Report results et multiple completion on Welt C~,mpl~tion ur R~:~m~l~ti~n R~p~1 ~n~ k~g t~rm,} , , Describe Proposed or Completed Operations (Clearly state all pertinent details, and give pertinent dates, including estimated d~te of starting any proposed work, If well Is dlrectlonall drilled, give subsurface locations and measured and true vertical depths for all markers and zones pedinent to this work.}~ Marathon proposes to mobilize coil tubing to olean out well KBU 43-7 Io PBTD. There is ~urrently in plaoea composite bridge plug at 5830' that was placed in preparation for fracture stimulation operations. Those stimulation operations are complete, ~o now the bridge plug will be removed to return all Beluga Sand perforalions to production. Marathon proposes to begin this cleanout on 10/19/2001, ia. I hereby ce~;~hal the f~z~g is true and correct (This spac~ fb~'Fed~tate office use) TITLE Production Engineer DATE October 16, 2001 APPROVED BY TITLE DATE Conditions of approval, if sny: 0r repmsefltatlOnS aa to any mat~er w~t~in it~ jurisdiction, *See Insstructioa on Reverse Side RECEIVED OCT 1 ZOO') Alaska 0il & Gas Cons. Commissio~ Anchorage Marathon Oil Company Alaska Region Domestic Production P.O. Box 1(36168 Anchorage, AK 99519-6168 Telephone 9071561-5311 Fax 9071564.6489 July 13, 2001 Mr. Tom Maunder State of Alaska Alaska Oil & Gas Conservation Commission 33 West 7th Ave, Suite 100 Anchorage, AK 99501 Reference: Field: Kenai Gas Field Well' KBU 42-7 Permit No.' 99-25 RECEIVED JUL 1 6 ZuUl Alaska 0il & Gas Cons. Commlss~o~ Anchorage Dear Mr. Maunder: Enclosed is the 10-403 APPLICATION FOR SUNDRY APPROVALS form for Marathon well KBU 42-7. If you require further information, I can be reached at 907-564-6315 or by e-mail at jgeller@marathonoil.com. Sincerely, J. Gary Eller Production Engineer Enclosure bjv STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS n:\drlg\kg f~43- 6xrcr~OG C~C03.×Is 1. Type of Request: Abandon Suspend__ Operation Shutdown __ Re-enter Suspended Well__ Alter Casing Repair Well__ Plugging__ Time Extensior Stimulate .~X Change Approved Program Pull Tubing Variance Perforate X Other 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface At top of Productive Interval 37'FNL, 4118'FWL, Sec. 7, T4N, R11W, S.M. At Effective Depth At Total Depth 1318'FNL, 4843' FWL, Sec. 7, T4N, R1 lW, S.M. 5. Type of Well: Development X Exploratory Stratigraphic Service Datum Elevation (DF or KB) 87 feet 7. Unit or Property Name Kenai Unit 8. Well Number KBU 42-7 9. Permit Number 99-25 10. APl Number 50-133-20488 11. Field/Pool Kenai Gas Field / Beluga 12. Present Well Condition Summary Total Depth: measured true vertical 7570 feet Plugs (measured) None 7309 feet Effective Depth: measured true vertical 7453 feet Junk (measured) None 7192 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented Measured Depth 117 20" Driven 117 1750 13-3/8" 734 sks 1750 5582 9-~8" 654 sks 5582 7518 3-1/2" 875 sks 7518 6500-10,6612-22,6747-57,6945-55,7153-63,7320-30,7400-10 True Vertical Depth 117 1732 5322 7257 true vertical 6239-49, 6351-61, 6485-95, 6682-92, 6893-03, 7059-69, 7139-49 Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80, 8rd @ 7453' cemented in place Packers and SSSV (type and measured depth) N/A RECEIVED JUL 7 6 2007 AJas/a 0il & Gas C0n~. Col'pmiss!o? 13. Attachments Description Summary of Proposal X Detailed Operations Program BOP ~thbrag.e._ 14. Estimated Date for Commencing Operation 15. Status of Well Classification as: 8/3/2001 16. If Proposal was Verbally Approved Oil Gas X Name of Approver Date Approved Service 17. I hereby ~~%d correct to the best of my knowledge.. Signed Gary Eller Title Production Engineer Suspended , FOR COMMISSION USE ONLY Conditions of Approval: Notify ~ommission so representa~tiye may witness s r,~ c Plug Integn'~j~/ BOP Te t_.~ Lo ation Clearance Date 7/12/2001 JApproval No O" Mechanical Integrity Test Approved by Order of the Commission Subsequent Form Required 10- ~,3~)t'"~, Commissioner Date -J'Jt~lO'-) J Form 10-403 Rev. 06/1,5/88 Submit in Triplicate ORIGINAL tl PI: 50~133-20488 T-GL: 2050' 7' FNL, 4118' FWL, Sec. 7, 4N, RllW, SM. res cxn = 3-1/2" EUE 8rd TOC (est.) - 5000' jPromore downhole sensor @ 5549' MD (5289' TVD) w/7/16" electric cable (dual- armored, 7*strand conductor) to surface two 10K pressure sensors one temperature sensor Wireline tagged fill @ 7163' MD 6/28/2001 KBU 42-7 ITD- 7570' PBTD- 7453' Ddve Pipe: 20", 133 ppf, K-55 to 117' Surface Casing: 13-3/8", 68 ppf, L-80 & K- 55, BTC @ 1750' 0' ~ 1099' ~ K~55 1099' - 1750' - L-80 Cml w/734 sks of class G cInt, Casin¢l: 9~5/8", 40 ppf, L-80, BTC @ 5582' mt w/654 sks of class G [0Prod. Tubing: 3~1/2", 93 ppf, L- , EUE 8rd with 5.25" OD ottod couplings to 7518' mt w/875 sks of class G _E_x._c_.~l~ 9_S3fst e m Details - 15 Excape modules placed ~ Green control line now open for me[hanoi injection (6/3/01) - Rod control line fires top 8 modules - Ceramic flapper valves below each module Module I - 7399' - 7409' (per[ed 3/11/01) Module 2 - 7319' - 7329' (per[ed 6/1/01) Module 3 - 7153' - 7163' (frac'd 6/1/01) Module 4 - 6943' ~ 6953' (per[ed 6/1/01) Module 5 - 6746' - 6756' (frac'd 6/3/01) Module 6 - 6611' - 6621' (frac'd 6/3/01) Module 7 - 6499' - 6509' (frac*d 6/3/01) Module 8 - 6366' - 6376' Module 9 - 6271' - 6281' Module 10 ~ 6123' * 6133' Module 11 - 5941' - 5951' Module 12 - 5863' ~ 5873' Module 13 - 5805' - 5815' Module 14 - 5737' - 5747' Module 15 - 5636' - 5646' Well Name & Number:] KBU 42-7 I Lease: ] Kenai Gas Field County or Par sh: Kenai I State/Prov. Alaska tPerforations (MD) ~ I (TVD) Augle/Per[s Angle @ i-(O, and Depth I BHP: BHT: I Completion Fluid: Datod Completed: 2/14/2001 Prepared By: J.G Eller [ Last Revison Date: Well KBU 42-7, Kenai Gas Field Fracturing Procedure, Modules 8-15 AFE 9207601 Objective: Fracture stimulate the remaining eight Excape modules in well KBU 42-7 and produce to sales. Procedure: MI ten 500-bbl frac tanks onto the KBU 42-7 location and load with #2 Williams diesel. All diesel and frac equipment is to be placed on top of an impermeable liner with adequate berm. Promptly repair any tears in the liner. . Shut-in well KBU 42-7. MIRU electric line. Test lubricator and BOPE to 3500 psi. RIH with FasDrill bridge plug rated to 5000 psi differential. Set Fasdrill bridge plug at 6400' below flapper of #8 module to isolate off existing perfs. POOH, RDMO electric line. 3. Bleed off trapped pressure on KBU 42-7. Load hole with 56 bbl diesel. Test Fasdrill bridge plug to 2000 psi (0.69 psi/ft equivalent). Bleed off pressure. . MI hot oil truck. Heat diesel to 90 to 100 degrees F using hot oil truck. The day of the frac the diesel needs to be 60 deg F or hotter. Hot oil truck should be at least 100' away from any diesel tanks during this heating operation. An MSDS sheet for the diesel should be on location, as should adequate fire protection. RDMO hot oil truck. o MIRU frac iron, Sand King, and flowback iron. Load Sand King with 16/20 Carbolite. (Note: Capacity of the Sand King is 250,000 lbs, whereas the total job calls for approximately 500,000 lbs of proppant. Will need to load proppant onto Sand King as compartment space becomes available during the frac.) Test the flowback iron to 4500 psi. Test the frac iron to 8000 psi. 6. Fire the Excape guns for the #8 module (6366' - 6376') by pressuring up the red control line to the firing pressure. Monitor for signs of firing. . MIRU fire fighting unit, tree saver, and radioactive tracer van. Conduct prefrac safety meeting. Top pressure = 7500 psi. Frac stimulate module #8 as per design. (Note: Preliminary design for each module assumes placing 70,000 lbs of 16/20 Carbolite using 550 bbl of Super Rheogel diesel gel.) Displace to the top per# and shut down. 8. Continue sequence of firing and fracture stimulating all remaining Excape modules in the same manner. Beluga Sand Excape perfs are as follows: Module 9 - 6271' - 6281' KBU 42-7 Frac Procedure, Modules 8 - 15 Page 2 Module 10 - 6123'- 6133' Module 11 - 5941'- 5951' Module 12 - 5863'- 5873' Module 13 - 5805'- 5815' Module 14 - 5737'- 5747' Module 15 - 5636'- 5646' o Following displacement of the frac on module #15, RDMO tree saver once surface pressure falls below 4500 psi. Flow back well to flowback equipment as per instructions of Production Engineer as soon as possible after the frac. 10. When instructed by Production Engineer, MIRU 1-3/4" coil tubing on KBU 42-7. PU motor and mill. Pressure test BOPE to 3500 psi. RIH cleaning out sand and milling through flapper valves. Continue until reach PBTD. Sweep hole, drop ball to open circulating sleeve. Displace well with nitrogen and POOH. RDMO coil tubing. 11. Resume flowing back KBU 42-7 to the flowback facilities. Continue testing and unloading as per instructions of Production Engineer. JGE- July 12, 2001 Marathon Oil Company Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 9071561-5311 Fax 9071564-6489 July 16, 2001 RECEIVED ,JUL 1 7 2001 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Alaska 0il & Gas Cons. Commission Anchorage Subject: KBU 42-7 Well Completion Report and Log Dear Mr. Maunder: Enclosed is the form 10-407 Well Completion Report and Log form for Marathon well KBU 42-7. If you need any additional information, I can be reached at 907-564-6315 or by e-mail at jgeller@marathonoil.com. Sincerely, J. Gary Eller Production Engineer STATE OF ALASKA r~ AL ,. (A OIL AND GAS CONSERVATION CO i~.,SSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well OILr"--j GAS J-~-J SUSPENDEDJ'~'J ABANDONED J'--J SERVICEFJ 2. Name of Operator 7. Permit Number MARATHON OIL COMPANY 99-25 3. Address 8. APl Number P. O. Box 196168, Anchorage, AK 99519-6168 50-133-20488 Classification of Service Well 4. Location of Well at Surface 37'FNL, 4118'FWL, Sec. 7, T4N, R1 lW, S.M. AtAt Total top of Depth Producing Interval 1318'FNL, 4843' FWL, Sec. 7, T4N, R1 lW, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 20.5' DF-G L I A-028142 12. Date Spudde, l~. 13. Date T.D. ReAched ,.-z.C, *" .~2,,~/2 1 ~lJ,,te/2001 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 7570' MD, 7309' TVD 7453' MD, 7192' TVD 22. Type Electric or Other Logs Run CMR-PEX-AIT-DSS-RFT-G R 9. Unit or Lease Name Kenai Beluga Unit 10. Well Number KBU 42-7 11. Field and Pool Beluga Pool Kenai Gas Field 14. Date Com~ Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 6,/,~2001./~ I N/A feet MSLI one 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost Yes[~'-~ N° r~I N/A feet MD I N/A 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 13-3/8" 133 K-55 K-55 & L-80 117 Driven Driven N/A 68 0 1750 17-1/2" 734 sks (to surface) N/A 9-5/8" 40 L-80 0 5582 12-1/4" 654 sks N/A 3-1/2" 9.3 L-80 0 7518 8-1/2" 875 sks N/A 25. TUBING RECORD 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) Beluga Sands 7399' - 7409' MD, 7139'- 7149' TVD (Module #1) 7319' - 7329' MD, 7059' - 7069' TVD (Module #2) 7153' - 7163' MD, 6893' - 6903' TVD (Module #3) 6943' - 6953' MD, 6682' - 6692' TVD (Module #4) 6746' - 6756' MD, 6485' - 6495' TVD (Module #5) 6611' - 6621' MD, 6351' ~ 6361' TVD (Module #6) 6499' - 6509' MD, 6239' - 6249' TVD (Module #7) 6 spf, 2-1/2" Excape guns, 60-degree phased SIZE DEPTH SET (MD) PACKER SET (MD) N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6499' - 6509' (Mod. #3) Frac'd w/6500 lbs of 16/20 Carbolite 6611' - 6621' (Mod. #5) Frac'd w/68,900 lbs of 16/20 Carbolite 6746' - 6756' (Mod. #6) Frac'd w/54,100 lbs of 16/20 Carbolite 7153' - 7163' (Mod. #7) Frac'd w/53,600 lbs of 16/20 Carbolite 27. PRODUCTION TEST Date First Production 3-Jun-01 Date of Test 6/18/2001 I Method of Operation (Flowing, gas lift, etc.) flowing Hours Tested I PRODUCTION FOR 24 ITEST PERIOD I CALC U LATED 124-HOUR RATE OIL-BBL o GAS-MCF 4029 WATER-BBL 0 Flow Tubing Pres. Casing Pressure OIL-BBL GAS-MCF WATER-BBL 1100 0 0 4029 0 28. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. JCHOKE SIZE JGAS-OIL RATIO 32/64" J N/A OIL GRAVITY-APl (corr) N/A Interbedded sandstone, siltstone, shale, and coal ORIGINAL R'ECEIV£D JUL 17 2001 ~laska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 N:\drlg\kgf~wells\KBU 33-6~,OGCOMP L.×ls CONTINUED ON REVERSE SIDE Submit in Triplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS __ Include interval tested, pressure data, all fluids recovered NAME MEAS. DEPTH TRUE VERT. DEPTH and gravity, GOR, and time of each phase. __ Middle Beluga 5617 5355 RFT data submitted Tyonek 7436 7173 RECEIVED dUL 1 ? ?_.001 Alaska 0il & Gas Cons. 60mmiss~ Anchorage 31. LIST OF ATTACHMENTS Daily operations summary, wellbore schematic, directional survey 32. I hereby ce~~_~ ~e and correct to the best of my knowledge Signed Gary Eller Title Production Engineer Date 7/14/2001 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other- explain. Item 28: If no cores taken, indicate "none". Form 10-407 N:\drlgksterllng~su32-9kAOG COMPL.xls Marathon ~,.."-#: ¢ DATE: 0~/'17'/0'1 LOCATI. ( YS: O SPUD DAYS; Oil Company ~, .#: 9203799 GL: . KB:~ . MOCWI: . WELL: KBU,4Z-T RIG: GlaclerDrllllnjTRIJ7 '! FTG: DEPTH: (MD) 0 (TVD) O CSG SIZE: CSG MD: CSG TVD: SHOE TEST: MAX. SI 0 LINER TOP: , iaRE~ENT C~Ia:RJ~ LIp l:),qJl-£lN~ EQUIPMENT MOJ)E Ri;3 7'0 K~U 4~.-7' LOC, A7'10N AND RIO3 UP DRILLIN{3 EQUIPMENT. SET MAT' ~IOARD$, SU~, AND SUMMARY CMW vis Pv YP GEL, WL T !.~ 3U HT FG C:EC ,AND SLD BENT =ALT DRILLED BARITE I I I I I I I I ! I 1 ~2 I I , / ppa ape ppe OC~T~ WTR,, pH Pm Pf Mf CL CA LIME MU-~ LOSSES Ibbl/ftI BI~GD ,CONN : tRIP" MAX dally cum ~, BIT~ SIZE TYPE OFF FTG,,, ,,HR$ FT/HR RPM, ,wqe ~o o L El GOT, R CPF COMMENTS I / .I. I I I I I I I I' .... { BIT# SERIAL# PRE$8. CPM dET$ TFA ANNULAR VELoCITY BIT HP I ....................... ,,~ ........................ , ................................................... , ........................... [ .............. ,,~,,,,,,.,,,,, .................. L, ............................................ I ................................................................................................... J. .................................................. 1 ........................................................................................................................................................................................ I Length: DRILL PIPE DES~;RIPTION: MA~'PULL ' I I I I I I ~ ,JARS MWD MOTOR TORQUE WEIGHT (lOgO} , J J [ ] [ I IBHA: PU Rof -So Eh' ..................................... t' ........................ , ....................... IIIIItllllilJlllll~llllllJ" ............... ~' ................................................. ,~, ....................................... ~,,, ................................................ ~h ............................................................................................... ~, ............... ~ ............................................................................................................................................................................................................................................................. CMEA. DEPT, H,,, ANeLE DIRECTION,,,,, TVD VERT. =E,C. NI= , E/W DOe LEG ., .... ~l,lllqll,l(rlJiiIrJlqlPllJqrlqllqll,lllqllllJlqU~ulqJpnlqb,mlHpll~4 ~qrPl[[,lflgjj,ln,Jll~JmlmUj,[llllljqllqUrmqwmqUqllqUqll, JlUl4m~U,l*l,Hl,lljqlfllflll,Jil,lUqU,llpnllruuuqu,nlqll*Ju, IqmnJqnqUgll'lll~Jlfllflll,lllqUUU,JuququqrpllplJlqUqlLr iqlllUl,UlqUqmlll,Ul,mqUq!l,~ltqlUUl,mqu,jlj~t.qu,Jmruqu, mlr~qmm,lmUlqUUll,mqmlJpU1,1flqlpnpupH~qlllUlqH,u ilmu,luqn,lllUUqmlu,lll,JUqH,UlUl}qllqlJ,lmmlJltrlltqJlllll ,lll,rlllllpUlUl~ltllrqmlmlHqu*r~lququqmluqll,lllqllqllqll,lU (~ OPERATIONS IN SECaUENC:E START END HOURS DESCRIPTION " f2:0~' 'f'9:30 7,~0 MOJE RIG TO KBU ,42-7 LOCATION AND ale UP DRILLIN¢~' E~UIPMENT. SET MA'n/Ne .... ,, ....... .,. ........ ~ ~ , , ~ ~ ,, , ., .... AFL; DH T=TIC=e COMP TOT LAST PIT DRILL DATE: 01/01/00 DALLY: O CUM: O DALLY: ?27'~1'~t& CUM: 127',10& NO ACC/DENTS REPORTED TODAY DRILLING SUPERVISOR: , .. ~N~ ~Y: GLACIER DRTLLING C0UPANY.: 907 288 1318; JAN-19-01 6'80; PAGE 1/1 , ,. · Marathon ':(" · 3 DATE; 0¢/~8/0f LOCATION ( ); O SPUD DAYS; Oil Company Al=c#. 9203799 GL: . KB: , MOCWI: , WELL: KBU42-'/' Rl{3:Glaclel'D~'llllnJTRIJ7 '1 FT{3: DEPTH: (MD) ' ('TVD) CSG SIZE: 20.000 CSG MD: t37. CGG TVD: t37. 8HOE TEST: MAX. 81 0 · LINER TOI~: , PRE~ENT OP'.PICK UP AND S'J'ANI~ JaACK 5" HWI~F RIG UP DRILLING EQUIPMENT ON i(BU 4~-7, NIPPLE UP AND I;UNGTION 7'E37' DIVERTER SY37'EM WITH EXECUTIVE AO~CC WITNESS. PiCK UP AND RACK BACK DP AND HWDP REQUIRED FOR FiR~'~T HOLE ~EC.rlON. SUMMARY I. I I I i I I I ~ I I i~ I I i PP~ PP~ COIL WTR I~H Pm Pf Mf CL CA LIME MUD LOSSES (bbl/ft) BKGD CONN YRIP MAX ( BIT~, SIZE TYPE orr FTC HR8 FTIHR RPM WOE iO D L B G OT R CPF COMMENTS · ~ BIT# SERIAL# PRE;SO. GPM JETS TFA ANNULAR VELOCITY BIT Length: DRILL PIPE DESCRIPTION ' IVIA~( PULL ' ,! ~ JARS MWD MOTOR TORQUE WEIC~HT (IOOD) C,MEA. DEPTH ANGLE DIRECTION TVD VER,'I'. eEC. NIS E/W, DOG LEG i]lqlpl~l,llllHiilllqll~lll,lll,lllqll~lllq.,Jllq~mllqll,l~lqn,ll~[imlll, ,rll,U~,lmmqll,lll,mml,mql[.lllmql~qflqll,JU,lllqll,lll. Ul, i,iii,m.llqllqml,lmlql,qmlll~,llqllqnqllqllqll,lllqllqllqlll I.~,qll,ll~,la,lll,nlqnqlml.mqll,lll.llq.rm,.l,ll~,lrl,.iql,,i lamqll,m,lmlllqllqll,lmlllrl],,lllqllqll.m*Ullm,I]l,mqll,elFtll, ,lll,lll,m,lll,ll~qll,,mlll,rllq~l,lllqllqrlqlPIIl,m,ll~ql]q~lqll,lll ii,lllqll,mqll,l.,rll,lllqll,lll,rlr,lmnl,lll,.l*rl,qle,llrqlllllrqll ,, START END HOURS DESCRIPTION , ~:00 '15:00 g. O0 RIG UP DRILLIN~ EQUIPMENT KBU ,42.7. FINISH RIG UP TOP DRIVE. PLUMB IN TRiP TANK. .... HOOK UP ¢EOLO~RAPH LINE. CHAN~E SHAKER $CREEN~ AND I. IN~R~ IN PUMR~,, RIG UP TO P/OK UP PIPE. SET PIPE RAOK$ AND SET DP AND HWDP ON RAOK$. ~5:00 0:00 g,O0 M~ ~PUD MUD. UNLOAD CUT'TIN~$ 'rANK, NIPPLE UP DIVER'rER ~'rACK~ NIPPLE~ FLOWLINE, FILL UP LINE~ TRIP TANK~ AND KNIFE VALVE. 0:00 f:O0 f,00 FUNOTION TEST DIVERTER WITH AO~O0 REP LOU ~RIMALDI WITNESSING. OHEOKED GAS DETECTER FUNCTION AND PVT ACCURACY. f :O0 2;00 1,00 CHAN¢;E ~A VER ~UB IN TOP DR/i/E, CHAN~E ELEVA.rOR 2:00 4:30 2.50 DRIFT, STRAP, MAKE UP, AND STAND BAOK 25 STANDS 4" HT,38 DRILL PIPE 4:$0 6:00 1.30 DR/F'r,, ~'rRAP! MAKE UP! AND ~'rAND BACK ,.~" HWDP · , RIG AOOEPTED FOR WELL WORK ON KBU 42.7 ~ f$O0 HOURS ON f/fS/0f HIIIhllhl[IJ]]lfllhllTIIIIlfl;lrfllliJl[[lllh;llll IIiIIIl~llrll;lllrllllllhllhl[lllll~ll[lllhll~rllhl Ilrlllrlllrl]hllllllllllllllltHIIIIIIHhl~[llllJ]lllllhi ~i~r~r~1~i~rr~]~r~1~]~i~i~1~1*~i~[~t~[~J~=~i~]1~r~r~r~t~it~t~ ~h1t~tih~r~1~i~r~h~r~r~]h1]1~h~ii~h~ih~h~i~h~r~r~h~[~]t~r~[~h~r~h~h~h~h~;~h~h~r~t~h1~[~h~h~h~ AFE: DH TaT/LaG COMP TOT LAST PIT DRILL DATE: 01/01/00 DALLY: 0 CUM: 0 DALLY: 2~G93 CUM: 179~327 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: RICHARD GIDEON ..... NT BY: GLACIER DRILLZNG COMPANY; 907 283 1313; JAN-20-01 6:05; PAGE 1/1 Marathon .~( ,4 DATE: 01/20/01 LOCATIC, ,~ ~ SPUD DAYS: Oil Company AFE#' 9203799 GL: . KB: , MOCWI: WELL: KBU 42-7 RIG: Glacier Dr/l/ItV3 RIf3 ? FTC: DEPTH: (MD) 1,230 (TVD) C:SG SIZE: 20.000 CSG MD: f37. CSG TVD: f$7. 8HC)E TEST: MAX. SI 0 LINER TOP: , I=RE~ENT OP'~RILL 17 1/~" HOLE PINISH PICKING UP DP. PIG/( UP BHA AND SPUD KBU 4~-7 WELL AT 10:30 1/19/01, DIREG'TIONAL DRILL AND IZXECUTIVE ;URVEY 37°- SUMMARY (,MW VIS PV YP GEI-S WI. T /.~ 30 HT FG eEC; SAND SI.D BENT SALT DRII-I-ED BARITE e.0 1~21 12 t a01 22 / 2,~ 1~.21 721 / I I 2 132 0.8 I 5.0 I I 0.1 PPB 6'/.0 PPB. PPB (O~L WTR pH Pm Pf Mf CL CA LIME MUD LOSSES Ibbl/ftl BKGD CONN TRIP MAX .... ......... ............. I%1 ......... ............ ........... t ........................... J .................................... 1 .................. ! ( BIT ii SIZE TYPE OFF FTC HRS FTIHR RPM WOB I0 B LB O OT R C:PF COMMENTS (' BIT# SERIAL# PRESS. GPM dETS TFA ANNULAR VELOCITY BIT ~1,111,11 ~,l#,llt,l.,lll,lll,ll~,;l~ fl,lll,~[i,lii~lll,lll,lll~ ~,lllrlrl~ I~]ll,tll,n pile,lit,01,111, ~ ~ I~1,~1~,111,11;,~ I,III,IIl,l[I,[)i,~ll,~ll,lll,l)~ III, HI,I)I, ~1,[I y;[~ IIl,illr~fy II~ll],lll,lll,lll~ ffll]l~tl~ Fr ~l~l~llfl i,lll,lll,lll,l[l ~,]tl,~l,lly iil,lly iil,ll[,[]l~lll,l(i, U i f i]l,lll,lll,ll],ll~,lll,~lt'l[IrU;,ll;,[~,lll'lll'l BHA: t B/; MSDGHG, Downhole Mo;or, $mb, MWD, Pul=er, XO $ub, 3-HWDP, Jam, E3-HWDP, XO $ub, Length: DRILL PIPE DESCRIPTION: Drlllplpe ;;1, MAX PULL: ~ ' JAR~ MWD MOTOR TORQUE WEI;3HT ~'~'1~r~s~'~'s["~1~'~1~r~"~"~r~"~[~"~"~"rr'~'1~1~1~]~1~'~$~r~1~1~s'~'1~1'~"~'~""~1's~n~1~')1s~"~"[~'s~'~n'~1~1~r~1~"~]~1~1~'~1'1~"~1~'~r~'~' [ ,m,, ,.,~, ..... , ,,,,, ,lll,.hl~.llh.h ,, ,, n,,, ,~,,, * ,, ,.,,,,, ,, ...... *, * *,,, ,,, ....... ,,, ,~,, a ..... , ,,,,,, [ MEA. DEPTH ANGLE DIRECTION TVD VERT. ~EC. N/S E~ DOG LEG 825,00 8,7~0 f 87,60 822,05 ~7.26 ~7,28 -f0,23 2,~ 852.00 8,500 150,10 ~7.03 -~.84 .~,84 -3,47 2.07 f, 074.00 8.~0 f35.50 f, OO&3f -79.06 -79.06 7.29 f.75 ii,lll,.,.,,.,..,,,,,.,,,,.,,.,.,,,.,,,m,,,.,.,...,,,,,,........,,,, ,,m,,,,,,,,,,,,,,.,,,,,,.,..,,.,.,,.,..,.,...,,,..,...,,.,,,,,, ,.,,,,,,,,,,,,,lll,llt,ll~,lll,flt,lt~,.,,,,..,,,,,,..,,.,,,,..,..i.,i., ,.,.,,,,.,,.,.,.,,a.,,.,,.,...,.,.,,,,.,,.,,,,,,,.,.,....,., ..,...,.,.,,.,.,,..,,.,.,,.,.,...,,,,,,,..,.,,,..,,,,.,,.,,.., ~,..,.,,,,,,.,,.,,.,..,,,.,,,,,,,,,....,.J....,,,,,.,.,,,,,,,,,,., ,,...,,,,,,..,.,,.,,,,.,,,,,.,,,.,,~...,.....,,,,..,4,.,,..,,.,, ,,,..,,.,,,,,.,,,.....,.,.,,,,.,,,,,.,,,....,,.,....,.,...,,i., ~ OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 8:00 7:30 f,50 I DRI~ MAKE UP, AND ~TAND BACK 5" HWDP 7:30 ~0:30 3.00 ~RAP AND PICK UP BHA ~, CHAN~E MOTOR ~/N~ ~0 ~ D~RE~. CHAN~ f0:30 ~ ~ :30 f. O0 ~A~ BO~OM A~ 37~ BREAK C/RC w~O ~PM AND 600 P;/. DRIC~ 37'- ~' fl:30 f2:00 0.~0 LOAD MWD 700L AND 7ES7 SAME. f2:00 23:00 f f. O0 'DRILL f7 f~' HOLE ~- 23:00 0:00 f ,O0 CBU, PULL f STAND AND CHANGE SA VER SUB IN TOP DR~E TO 0:00 ~:00 6.00 DRILL a79'- 1230' ]]~llllilll~[hl]lllit[iltlllhlliltBl[i)llhllhlll~[ [llBtlhHhllhllhlflllll~lllllJ[i]lldll~[~ll]llll~l Ihllhllhllkllhllhllhil;t[thllhllhllhllfflllfllh ~t~k~i~i~[~[~t~i~[~t[~[~]k~i~[~1~;~;~1~[~i~1~1~]]~i~[[[~[~;~;~;i~[~j~]~1]~[[~1~i~[~)~]~i~;~E;~i~ ~id~h~i]~t~h~;h1i;~h~i[~h~h~1~h~;~h~h~h~;i~)~h~i~i~[H~h~H~h~i~]~h~(~{h1]~h[~hi~k~i~Bd~h~[~(~h~hi~hi~h~j~[~d~1]~h~h AFE; DH T~T/C~G COMP TOT LAST PIT DRILL DATE; 01~1~0 Iiillla;]llillliillilll;lll;~ up CO~T~ ~c~ii~ii~t~;t~f;~i~i~i~t~;~iiii~iifi~i;~[~ W~LL CO~T~ ACTUAL llt[lllllli[lli;l]~ LAST BOP TE~T DATE; 01~1~0 DAI~Y: 3~30 ~UM: 3/130 DALLY: 3~ZO0 GU~: 2~033 NO AGCIDE~S REPORTED TODAY DRILLING SUPERVISOR: RIOHARD GIDEON NT BY' GLACIER DR~'LLI'NG COMPANY; 907 283 1313; JAN-21-01 '/'54; r~'Au~ 1/1 , Oil Company AFE~' 92037~9 GL: . KB: . MOCWI: . WELL: KBU4Z-T Rl{3:GlaclerDrl/lirljTR/j7 ? FTC: ~3~ DEPTH: (MD) ~,75~ CSG SIZE: 20.~00 CSG MD: f37. CSG ~D: f37. SHOE TEST: MAX. 81 0 LIN~ TO~ , ~RB~ENT OP: RUN f3 3~" C~IN~ DRILL AND SURV~ 1Z30' - 1~0'. GBU. ~PER T~P TO B~. GBU. POH ~H ~. RI~ UP AND RUN 13 3~" ' EXECUT~E OA~IN~ ~UMMARY [~W VIS PV YP OEE~ WE T /,b 3U HT PC CEC SAND SED BENT ~ALT DRILLED BARITE , COIL WTR' pH Pm ~ Mf CL CA LIME MUD LOSSES {bbl,} BKGD CONN TRIP MAX o.o I,S.o a.o /o.o o.o I o.~ I ~so au/ l,a,y =am / / ( BIT~ 81ZE TYPE OFF FTC HR8 FTIHR ,RPM WOB IOD LB G OT R CPF COMMENTS C BIT~ SERIAL~ PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP~ · RR3 ~NO~2, I ,3~0 I ~20 I ,~,~,6,2 I 0.7~0 [ i,ii i ~ III'R Iff Ilflli[l[l~lll'lrl'R I']Ii'III'UI'IR'IU ~'R I fl I fill'lift R ff IP Ili'fl'H ~III~I'III'III'R t'lll'l~['lll' Ri'II ,~['lR,IIr i~l,a i,lll~t R ~llr [11'11['111,~ ~,la,II R t'~II[' H I'III'RI' R I'I~I'R ~'lllq11'~ll' I Il'lllqlrlll'liR IR'il I'llrllRIII 'IIP111'R R Ill' HI' I II'R I'lll'lU' II I'111' I I1'1~'11 F R~lli 'iR'iR '1~ 'RI'IIi' Ri'ill' II1'11i' IR'Ill,ltl' m~l q~R I R'llt'R fill'ltl' il iR I IqR' tlr'ill'Ill'ill' IR'ii Iq[ri ii 'IR' RI' II I~1 I1~1[1'1[~'111' IR'I~I[I ~111~t[l~lli'llPI11'lll'll r ll R IR'Ht"IR 'III'II~'R i qlrllr R I' Ill'Ill '11['1 I1' II1' Ill'IR R Il' l ill}}Pill'lll'lll' i~'11~111' IRRR' II1' II1'1 Il'IR' ,l~ll BHA: t Bh M3DGHO, Downho~ ~mr, 3[ab, MWD, Pul~er. XO 3ub, 3.HWDP, Je~, a3.HWDP, XO 3ub, Length: 880,~6 DRILL PIPE DESCRIPTION: Drlllplpe ~1, MAX PULL' ~ JARS BWO ~OTOR TORQUE WEIOHT (1000} ~''~'"~'''"~''''~"~'"'"~"''"~'~"""~"~"'["''"~''''"~''"~`~'''~'~''''"''~'~'~"~''~''''~~~"''''''~~~"~""'"`'~"'"''~"""'"~"~"~~'''~''~~'''~"`~"''"'~"'"'''"""''"''"~'~~"'""'''''"`""'"''''''"~"~"''"'""~"`~'''~"~'''~"~"'"'''"~1~[~'~"~`"'~'''"'~'""`'~T~ ............. "`'"'~"~1~ii~ii~11~P''"~''`~"`~"'"''"~[~"'~~"~~~''"'''''''''"'~1ii~'~"'~'''~'"''''""~"~""""'"~'''""""'"~'"~"~'~~""'~'"''"'"['~~'"~'"'''~~""""~'"'~''~"~``''~"~ "'''''"'*"''"''"'"''''''''''"''' ~MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS E~ DOG LEG f ~S f 3,00 lO.g00 f 3g,~O f /~Of .55 -f 28.g3 -f 28.g3 57,27 ,,, 1,010.00 13.040 130.80 1,5~0.~ -143.87 -143.87 70.73 f, 706.00 f4010 f43.80 f, 689.77 -f6f.f8 -fOr. f8 85.04 2.02 ~ OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 f~:30 8.~0 DRILL AND SURVEY f230'- f760' ' f~:30 ~6:00 f,50 PUMP HIgH VI~ ~W~P AND CIRCULAT~ HOLE CLEAN' f6;O0 fB:O0 2.00 ~PER TRIP TO B~, OLEAN SHALE OFF B~ AND STABIL~ER; fg:O0 20:00 f.O0 RIH ~H B~. NO FILL. ~0;00 2f ;O0 f.O0 PUMP HIgH VI~ ~WEEP. 29:00 0:00 3.00 POH ~H B~. PULL MWD ~OOL. LAY DOWN ~OP $TABIL~ER. o:oo ~:oo ~.oo R/~ UP ~o RUN f3 3~" GA~/N~. FUNGi/ON ~AF~ VAbVE. HE~D PRE-JOB ~AF~ ME~ING. 4:00 ~:00 ~,00 RUN ~3 3~.. CA~ING, Itlllt~ihl[lf[Ih~l~dlhll[ltlhi{hllHIkllHihl~l [hHhllHIhllhll~llth[lll~l[dlhllhllhllhlthll hllhl;lllHIIIhlHIIIhflhllhlllllttll;~hllhlll' ~[~i~i~[~1~;~1~;i~1~1~1i~;~[~;~]]~11~1~f~t1~r~;t~a~[~)[~ii[~;~t~1~[~t~)~;~a~t~[~t~t~ ~1d~k]~h~ht~h~1~h~h~h~;t~]~{~H~d~h~;~dih~"~1;~h~h~i~d~t~iHN~h~t~RRRR~R~R~ht~h~h~h~1~;d;h~j~1~;~iHHd~hti~[h~h~h~h~;~ AFE: DH T~TICSG COMP ToT LAST PIT DRILL DATE; 01~1~0 MUD C ............. CO~T~ A TUAL WELL ~lll[lll~ltt[ll]~tlt~tl~il!ll~l~[tll!tlt~itl!~ll~ltt~ ~ii[[i~ti~i~t&~i~ii~[~t~i[~[[~t~i~ttt~i~it[i~i~i[~1~i~[~i~i~[[i~i~[~i[~ ' , ACTUAL ~tlill~lt~il[[!itl~llt~lll~tt[[li= LAST BOP TEST DATE; 01~1~0 DAILY: 3~967 CUM: 7/117 DAIEY: 34/132 CUM: 249/1~5 NO ACCIDE~ REPORTED TODAY DRILLING ~UPERVISOR: RICHARD GIDEON NT BY' GLAOTER DR"rLLTNG COMPANY; 907 283 1;313; JAN-22-01 6:42; PAGE 1/2 ., Marathon ,~( 0 DATE; 0f/22/0f LOCATI~, ~(' 4 SPUD DAYS: 3 Oil Company AFE#' 9203?99 GL: . KB: . lVlOCWI: . WELL: Ir, Bu42.7 All3:Glac/erDrillin~7 Rl~7 ? FTC; DEPTH: (MD) ~,T~g (~D] ~8G S~E: f3.375 CSG MD: f.750. CSG ~D: f.732. SHOE TEST: MAX. SI 0 LINER TOP: . PRE~ENT OP: WEL~ ON W~LLHEA~ RIH ~H ~AB IN A3~EMBLY AND 4" DP. CIRCULATE AND CEME~ 13 3~" CASING ~H 734 SX CEME~. EXECUTIVE NIPPLE DCWN D~ER~ER AND WELD ON WELLH~D. SUMMARY ~OIL WTR pH Pm ~ Mf CL CA LIME MUD LOSSES ~bbl~) BKGD CONN TRIP ( BITe SIZE TYPE OFF FTC HRS FTIHR RPM -WOi IDB L B G CT R OPF COMMENTS ~ BIT~ OERIAL~ PREO0. GPM JETS TFA , ANNULAR VELOCITY BIT HP) BHA: Length: DEILL PIPE DESCRIPTION ' ~AX PULL' I ~ JA~ MWD MOTO~ TOK~UE' WEIGHT (1000) I I i i i ~MEA. DEPTH ANGLE DIRECTION TVD VERT. eEC, NI~ E~ DOG LEG ~ ;5 ~ 3.00 ~ O. gO0 ~ 39.~0 ~ ~50 ~.~5 -~ 28,93 , ~ 28,93 57,27 ~.2~ 1,610.00 13.040 136.80 1,5~0.~ .143.~7 -143,87 70.73 f, 706.00 f4070 f43.80 f, 689.77 -fSf.f8 -fGf.f8 85.04 ~ OPERATIONS IN SEQUENCE START END HOUR8 DESCRIPTION 6:00 7:30 f.50 RUN ~3 ~$ f3 3~" 68~ K.55 AND L.80 BTC CASING. LANDED AT i 9;30 f3;O0 3.60 RIH ~H STAB IN ASSEMBL Y AND 4" DP, STAB I~O FLOAT ~OLLAR A~ fT06~ ,,, f3:00 f3J30 0.50 CIRCULATE HO~E f3:30 f~:O0 0.50 HOOK UP CEME~ LINE AND PRESSURE TEST TO 3000 PSI f4;O0 rS;f5 f.25 PUMP 40 8BL PREFLUSH FOLLOWED DY 724 SX GLASS I ~EME~ ~H 20% Lw.6, MPA~f~ f% SMS~ f.5% CAL.CL, .3~ CD.32 M~ED AT f2.0 ppg AND w~.5 CU.~./ DISPLACED ~H Rf.5 ~L MUD ~H ~J ~RUCK. DID NO~ ~EE PLU~ BUMP, DISPLAOEME~ WAS fa.S 8BL w~ BBL. SHOE JOI~ CAP. CHEOK PLOAT. 1~:1~ ~6:00 0.7~ UN~IN~ FROM ~AB IN F~OAT CO~AR AND PUMP 2 ~BL MUD. DID NO~ ~EE INCREASE. PRESSURE. 10:00 18~00 ~.00 BREAK O~ QEME~ HEAD. POH ~H 4" DP AND S~AB IN SUBS. FOUND PLUG IN PLUG CATCHER. HYDRA ULI0 SYSTEM, OHANGE PUMP LINERS TO IIIIIIIl)ll~llllllllllll~lllll~]ttl~lt~)lil~llll[l[llil Bll[~ltlllIH)lllll;ll)l]lliillll~bl~[lll)lllltlllll~ Ii[BItlllllllllillllll~)lllllIHIIIIl[llll;~lhll(llll) ~;~ii~1~i~i~;~i~]~i~i~i1~it~i~;i[~[~i~i[[t~t~1~1~;~1i[~i~1~i1~1~1~h~ti~1it~ii~1~[t~i~[~f~ti~1~i~i~1~n~t~f~i~[~t[[t~1~1~i~[~t~1~t~t~1~1~1~[~ ~1i~i[~[)~i1~t~1~f~;t[~i~[~1~;~t~i~it~1~i~1~ii~[;~[~[f~1[~t~1f~i~j~t[~[[~1~i~i~1ii~ ~FE; DH TST/CSG COMP TOT LAST PIT DRILL DATE: 01~1~0 DRILLING SUPERVISOR: RICHARD GIDEON NT BY' GLACII=R DRI'LLING COMPANY; 90?' 28~ 1313; JAN-22-01 ~:4~; W.ll: K~U ~2-7 (': (' Op~r~tlon~ cont Da~: 22-Jan-O~ ~EQUENT~L OPB~TION~ (RBPORT TIGHT SPOTg, LOC. TORQUING UP PROBLEMa, ETC.: ~TART END HOURS DESCRIPTION GA$1N~3. 5:00 0:00 1.00 SET ON AND PREHEAT 13 $/~" WELLHEAD. ,., , ,.. . , .... , . ., .,, .,, ~IT BY' GLACIEF~ DRTLLI'NG COMPANY; 907 283 1313; JAN-24-01 6:42; PAGE 1/1 Marathon 0. DATE; 01/~4/01 LOCATION, ~ 6 SPUD DAYS; $ Oil Company ARE#: 9203799 GL: . KB: , MOCWI: WELL: KBU ~Z,-7' Rll3: Glacier DrllllllEl RIEl ? FT{3: 4/'6 DEPTH: [MD) Z, Z3~ (TVD) C~BG Sl2E: '13.$75 CSG MD: f.?50. CSG TVD' f.732. SHOE TEST: f5.60 MAX. SI 603 LINr=R TOP: , PRE~ENT OP:~RILI-IN~ AHEAI~ GONTINUE ~0 TE~ BOP AND RELA~ED EQUIPME~- MA~ UP BHA AND ~H . PIGK UP 4" D~LL PIPE TO EXECUTIVE D~LL N~ HOLE ~EC~IQN - ~H AND D~ F~OA~ EQUIPME~- PREFORM ~EAK OFF ~E~- SUMMARY MUD S~EM~O PLO.PRO - DIREC~ONAL DRILL ~HEAD (OIL WTR pH Pm Pf Mt CL CA LIME MUD LOSSE$ ~bbl~) BKGD CONN TRIP M~ ~ o.o I~.o/ ~.o /o.9 o.9 / o.~ I ~oo I ~S°l I~n~ ~um I / / ( BIT~ SIZE TYPE OFF FTC HRS FTIHR RPM WOB IO D L B G CT R CPF COMMENTS C BIT~ SERIAL~ PRESS. GPM dETO TFA ANNULAR VELOCITY BIT HP~ BHA: ~ {~ {/4" OM~H ~OD~L, MA~H { ~ MOTOR AKO .~, ~" OTAB, MWD, PUL~ER ~U~, X~ OU~, 3.$" HWDP, Length: JARS, 23.5" HWDP~ X/O 88~5~ DRILL PIPE DESCRIPTION: a~O Jrs- 4" DRILL PIPE, MAX PULL: I ~.o (~azz.o~71 ~.o l~o~o~a] ~.o l~o~ I ~,~oo~#~s [~,A: 'Pu~ ~ ,o~- a~ ~ a~ ~ (~EA, DEPTH ANGLE DIEECTiON TVD VERT. SEC. NI~ E~ DOG LEG f , sgg. o0 f6.860 f48.00 f,875.30 -202.7f -202.7f fff.gg f. f3 Z,024.00 17.810 148.80 1,~5.~ -~33.5~ -~33.5~ 130.~ 1.5~ 2, fSf. O0 20.2f0 f49.60 2, fl6.00 -269. f2 -26~.f2 f52.05 f.gO ~TART END HOUR8 DE$CRIPTION 6:00 g:30 3.50 CO~INUE ~0 ~E$T BOP AND RE~ED EQUIPME~ AT 2~0 P~I. LOW AND 3000 P$I HIGH g~O ~0~00 0.50 IN~A~ W~AR RIN~ - ~A ~ DOWN ~ JOi~ ~ IN~A~ 5" ~VA~OR f f ~O0 f3~30 2.S0 MAKE UP f2 f~" DRI~UN~ A~EMB~ ~ AND RIH - ~URFA~E ~E~ MOTOR AND MWD f3:30 f8:30 5.00 PICK UP AND STAND BACK 80 $TAND$ OF 4" DRILL PIPE FOR DRILLIN~ ~0 rS;30 fg;30 f. O0 GIRGULATE AND GOND~ION THIGK MUD IN HOLE fg:30 20:30 f. O0 RIH TA~ FLOA~ COLLAR AT f703' AT f745~ WASH TO BO~OM AT f760' 22:30 23:00 0,50 PREFORM LEAK OFF TE$~. EMWAT 15,0 PP~ 23:00 0:00 f. O0 DISPLACE MUD $YSTEM~O FLo.PRo 0:00 0:00 0,00 DIREGTIONA~ DRILL AHEAD PROM 1760'T0 2236'- ACTUAL ~UDE TIME ~.G HOUR~ . ACTUAL ROTATING TIME f.25 HOURS . ACTUAL SURVEY TIME f.0 HOURS Ilrllll~llllllllllllll*ll~llllllilllll~llll~[~lllllll~lll IlllllllJ~llllll~lU~llthllhllllllhllflllhllhlll~ll II[Ihlllllll~llhllllllhlJllllllllllllhll~ll~t,~[ll~l ~i~i1~i~i~ifi1~iii{~1~1~1~r~[~t~1~i[[~it~1~*~ii~i~i~Ri~i~i~{~1i~ti[~ti~{i~1~=ii~if~i[~1~t~i~i~t ~h~H[h~i~h~h[~i1~[~h~h~ii~1~}"h~i~i~h1~1~i~[[~h~h~h~[h~h1~h~}~t~h~r~t~h~d~h1~h~[d~h~k~h~it~h1i~1~]~d~[~hi~i~i~t[t[~id~h~h[~ ~FE; DH TSTIC~G COMP TOT LAeT PIT DRILL DATE; 01~3~0 MUD ACTUAL ................................ Ililllilll!lllil~l!lllilll~lll!lllilll~lll!lll~l~l~lJl~lll!l CO,TO ~]~i~i~i~i~[i~i~i~i~i[~i~[i~i~i~i~i~i~i~i~""~i~i~i~LL CO~T~ ~cru~Clllilllilll~lll!lll~l"ill[illl, LAOT BOP TE~T DATE;01~3~O DRILLING SUPERVISOR: DARRELL GREEN JAN-25-2001 THU 08:49 AM M~R/~THON OIL OOMP~NY tViarati~on Oil Company WE. LL: KBU 42.7 LINER TOP: . FAX NO, 907 283 61f5 ,. ,~.' 9 DATE: 0.'//2.~01 LOCATIO~ f 7' SPUD DAYS: AFE#: 920379..9 GL: _.. KB: ,_.._ ~OCWi: _ CSG MD: f,750. CSG TVD: 1,732. SHOE TEST: 15.69 M~. S1 567 ~,~ ~ ~ , , ..... ,, = ,,.- _,. PRES ENT DP ;DRILL A HEAD ......... DRILL AHEAD TO S, 455'- puMp O~I~' OF T~tE HoL~'TO 13 3'/8" CA'sIN~ SHO~ ~T 1,75~"'- ADJ'U~T TOP DRIYE ~ Ex~ctmV~ r, WL- CIRCUUYrE ~O~O~S U~- Rm- ~ILL A~ ~O 3,~' SUMMARY ' ~"*""~ '~ -' - , , ,, ' i -- r~:: ~ I~'V--':YP' ''(~'~[S WL- T ~:5 3(~' HI FI; CE~:' SAND --SLD AENT ~ALT DRIL'LED B~RITE ([)IL WTR ~H Pm Pf Mf CL CA LIME MUD LOSSES{bblift) BKGO CONN TRIP MAX , ~"I"~~---~--~-~-"-'~,~'-- 2'~ -32;0001 560 '?;i;ily --" cun~ .... 25 'I .... 25 _.:_~,.= ....... =_.,',____L.' ! ..... I .... , I · I I .., "B~T~# ~b2-~.: ....... ~'¥PE ' "--OFF ~bTG - has FT/HR RI[M' k~/6B ! O O L B G O'T R "~PF ' COMi~IENTS ~ BIT g SERIAl. ~ PRESS. GPM JETS TFA ANNU~R VELOCITY BIT HP Length: ~ JAR~;, 2~.5" HWDP, X/O SU~, DRILL PiPE DESCRIPTION: 2~0 Jts . 4" DRILL PIPE, MAX PULL: '~L'. . .,~X~--. ................MWO' ....... ' ........... ' ..... MOTOR'"'"" "' ........ '*" ...... TORQUE--"-'--- "- .... ' .... '~'WEIGHT' ......... {1000)'"- ....... '"~' ...... ' ..... __ ~~~EPI~ ANGLE DIRECTION TVD VERT, SEC.- NIS E~ DOG LEG~ ' ,~,i~&~ -i~.~0"l '"~o.~o ~' ~,~,~7 I--'"' -7~-~ I'- -7~S'.~ I" ~.~ / o,~' ?==.=~.-.=.~=-: ...... , .... ~ ....... . .... ~ ..... _ ,,---~ii~~-~~~,i~ .......... ,~ ,..~.--,,._ ...... ,. ,,,,= START - .. ~.~. ~.~ 6:00 21:00 23:30 1:30 $.'00 END ....... ~. ,~-~-- ~ f:O0 .... ,~..~ 23:30 1:30 , 3:00 6200 HOURS 15.00 2.50 ZOO 3,00 DESCRIPTION CONTINUE TO DRILL AHEAD FRO.M,.,2237' TO 3455'. ACTUAL ROTATING TIME AT ~;.75 ..... SERVICE RIG AND TESCO TOP DRIVE. CIRCULATE BOTTOMS UP. ADJUST TOP DRIVE ~...~, .. ::: ~ .v,~--.-----i-..~. = ,J , . ,~,.----- TOROU~ TU~E (NOT ov~e .OLE) ;SLIDE TIME AT.5 HOURS ~F'E: DH 'TSTICSG ~..T,.-t,,,.-~~,;- , _..,-----:_....,:': ........ COMP TOT ~,MdD CO~T~ ACTUAL .......... ' "]'.WELL CbSTS ~.C:i'UAL DALLY: t7, t¥)'' CUM:' 2.~:~;~a' DAILY; 43,~06 CUM: 523,426 ~'-I~iI~[.I~J'(?~L~P~?~'~R; DARRELL GREEN LAST PIT DRILL DATE: 0t/23/00 LAST BOP TEST DATE; 01/23/00 NO ACCIDENTS REPORTED TODAY .~.~ Ul/Ob dT BY: GLACTER DRTLLTNG COMPANY' 907 283 1:313; JAN-2~-01 6:56; PAGE 1/1 Oil Company AFE~' ~2037~ GL: . KB: . ~OCWI: . WELL: KBU42-7' RI{3:GlaclerDrlllinJTRiJ7 f PT{3: ?,OOZ DEPTH: CaD) ~,000 (~O) CSG 8~E: f2.275 CSG MD: f.750. CSG ~D~ f.722. SHOE TEST: f5.60 MAX. 81 LIM~R TOP: , D~LL AHEAD SUMMARY ~-~ I'~1 ~ I~Sl ~a / 261'-01~1 / I 12 132 0.~ I 5-21 I 9.8 PPB 70.2 PPB PPB :~OIL WTR pH Pm ~ Mf CL CA LIME MUD LOSSES ~bbl~ BKGD CONN TRIP MAX ~ BIT~ 81ZE ~PE OFF FTC HRS FTIHR RPM WOB IO D L B O CT R CPF COMMENT8 ~ BIT ~ OERIAL~ PREO0. GPM dETO TFA ANNULAR VELOCITY BIT HP~ II~ I'IHIIII, I II'lll'lllllll'lll'lllllll,lll,[I ~lll,lll,lll,lfl ,l~l,lll,l~,~ll,lll,lll,l~l,lll~l~l,lllllll,~ll,lll,lll~ll~lll,ll ,lll,l~l,lll,lll~ll,~ I,IIl,lll,lll,lll,lll,lll,l~t ~l~lll,lll,lll'lll'lll'lll,lll,I ~,~11 ~'~'~l~'~'~'~l.l~.l~'~l'~.l~'~l'~.~'~l~.~l.~.lll'~'~'~'l~'~'I~'~ll' ~ ~'~'lll'~l.lll'lll'~.~l'~].~'~'~l'~.~l~'~'~l~'lll'~'~l.lll'~'~ '~.lll'~'~'~'}~l'~$~ll~'~l*~l'~'~l'~l'l~'~'~'~l~*~'~l'l~l~'~l*~'~l*l~['l~'l~ P IIl'l~l~ll'lll~ll'lll'lll'lll'l ,~l~l I ~'lfl'lIPI H 'lllgll'lll~ll 9 a 91P ~ m BHA: 2 ~J fl4" SM~H ~SOD~L, MA~H ~ ~ MOTOR AKO .e, fi" STAB, MWD, PULAEA SUB, X~ 3~, 3-5" Length: JAR$~ 23-~" HWDP~ X/O 882.53 DRILL PIPE DESCRIPTION: 210 JrS - 4" DRILL PIPE, ~AX PULL: [d~h~h~p~h~b~h~lId~]~b~h~h]~d~J~h~h~h~*[~h~h~*~d~d~h~h1~Hh~h~h1~M~h~h~d~d~h~h~hHh~h~h~h[~hHh~h~d~d~h~]~h~huh~[~hm~pd~hr~h~?~hur~Hd~d~i~`~[h~h~.~[~i~h~`ii~f~h~h~h~d~h~]~hm~h~d~h~b~1~h~h~h1~hHh~11~h~ih~h~h~h~M~hHh1~h~h~i~h~h~h~h~]~d~`~h~`~1~[H~bm~h~h~M]h~d~Hh~h~h~[h~d~ (~EA. DEPTH ANGLE DIRECTION TVD VERT. ~EC. NI~ E~ DO6 CE6 ~Og. O0 f7.700 f~9.60 ~, f ~7.g9 -f,076.55 -f,076.55 629.86 f.83 4,470.00 1~.77~ 15~.~0 4,~.~5 -1,08~.33 -1,08~.33 ~3~.~ 4,53f.00 f5.650 fSf.90 4,284.82 -f, f07.37 -f, f07.37 ~O.~ f.84 Iqmmm;IPll~mNmPlrPmlm,mlPmu,mm;llmllpmm~lmqllqmmmmtmqmmmmm,,mmmmPHmm m;mmmmm,,Hmm;m;~mmmqmrmmmmqt~*m[mmmmm,tmPlmm,mml,mmmmm~mmmmmm;,mmmmrmmm;, m*mmmmmmt*mm,qlpHmqllq~Pmmm,mmPflm~mmPmmm,m,mqmm,;mm*mmtqHqllm~mqlp ~NPmmPmmPmmm,m;m,mmm~,ltqlmmmmllPlllmmqllmmqumlllmmu,m;mqllmtu, m m,m,m~l,mmllmql~mmqtlqllqlPmq]mmm;im,mmmm,m;,,mummmmmmmPmmmq~mq;m~m ,mmll,lt[qml,lU,lllqflqllqlPlllmllimi~lmlttmmt~qmmmummmrm*mmm'mtpmmm'mmm ~mqmmmlrmmmmpmm;*mmPll;mlll~ltmqllmlll~uumml,lml,l;m,ummulmmummqru]lm START END HOURS DESCRIPTION 6:00 6:00 2~.00 DRILL AHEAD FROM 3~6~8'70 ~680'. ACTUAL ROTATIN~ TIME AT f2.76 HOUR$ - m A C~UAb ~IDE ~IME A~ 6.5 HOUR~ ~mahmm[mmJmm~mmmmdmmm*~mmmmmmfih[mmmmmhmme~hlml mmmmmmmmmlmlmmmmmma~m~emmmmmmmmmm~*e~mmemmemmmmmmmmll hmmmmmmmermmmme~mmmm~lm*mmmmmmmmflhmmmmmm*mmmh ~1m*e~m~m~m[e~m*~j~1~me~*~1~J~a~a~e~eea~*~m~1~m~e~m~m[~&~m~m~ee~m~[~t~em~eeme[~me~m~*~e~a~mam~m~1~e~e~m~*~e~m~mmJ~m~em ~mm~hm~e~Hd~e~*~1~h[~mm~a~11~h~m~m~m~m1~ee~m*m~m*m~m~m~me~mm1~m~1~m1~jm~1~m~m$~a~d~m~m~*~m~hH~m~h~e~m~m ~FE; DH T~TICe~ COMP TOT LAST PiT DRILL DATE; 01~0 MUD ............... CO~T~ ACTUAL ........ [ lll!],!rllilll lll!lll!lll!lll[lll!lll!]ll!lllJllrill il CTM L IlrilU!l[l!lll!lll!lll!lll!lll[I LAST BOP TE~T DATE;01~3~O DAILY: 11~21~ CUM: ~0~7~0 DAILY: ~1~1 CU~: ~90~T~9 ND ACCIDE~ REPORTED TO~Y DRILLING SUPERVISOR: DARRELL GREEN NT BY' GLACIER DRTLLTNG C0MPA~~v' 907 283 1313; JAN '"'-01 7':41; PAGE 1/1 Marathon ~'~'"" If DATE; 01/27/0f LOCATION Dj~'' 9 SPUD DAYS: Oil Company AFE#' 9203799 GL: . KB: . MOCWI: . V~rELL: KBU ,~.-7 Rl(3: G/ac/er Dr/I/lng RiJ2 ? FTI3: ~39 DEPTH: (MD) ~,699 (TVD) C~G SIZE: f3.375 CSG MD: f,750. CSG ~D: f, 732. SHOE TEST: f5.60 MAX. 81 567 LINER TOP: EXECUTIVE TO ~egg'- CIRCU~TE LCM ~WEEP~ - MON~OR WE~L AND ~UILD MUD VOLUME - POH TO 3~3~'- PUMP SUMMARY O~OPTHEHOLE~Q~PROM3,3~'TO3, f~'.POHTO f33~"CASINQSHOE.BUILDLCMPILLPOR ~A GING IN HOLE · .~ I~1 ~21SI 2 / S 1~-21~1 / I I 2 132 0. f I 5.6 I I fO.3 PPB 6f.3 PPB PPB COIL WTR pH Pm ~ Mf CL CA LIME MUD LOSSES ;bbl,} BKGD CON, TRIP MAX Of ~ 3 g 5 O ~ 03 3 ~ 3f, O00 280 dally cum ( BIT~ 81ZE TYPE OFF FTG HR8 FTIHR RPM WOB IO D L B O BT R CPF COMMENT8 { BITH ~ERIAL~ PREO0. GPM JETO TFA ANNULAR VELOCITY BIT Hp.~ Ll~lll'lU~ll~'ll~'tfl'lll'lll~lll'tll~ll~fii~llrlll'lll~ll,l,, ' ' I'[[l'lll'l[l'lll'lll'fll'll~lll'l~'lll ....... r ........ ~' ' ~lll'll)'lll'lll'lg'fll'lll'lll ...... ~ .... ill' ' ', ...... ~ ...... rltl'fll,lll,l~rll fl'l~l'ltl,lelll'ltl'~l'fll,tll'fll,lll ...... h~r~`~'~r~'~1~]~[~P1~i~H`~i`~`i~'~r~[~[~r~r~`~'~"`~r~'~r~'~i`~ii~i~`~]~'~'1~`~['~`~ BHA: 2 ~a ~/4" 3M~H ~530DOL, MAOH f O MOTOR AKO .8, ~Z" 3TAB, MWD, PUL3ER 3U8, X~ 3U8, 3-5" HWDP, Length: JARS~ 23-5" HWDP~ X/O 88~,53 DRILL PIPE DESCRIPTION: ~10 Jts. 4"DRILL PIPE, MAX PULL (~EA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIB ~72f.00 f3.~30 f50.60 ~,~68.65 f~330.2~ -f, f4g.42 66g.~ f.36 4,784.00 12.400 151.70 4,530.07 1,3~.3Z -1,101.75 ~70.~ 1.68 4,847.00 ff.290 f SO.O0 4,5~f.73 f,357.25 - f , f 73.05 682.73 f.85 rrmq~lll;IqlPlllqll,rflqllllUllllllll,,llqfl,m,lllqll,lll,lllllll,lflqlll, i,iiiii;~llllqllllllqllqll,mllllllllllnllll,nlqlllHiqllllllqll,mql~ ~llnlllfl,lllllflll[iqllllllqllqll,~lqlllllPlilqllqlllllllnplll,llplflll qjll[ll,llllfllqllmllHiqllUipllplnllllqll,fll,[flqllqll,lllqllql], 'lll'~llqll'lllqllq;IqmHl'lU'lllqmlllqll']l(qllqllqll'lllqHq~lqll' i,nlqll,lll,;ll,lllllllltl~,lllllll,lll,;~lmPlll,[~,lll,fll,]]l,U~qllqfl/t[ ~ OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 g:30 3.~0 DRILL AHEAD ~,~6'~0 d, Tdf'- ACTUAL ROTATIN~ T/ME f.75 HOURS. ACTUAL SLIDE ~IME.T5 ~0 9:30 f3:O0 ~.60 PUMP HI-VIS SWEEP AND PUMP O~ OF THE HOLE T03,3~~ f3:00 f4:00 f,O0 RIH TO BO~OM AT 4~74f~ f4:00 fg:O0 5.00 DRILL AHEAD FROM 4~74f'TO 4~899'- ACTUAL ROTATING TIME f,5 HOURS - ACTUAL ~LIDE TIME A T 2.5 HO UR~ f9:O0 f :00 6.00 CIRCULATE LCM SWEEPS - fO0% TOTAL LOSSES - ABLE TO REGAIN CIRCULATION F~E TIME~ - BUILD VOLUME. MON~OR WELL - MUD LO~E~ AT f TO 2 BARREL PER MIN. . TOTAL LOSSES,AT425 BARRELS ~ :00 3:00 R. oo POH FROM ~fegg'TO 3~3~' N0 3:00 4:00 f.O0 HOLE TIG~ AT 3~3~'TO 3~f~'- BAOK REAM AND PUMP O~ OF THE HOLE - ~H FUfiL R~URNS ~:00 6:00 2.00 POH FROM 3~ f~'TO f3 3~" CASIN~ SHOE AT f ~750'- DRILL STRIN~ iNCREASED DRA~ Ihfil~llhllhllldlldlllflldlhllhlllrllhllhflh IIIJIrllhlfllllhlllrllhllhl~hllhlfllflhllHIhfll II~flhllhllhllhllhllhllhllhllhllhllhllh]lhilll ~i~i~i~i~i~i~i~i~i~t~t~*~i~]~*~i~i~i*i~i~ri~[~i~t~t~[~[~ii~i~j~t~*~ ~h~h~h~ih~h~hHh~h1~h~hi~h~d~i~h~h~[~h~h~h~h~h~h~i~d~tr~h~d~h~h~h~h1~h~hi~i~hi~hi~h~h~h~h~h~h~ih1i~ht~h~h~h~ ~FE; DH T~TIC~G COMP TOT LAST PIT DRILL DATE; 01~0 ACTUAL WELL =l~l~l~lll~ll}~lll~l~l~lll~lllJlll~lll!lll~lllilll~l~li[ll!lMUD COATS ~[~i~1ii~i~i~[~i~i~i~i~i~i~i~i~i~i~i~i~[~ii~i~[[~i~i~i~ COSTS ACTUAL IIl~lll~l~lilll~111~lll~lll~lllil LAST BOP TEST DATE; 01~3~0 DRILLING SUPERVISOR: DARRELL GREEN [NT BY' GLACTER DRTLLTNG COMPANY; 907 283 1313; JAr,' ~8-01 9:57; PAGE 1/1 ' : Marathon ,~ '~ DATE; 0f/Z$/0f LOCATI,.,,~ f0 SPUD DAYS; e Oil Company AFE#' 9203799 GL: . KB: . MOCWI: . '~/VELL: KBU42.7 RI(3:GlaclerDrllllnj~Rff7 ? FT(3: 40? DEPTH: (MD) ~,300 (~D) ~8G 81ZE: f3.375 CSG MD: f,750. CSG ~D: f,732. SHOE TEST: f5.60 MAX. SI 558 ~EEgENT O~I~C710NAL D~L AH~ - ~OPIN~ BUILD VOLUME AND LGM PILLS AT 13 3~" CASING SHOE- R/H ~AGING IN BREA~NG CIRCULATION PUMP SUMMARY C~W VIS PV YP ~E~S WE T /.~ 3~ HT FC CEC SAND S~D ~ENT ~ALT DRILLED ~A~ITE ~-~ I~1~1'1 ~ / 7 15.SlgZl / I i2132 O.f ] 6.6I ! 9.8 PPB 75. f PPB PPB CO~L ~R pH Pm Pf Mf CL ~ LIME MUD LOSSES ~bbl~} BKGD CONN TRIP MAX o.~ I~.~I ~.~ o.~ o.~ I ~'~ I ~o, ooo ~o Id,,y =am / ~ I I I ~1., ,,~.~,.~..:,,~.~,~,,~n,~m,~ .,...~ .,~ .~ ~= .~,~m.~m~.~..~,. ,m,~m,~ ..r,~ ~ =~,., ..~.,.,., ,~ u ~ ..~, ,. ,...,.,,, .,, .,,,~. ~.~R,,, ~,.~ ,~,,.r, .,,wr,rn,.. m.,~,,~ nh..,,aa ~.~.~,m ~ ,~ ,~. a.r,, n,m,m ,~.,,~,r., m,..~,h ,~m, .~ r,,m. ,ln,.~ ~,,~ ,~,,,,~,,,~m,,.....,,.. ~l,.,r, m, m.~l~ ,A,,,~,~,~,,,,,,iii ~ll~l~h~i MII~~ n,~%. ~,m, a,.~ ~.m~., ~ BIT~ 812E TYPE OFF FTC HRS FTIHR RPM WOB I0 D L B G OT R CPF COMMENTS ~ BIT~ SERIAL~ PRESS. GPM dETS TFA ANNULAR VELOCITY BIT I[~lltflll~lll~lll'lllqll'i~'lll'lllqllqll'lll'lllq~i'm'lll 'ilI'UI'IIPIIIIII' IIn'lll'l~'lll~ll'lll'lllqlPIIl'~il Ill~llqll~lll'lfl'ffi~lH~l[t'lll'lll'lllqll'lll"ll IIl'"l'Ul'lll'i~lll'lllqll'ill'[ll'lllqll'll~J ll'lllqEIIPlllql[I 'N'UI~III~I'III"III'III'III'Ili'IIWII'alPtlPIIRI~IIl'lll'l~'lll'lll'lll'lll' '111'111'1 ill'lll'l~lll'lll'lli'lll'ilPg ' ~ f '' ' ~ .... r~q~'~i~'~q~H~'~P~'~'~g~ii~f~'~Pi~i~i~r[q~'~r~Hq~'~'~H~'~ii~m~'~gq~q~P~'~q~q~r~q~'~i~`~'~q~R~i~ BHA: 2 TE ~/4" 3M~H ~5SODGL, MAGH ~ G MOTOR AKO ,8, ~" STAB, MWD, PUL3ER SUB, X~ SUB, 3-5" HWDP, Length: JARS/ 23-~" HWDP/X/O 8a~,53 DRILL PIPE DESCRIPTION : ~1~ J~S - 4" DRILL PIPE, MAX PULL ' g a~.s awa aOTO~ TO,aU. Wa~HT Ifllih I 114.illlhl;h rlhllhffl*[~llllalhUf,lfl hf iiiiiil~llll,lllllll,llrl~.la ~1111,11~11 .,1111111,11 IiIIl,lfl,lll,llr,,lltllll,l~ll,*lll,lll,l,l*lll,i ~l,rl,,r ~n~`1~1~i~1~i~]~11~'~[~]~1~1~*i~i~`~ri~r r ~*~1~'ii~*~1i~"~ii~1~`~1~1~n~.~ ~r~*~'i~'~]~t~i~'11~i~1~'~`~`[~1~`3~i~i~1~{~i~i*~1fl ~MEA. DEPTH ANGLE DIRECTION TVD VERT. ~EC. NI~ E~ DOG LEG d/972,00 9,280 fSO,dO ~,Tf~,~ f,379,~ .f~fg2, S9 693,7~ 2.20 5,033,00 8,4ZO 150,~0' 4,774,8~ 1,389.33 -1,~01,07 ~,3~ 1,4~ 5,096,00 7,500 fSf,00 4,837,3f f,398.05 -f, 208.70 702,59 f,46 ....,.,,.,.,.,,,,,.,..,,,,,,.,,,,,ll.m,.i,.~....,ll.,,..,,,,,,, .,,,,.,,.,,,.,..,..,,,.,,..,~u,..~.,..,.,.,,,,,.,....,,,.,. ,.,,,..,..,..,.,,,.,,,..,,,,,,.,..,,,,,..,,.,,,,,...i,.,,,,,,....,.,....,,.,.,.,,...,,,,,,.,..,.r,,..,,,,.,....,,,,.....,,., .,.,.,,,.,,.,,....,.,........,,.,,.,,,,,.,,.,,,,,...,,.,...... '.,'...,',,,',,....',,,',,..,',,,',,.,,,'...,,,I,,.,..,,,..,.11,.I .,I.,;.,.I,~1,.I,.I,..111,.,,..,,*.,.,,,.,,.,,,,,,.,..,,.,,,,.. ~ OPERATION~ IN ~EQUENCE START END HOURS DESCRIPTION 6:00 8:00 2,00 CIRCULATE AND BUILD VOLUME AT f3 3~" CASING SHOE- BUILD LCM PILL A7 fS PPB 8:00 f2:00 ~,00 RIH (~TA~/N~ IN THE HO~E) . BR~K CIRCULATION A~ 2~750~ 3~750~ ~dOO'~/S85~Tff' WHILE BRINOlNO PUMP RA~E ~0 DRILL RA~E- TlO~ AT 4,Sff~ WORK ~HRU AREA - AN~ REAM 70 ~/Sgg' WH/~E PUMPIN~ fst ~CM 30 BB~, P/~ ( MU~ ~O~E; A7 80 f 2:O0 f~:O0 2.00 WORK PIPE AT ~899' WHILE PUMPING 2nd LCM ~0 BBL. PILL . INCREASE MUD PUMPS 70 DRILL RATE f~:O0 0:00 fO. O0 'DRILL AHEAD FROM ~899'T0 5~205'. ACTUAL ROTATING TIME AT f.25 HOURS . ACTUAL ,, , I ~U~E ~/ME 6.7~ HOUR~ (OROPINQ AN~LE PER DIRECTIONAL PLAN) 0:00 2:00 2.00 PULL ONE STAND OIRCULATE AND TROUBLE SHOOT PLC PROBLEM ~H NO. 2 MUD PUMP 2:00 6:00 ~.00 DIRECTIONAL DRILL AHEAD FROM G/205"70 ~300'- ~R~NG ~0 DROP Illllllll[lt~lllh[l[lll]}[~llllhltldlhllhllhllhlll ll;I]ldfldll)llldrhllhllhllhlll~llhllhll~rilllll! Illlllll])llhllhl~hllhllldlhlfltllhlrhllhll[dl(i ~[~f~i~i1~i~fi~i~t~it~i~*~;~i]~1~1~i~t~i~ii~t~f~i~*~[~j~i[~][~1~;~(;]~t~d~1~t ~hi1i~;d~h~;h~H~i~h1~h~h~h~[~d~h1~[d~[~h~i1~1~1;~{~h~t~ht~h~h~1~t~h~h~h~h~h~h~*~i~h~h~h~U~id~di~d~h1~id~t~d~r~h~1h~d~1~]~ ~FE; DH TeTICSG COMP TOT LAST PIT DRILL DATE; 01~7~0 IIII]~IIIrlIIIIIIIIIItI[IIIIIIlllI[I[HIHIIlMM~ CO~T~ ~cT~L~i~[~"J~J~i~[~-~`~t~r~J"~L~ C~T~ ~cmUAL~l!lll!ltl;lllilli!llli[llilll;I LAST BOP TEST DATE:01~3~O DALLY: 22/927 CUM: 60~7~ DAIkY: 7~/743 CUM: 737/~00 NO ACCIDE~ REPORTED TODAY' DRILLING SUPERVISOR: DARRELL GREEN BY' GLACTER DRTLLI'NG COMPANY; 90?' 283 1313; JAN-29-01 6:23; PAGE 1/1 Marathon {'" f$ DATE: 01/2I)/0'/ LOCATI{,. ,~ ' l~ SPUD DAYS: '/0 Oil Company AF=~' 92037~9 GL: , KB: . MOCWI: , WELL: KBU42-T RI(3:GlaclerDrllllnJTRIJ7 ? FT(3: 259 DEPTH: (MD) ,5,~9 ('rvD) CSG SIZE: f3.375 CSG MD: f. 750. CSG ~D: f. 732. SHOE TEST: f5.60 MAX. 81 567 LINER TO~= . ~XECUT~E CHAN~E ~- MOVE ~D¢E C~NE TO OO~ - ~H TO {3 3~" CA~IN~ &HOE SUMMARY ~-~ I~°1~1~1 ~ / 2~l~-el~l / I 12 ~2 0.~ I ~-~1 /~.8 PPG ~3. f PPG PPG ~ WTR ~H Pm Pf Mf CL CA LIME MUD LOSSES ~bbl~} BKGD CONN TRIP MAX ~ BIT~ SIZE TYPE OFF FTG HR8 FT/HR RPM WOE IO D LB G CT R CPF COMMENTS ( BIT~ OERIAL~ PRE00. GPM JET~ TFA ANNU~RVELOCITY BIT HP) i~l[l~l~l~ll~lll~lll,lll~lll~l~ll~[ll~lll~lll~lll,l~l~ ,lll,lll~l,fll,lll,[ll,llPiil,l~ll,ffiqll,lllqlPiil,lflqll~ , , ~ i qfl'lllqll'lllql'~'~' ~gP ' ' i~ , ~ *n' ~ '$V ~' I' ~ '~' ' ' ~ ~ .... ~ ' '~ ...... ~ '~' ~ 'm' ' r ' 'U .......... a~ ~ 'fl~lll' ' *U .... U~'l~lll~ll'lll'fl~'lll'~'~l~'~ffil'~' ' '~ ' '~ ' ~' ~' ' 'n~ ........ ~ .... irfll,fll,lll*lflqll*lll,~l,llrlll~lll, ,, v .... BHA: 2 ~ ~/4" ~M~H ~OOD~L, MA ~H ~ ~ MOTOR A~O ,8, ~" OTA~, MWO, PULOER OU~, X~ 3U~, 3-~" HWOP, Length: JAR$~ 23.5" HWDP~ X/O 8a~.53 D~ILL PIP~ ~C~IPTION ' ~10 JrS-4"DRILL PIPE, ~A~ PULL: ~ JARS MWD MOTOR TORQUE WEIGHT (1000) ~drial~h~h~h17[~h[~1~d~1~1~u~1~dm~h~h~a~d~hu~hm~1~111h~h~h~h~[~N~i~h~h~h~i~IIi[~h~8dH~`~h~d~i~d~h~i~"h~M~iU~d]h~h~]~h~M~h~h"~i~`[~h~h~]h~h~h~d~h~h~h~h[~h]~h~h~h~h~h~H~h~h~h1~h~h~F~h~d~h~h~H~11]`~i~h[~h1~d~`~h~d~d~h~h~hifil~h~h~d~lIft fi lli~h~;~h~[]~h~h~y~Ut~h~h~1~d~h1111111~h~h~h~hH~d~h (MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS E~ DOG LEG 5~3~6.00 3.600 f~.20 ~08~.~3 f~Zf. Zg -f~22g.33 7f~.33 5,408,00 3,030 14~.70 5,148.01 1,425,~ -1,a3Z. 78 710,17 5,470,00 3,730 f~,60 ~0g.8~ f,4~g, 67 -1,236,29 7f~.O~ 0,53 lill[lllllllllqlPlllllllqllllllllllllll'llllMIqlPlllllUqllqllqllllllllll,l[ll IIIqllqlllllllltll]]lqllllllllllllllqllqflqlllffillllqllllll~]llqllqll IIIIql[llllqlPll]l]llqllqlllllllllllllPlllqllllllllllql]llll,lllqllllll~l qlll,illlllllllllllqllffllqllqllllllqllllllqllllllqllllllHIIqllqllllJlI ;lllllqll'Ul'l[Iqflqll'lllllflqllqllql]l]llllllqlUIIIqllrtl[,];Iqlllllllfllll ,ll[llllqTIqll,tlI,UIIlllllllllllllUIIIIII]lqllllllllllqllqllllllqllllflqll IlqllqUlillqllllllqlllll.lllqllllll~llllll(llllqlllllllllP,ltlHIqlllfll ,qt,ll[qil,lllllll,ll[qll,llllll[llli,ll[,Ip,mll,m,.I,..Imlllllll,lll ~ OPEEATIONS IN SEaUENCE START END HOURS DESCRIPTION 6:00 f7:O0 fl.00 DRILL AHEAD FROM 5~300'T0 5/55g'- ACTUAL ROTATING TIME AT 5.0 HOURS - ACTUAL ~LIDE ~IME A~ 2.25 HOURS fT~O0 f8~30 f.60 OIROULATE HI-VIS SWEEP- LEVEL MAST f8:30 22:00 3.50 POH BACK REAMIN~ ~I~ FROM S~f30'~O 5~025'- ~OOeE R~URNe A~ 5~026'- WORK FIFE O~ OF THE HOLE NORMAL UFWARD DRAG AT f35K FULL UP TO 2fOK- PUMP ~NIMAL ~TE WHILE PULLINO O~ OF THE HOLE TO KEEP DRILL STRING FULL AND PREVE~ $WABING - FiFE PULLING FREE AT 4,46f'- BREAK CIRC. ~H FULL R~URNS 22;00 R2:30 0.50 MON~OR WELL. PUMP SMALL DRY JOB A7 4~d08'. B~OW DOWN 3URFA ~E EeUIPME~ 22:30 f:30 3.00 POH ~H 4" DRILL PIPE- MON~OR WELL AT CASING SHOE 3:00 G:oo z. oo RIG DOWN ~E~ NIPPLE AND MOVE BOP BRIDGE GRANE 70 OD~ - REIN~TAL~ BE~ NIPP AND FLOW LINE 5:00 6:00 f.00 RIH TO CASING SHOE ~H BHA AND ~" DRILL PIPE Irlllllllllll;illllllllllll;llllJlilllllil[lllllillrlllll )l~llllll,llllllilllfllfllfllllfltllhill~illlllhifldl; IIIIIlfllfll[llllllllllli~llllllhllhllhlllfflhllhflht ~*~;~*)~;~t~i~f~i~ti~i~t~*~t~t~i~1~i~i~i~;~*~i~iit~i~1~{~i~ti~rt~i~[~i]~]~*~i~z~ ~FE; DH TSTICSG COMP TOT LAST PIT DRILL DATE; 01~8~0 .......... CO~T~ ACTUAL .................... WELL I~II~II~I~I~II~III~IEIII~III~IIIilIIilII~IlI[III!IMU~ ~[~p~i~i~i~i~]~i~ii~i~[~iE[~i~ COST~ ACTUAL Itl{rll!~l!l~l{lll[lll!lllilllill LAST BOP TEST DATE; 01~3~0 DAILY: 9~4~3 CUM: 90/~07 DAILY: 4~/017 CUB: 762/123 NO ACCIDE~3 REPORTED TODAY DRILLING SUPERVISOR: DARRELL GREEN N'I' BY: GLACTER DI~ZLLTNG COMPANv' 90? 283 1313; JAN '~-01 6'26; PAGE 1/2 M=rathon d~( 14 DATE; 01~0/01 LOCATION O le SPUD DAYS; Oil Company AFL#' 9203799 GL: . KB: . MOCWI: . W'ELL: KBU4?..Y RI(3:GlaclerDrlilin~TRIJ7 ? FT(3: 31' DEPTH: (MD) ~,~gg (~D) ~,330 C~G 8~E: f3.375 CSG MD: f. 750. CSG TVD: f. 732. SHOE TEST: f5.60 MAX. 81 576 LIHER TOP: PRE~ENT OP:WORK ~HA GO~INUE TO ~H TO 13 3~" GASING SHOE- IN,ALL GASING ~ABING BOARD - RIH TO 4,45~' GIRGULATE E~ECUTIVE ~O~OM~ UP - WASH AND R~M ~0 5~080'- WHI~E CIRCU~IN~ ~0~ R~URN~ ;PO~ 60 B~L. LCM PIL~ SUMMARY PULL UP ABOVE ZONE . RIH ~0 5,0BO' REaM TO BOSOM . DRILL ~0 5,590'. ~PER TRIP TO 4,400'. CIRC. AND COND~ION MUD - POH TO 5~087' SPOT LCM PILL. CO~INUE TO POH ~.2 I~l~Sl~Ol~O / ~1~.o1~1 / I i2 1~2 o.f [ 5.7 I I o.s PPB 70.2 PPB PPB (OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES (bbl.} BKOD CONN TRIP MAX ( BIT~ SIZE TYPE OFF FTG HR8 FTIHR RPM WOB I OD LB GOt R CPF COMMENTS ~ BIT~ 0ERIAL ~ PREO0. GPM JETO TFA ANNULAR VELOCITY BIT HP~ PIIl'i~l~lll~llflll~llflll'lll'Uflll'llfllflll'lll~lll~lll~l ~ifi~i`~i~'1i~`~'~`~'~i~i~i'~i~i`~i~i~'~i~`~i~i~i~'i~'~`i~`ii~`~i~i~i~ii'~h~i`~i'~'~ii~'~i'i~'i~`i~qii~ii~`~`~'~i~i'~i~'~iii~i~'~`i~i'i~B'i~`~1~'~1~i'~i'i~1'B~ii`~`~`~'~`~'~'~i~i`~i~`~i`~i~'~`~ifi~i~i~i~'~i~i~'~'~[~i~i`i~i~`~`~`~ii~`~i`~`~'i~i`~iii~i~`i~i~'~i`r~i~'i~' 'lll'lll'lll'lll~lflfl'ill'lfl'llflfi~lB'lll'lllflll~lll~lll~lll'.ll~ BHA:3 ~z ~/4~ R8~ G~LR~3P~ MAGH f G M~T~R AK~ ~ ~ 3TAB~ MWD~X~ 3UB~ 3~5~ HWDP~ JAR$~ a3-5~ HWDP~ Length: X/O SUB, DRILL PIPE DESCRIPTION: ~10 J;S. 4" DRILL PIPE, ~AX PULL ' ~ JARS ~WO MOTOR TORQUE WEIGHT (1000) , ~1 ,. ~, i i.. ~,1.,111..,111,..i., .I,.. ii1,1., i., re,l i i, i.,111, i. ,..111 ,i., i.,.i,~11,111, i i1,~., .i, i i1,111,~ .,...I,IImll,l.,lll,l.,.,, ,. ,..,.,,1 ,,,...,,.,, ,.,, ,.,.,, ,.,,,,, ,,,,., ,,,,, ,,,,, ,.,111, i.,.i, i1.111 ,. i,.i, ii1,1.,.i,]., ,i,i., ii i,iii ,;~,11~ ,...I,~ .,111 ,~ .,I,, ,,, ,, ,,,,.,, ,, ,,1 .,, .,. ,,. mil,ill ,111 ,..i .,111 ,i]1,.i, i. ,i .,I .*..m, .i ,..11~, i., i. ,...., ,,,, ,,,,.] ,111, iii, i..i i,m,.,, ,., ,., .1..,.i ,~., .~,.~,1 ...,.. ,,,,.i ,i... ,... i,.i ,., ,,. ,, ,1,,,,,.,, ,. ,,,,, ,. ,...i ,.i,.i ,i.,.,,.,, .,, ,,,,,., ,,,,1,,,1.,. i,...~,11.111, i il,.i,.r,~., i Il,.h II ~EA. DEPTH ANGLE DIRECTION TVD VERT. 8EL. NIS E~ DOG LEG 5,346.00 3.600 f~.20 5~086. f3 f,42f. Tg -f,22g.33 7f4.33 f.47 5,408.00 3.~30 14~.70 5,148.01 1,4~5.~ -1,~3~.~8 71~. 1~ 0.46 5,470.00 3.730 f~.50 5,209.88 f,42~.67 -f,236.29 7f8.02 0.53 ~[~1~`~q~q[U~Uq IllllUlllll~Ull(llllllqUllllllllllllqliqllllliq[ilqllqlllilUIIlllllql IIUIIfllIIIUIIIIIII'IIIIIflIII]tJILIIIIIIlPlilIIILIIIIIUIIIIIII~L'III~I[I'IIItl LllUIIIIqlllllillglll~lllllillllllqllllllqU*lllllllllll~llUIJ~qLUIIIql[ I~IIIJlIIULqlIIIIIIIUIIIUIIIIIIIIIIIIIUIIIIIIIIqlIqlI~LIIIIIII[LIIIIIIIIIILIIIL I1111JJlllllllllll[(lJllllllllltllllll~lllllqltqll11111flPlll'lll'UIqllllllq IIITllqllqllllllllllllllqll')llllllqllllllllllllllllllqllllll'lllqlllllllTIII IIIIIIIIIIIIIqllqllllllqllqllqllqllllllllLIlfllllllllNIIIllBllJlJltll~JJllJb START' END HOURS DESCRIPTION 6:00 6:30 0.50 CO~INUE ~0 RIH ~H ~" DRILL PIPE ~0 9~700'- PILL DRILL PIPE 6:30 ~0:00 3.50 REMOVE O~D g~AglN~ gOARD AND INgTALL NEW ~TAglN~ ~OARD . CHAN~ ~WA~ IN NO.f MUD PUMP - OHANOE SHAKER SOREENS qO:O0 ~ ~ :30 ~.50 RIH ~H ~" DRI&L PIPE TO fl:30 f2:30 f. O0 CIRCULATE BO~OM~ UP AT 4~458' f2;30 f4;00 f.50 WASH AND REAM TO 5,080~- ~IR~ULATE AND WOR~NG DRILL ~TRINQ TO ALLOW HOLE TO CLEAN UP "LOST R~URN$" 14:00 15:30 f.~O CIRCULATE ~CM 60 BARRE~ PI~ ~PO~ AND PU~ UP AEOVE THIEF ='ONE - ~ ~CM S~LE FOR 30 MIN~E$. TOTAL LOSSES AT 98 BARRELS ~;30 f7:30 R.O0 RIM ~MRU ~MIEF ZONE AT 4~9~4'~0 6~0Z3'- WA~M AND REAM FROM G~060'~O G~SG9' ~H 17:30 18:00 0.50 DRILL AHEAD FROM [558' ~ 5,590'- a ~" OASING f8:00 fg:30 f.50 CIRCULATE BOSOMS UP - WHILE PUMPING HI. VIS SWEEP . ALLOW C~INGS TO CLEAN UP AT f9:30 2f:30 2.00 SHORT TRIP POH TO 4400'- ~OESSNE UPWARD DRAG FROM [590' TO [275'- MONffO~ hllhllhilhllhiihllllilhllhlihJJJlJJ~lifhllhlll Ihllhllh[r[dlhllhfihlJ~dthlJhllhllhl]hllh]ll JlidlldlhUhllllflllllldlhlllllllllllllJhlilllthllh ~1~i~i~1~i~]~*~t~i*~]~i~;~}~i~1~ii~1~tii~t~t~i~;~{~iir~i~1~i~ ~i~ih~[~h~h1~h~h~i~ih~i~h~h~h~h~h~h~h~h~h~i~U~tt~i~¢i~i~]~;~t~1~1~1;ti~d~d~d~1~t~hi~i~d~;~]~]]~t~ kFE: DH TeTICSG COMP TOT LAST PIT DRILL DATE: 01~8~0 lilli~rllilll;Jllilll~;llil[ri~lliJllJJllilll[lllill~ilrril~U~ CO~TS AcT~]~]~;~i~[~[~""~[i~]~;~[~i~;~i~]~i~=~ costs ACTUAL Ill;l]l;lll~lllill];iiiilllilll~l;l LAST BOP TE~T DATE;01~3~O DRILLING SUPERVISOR: DARRELL GREEN NT BY: GLACTER DRI'LLTNG COMPN''~'', 907 21~3 '1313; JAN -'~-01 6:40; PAGE vverk I~u ~Z-7 ,('" ( Operations Cont (d) Dat~: 30-J~n-01 ~' sEQUEiNTIAJ. OPERATIONS (REP*O-'~'TIGHT SPOTS, LOC. TORQUING UP'-'~-I~Oi~[,EMS, ETC.: ¶!2 HO'--'~R MINIMUM *'-~TART !END-~- H~)I.IR8 ............... DESCRIPTION ~ :~o ~:~o ~.oo WASr~ ANO ~ 4~.~ PROM S,2?$' TO S, SgO'. ~ON~o; ~ FOR LOSSES ~.~0 1:30 0.50 ~PUMP AND S~OT LCM ~ILL ACRES ~IEF ZONE 1:~0 ~6:00 4.50 ~H G~ ~0~ LCM PI~ . BR~K CIRCU~ON - PUMP VERY SMALL DRY JOB -' ~t ' CONTINUE ~ ~H ~ 4' DRILL ~PE " ' ' ~ ~ ,, I ~ -. NI' BY' C~LAC-L~-R U~.LLL.LNU UUM~-'ANY; uu~- ;.'u~ 1~1d; JAN-~-U~ a.ud~ ,At.,,.. ~j.. Marathon ~" '/$ DATE; 0f/3f/0f LOCATI ~" "~; f3 SPUD DAYS; ~2 Oil Company A~,.~' 9203799 GL: . KB:ii· . MDC WI: . ~/VELL: KBU42-7 All3:Gfac/erDrlillflJTRff7 ? FTC: 0 DEPTH: (ffiD) ~,~9G (TVD) ~,330 CSG SIZE: f3.37~ CSG MD: f.7~O. CSG TVD: f.722. SHOE TEST: rS.60 MAX. SI LINER TOP: , . PRESENT OF:CIRCULATE CASlN~ ON ~O~OM ~XECUTIVE PRO~M BR~K CIRCULATION WHILE RUNNIN~ IN THE HOLE A~ NEEDED - WASH TO BOSOM- SUMMARY CIRCU~TE AND CONDmON MUD 0.~ IS~l~l~al~0 Z ~alz, ala~I X I J2 ~2 0. f FsL8 ] I 8.7 PPB ~.0 PPB PPB ~OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES [bbl~) BKGD CONN TRIP MAX ~ BIT a 812E, TYPE OF~ FT~ HR8 FTIHR RPM WOB I0 D L B ~ OT R ~PF ~OMMENT8 { BIT~ 0ERIAL~ PREO0. GPM dETO TFA ANNULAR VELOCITY BIT HP~ BHA: ~ ~a ~/4" RBI G~LRG3P, MAGH ~ G MOTOR AKO .8, ~" 3TAB, MWD, X~ 3US, 3-5" HWDP, JAR3, Z3.5'* HWDP, Length: X/O SUB, DRILL PIPE DESCRIPTION · ~10 J~S - 4" DRILL PIPE, MAX PULL" '"1 ~ JARS BWD ~OTOR TOR=UE WEI= H,T (1000) ............................................................................................................................................................................................................................................................................................................. I .......................................................................... IIIIlllllll ........................ llll ....................................... IIIIII ~MEA. DEPTH ANGLE DIRECTION TVD VE~T. ~EO. NI~ E~ DOG LE~ ~ ......... II 5,346.00 3.600 ~.20 ~,086. ~3 f ,42~.Tg .f,229.33 7f4.33 .~.47 5,408.00 3.630 14~.70 5,148.01 1,4~5.69 -1,~3Z, T~ 710.17 0.40 5,470.00 3.730 f~.60 5,209.88 f ,4~9,67 -f,236.29 7 f 8.0~ 0.53 ~,r,.,,.r*~,~.,.,,m,~;~.~,~;~,,...,...~.,.,.,.,,,.,,,..,,~ ,.;,m,.~,.~,..~,m,....~;.~..~,..mq.,m,..~..ll,l~t ,~..,..~;.m,m,m,~,,.~,..m;;,.r.u,...,,.,,.,,,,,,u.* ,..,,.,,,,,,..11,11,,.,,,,,,,,,,.,,,,,*,,,,.,,.,.,,,,,,,,,,,,,.,.,,.,~ ,m,H,,m,,,,,m,mqm,,,,u,q,,,,,,,fllqfl,lll,Jlff,m,,,,,,m,*,.,,,,,,,I ,lll,lll,fll,fll,fll,ji[,U[,lll,llJ,llmm,,,,,,u,,,,,uqu,m,m,,,,,~[[,llj ,,,,,,,,.,m,,l~q,m,m,,,,,,m,,,,rq,,,mq,mm,,,,mm,,m,,,,,m, ~ opERATIONS IN SEQUENCE ,--. START END HOURS DESCRIPTION .. 6:00 8:00 2.00 POH ~H 5" HWDP . LA Y DOWN MWD COL~R~ MUD MOTOR~ STRIN~ $~ABIL~ER AND , 8:00 fO:O0 2.00 PULL WEAR RWO AND $~TEST PLUG - ~HANGE UPPER PIPE RAM$ TO 9 ~" AND .... , TO 3000 P;I, - CHECK DOOR ;EA~; - TE;T fO:O0 f3:30 3.50 CHANGE O~ BALES - MAKE UP LaFLEUR CASING PILL UP TOOL . LAY DOWN TEST JOW - RIG UP BAGK UP TONGS ON DRILLERS ~IDE - FOLD DOWN STABWG BOARD . ADJUSTT ,, , .... DR~E TORQUE TUBE ~ RIG UP CASING TONGS, ELEVATORS, AND SLIPS ..f3:30 ~9:30 6.00 HOLD PRE.JOB ~AF~ ME~INe ~H ALL PERSONAL. RUN 9 ~" ,0 ~B. C.aO PER PROGRAM- ~IR~ULATE THRU FLOAT EQUIPME~- RIH TO f3 3~" CASING SHOE, WHI~E MON~OR R~URN~ AND ~O;~E; . 2 BPH i ~9;30 20;00 0.~0 CIRCULAte 9 ~' VOLUME AND ~RK PIPE ~OOK UPWARD DRAG. R~K DOWNWARD 500 PSI AT 125 3PM 20:00 22:30 2.50 CO~INUE TO RUN g 5~" CASING TO 3~ f29,- MON~OR R~URNS - 2 BPH LOSSES ,, DRAG. ~0 PSI. AT f25 SPM I~l~lll;~hllhllhllhllfll[[lllhl[hl;l~llldlhlllllll ,Ihtllllllllllll[hllhlfldlhllhlllllfll[Ihllh]~[lllh hllhllldlhllflllldlhllhllflllldli;llhlUlllhllh ~[~i~i~1~1tk~i~1~1~1~i~i~[~1~[~;~[~i~r~t~t)~i~t~1ii~1~1~ti~1~t~1~r~1[~i~[~1~ ~]~h~1h~h~i~DH[~d~h~h~h~k~d~h~d~h~d~i~[~th~h~h~k~d[h~h~h~i~h~i~1~h)~1h~h11[~Uh~T~h~]~[11~h~i~ih~h~h~h]~d[h~h1~f~[[1 ~FE: DH TST/C~G COMP TOT LAST PIT DRILL DATE; 01~0 ....... MUDACTUAL ........................ WELL "DRILLING SUPERVISOR: DARRELL eREEN · 'NT BY' · GLACTER DRTLL'rNG COMPANY; 907 283 1313; JAN-31-01 b'b3; ~"Au~- ZJz · Well: KBU 4:2-7 { Operations Cont (d) Date; 31-Jan-01 [ ~I;;QUI;;NTIAL OI=BRATION~ (RI;;i=OR.T TIGHT SNOTS, LOC:. TORQUlN~ Ul= I=R.O~Li;MS, E;TC:.: I12 HOUR. MINIMUM 1 J START END HOURS DESCRIPTION 1:00 Z:O0 1.00 ¢iROULA'IE BO'ITOM$ UP A'1'4,400'- WORt( PIPE 200K UPWARD DRAG - 12C,1( DOWNWARi DRA~3 . 120 $PM A'I 051 P$1, 2:00 2:30 0,50 RIH WITH g $/8" OA$1N~3 7'0 4,815' 2:30 3:00 0.50 C, IROULA'IE AND WORK PIPE- 2151( UPWARD DRA~3- 140t( DOWNWARD DRA;3 . 120 A 'I O40 PSI. 3:00 3:45 0,75 RIH wr/'H 9 ~,T~" OA$1N~3 '1'0 5,150' 3:45 4:00 0.25 BREA1( C, IROULA'IiON AND MOVE FLUID - 250K UPWARD DRA~3 .1#01( DOWNWARD DRAG 4:00 5:00 1,00 RIH wrrH l) ~.~'8" CASING 7'0 5.507'- 'IA ;3 FILL 5:00 0:00 1.00 CIROULA'IE WITH FULL RETURNS A'I S,507'. 134 5PM A'I Oe4 P$1. - 38~ FLOW- WA$H AND WORK GA$1NG TO BOTTOM AT 5,,~TG'. GONDrI'ION MUD AND PREPARE FOR GEMEN7 JOB ,., ,. , ~T BY'.,GLACTER DRTLLTNG C0MPANv' 907 283 1313; FEB-J '~1 4'49; PAGE 1/2 Marathon ,,~ l~ DATE; 0,~/0¢/0{ LOCATION D 14 SPUD DAYO: ~3 Oil Company AFE#' 9203799 GL: . KB: . MOCWI: . WELL: KBU4Z-7 RI{3:G/aclarDrllllnJTRiJ7 ? FTI3: g DEPTH: (MD) ~,5~g (~D) CSG S~E: 9.625 CSG MD: 5.582. CSG ~D: 5.322. SHOE TEST: MAX. SI 0 E~ECUTNE ~H MUD - WOC - NIPPLE DCWN - ~ EMERGENCY ~MP~ - IN~AL~ ~U~IN~ SUMMARY NIPPLE UP BOP AND RELATED EQUIPME~ ( BIT~ SIZE TYPE OFF FTG HR8 FT/HR RPM WOB IO D LB G CT R CPF COMMENTS I I Ill I { BIT~ OERIAL~ PRE00. GPM JET~ TFA ANNULAR VELOCITY BIT HP~ ........................................................................................................................... I ....................................................... I .......................... .............. I ............................................ _,b ............ DRILL PIPE DESCRIPTION: ~A~ PULL ' ~ JARS MWD ~OTOR TORQUE WEIGHT ........................................ [ ...................................................... 1 ........................................ [ ................................................... J, ........................................ [ .................................................... 1 ...................................................................................................... [,~,?,~ ........................... ~,~.~ ................................... 2~S~,~ .................................. ~,~ ................................. ~[,~, ................................. (MEA. DEPTH AN~LE DIRECTION TVD VERT. ~EC. NI~ E~ DO~ LEG ~3~6.00 3.600 f~.20 ~,086. f 3 f~2f. T9 -f ~229.33 7 f~.33 5,408.00 3.030 148.70 5,148.01 1,4Z5.08 -1,Z3~.78 710.17 0.40 5,470.00 3.730 f~.O0 5,a09.88 f,429.67 4,236.29 7f8.02 0.53 8TART END HOURS DESCRIPTION 6:00 8:00 2.00 Cl~ulate and cond~lon mud at ~582'- f34 spm at 775 psL wa~r-Te=r wu~eee I/new er 3000 psi. -Dmp bor~m pl~ - M~ end pump 40 bbl. ~D ;pecer w~h the following =ddfl~ee 6 Ibs/bbl MC;-D~ 30.8 Ibe/bb/ Bentonfle~ g2 /bs/bbl Barge followed by ~20 sacks of C/ass "G" f2.5 ppg Lead Cement w~h a yield of 2. fO =u~ per =ask wkh ~he ~lllng o~Ne= .3% bwo= Oal~um Oh~, .4~ bwo= CD-32, f gal/fO0 sack FP. SL, 2% bwoc Sodium Metasllllcate fol/oweE by 234 sacks of . Class "~" fS.a ppg ~afl Cement w~h e y~ of f.f~ cu~t per sack w~h the ~lllng ;dd~lves .3% bwoc OD.3Z .6~ bwoc PL.33, f gal/fO0 sack FP.6L . The re[plug was : dm~ed and 5 bbL wa~r pumped ~ clear surface//new and then turned o~r ~ r~ ~r d~placement A ~tal of 4~O00 stmkes ~m pumped at G.9 bpi and losses sm~d m occur, ;he pipe wes then parked end ;he pumping ~m was md~ed ~ 3.9 b~m at ~600 stmkes losses still becomln~ Fmater and the eum~ln~ ~m was Ina ~e dlsplacemenr no arums m sudace occumd, a m;al of 8,99f s;mkes were numn an~ rna c;~ularln~ nmssum at this ;lme was ~98 esl. The nlu; ~IE not Ill~l]lllll~lih[Hllillllllllltllllll]llilllll}llllllll IJIllrlll~li~lllllllllll;llllllhilrlllrllilflll~lll~lll Ihllhllhllhllil~lhllhilhllllllllllhllllllhllhllh ~i[~i~[~ii~t~t~i~i~*~[r~]~i~[~r~}~i~t~t~r~;t~ii~}i~;~iii;iir~i~r~;~]~]~;~i~i~i~r~i~i~ '~hi~h~h~;[~h~1h~hi~h~h~h~hi~r~i~hi~i~;~h~h~h~h~i~ih~hr~i~i~;~h~*~h~h~h~;~i~h~R~h~1~h~1~iJ~h~ih~h~ kFE; DH T~TICeG COMP TOT LAST PIT DRILL DATE: 01~8~0 MUD ........................... ............... ACTUAL WELL ll~lll~]ll~]ll~ll~ll]~lll;lll~ltl~lH~lt~[lll~HI;lil;~li~l CO~T~ ~;i~ii~ii~;~;~ii~iii~;ri~i~i~ji~;i~ii~;~;i~]~;i~t COOT~ ACTUAL II[~];lll!lll~]tlilll[lil~llil~ LAST BOP TEaT DATE: 01~3~0 DALLY: 1~226 CUM: 100~G19 DALLY: 91~002 CUM: 1~001,740 NO ACCIDE~S REPORTED DRILLING SUPERVISOR: DARRELL GREEN NT BY: ¢LACIER DRILLIN8 OOMPAINIV: 907 283 t3t3; FEB,' Ot 4:4g; PAi2E 2/2 Well: KBU 42-7 l' Operation8 Cont (d) Date: 01-Feb-01 SEQUENTIAL OPERATIONS (REPORT TIGHT SPOTS, LOC. TORQUING UP PROBLEMS, ETC.: I/2 HOUR MINIMUM S~TART END HOURS DESCRIPTION and total losses at this point were 7 f bbls. 7'he pressure was bled down and the floats were checked, and were holding. Cement was In place at f1:27 A.M.. All surface lines were flushed and blown down. f2:00 tS:00 6.00 Waif on Cement. Rig down Bop and relared equipment, prepare fo lift stack fo Ins{all emergency slips. Change pump liners fo 4 tS:00 20:30 2.50 Pick up f3 $/8" BOP and set casing slips with fSSK on slips 20:30 0:00 3.50 Rough cur casing and lay down stub. Set BOP out of the way. Make final cut on casing and dress up same - Set tubing spool In place 0:00 4:00 4.00 Tighren down tubing spool and attempt fo rest, leaking on Inside of packoff, Inject plastic and retest al' 2f00 psi. for f5 rain. Change out link's fo short set 4:00 6:00 2.00 Nipple up Bop and related Equipment NT BY' GLACIER DRI'LL1'NG COMPANY; 90'~ 283 1313; ~-B->'-01 ~:4~; ~Au~- 1/;' Marathon ~ 17' DATE; 02/0£/0'/ LOCATI~ 'J'i' ¢5 SPUD DAYS; 14 Oil Company AFL,' 9203799 OL: . KB: . MOCWh . ,, WELL: KBU ~'-T Alt3; {;lacier DrllllflJ7 RI, iL '/ FTC3: O DEPTH= (lt,qD) ,5,~gO (TVD) ~,330 CSG SIZE: 9.625 CSG MD: 5.582. CSG ~D: 5.222. SHOE TEST: MAX. SI 0 LINER TOP: GO~INU~ ~0 NIPPLE UP BOP AND RELA~ED E~UIPME~- ~E~ BOP E~UIPME~- IN.ALL WEAR RIN~ ~XECUTIVE ~ UP ~CHLUMBER~ER AND RUN OBL - ~ DOWN ~CHLUMBERCER - TE~T g 6~" CA~IN~ SUMMARY AT 2500 PSI.. ~KE UP B f~" ORIL~NG ASSEMBLY AND RIH - C~ f 1~" DRE~NG ~NE . CO~NUE TO - TAG CEME~ AND D~LL FLOAT EQ UIPME~ (BW VIS PV YP eELS WL T I,~ 30 HT FC CRC SAND SLD BENT SAlT DRILLED BARITE {OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES [bbl~} BKGD CONN TRIP MAX .o/o.o o.o / ado/ I I / / ,~ BIT~ SIZE TYPE OFF FTC HR8 FTIHR RPM WOB I0 D L B G OT R CPF COMMENT8 ~ BITg OER~L~ PREOO, GPM dETO TFA ANNULAR VELOCI~ BIT H~) BHA: 4 8 fiE" RBI O~ALRG3P, MAOH f X MOTOR AKO .8, 8 3~" 3TAB, MWD, PUL$ER 3US, X~ SUB, 3-5" HWDP, Length: JAR$~ 23-5" HWDP~ ~0 876,75 DRILL PIPE DESCRIPTION ' ZlO J[s. 4" DRILL PIPE, MA~ PULL · ~" ,JARS MWD MOTOff TORQUE WEIGHT (1000) h1~h~fh~h~1~d~hHh~h1~d~hU~d~h~h~h~h~h~hHh~*[~hNh1~h~]~h~d~h~M~h~h~h~h~h~h~d~d~h~h~h1~hUh~H~h1~h~d~`Hh~d1 (YEA. DEPTH ANGLE DIRECTION TVD VEET. SEC. NI~ E~ DOG LEG~ 5~3~6,00 3,600 f~.20 5~086. f3 f~2f,T9 .f~229.33 7f~,33 5,408,00 3,030 149,70 5,148,01 1,425,09 -1,~3Z,78 710,1Z 0,40 [470.00 3.730 f~.60 5,209.88 f,429.67 -f,236.29 7f8.02 0.53 :{ OPERATIONS IN SEQUENCE START END HOUR8 DESCRIPTION 6:00 fl:30 ~.~0 CO~INUE TO NIPPLE UP BOP PSI, FOR HIGH - F~E FAILURE$ O00URED DURING ;EST (f) UPPER PIPE RAM$ (2) OHEOK , VALVE ON ~LL LINE (3) H2; D~EC~OR A~ RI~ FLOOR (~) LEL D~EC~OR A~ BELL NIPPLE (5) KOOMEY REMOTE AT DRILLERs CONSOLE WOULD NOT FUNCTION UPPER PIP~ RAMS OHANQED O~ HOSES ~H LOWER PIPE RAM O0~ROL~ . ALL ~EMS REPAIRED PULL TEST PLUG AND INSTALL WEAR RING , fg:00 22:00 3,00 RI~ UP ~CHLUMBER~ER ~RE LINE ~ERWCE~ - RUN CBL - RIH ~H LO~ NOW ~0 5,~0' . , POH LOGGING. RIG DOWN SOHLUMBERGER AND OLEAR RIG FLOOR - LOG $HO~ THE FOLLO~NG NO GEME~ A~ ~30'. LOW QUAL~TO ~d60'- GO~ BOND IND~ DOWN ~:00 Z3:00 1.00 TE3T 9 ~" OA$1NG AT ~,~00 P~I. FOR 30 ~N~E3 . ADJUST ~P DR~E ~RQUE TUBE. BLOW DOWN CHOKE MAN/FOLD ~3:00 1:30 2,~0 PICK UP NEW6 !~" DRILLIN; BO~OM HOLE A~EMBL Y . ~UR~A GE TEST MWD TOOL AND MUD MOTOR - RIH ~H 5" HWDP 1:30 2:30 f . OO RIH ~H 4" DRILL PIPE TO 2,~f2'- PILL DRILL ~TRING IIil[lltlhl~hlllt[lllllllllhllhlll*llhlJidildlh[[ll hlthlfll[llll~hlHillhlll~llhllhltlllthllllllttlll[ IdlhllllllllllhllhllldlhlJIdlllllldl~llllllllllll ~i~i~1~1~t~t~)~*~i~11i~1~i~i~i~i~1*i~i~i~i~i~i~i~i~j~1~i1~ii~i~i~1~1~ti~i1~tiiit~1~1~1~[i~i~t~ii~ii~Hi~1~i~1~1~i~i~ ~h~h~hi~h~ihi~1i~1~i~i~h~ih~idi}~ih~h[ih~h~h~H~i1d~h~d[H~h~d~h1~id~dih11~[~hiihi~h~1h~h~h~h~h~i~h~ih~hiU~h~dihi~h~h~ih~h~h~ih~t~1~ ~FE; DH .TeTICSG COMP TOT LAST PIT DRILL DATE: 01~8~1 DAILY: f~YY7 CUM: f02~295 DAILY: 37~266 CUM: 1~099~034 NO ACCIDE~ REPORTED TODAY DRILLING SUPERVISOR: DARRELL GREEN !NT BY: GLA(::;3:ER DR'rLLI'NG (:;O~PANY; t 'o '~at¢: 02-Feb-01 907 283 1313; FEB-2-01 6'43; PAGE 2/2 - { Operatlon~ Cont (d) ~I=QUI=NTIA. L OPI=R.~TION~ (REPORT TIGHT ~POT~, LO~. TORQUING UP PROBLI=M~, I=T~.: '"1/2 HOUR MINIMUM START END HOURS DESCRIPTION 2:30 4:00 I.,50 SLIP AND GUT 0~' OF 1 11'8" DRILLINg3 LINE - SERVIGE TOP DRIVE AND CARRIER - ADJUST DRAW WORKS MEOHANIGAL BRAKES 4:00 5:00 1.00 OONTINUE TO RIH WITH 4' DRILL PIPE 5:00 0:00 1.00 BREAK OIROULATION AT 5,402'- WASH AND REAM TO 5,451' AND TAG CEMENT- DRILL C. EMENT TO 5,48G' AND TAG FLOAT GOLLAR - DRILL FLOAT EQUIPMENT IT BY: GLACTER DF~'rLL'rNG COMPANY' ,, 907 28;3 1;31;;3; FEB-? ""1 10'1;"; PAGE 1/1 Marathon ~,.. '/0 DATE: 02/03/0'/ LOCATION I., '/6 0PUD DAYS: '/5 Oil Company AFE#' 9203799 GL: . KB: . MOCWi: . WEELL: KBU4;2-7 RIG: GlaclerDrllllnl3RID ? FTI3: 57'5 DEPTH: (MD) 0,Z~ (-I'VD) CSG SIZE: 9.625 CSG MD: 5.582. CSG TVD: 5.322. SHOE TEST: f3.30 MAX. 81 996 EXECUTNE 6,6f0'- Cl~ulete bottoms up - P~form leek off test - Drlll ehead to 6,265' 8U MMARY . ~-7 1~1~12~1~/271~0-"~l / I ]2 132 0.3 I 7.e I I 8.9 pps 75.6 PPB xa PPB [OIL ~R pH Pm Pf Mf eL CA LIME MUD LOSSES [bbl~ BKGD CONN TRIP MAX o o ~ ~ ~ ~ 07 o J J J ~8,000 JGO dally cum ~8 ( BIT~ 812E TYPE OFF FTG HiS FTIHR RPM WOB IO D L B G CT R CPF COMMENTS { BIT ~ ~ERIAL~ PREOO. GPM dET0 TFA ANNULAR VELOCITY BIT HP~ I~111~111~1111ll I ~lll~lll~lli~111~lll~lll~iil~l11'lll~lll'lll'lll'I ,'itillll~lll~lll~llllllilllllliF lll~lll~]]l~iil~ill~lll~lll~lll~]l ~lll~lll~lil~lll~lll~ilBll~lli~llL~lll~ II,Ill,Ill,ii ~i~.]~i~i~i~H~B.~i~]~.~i~]]]~][~]~]~ Nlltflt~lU'lfl'tB'fllqfl'lIPfli'HPllllfl RfllHi*U BIP fl B fl'fil~lfl'l ~IIPI}P fll~ Plll~ fli'iW fl 1'iii' ill'till fll~lll'll ~fll'~Plfl~lfl~fl Pill'flPflllfll~fl Ril~fll~lH~Hl~lil~lll~fl]~Hiqll*III'BpUP fllllB'lll~fll'fll~ll BHA: 4 8 ~" RBI G~ALRGSP, MA GH ~ ~ MOTOR AKO .O, 5 3~" STAB, MWD, PULSER SU~, X~ ~U~, 3.5" HWDP, Length: JARS, 23.5" HWDP, X/O SUB, 876,75 DRILL PiPE DESCRIPTION: ~10 Jfs-4"DRILL PIPE, MAX PULL: ~ JAR3 MWD MOTOR TORQUE WEI6HT (1 ~MEA' DEPTH ANGLE DIRECTION TVD VERT. SEC. NIG E~ DOG LEG ~,976,00 0.880 f63.70 ~,7 f ~.35 f ,~O,~7 -f~2~.25 726.77 O. f f O, IOZ.O0 O. TSO 15Z. 80 5,~41.34 1,45Z.~7 -1, Z5~.80 7ET.~ 0.14 5,226.00 0.880 fSO. fO 5,965.33 f,4~.07 -f, 256.6f 728. f6 ( OPERATIONS IN START END HOURS DESCRIPTION 6:00 7:30 f.60 Continue to drill cement to top of float collar at ~g~'- Drill ~ment to top of float 7:30 8:30 f.00 Drill 8 f~" ho~ lmm 6,590' ~ 6,6f0~- Actual ~reflng dine e~ .76 houm 8:30 9:30 ¢.00 Cl~ulate bottom; up and condfllon mud 9:30 fO:30 f .O0 P~form leak off test. EMW at f3.3 PPG fO:30 6:00 f~.50 Drill ahead from 5,6f0~ ~ 6,265'- A=~ual mfaflng f/me ar f¢. f houm . A=fual ~1~ f/me at f.0 hou~ hllhllhllh]lhllhflllll[lllhlJHBBillhllhll I;llllllhllhllhllhllhtl]lllhJlhllllllhlJllilllllh hl[hllhllllllhllhilltllhllllll}tllllllhflhlllllll ~i~[~[~1~tt[~[[~;~i~11~J~[~[~]~1~[~1~]i~;~j~i~j~;~i~1]~1~[~]~;~f~i~[~]~1~t~[~[[~[~ ]~h~t~B~h1~hHh~h~h~h~h~h~h~h~h~h~h~h~h~h~d~h~h~1~h~h~d~h~h~h~h~hB~h~h~d~[d~h~h~h~h~h[~ht~h~h~ AFE: DH TSTICSG COMP TOT LAST PiT DRILL DATE: 01~0~1 ACTUAL WELL Ill,ileitis,lieUD f~ ~lll~ll~lfill~lf~lll~ I~lll~lJl~lllllJHl~lll~JJtJl~lll~llJ~lJl~lll~lll~lll~l ~st~ ~i~iii~i~jj~ii~j~1j~ij~i~ii~iii~j~i~i~jj~]~j~i~ ~ost~ A~tUA~ lll~llJ~Jll~lli~lll~i~lll~lll~l ~A~t B~P t~St ~At~: DALLY: ~,2~3 CU~: ~06~9 D~LY: ~,6~ CU~: ~I~3~69~ NO ACCIDE~ REPORTED TODAY' DRILLING SUPERVISOR: DARRELL GREEN T BY' GLAOTER DR:]:LL:I:NG O0MPANV" 907 28;3 1;313; FEB-/ ~1 7:3;3; PAGE 1/1 Marathon r,, ¢ '/ DATE; 02/04/0¢ LOCATION I~'~. ¢7' SPUD DAYS; Oil Company AFE#' 8?.03799 GL: , KB: , MOCWI; , WELl..: KBU .47-7 RIG: Glacier Drill/nY3 RlY3 ? FT~I: .4'/4 DEPTH: (MD) 0,7'3.9 (TV'D) C:8G SIZE: 9.625 CSG MD'. 5.5B2. CSG TVD: 5.222. SHOE TEST' ¢3.30 MAX. 81 LIN ER TOP. PR.I='~I=NT C)P'.~HORT TRiP ........................ mm Ir .......... I~ ~111111 ................................................................................. .......... "' .................................................................... DRILL AHEAD PROM 0,205'T0 0,714'- WORK 7'lGl'n' HOLE AT 0,704'- DRILL PROM 0,714'T0 0,738' EX ECUTIVE REPA/R WA~/-/ OUT'/N 7'EE ON MUD/./NE BETWEEN MUD PUMP8- POH AND BACK REAM TO g 5/8" CA~/N~ SUMMARY SHOE (~OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES[bbl/ftI BKGD CONN TRIP MAX (' BIT~ SIZE TYPE OFF FTG HRS FTIHR RPM web I OD LB O eT R CPF COMMENTS (' BIT # ~ERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP'~ Ill Ill Ill IlL Ill [][ [ I [ Iqll'lJl'fll[lil,ldl'Lli'lll'lil'lii~ll&[lll[lll,lfl,t]l,llrH&, ~`i~[f~1~`~4~i~iit~[~i~q~Ji~`~4]~i~i~i~&~4~J~&~t~1~F~1~]~]~m~[t~[~1~i~qii`i~F~ii~4[~)~H~iq~[~&~`~i~i]~q~tq~]~i`~4`~i~&~iTi~iT~1~T~1i~irLFi~F~i~J~i~r~4~'~rF[~q~'~F~t~i[~r~`4]4'4~T&~i1j~&[F~j~j~F~1[i~`~F~t~t~f~Ht~[~i~]i~i`i]~`i&~1~tq~i*[t~`i~JiJ~' ' 'Ill,ill'ltl'Ill'Ii' I'llr&H'lll'llrll&'ll~ ~ ' ~ ' ~ ~ ~ ~ ~ I~Jll~lli:llJ Length: JARS, 23-5" HWDP, X/O SUB~ 87~,75 DRILL PIPE DESCRIPTION: 210 Ji'$ - 4" DRILL PIPE, MAX PULL: ~ JARS MWD MOTOR TORQUE WEI(3HT (qO00} h~h~h~""~'"~'1"~1"'~'~"";"`"1'~"'["~"'~'"~`r"~"'m`"~`m`"h"~1"~"'"""h"~"~"[~"~"~';"'m`~"~h~"'~"~"h"~'~"'"~h~"'~h"~"'1"'"1'"['"~`"~"'~"h"~"~'~""`"~"h~"~"h~h"~""'"h~"'~"'~'1"~'1"'"~"~'~"~1"~"h~h"~""'"~"~"~"~'~"~'1"'~"~"`1"'~'~"~"~'"~`"h~"~"~'~""~h~'~"'~h"~'~"~`"h~"~"~"h"]~"~"""~"~""`"~'~"`~"'~""'~'~"~"h"""h~h~'"~"~""~"'~'~"~""~'1"~"'1"~"h"h~h"~"~'"""h~h"~""~"~h"~'"h~"`"~`~"~"~"""""'"1"~"~'"~`~'"~ ('"M EA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS E/W DOG LEG TM 5~g?$.00 0.880 ¢63.70 5~7¢5.35 ¢~0.~? -¢.,2,55.26 7'26.77 0. fl O, IOZ.O0 0.7~0 15~.80 5,841.34 1,45;J. Z7 .1,Z50.8~3 7?.7.44 0.14 6,226,00 0.680 f60. f0 5,865.33 f,454.07 .f,256,6f 728. f§ 0. fl { OPERATIONS IN SEQ. UENC;E START END HOURS DESCRIPTION 6:00 22:00 ¢6.00 DRILL AHEAD FROM 6~26~'T0 6~7¢~'- ACTUAL ROTATING TIME AT ¢¢.2 HOURS. ACTUAL ~LID~ 'rIME A 7' .5 HO 2,?,:00 ,?.3:00 f. O0 WORK TIGHT HOLE AT 6,704'- WORK DRILL STRING FREE AND BAOK REAM AND ROTA TJ 7'HRU COMPLET'E ~7'AND 23:00 0:00 ¢.00 DRILL AHEAD FROM 6,7¢~'T0 6,739'. ACTUAL ROTATING TIME AT.?'~ HOURS - ACTUAL SLIDE TIME AT 0 HOURS 0:00 ¢:00 '/.00 WASH OUT IN MUD LINE BETWEEN MUD PUMPS ON TEE. WORK PIPE FILL TRIP TANK - ROUND UP WELD/N(; 13EAR 7'0 PA7'CH 7'ER f :O0 6:00 5.00 WORK OUT OF THE HOLE TO 9 5/8" OASING SHOE PULL FIRST 6 STANDS NORMAL UPWARD DRA(; AT' ~ISK WORK 7'HRU 7'IGH7' SPOT'S UP WEIGH7' AT' RG3K - WELD 7'ER ON MUD LINE PUMP AND ROT'AT'E OU7' OF ?'HE HOLE hllll[lllllldlldthllllllhlfll[ihllldlhllhllh[I hllhllhHh~lhllhflrdlhllrlllhilhllldll~llrllll ]h]l]~lihflhllhl~hllldfldl~lllllllhl~hllhllhflhl ~i~=~t~t~i~i~r~1~[tf~1~;~i~r~=~i~rt~i~t~i~i~i~*~tt~ttii~ii~i~]]~i~;~rr~r~it~r~;~a~ti~}~i~*tt~r~tr~r~1*~]~;~;~tit~ ~d~h~h~h~h~h~h~h~h~tH~dHd~;~H~h~d~h~h~ih~h~hiir~h1~h;~h~H[d~h~h~htih~h~i~h~ihiih~h1~i~h~h~h~[~h~ih~h~h~i[d~]d~]d~d~t~d~ih~ A. FE; DH TSTICSG COMP TOT LAST PiT DRILL DATE; 02/03/01 MUD ............... ACTUAL ........................... WELL ........ I!lll!lrlJlll!lllilllilll!lll!ill!l[r!ll/illl,ll!lllirllil COSTS ~~~!~~~g~~~!~~~!~~~i~I~~~~~~~~~~~~~i~~~~~~~!~~]!~~~i~~~i~~~i~~~i~~~i~~~i~i~i~~~!~~~i~~~!~~~!~~~!~~~!~~~!~~~!~ COSTS ACTUAL Illilllilllillli]ll![llilllirllilll LAST BOP TEST DATE; 02/01/01 DAILY: 10.,107 CUM: 724~T21~ DAli. Y: G6~3,.2 CUM: 1~20&267 NO ACCIDENT~ REPORTED TODAY DRILLING SUPERVISOR: DARRELL GREEN IT BY' '~LAOI'ER DR'I'LLTN{2 COMPANY" 90'7 283 131;3; FEB-.~ """1 6'54; PAGE 1/2 Marathon ,.. 20 DATE; 0£/05/0f LOCATION ~,,-~ f8 SPUD DAYS; Oil Company AFE#' 9203799 GL: . KB: . MOCWi: . WELL: ABUZZ-7 RI{3:GlaclerOrllllrljTRIJ7 f FTe: ZOf DEPTH: (MD) T, OOO (~O) CSG SIZE: 9.625 CSG MD: 5,582. CSG ~D: 5,222_ SHOE TEST: f2.20 MAX. 81 LIMER TOP: , CO~INUE ~0 POH ~0 9 ~" CASING SHOE - SERVICE ~ AND TOP D~E - ~H ~ PILL AT ~,720' WASH E~ECUT~E ~0 BO~OM A~ 6~73g' - ~ AH~D ~0 6,g03'- CHAN~E ~WAB IN ~0,2 MUD PUMP - CO~/NUE SUMMARY AHEAD TO 7.000'- POH BACK R~MIN~ TO CASING SHOE. CIRCULATE BOSOMS UP - CO~NUE TO POH ~H B~ NO. 4 (MW VIS PV YP GELS WL T f,b 3U HT FG CE6 SAND SLD BENT SALT DRIggED BARITE "-" I~1 ~ I ~"l a / ~61 r.e ISO~l / ( I 2 ~2 o.~ I e.a I /fO.8 PPB 78.g PPB f3.8 PPB (OIL ~R pH Pm Pf Mf CL CA LIME ~UD LOSSES [bbl~ BKGD CONN TRIP MAX o.o gl'd/ g'f /0-~ 0.~ / ~.S 12~,0o0 ~ooI Idally cum / gO / ( BIT~ SIZE TYPE OFF FTG HR8 FTIHR RPM WOB I OD LB G OT R CPF COMMENT8 d 8.500 CfALR~P 7,000 f,dfO 33.70 df.8 ~ fS POH .~ BIT ~ SERIAL ~ PRESS. GPM JET= TFA ANNULAR VELOCITY BIT HP~ BHA: 4 8 ¢~" RBI G¢ALRG3P, MAGH ~ XMOTOR AKO .8, 8 3~" 3TAB, MWD, PUL3ER 3U¢, X~ 3UB, 3-5" HWDP, Length: JARS~ 23-~" HWDP~ X/O 876.75 DRILL PIPE DESCRIPTION: alO Jm- 4" DRILL PIPE, ~AX PULL' ~ JARS MWD MOTOR TORQUE WEIGHT (1000) ...... .............. ..................... I ..................... ..................... ................................. .............. .............. ................................... (MEA. DEPTH AN~LE DIRECTION TVD VERT. SEC. NI~ E~ DO~ LEG 6,60~.00 f.f~0 f83.00 6,3~3.26 f ~60.57 -f ~265.60 729.07 0.03 ~,73~.00 1.050 1T0.70 ~,471.~3 1,40~.74 .1,Z~8.03 7~a. 1~ 6,859.00 0.880 fSf.20 6,598.22 f,4~.67 -f,270. f5 729,36 0. f9 .........,.,,....~..~.........~....~..,........, ,.,..,................,~.~.,..~.,.....,.,.,.,., ,,.,,,,,,,,.,,,,,.,,,..,,,,.....,.......~....,..~.,...., .r.,,..,.,..,,,.,.......,,.....,.....,...,,,...,, ,,,,.,,.,,....,,,,,,,,,,,,,,,,,,.,,,,..,,,,,,,.,.,.,,,,,,,,......r ,11......+,.....,,...,,.,,.,,...,,.....~,.,,.,,.I,.I,. ,,,,,,,,,,,.,.......,,,,,,,,,,..,.,,,,.,,,,,...,.,.,...,.,.,,., ...,.i..,.,..,,,,,,,,,,,........,,,,,,,.,.i.,i..,,..,.,.,,, ~ OPERATION~ IN ~EQUENCE START END HOURS DESCRIPTION 6:00 g:O0 3.00 CO~INUETOBACKREAM WORKPIPEANDPOHTOgS~'CASINGSHOE'PULL TO265K NORMA~ UPWARD DRA~ A~ ~5K A~ER WOR~N~ ~HRU AR~A O:O0 fO~O0 f. O0 SERVICE RI~ AND TOP Dfl~E- BLOW DOWN TOP DR~E AND 8UflFAOE OlflOULATIN~ LINE; ~0:00 fO:30 0.50 RIH FROM 9 ~" CASING SHOE - TAG FILL AT 6~720'- BREAK CIRCULATION AND WASH TC 80~OM AT ~0:30 f7:30 7.00 DRILL AHEAD FROM 6~73g'TO ~,903'- ACTUAL ROTATING TIME AT 5.5 HOURS - ACTUAL ~LIDE ~IME A~ 0 HOUR~ - ~ACK REAM EVERY f&' DO TO HOLE COND~ION~ f7:30 rS:00 0.50 OHANGE SWAB IN NO. 2 MUD PUMP ~6;00 f9;oo f,oo DRILL AHEAD FROM 6~903'~0 6~9~2'- ACTUAL ROTATING TIME AT .~5 HOUR~ ~9;00 fg;30 O.GO CHANGE ~WA~ IN NO. 2 MUD PUMP 19:30 23:00 3.50 DRILL AHEAD FROM 0,~12'~ 7,000'- AGTUAL ROTA~NG ~ME AT ~.~5 HOURS 23:00 2:30 3.50 WELD OTHER SIDE OF TEE ON MUD LINE B~WEEN MUD PUMPS - POH BACK REAMING 2:30 3:30 ~,00 ' CIRCULATE BOSOMS UP. PUMP DRY JOB AND BLOW DOWN CIRCULATING SURFACE UNE~ ~FE; DH TST/C~G COMP TOT LAST PIT DRILL DATE; ............... MUD CO~T~ ACTUAL .......................... WELL Ililrl!lllill~irllilllilllilllilrlilllillrilllilllilHilllil ~i~i~i~i~i~i~;~i~;~i~i~i~i~i~ COOT8 ACTUA~ Illilll!lllirllillliBIIfll LA=T BOP TEOT DATB; DRILLING SUPERVISOR: DARRELL GREEN T BY' GLAC1'ER DRTLL1'NG C0MPANV' 907 283 1313; FEB-~ ~1 6'54; PAGE Date: 05-Feb-01 gEQUBNTIAL OPI=R.A,rlON~ (REPOE'I' ,rIGH,r ~POTg, LOC:. -rORQUING UP PR. OBLI=Mg, I='ro.; I/2 HOUR MINIMUM START END HOURS DESCRIPTION 3:30 0:00 ~..~,~0 GOIV'TINUE 7'0 POH WITH BIT NO. 4 ENT E~Y: GLACIER DRILLING COMPANY; 907 283 1313; FEB-6-01 7'30; PAGE 1/1 ,, ~ Marathon ( ' Zl DATE: 0Z/0C~01 LOCATI~ ~ ~; ~) SPUD DAY0; {$ Oil Company AFE#' ~203799 GL: . KB: . MOCWI: . IWELL: K~U,=Z-7 RIG: G/ac/er Dr~l/lng R/~ f FTC: ~ DEPTH: (~D) Y,~ 'CSG 81ZE: 9.625 CSG MD: 5.~B2. CSG TVD: 5.322. SHOE TEST: f3.30 M~. SI 886 LINER TOP: ~R~S~NT ~LL AH~A~ GO~INUE TO POH' GHAN~E B~- ~H TO ~ ~" GASING SHOE- BRE~K GIRGULATiON- ~O~INUE TO ~H ~XECUT~E TO 6~850'- WASH AND REAM TO ~O~OM A~ 7~000'- D~L~ AH~D TO 7~' SUMMARY ,:~ ............................................................................................................................................................... ; IIIHIII Illlllll I Ill ~o.~ 15si SSl~Sl e / f617.51.Ol / I I 2 132 O.f I 9.3 I I 9.5 PPB 7d.9 PPB 29.3 PPB ~OIL WTR pH Pm Pf Mf ~L CA LIME MUD LOSSES ~bbl~) BKGD ~ONN TRIP M~ 0.0 l g0.7/ e.o [ O.O 3.2 ] 3.2 /30'0~ 200] ~dally cum / ~ / / [ ~ BIT~ SIZE TYPE OFF FTG HR8 FTIHR RPM WOE IO D L B G OT R CPF COMMENTS ~ 8.500 }C~LR~P 7,000 ~,~0 33.70 ~.8 ~S ~5 3,3,~,F, 3,NO, TQ POH F/NEWBff C BIT~ SERIAL~ PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP~ BHA: 5 ~ ~" RBI Of ALRGSP, MA OH ~ X MOTOR AKO .8, ~ 3~" STAB, MWD, PUL~ER SU~, X~ ~U~, 3-5" HWDP, Length: JARS~ 23.5" HWDP~ X/O SUB~ 876,75 DRILL PIPE DESCRIPTION: ~10 J~s - 4" DRILL PIPE, MAX PULL ~ JARS MWD MOTOR TORQUE WEIGHT (1000) ii ill, flh l lll I Ih I Ih I Ih Iff, ~111 III111 E.,~., m, Ilk I Ih II]1 I IIdll il Ih Ilk U ltllh I lll ~ Ii~ll* IIIi flh I~h I Ih fl I, I Ih IIIi lib I Ih I h,~l~, re*l., .k ~., m,[l~, .h II1, .~, m, .h .h l~lll,lll~,~h m,a., III, I I Il Ili* I Ih ~lh Iff, IIIi I Ih ~l Ill, lib nh I Ih II h I Ih [[[i Iff* .11 Ilk flh I Ih I}h l lh )111 Iff* I Ih l lll I IJ;lll,~ll IIIi IIIi I Ih I Ih I Ih l lb Ilk ffh I Ih In, Rh Ill, (ill III, ~J RI, I Ih I I Id hi I Ih .E flh [Ih IIIi ~111 I Ih Il ii I Ill Illth Ilk Ifil Ifil I Ih I[11 lib I Ih I Ih Ilk l lll I Ih I Ih II1' '1 h ah I Ih I Ih I Ih I Ih I th Iff* I Ih I Ih flh IIII I I1~ I Ih I Ih I Ih flh Uh t I I* l tll Ifil (MEA. DEPTH ANGLE DIRECTION TVD VERT, SEC. N/S E~ DOG LEG 7~ f f 3.00 f.0~0 fgS:50 6~852, f 7 f ~d68, f5 -f ~EYd, 70 728.~ O. 7,Z41.00 O.~TO 1~8.80 0,880.15 1,408.03 -1,Z70.83 7Z7.70 0.07 7,404.00 0.970 f99.00 7, f43. f3 f,47f.43 -f,279,43 726,78 0.0f ,...,...,,,,..,.,,,,,.,,,,.,.,,,,,,,,,.,,...,...,,,,.,m,,,,,m,.,, .,.,.,,.,,,,,,.,.,,.,,,...,..,.,,.r.,,.,,.,...,...,,,,.,.,,,,. ,,,,,,,,,.,,..,..,,.,,...,..,,,..,,,,,.,,.,.,,,.....,,,,,,...,,,,..,.,,..,,,,...,.,..,,,.,,,,.,.,,,,,...,,,..,,..,,,,,, ,.,...,,,.,,..,.,,,,,,..,..,,,,.,,..,,..,...,.,.,,..,.,,,..., ..,.,,,,.,.,,,,.,,,,,,.,......,,,,..,,,,.,.,.......,,.,,,...., ,,,,,,,,,,,....,.,r,,,,,,,,,...,.,,.,,,.,,,...,.,.........r, ~ OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 7:30 f .50 CO~INUE TO POH ~H ~" DRILL PiPE- CHANGE O~ FLOWTEE ON MUD LINE B~WEE~ MUD PUMP~ 7:30 8:30 f. O0 POH ~H 6' HWDP AND BHA - BREAK Eft- OLEAR RIG FLOOR 8:30 g:30 f . O0 MAKE UP Bff NO. 5 AND R/H WffH 6" HWDP . 9:30 fl:30 2.00 RIH ~H ~" DRILL PIPE TO 9 5~" CASING SHOE. BREAK CIRCULAT/ON AND CHECK MWD f f:30 fZ:00 0.50 SERVIOE RIG AND TOP f2:00 f3:30 f.50 CO~INUE ~0 RIH ~H ~" DRILL PIPE TO 13:30 f~:O0 0.~0 WASH AND REAM FROM ~850'~0 7~000'- DUE ~0 POssiBle UNOER eAUeE f4:00 6:00 f6.00 O0~INUE TO DRILL AHEAD PROM 7,000'TO 7,404- AOTUAL ROTATING TIME AT f2,4 HOURS. CHANGE SWAB NO. 2 MUD PUMP. NO~E A~ER SWAB CHANGE h[lllilldl]tlillllrlllllll[lllllllllllldl[llll;llhl ,lll[t~llld]i;llhllhl]hllhlll~lJl~lltflillli;rllhll hltllttlfl~hl[;llllllllllllllihllhllhllhllhllhlihl ~i~t~1~i~i~i~i~}~t~di~]i~]~;~it~ii~i~i~i~i~[~i~i1~1~iir~i~i~;~ii~1~1i~[~i~ii~1~[~1~]~i~;~1~i~ii~;~]~ ~ii~[h~ihi;~ti~[~h~id~h~1d~h~1~hi1H~;~1~1~h~J~]~ih~t~h[~hiJ~(tti~tU~t~h~d~iU~h1~t~h~h~i~h~[~t[[~i~h~1~h[ih1~h~;~d~ kFE; DH T~TIC~G COMP TOT LAST PIT DRILL DATE; CO~T~ ACTUAL WELL CO~T~ [~lll~lll~llirllill[~lll~lllilll~l~Jllilll[lllill~ll~lMUD ~i~i~f~r~i~i~[~r~[i~j~i~i~[rir~i~"~i~ ACTUAL IllilllJlll!~l!lllilll~ll!lllJl]l LAST BOP TE~T DATE; 0Z~1~1 DEILLING SUPEEVlSOE: DARRELL GREEN BY: GLACTER DRTLLI'NG C0MPANV' 907 283 1313; FEB-?-01 5'44; Marathon .,i~ ~ DATE; OZ/O?/Ol LOCATIO...,( ' ~0 SPUD DAYS; Oil Company AFE#' 0203790 GL: . KB: . MOCWi: PAGE 1/1 WELL; KBU4~.-T RI(3:Glacl@rDrlllirl~TRlJ7 ? FTC: f0O DEPTH: (MD) ~,~TO (TVD) ~SG S~E: 9.625 COG MD: 5,~82. COG TVD: ~.222. SHOE TEST: f2.20 MAX. SI LINER TOP~ , GO~INUE ~0 D~LL AHEAD ?0 X, BXO'. GIRGULA~E BO~O~ UP - BAGK REAM O~ O~ THE TO EXECUTIVE CO~INUE TO PON TO 5~582'- ;ERVICE ~G - ~H ~0 BOSOM A ~ 7~570'- CIRCU~E AND COND~ION MUD SUMMARY ~ISE MUD W~Q~ ~0 fO. 5 PPG - POH ~0 5,972'- PUMP DRY JOB - CO~NUE ~0 ~ ..................... ,,,.,..,,.,..,,.= ................................................................... ~.MW VIS PV YP ~ELS WE T f.h 3O HT FC CBC SAND OLD BENT SALT DRIEEED BARITE :~ ~IT~ 812E TYPE OFF FTO HR8 FT/HR RP~ WOB I OD L~ 0 OT R gPF ¢O~ENT8 C BITg OERIAL~ PREO0. GPM JET~ TFA ANNULAR VELOCITY BIT HP) ~ ~Z339 ~ 23~0 I ~fO[ ,~l~f~ I 0.~70 I DP,73.~ I f33.0 BHA: 5 8 f~" RBI O~ALRGSP, MAOH ~ X MOTOR AKO .8, 8 3~" 3TAB, MWD, PULSER SUB, X~ 3U8, 3.5" HWDP, Length: JARS~ 23-5" HWDP~ X/O 876,75 DRILL PIPE DESCRIPTION: glo Jts - 4" DRILL PIPE, MAX PULL: ~ JARS ' MWD MOTOR TORQUE WEIGHT (1000) ~MEA. DEPTH ANGLE DIRECTION TVD VERT. OEC~ NIO E~ DOG LEO 7~368.00 0.790 222.00 7~f07. f~ f~70.~0 -f~278.~g 726.7~ 0.30 7,4~3.00 0.700 ZZZ.40 7,~3~.13 1,471.10 .1,~7~.70 725.~5 0.07 7,523.00 0.790 ~09.40 7,~62. f3 f,47f.26 -f,280.0f 725.43 0.~ ~. OPERATIONS IN SEQUENCE START END HOUR~ DESCRIPTION 6:00 f2:30 6.50 DRILL AHEAD FROM ~'~0 7~570'. ACTUAL ROTATIN~ TIME AT ~.~ HOUR$ ~2:30 ~3~30 f,O0 CIRCU~A~ ~O~OM~ UP f3:30 rS:00 4.50 BA OK REAM O~ OF THE HOLE TO 6,~0' - TIO~ AT 7,243L7,26~6,826~ - NORMAL UPWARD DRA~ A~ fBSK - WORK PIPE A~ 2OSK ~0 250K f8:O0 f~:00 f,O0 CO~INUE ~0 POH 70 9 5/8" CASING SHOE AT f~:O0 f~;30 0.50 ~ERVIOE RIO f9:30 2f :O0 f .50 RIH TO 7~570'- 4' OF FILL 2f :O0 2:30 ~,~0 CIRCUlAtE AND CONDfflON MUD - ~I~E MUD WEI~ ~0 fO,6 2:30 3:00 0.50 POH TO 6,972'- UPWARD DRAG 5K ABOVE NORMAL UPWARD DRAG. NO PROBLEMS 3:00 3:30 0,~0 PUMP DRY JO~ AND BLOW DOWN ~URFACE CIRCUlAtING ~Y~EM OLEAN UP GOOD ;~[IJrl]lhllr~l~hlthJ;t~ll*[Ihll;,ll;~ll[iJ)hl~hH fll;lllllll*illtllhllrllffrllrlllhlile[Ihlflllihiit~llh Illlllillllil~lllflll;lllllll~llhllhllhllhiihllhllhl ~h~i~i~[i~;t~t~t~r[~t[~t~s~11~i~;[iitiii[[~[~i~t~1~i~;;i~;~i~*~i~t~1]~i[~ii~1~t1i~;]~;~i~;~;~t~ ~h~i~h~*~i~i~f~h~hi~t~h~H1~b~t~1~ht~h~i~1h~i~hiih~hi~hi~h~h~1h~h~h~ih~h1~h1~h~h~h~tHh~h1~(i~h~h~h~r~h~h~i~h~[h~h~it~ih~i~N~h~ AFB: DH TOT/COG COMP TOT LAOT PIT DRILL DATE; ACTUAL WELL ........ DAI~Y: 1~06~ CUM: ~0;9~3 DAI~Y: ~6;367 CUM: ~,3~6~36 NO A~/DE~ ~EPO~TED DRILLING SUPERVISOR: DARRELL GREEN ENT BY' GLACI'ER DR'rLLTNG O0MPA~' .... 907 283 1313; FEB-""-01 6'50; PAGE 1/1 M~mthon .~- ~$ DATE: 01~t~$t~¢ LOCATIO~,~ O: ~f SPUD DAYS; ~ Oil ¢om~an~ ~F£#: 0~0~?~0 01.: . KB: . ~0¢ WI: . IA/ELL= KBU4?..T RIG: GiaclerDrlliln~'lRIj7 ? FTG: 0 DEPTH: [MD] ?,~?0 (~D) CSG SIZE: 9.625 CSG MD: 5,~B2. CSG TVD: 5,322. SHOE TEST: f3.30 MAX. SI GO~INUE TO POH ~H B~ NO.5 - L~Y DOWN DIR~ONAL TOOLS AND GLEAR RIG ~LOOR - EXECUT~E D~E VA~VE~ - RI~ UP ~OHCUM~ER~ER - LO~IN~ RUN NO.f "P~-D~" - LQ~CING RUN NO,2 SUMMARY "CMA" - LOG~NG RUN NO.3 CMW VIS PV YP GELS WL T l.b 3U HT FC CEC SAND SCD BENT SALT DRILLED BARITE fO.6 1551~1~1 ~ i ~7j ~.61~o~ i J t ~ ~= o.~ I '-~1 i 8.6 PPB 78.S PPB ~.~ PPB ~OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES Jbbl~J BKGD CONN TRIP MAX O O 88 6 g S O 6 O. . O ~8,OOO ,60 dally ............ .~,~ ........................,,.L ...................................................................................J .... ,,: ....... I ............. :,5 ..... : ..... &,: ............. : ....... L..: ........ 1 ............................................. 1 .............. 1 ~ BIT~ SIZE ~PE OFF FTG HR8 FTIHR RPM WOB I OD LB O OT R ~PF COMMENT8 { BIT~ 8ERIAL~ PREOS. GPM ~ETO TFA ANNULAR VELOCITY BIT ii~lll ii ~ll[i ~lllll ii ~l iii i[i ii II~Jl~lJJ~Jll~l~lJl'lll~lll~flJ~lll'll['lll'l~'lll,liltlll, ~`~ti~'~i~'~i'~r~'u~`~'~i'~1~'~i~'~'~iq~'~i~'~ii`~B~r~ ' ' ,~1, ' , .... ~ , ....... BHA: ~ 8 ~" RBI G~ALRGSP, MAGH ~ X MOTOR AKO .8, 8 3~" STAB, MWD. PULSER SU~,X~ SUB, 3.5" HWDP. Length: JAR$~ 23-~" HWDP~ X/O "DEILL PIPE DE~CEIPTION: ~10 JJS - 4" DRILL PIPE, MAX PULL: I ~ JAR~ MWD MOTOR TORQUE WEIGHT (10O0} I, ,I ~ l, I, ~ II ,..,,i.,..,.,,.,..,..,,,.,.,,,,,,,,.,..,...,..,..,,.,,,,,,..,.,,.,,,,,,,.... .......................... ,.,.,,.,,,,. ................. ,,,,.,..,.,.,.,,,,.,,,,,.,.. ................................... , ................................... "'"""""""'"'"'"""'"'""""11 ................. Illillllllll"'"'"""""'""'""'"'"~llll/lllllllll'"~'"~"`~"'~"~'''~'''~'''''''~''''"~'''""~'"'"''''''''''~'''~'"`"'''''`'~"'~"''"'~'''~'"~'''~'''`"'~"'`'""~`~"'~"'~''~"~"'~"'~"'"''~"'~"'~'"~"'~"""''''~''''' .................... ""'""'""'"'""'"""'"'""""""~'"~' (MEA. DEPTH ANGLE DIRECTION , TVD VERT. SEC. 'NIB E~ DOG LEG , 7,3~8.00 0.790 222.00 7~ fO7. f~ f~470.60 .f ,27~.49 726.75 0.30 7,4~3.00 0.700 22~.40 T,23~.13 1,471.10 -1,Z78.70 7~5.~5 0.07 7,523.00 0.790 209.40 7,262. f3 f,471.26 .f,280. Of 725.43 0.~ I'lll~Ul~J[~rllqll~UlqllqU,fllllllqrl+ll~qllq41~lllqltl~lql,,llPllllll[,I IIIIIllPr,lllllllllllllqll,fll,ll}qllllll~lrPllfllltqll,lllrllllll~,,llqll 'l~l'lll'l]lllllllllql~qll~lltql~'llrqllqflqll,l*~,lllqkl,klllr~qll**~'l I'lllqllq.~.*~ll*ql*,~lq.*.l,.lqlp.pr.ql~rlt,.,qllql,,]B,*U,, Iq,p.pup.pr~,q~FlU,.p,;p*~p.p;;,ql,,rlrqu~lUq~pllprl;qlpll~l iql;,iipliplipliiqliqlplipli;~r;plii;~iFiipJiplii~Ulql;qlr,rUq.~,. .'.I'~,,,uqlplIplIpRpllPH,'*rP.PHP.plU']Ip]I;q;I~rr~qlI'III ( OPE~ATIONS IN SEQUENCE START END HOU~ DESCRIPTION iii 6:00 ~:30 ~0 CO~INUE TO POH ~H ~" DRILL PIPE gJ~O ~oo ~,5o ~o~ ~ 5" DRI~ ~1~ AN~ ~ ~ ~Y DOWN DIR~C~IONA~ ~0~ . C~AR ~1~ f f :O0 fl:30 0.50 TE~T TE~O TOP DR~E UPPER AND LOWER IBOP VALVES , ff :30 f3:00 f,60 HO~D PRE-JO~ ~AF~ ME~IN~ - RI~ UP ~CHLUM~ER~ER f3:00 f~:O0 2,00 LOGGING RUN NO.f - P~AND ,,fS;O0 4;00 f2,O0 LOGGING RUN NO,2 . OMR ~:00 6:00 2,00 LOGGING RUN NO,3. R~ .. ,, .llllb#lllllllllllit~llillllllllll~irllll~llll[lll~l~ll Ilhl[llBIiIIItllhllhllltl[illllllllll~llllltllllllllllll hlillllll[Ih[Ihll]lllllllhlllllillllhllhl[llllhlll ~]~[~[~i~[~ii~*~i~*~i~ii~]~[~t~[~t~][~i~[~i~i~[~i~i~(~i~j~ ~FE: DH TSTICSG COMP TOT LAeT PIT DRILL DATE; I~lll~lll~lllilllilll;lliil~lililll~lllilll~lll[ll[~ll!lMU~ CO~TS AcT~AL~B~[~t~[i~i~i"~";~i~ii~;~i~[~L~ CO~ ACTUAL tllill[illlilllilll!l[[illl!lllill LAST BOP TEST DATE;OaSIS1 DAILY: 4~05T CUM: IOG~O20 DAILY: 33~000 CUM: ~391~136 NO ACCIDE~S REPORTED TODAY DRILLING SUPERVISOR: DARRELL GREEN . . -'NT BY: GLACIER DRILLING C0UPANY; 907 288 1313; FEB-9-01 5:28; PAGE 1/1 Marathon - ~4 DATE: 0g/0~/0~/ LOCATIL ~: ~ SPUD DAYS: g~t Oil ~ompan¥ AS~'#' ~037~ Gl.: . KB: . ~OCWI: . WELL:/r~lU~2-7 RIG: G/ac/@rDrlll/fTj7 R/~I ? FTC: O DEPTH: (MD) 7,~70 (~D) 7,SOg ~SG SIZE: g.62~ CSG MD: 5.~B2. CSG ~D: ~.322. SHOE TEST: f3.30 MAX. SI LINER TOP: , '" '"" '"'" "'" "' '"' "'" '""' '" ~a ~ ff i~ i"-"' "' ---" "' · ~ · -- '"" ="' '" · '~- -"- "'" '"-~ · --"" - - '" ~ '"-'"*~ "~'"-- ="'-'"" "' -- - '" -'""- '""'-'"'" "- = '"- "'" "" "" '--" '" .,... ,.~ ,~... ,. =... ,..,.. ,... ,,, ,....... ,. ,... ,... ,~......, ,..,. ,...,.,., .,..,. ~..,..,~...., .... ,..,.. ,. GO~INUE TO LOG ~H SCHLUMBERGER TOOLS ~UOK AT 0,030' R~ PROBE DE~H - O~ E. LINE AND EXECUTIVE ~G UP ~O ~T~P OVER CABAL - ~RIP IN ~HE HOLE ~0 ~720'- CHANGE O~ BAAE~ FOR LONC ~- SUMMARY ~H SINGLES IN ORDER TO KEEl; UNE ~G~ ~H O~ ~G~ BINDING ON TOP CHANGE SAVER SUB AT 5~562'T0 ~ f~ IF fO.6 I 621 fg I f61 7 I f6I 6.g ~ g0J I I I 2 ~2 0.2 I ~-? I I ~.6 PPB aa.o PPB aT.f PPB COIL WTR pH Pm Pf Mf CL ~ LIME MUD LOSSES [bbl~} BKGD CONN TRIP MAX o.o l ee.=t =.s I O.~ o.= / ~.o / ~,°°°1 ~ / /"='v =um I / I ~ BIT~ ~IZE TYPE OFF FTG HR~ FTIHR RPM WOB I0 D L B ~ OT R CPF OOMMENT~ ~. BIT~ SERIAL~ PRESS. GPM JETS TFA ANNULAEVELOCITY BIT HP~ BHA: e ~UIDE, OVEROHOT, TOP OU~, ~.5" HWDP, PUMP O~ ~UB, OOM~O. JAR~, ~3-5" HWDP, X~ ~UB, Length: 787,66 DRILL PIPE DESCRIPTION: MAX PULL: ~ JARS MWD MOTOR TORQUE WEIGHT (1OO0) ............. ................... 1 ........................................ [ ..................................................... 1 ....................................... [ .................................................... 1 ...................................................................................................... ......... ........... ......................................... ......................................... CMEA. DEPTH 'AN~LE DIRECTION TVD VERT. SEC. NI8 E~ DOG ~ , 7,368.00 0.?g0 222.00 ?~f0?.f4 f,470.60 -f ,278.4g 726.75 0.30 7,483.00 0.700 ~ZZ.40 7, Z3Z. 13 1,471.10 -1,~78~70 7~5.05 0.07 7,523.00 0.790 209.40 7,~6Z f 3 f ,47 f .26 - f ,~80. O f 7~5.43 0.~ ,,,.~.,.,.,,.,,.,,,..,,,,,,,,,,,,,,..,,~,.,,,,,,,,~,~.,,,,,,,,,,,,,.,,,,,,.~, m,;~..r~.,~..~,.rl~,~,~e~l,~la,u~,,I,al~;~,.~,,,,,.,,,., ,,,.,,,,~,,.,,.,,,,,,,,,,,,,,,.,,,,,,,,,,,,,,,,,..,,'..,.,~,,,',.',,,,,,,,, ',,,,.,.,,,,~,,,,,,.,',,....,,',,,'.,'.,,',,,'.,,',,,'.,',.,,,,'..,,,. ,,..,,,,,,,,...,,.~,,,,,.,,,...,,,,,,.,,,,,.,,,,,m,,,,,,..,,,,.,,,,,,.,, ,.,..,,,.,,.,,,,,,,...,.m,...,.,,.,.,..,,.,,,.,,,,,,,,.,,,,,,,, ..,,,,.,..,,,,,.,,,..;,..,.,,.~..,,,~,m.,.,,,.......,...,, ,.,,,,,,,.,,.,,;..,,,..,.,,,,,.,,,,,,~.,...~,..~,..~,,,,,~,,,s,,,..~ START END HOUES DESCRIPTION 6:00 7:30 f.~O CO~INUE ~0 LO~ ~H SCHLUMBERGER RUN NO.3 "R~" . PROBE A~ 6,030' 7:30 fZ:00 ~.50 WORK ~UCK LOOOlNO ~00~ AT 6~030'. NORMA~ LIN; WEIO~ AT 3f50 ~. PUL~ UP TO 7000 LBS. - TOOLS APPEAR TO HA VE MOVED UP HOLE 3 FE~- NO MORE MOVEME~ HEAD WEll. AT 800 ~;. - ~/NE APPEAR~ ~0 ~E HUNO UP , fZ:00 f5:00 3.00 C~ AND THREAD SCHLUMBERGER CABLE- HANG $HEAVE AT CROWN- RIG UP TO IN THE HOLE OVER E. LINE. THREAD THRU OVER SHOT, ONE ~TAND OF 5" WE!O~ PiPE , AND JARS . IS:D0 0:00 9.00 RIH ~H 4" DRIL~ PIPE ~TR/PPIN~ OVER E.~/NE TO d~720' 0:00 f :O0 f. O0 CABLE TA~NO WEIG~- RIH T0 4,805'. UNABLE TO O~ SLACK PULLED BA CK TO ~URFACE - LAY DOWN ~INGLE IN MOUSE HOLE AT d;775'- PICK UP DOUBLE . PULL WEIG~ . RIH ~0 ~6~6' . UNABLE ~0 G~ ALL ~LACK O~ OF CA~LE WEIG~ H~ING ~P DR~E - POH ~H SINGLE AND MOUSE HOLE A~ 4,770' f :00 2:30 f.50 PULL $LA CK.TO ROTARY TABLE. CHANGE BALES TO LON~ S~- REMOVE WEIGHS 2:30 6:00 3.50 PICK UP SINGLES AND STRIP OVER CABLE TO 5,562'- CHANGE SAVER SUB TO 4 f~ IF [~lt~ilhiUlilltll~llllt[llllll[llltl]l;lllllll[llllll ~lti;llltl[lllllllltthilhllhU[llll~UhUl~llhl]i~h Illltll~llllfllll~lli~llhllllliltllhlll~lllli~lliglill ri~tt~i~t~iiit~it~]~]~[bi~[~[~H~i~i~i~i~i~t~i~i~ii~i~i~i~[~i~i~;~[i~ii~;~i~i~t~ii[~[[~i~i~t[i~i~ ~FE; DH TeTICeG COMP TOT LAeT PIT DRILL DATE; Oa~l lill~lll~lll[[[l;ll~;lll!lllilll~ll;l;lil~[l~[ll~rll;MU~ CO~T~ ~c~AL~;~i~;~i~[~;~r;~i~i~i~[~"~]~;~j~ii~i~;~ CO~T~ ~CTUA~lll;~ll[It[illlilllilll;lll~lllJll LAST BOP TEST DATE;O~I~I DRILLING SUPERVISOR: DARRELL GREEN kit BY: GLACTER DRTLLTNG C0MPA~"". 907 283 1313; FEB ' 01 5'49; Marathon ~ 30 DATE: 0,~/1,~01 LOCATION D ,~0 SPUD DAY~; ,~7 Oil Company AFL#: 9203799 GL: . KB: . MOCWI: . PArlE 1/1 WELL: KBU,d'2.7' RIG: Glacl@rDrlllln~TRff3 ? FT(3: DEPTH: (MD) 7',,57'(7 (TVD) CSG SIZE: g.§25 CSG MD: 5.582. CSG TVD: 5.322. SHOE TEST: f$.30 MAX. SI 0 LINER TOP: . NIPPLE DOWN BOP. DRESS OASlNG $'7'UB AND NIPPLE UP TREE. PRESSURE TEal'AND i;REEZE PROT'E~I' EXECUTIVE TREE, RIG REI. F,A~ED FOR MOVE A?' f.~.'O0 2/f,~/O,l. RIG ~0 WN AND PREPARE FOR RIG MOVE, SUMMARY (,,w ws Pv YP eEcs wc T ~.~ ~u HT PC CaC SAND SCD B~NT SA~ D~CCED BA,~Ta (OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES [bbl~ BKeD CONN TRIP MAX dally cum ..................... l ...................... 1 ................ 1 ....................... [ .............. 1 ............................................... 1 ................... ~ .............................................................................. l ................................................ 1 .................................. 1 ( BIT~ SIZE TYPE OFF FTG HR8 FTIHR RPM WOE IO D L B G OT R CPF COMMENTS { BIT~ 0E~IAL ~ PRESS. OPM ~ETO TFA ANNULAR VELOCITY BIT HP) .. ...................................................................................................................................... I ..................................................... I ..................................................... I ....................................................................................................................... I ..................................................... I ......................................................................................................................................................................................................... I D~ILL PIPE DESCRIPTION: ~A~ PULL: ~h~j]~h~j~h~*~'~h~j~h~1~j~1~m`~"'~'~+~uj~h~'~h~"~h~h~j~h~hm~~'~'1~'1~'~h~'~~'mj~h~`~j]~j"~j*~j~j'~"'~h~h~'~'i~'~'~'~j~h~h~1'~'j~h~h~'~'m`m'~h~j~j~'j~`~"j~j~j~h"~h~"`~h~h~`1~'*~'~'~`~`~h~'~h~'~u"~h1~h~j~'*~'~'j~~m'~`~"'~j~t~h1~'11*'1~*~j~'~~'~h~*`~'"~j~`~j"~'~j~"~'"~'~h~'~~j~*~'~'"~'~h~h~rj~~j~"'~h~r~j~*`~'~'~j~'~h~h~hu*j~~'~j~'~'"h~h~*`~jh~h~j'm~j~"'~j~1'~h ~MEA. DEPTH ANGLE DIRECTION TVD VERT. ~EC. NI~ E~ DOG LE~ ~,368.00 O. Y90 222.00 Y, fOT. f~ f ,~70.60 .f ~278.~9 72~.75 0.30 7,4~3.00 0.7~ Z~.40 7,~3~.13 1,471.10 -1,~T~,7~ 7~5.~5 7,523.00 0,790 209.40 7,262. f3 f,47f.25 -f,280.Of 725.43 0.~ ~ OPERATION~ IN ~EQUENCE ,, ;TART END HOURS DESCRIPTION 6:00 9:00 3,00 NIPPLE DOWN BOP. REMOVE DSA. INSTALL ANNULAR PLUG. P~ BOP ON CARRYIN~ ~AND AND REMOVE FROM CEllAR, ~00 f4:00 5.00 MAKE FINAL O~ ON OARING AND DRE~8 STUB. NIPPLE UP TREE. TEST PAOKOFF ~0 500o P~I. FINISH NIPPLE UP AND FREEZE PRO~ECT ~REE. PRESSURE 250/f0 MIN AND 5000ILO MIN. RIG RELEASED FOR MOVE f~:O0 2/f~f f4;O0 6;00 f6.00 RIG DOWN TOP DR~E AND TORQUE TUBE. LOAD ON TRAILER. RID ~TAND PiPE MANIFOLD~ CHOKE LINES, FILL UP LINE~ ~LL HOSE$~ AND ROTARY MOTOR, LOAD O~ EPOCH UN~ C~IN~ TANK~ ~OPE RACK~ ~ AND WEA~HERFORD EQUIPME~, RIG DOWN BERM AROUND RIG, RID DERRICK BOARD, ~HANGE OIL ON ~ DRWK MOTOR AND ~ MUD PUMP MOTOR. DICONNEC~ DRE;~ER ~LEEVE~ . Illllhl]llllllllll[lllilhllh[ll;~lr[il[{llhlll~llh[rl llllllllllll[llllhl(llllhllllillllHiIIhilllllhl[llt[ hl[hllllll]lllllllllllll~lhllllllllll[it[illl[lilhllll ~i~[~;~1~[~[~i~i~ti~[~i[~[i~]~i~;~i~;~i~[~[~[~[~t[~[~[i~t~]~i~i~iii~ii~[~ ~h~i[~h~ih)~h~d~i~h~h~ih~h~it~h~h~h~h[~h~h~h~h~h~h[~[~h~h~[h~h~[~[~ih~i~1~ih~hi~h1~h[[h1~h~h~1~t~h~h~ht~i~"~ AFL; DH TSTICSG COMP TOT LAST PIT DRILL DATE: DAILY: 0 CUM: 172~70 DAILY: 73~3 CUM: 2~324~92 NO ACCIDE~ REPORTED TODAY DRILLING SUPERVISOR: RICK GIDEON I~W...E. LL: KBU 4~-7 RIG: G~c/er Drflling Rig ~ FTC: DEPTH: (MD)... 7,570 (TVD) 7/309 ~SG 81ZE: 9.625 ~G MD: 5,582. CSG ~D: 5,~22. 8HOE ~ST: "' 13.30 M~ $1 0 [UN~:~O;: : ...... PRESENT OP~ MOVE ~G O~ ~OCA~ON ' ' ~RIG .DOWN DRILLING EQUI~ENT AND MO~ TO ~U 2&8 L~A TiON ~ECU~ · SUMMARY qMW ViS ~;YP GELS WL T 7.5 30 HT FO CEO SAND ELD BENT 8ALT DRILLED ~1~ iii i i ii I iii ~ ~ ~ i' ..... .... I J ......... I [ i J ~ 132 ..... I [ I PPB PPB PPB 'Si'L ~R ~H Pm ~ Mf "~L ..... cA"LI~'~'"MUD LOSSES (bbUE) ..... BKGD" ~oNN ....... TRIP '- ~ BIT, 8~Z~ ~PE OFF ~G HR9 FT~R RPM WOB IOD LB OOT R CPF COMMENTS "':.!. · I '! :,1 ...... I' t,, t, ' I ..,....:1 ...... . ,, ,,,, , . BHA; : Len~: . DRILL PIPE DESCRIPTION i M~ PULL: ~' jARs '.- , ",'""'~' ...... ~D .......... MOTOR"'""__ ,. ,, ,, .... ,,,,,, TS~QUE ....... ,.,,,, ' ............ WEIGHT. 11~0~ ........ , , ,,,,, : ~_ -- ~ -- .... __~ / ] -[- -' / :B~= Pu Hot ..... So . P?THi ANGLE DIRE~ION ...... ~D VERT. SEC. ,, ~1~.... ~ ~G LEO 7.3~.~ ~ 0.790 222.~ 7,107.14 1,470.60 -~,2~,49 T~,7~ 0.30 ~ ........ 0.7~ 222.40 7,~13 '"~4'~f.10 .~,279.70 725,6~ ...... 0.07' ..... 7'~3~. ~, 7,523.~ ~ 0,7~ ~9,40 7,252.13 ~,471.2e -f, 280,01 72~43 0.~ ~"m ................................... _ ............................ ii i i · ' ( ~i. op~R_~TIONS IN SEQUENCE START END HOURS DE~RiPTis~ ............................ ~ ........................... 6:~ 1~1~ 6.~ RIG OO~ DRIVING EQUI~ENT AND MO~ OFF LOCATION_.. ............. , , ', , , , ,,,,,,,~, .,, . .,.,, ,..,~ ....... - ', : ........... .... , ............ . [ ,, ~,, ~FE: DH ' ~T/CSG COMP TOT ~T PIT DRILL DATE: ~.~U¢ CD~ ACTUA~ ~::~:~':~ ACTUAL ~ ~T BOP T~T DATE: DALLY: ~ 0 CUM: t7~770 DALLY: ~,9~ _CUM:_ 2,32g,50f ,NO:ACCIDEN~ REPOR~D TODAY DRILLING sU'p~RVlSOR: RICkGIDEON"' 1 rk)/ •Operations Summary Report by .• Marathon Oil Well Name: KENAI BELUGA UNIT 42 -7 t 1 \ _ O'Z' Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country I KENAI ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) I KB -Ground Distance (m) Spud Date Rig Release Date 0.00 20.12 26.521 6.40 1/19/2001 2/14/2001 Daily Operations Report Date: 2/11/2001 Job Category: COMPLETION 24 Hr Summary Continue to POH striping over wireline. Spool up electric line and rig down Scholumbergerl Lay down fishing tools. Make up BHA and RIH. Circulate and condition mud. Spot 15 ppg pill on bottom. POH. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 10:30 11:00 0.50 SERVIC RIG AF Change out saver sub on Tesco top drive to HT -38 connection. 11:00 12:00 1.00 PULD BHA AF Make up bit #5 (RR) and BHA. RIH with 5 "" HWDP. 12:00 13:30 1.50 TRIP AF Continue to RIH with 4 "" drill pipe to 2,500'. 13:30 13:45 0.25 TRIP AF Break circulation to fill drill string. 13:45 14:30 0.75 TRIP AF Continue to RIH with 4 "" drill pipe. to9 5/8 "" casing shoe at 5,560'. 14:30 15:00 0.50 TRIP AF Break circulation at soe. 15:00 16:30 1.50 TRIP AF Continue to RIH with 4 "" drill pipe to 7,530'. Break dirculation. Wash to bottom at 7,570'. 16:30 18:00 1.50 CIRC MUD AF Circulate and Condition mud for casing Excape system. 18:00 19:30 1.50 TRIP WIPR AF POH to 9 5/8 "" casing shoe at 5,582'. No problems with hole. 19:30 20:30 1.00 TRIP AF RIH to bottom at 7,570'. No problems. 20:30 23:00 2.50 CIRC ' MUD AF CIRCULATE BOTTOMS UP AND CONDITION MUD - BUILD 16 PPG PILL - RABBIT LAST ROW OF CASING 23:00 00:00 1.00 CIRC MUD AF PUMP AND SPOT 16 PPG WEIGHTED PILL ON BOTTOM UP TO 7,500' 00:00 01:30 1.50 TRIP AF POH TO 9 5/8 "" CASING SHOE AT 5,582' - NO PROBLEMS 01:30 02:00 0.50 NULL AF PUMP DRY JOB - BLOW DOWN ALL SURFACE CIRCULATING LINES 02:00 06:00 4.00 TRIP AF POH LAYING DOWN 4 "" DRILL PIPE Report Date: 2/12/2001 Job Category: COMPLETION 24 Hr Summary Pull out of hole with drill pipe and lay down. Test choke manifold, upp pipe rams and blind rams. Pre -job safety meeting on running casing. Begin running 3 1/2 "" Excape production casing system. Ops - -- Trouble- - - .. - • -- - - - - - - StartTime End Time Dur(tx) - OpsCode. Activity Code - -. Status Code Com . .. - • , , 06:00 08:00 2.00 TRIP AF POH LAY DOWN 4 "" DRILL PIPE 08:00 09:00 1.00 TRIP AF RIH WITH 4 "" DRILL PIPE FROM MAST 09:00 12:30 3.50 TRIP AF CONTINUE TO LAY DOWN 4 "" DRILL PIPE 12:30 14:30 2.00 TRIP AF ' LAY DOWN 5 "" HWDP AND BHA - CLEAR RIG FLOOR 14:30 16:00 1.50 NULL BOPE AF PULL WEAR BUSHING - SET TEST PLUG - CHANGE OUT UPPER PIPE RAMS TO 3 1/2 "" 16:00 18:30 2.50 NULL BOPE AF TEST CHOKE MANIFOLD VALVES - HCR - INSIDE CHOKE VALVES - MANUAL VALVES ON KILL LINE - ANNULAR - UPPER PIPE RAMS - BLIND RAMS - AT 250 PSI. LOW AND 3000 PSI. HIGH 18:30 00:00 5.50 NULL AF HOLD PRE JOB SAFETY MEETING WITH ALL PERSONAL ON LOCATION - RIG DOWN RIG TONGS - PIPE SPINNERS - CHANGE OUT BALES TO LONG SET - PICK UP 75 TON " "YT "" ELEVATORS - SPOT 45 TON CRANE AND PIPE RACKS FOR TRI -POINT PERFORATION GUNS RIG i gu 2 1 .02 UP WEATHERFORD CASING EQUIPMENT - RIG UP PROMORE AND TRI- S �,1 NED POINT PERFORATION CONTROL LINES 00:00 06:00 6.00 RUN CSG AF RIH WITH 3 1/2 "" CASING AND EXCAPE SYSTEM PER PROGRAM Report Date: 2/13/2001 Job Category: COMPLETION 24 Hr Summary Continue running in hole with 3 1/2 "" Excape modules. Make up Promore downhole pressure sensor. Continue to run in hole to 7,517' (shoe depth). Circulate bottoms up. - - Ops Trouble - Start Time - End Time Dur (hr), Ops Code Abtivlty Code Status Code , - - Corn 06:00 15:00 9.00 RUN CSG AF Continue to TIH with 3 -1/2 "" Excape modules. 15:00 17:30 2.50 RUN CSG AF MU Promore downhole pressure sensor. Circulate hole while tying electric cable into pressure sensor. 17:30 20:30 3.00 RUN CSG AF Continue to RIH with completion assembly 20:30 21:00 0.50 REPAIR RIG TA MSTB Repair Tugger 21:00 00:00 3.00 RUN CSG AF Continue to RIH to 9 5/8 "" casing shoe 00:00 01:00 1.00 CIRC MUD AF Circulate bottoms up 01:00 05:00 4.00 RUN CSG AF Continue to RIH to 7,517' (shoe depth) with Excape System 05:00 06:00 1.00 CIRC MUD - AF - Rig up to circulate - Circulate Bottoms Up www.peloton.com Page 1/2 Report Printed: 8/3/2011 /j'ts jJ •Operations Summary Report by Marathon Oil Well Name: KENAI BELUGA UNIT 42 - Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 'KENAI ALASKA USA Casing Flange Elevaton (m) 'Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.001 20.12 26.52 6.40 1/19/2001 2/14/2001 Daily Operations Report Date: 2/14/2001 Job Category: COMPLETION 24 Hr Summary Circulate and condition hole. Rig up Schlumberger. Log upfrom 7440' to 5500' with GR /CCL. Adjusted gun position down 0.5'. Rig up cementers. Cement with 15.7 ppg class G cement. Bumped plug. Floats held. ND BOP. Thread control line through tubing spool. Ops Trouble Start Tim a End Time Dur (hr) Ops Code Activity Code Status Code Com 06:00 07:00 1.00 CIRC MUD AF Circulate and condition hole 07:00 09:30 2.50 LOG CSG AF RU Schlumberger. RIH w/ GR /CCL. Log up from 7440' - 5500' to tie -in tubing- conveyed guns. POOH, RD Schlumberger. Decided to adjust gun position 0.5' deeper. 09:30 14:00 4.50 PUMP CMT AF RU BJ cementing equipment. Test lines to 3500 psi. Pump 40 bbl of 11.0 ppg spacer . Batch mix and pump 184 bbl (875 sx) of 15.7 ppg class G cement with 0.6% CD -32, 0.2% FL -63, 1 gps FP -6L, 0.15% sodium metasilicate, 0.15% R -3, 0.9% BA -10, and 2% potassium chloride. Drop wiper plug, displace with 66.8 bbl of 3% KCI. Bumped plug at 1356 hrs with 600 psi over pump pressure (2445 psi total). Bled off trapped pressure; floats holding. 14:00 22:00 8.00 WAITON CMT AF WOC. Clear rig floor, ND bell nipple. 22:00 00:30 2.50 NULL BOPE AF NIPPLE DOWN BOP. PICK UP BOP AND RIG UP SAFETY SLINGS ON STACK. 00:30 06:00 5.50 NULL BOPE AF THREAD CONTROL LINES THROUGH TUBING SPOOL OUTLET. SET SLIPS ON CASING WITH 50,000#. INSTALL PACK OFF ON CONTROL LINES. ROUGH CUT CASING. SET BOP OUT. Report Date: 2/15/2001 Job Category: COMPLETION 24 Hr Summary Nipple down BOP and remove from cellar. Make final cut on casing. Nipple up tree and freeze protect tree. Presure test. Rig released for mvoe at 14:00 on 02/14/2001. • - - _ - - - - Ops Trouble - - -,_. Start Time - End Time Our (hr) _Ops Code Activity Code- Status Code Com 06:00 09:00 3.00 NULL BOPE AF NIPPLE DOWN BOP. REMOVE DSA. INSTALL ANNULAR PLUG. PUT BOP ON CARRYING STAND AND REMOVE FROM CELLAR. 09:00 14:00 5.00 NUND WLHD AF MAKE FINAL CUT ON CASING AND DRESS STUB. NIPPLE UP TREE. TEST PACKOFF TO 5000 PSI. FINISH NIPPLE UP AND FREEZE PROTECT TREE. PRESSURE TEST 250/10 MIN AND 5000/10 MIN. RIG RELEASED FOR MOVE 14:00 2/14/01 14:00 06:00 16.00 AF RIG DOWN TOP DRIVE AND TORQUE TUBE. LOAD ON TRAILER. R/D STAND PIPE MANIFOLD, CHOKE LINES, FILL UP LINE, KILL HOSES, AND ROTARY MOTOR. LOAD OUT EPOCH UNIT, CUTTINGS TANK, BOPE RACK, TBG, AND WEATHERFORD EQUIPMENT. RIG DOWN BERM AROUND RIG. R/D DERRICK BOARD. CHANGE OIL ON #1 DRWK MOTOR AND #1 MUD PUMP MOTOR. DICONNECT DRESSER SLEEVES AND ELECTRIC LINES. Report Date: 2/16/2001 Job Category: COMPLETION 24 Hr Summary Complete rig down of drilling equipment and move off location. - Ops- - Trouble - _ .: -- - . - : - - - . . Start Time End Time Dur (hr) a Ops Code Activity Code Status Code Com 06:00 12:00 6.00 RURD AF RIG DOWN DRILLING EQUIPMENT AND MOVE OFF LOCATION. www.peloton.com Page 2/2 Report Printed: 8/3/2011 KI~U 42-7 ExcapeTM Well Operations Report March 11,2001 ActivitY: Perforatit lowermost interval of the 15 m~dule ExcapeTM ;ompleflon. 8umma.' r).: It went perfect. Modul.~ 1 of the 15 module ExcapeTM completion on well KBU 42-7 well was perforated on Ma~h 10, 2001 by a group of Marathon, Tdpoint, and PROMORE individuals during break from the completion of the offset well. KBU 24-6 (which has 12 modules), : The Io.'wermost perforations, Module 1, at 7,400 - 7,4t{3 feet, were perforated by attaoh~g to the lower green control line and pressuring to 2,200 PSi via the Trlpoint l~Uml3i~g system in the ExcapeTM lB wheeler to actuate the pressure fired head. Shot detect.ion was noticed at the same time by people watching the PROMORE[ downhole pressure recorder data. the shot detection TDR. as well as the sound was acoustically heard,iaa well as recorded on the listening devices. The g.ans firecl at tile nominal shear pin values, and control line integrity was evident after fi.ting. It waa encouraging to note that little fluid volume had to be pumped to re-fill the control line (which was subsequently left open to vent after firing), This is a very tight ir~erval, but by the next moming pressure had built a few hundred psi. against a full columm of KCl fluid. The production facilities are not coml31eted to the ~3oint the well can be fioa~d and unloaded, but ati'orts in that regard need t~ proceed as rapiclly as possible. NOH.L¥~¥N :AN¥~OO gNIqqI~a B3IOYq9 :~,~ J. OI0601.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 6/1/2001 FI LL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9203799 FIELD: Kenai Gas Field TUBING: N/A Frac module #1 through #3 WELL # KBU 42-7 CASING: 3.5", 9.3#, N-80 TREE CONDITION: good BENCHES OPEN: SUMMARY OF OPERATIONS 5/31/01 MIRU frac spread, including 2200 bbl of Williams #2 diesel, 250,000 lbs of 16/20 Carbolite, Stinger tree saver, and flowback iron. Diesel was heated to 80+ degrees prior to mobilization of frac pumps. Tested flowback iron to 4000 psi, and tested frac iron to 7500 6/1/01 Held prejob safety meeting. SITP = 85 psi, SICP = 0 psi, and module #1 perfs are open. Module #1 Pumped 46 bbl minifrac and step down test in module #1, all with 3% KCI across the perfs. Closure pressure was 5005 psi or 0.70 psi/ft. Step rate test showed significant near-wellbore friction. Pumped additional diesel to completely displace the hole with diesel. Shut down ;pumps. Fired module #2, confirmed proper firing of module #2 several ways. Module #2 Pumped 43 bbl minifrac and step-down test in module #2 with straight diesel plus 1.0 gpt NE-110W. Diesel was also traced with chemical tracer and Sc-46 LZW tracer. Closure pressure was very similar at 0.70 psi/ft. The G-function at closure was 3.3 indicating the zone is pretty tight. Pumped another 20 bbl of diesel to displace tracer into formation. Shut down, fired module #3. ..... SEE PAGE #2 ...... Vendor Equipment Daily Cost Cumulative Cost DALLY COST: $0 CUM: $0 REPORTED BY: G. Eller 010601.XLS MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE I OF I DATE: 6/1/2001 - page #2 FI LL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9203799 FIELD: Kenai Gas Field TUBING: N/A Frac module #1 through #3 WELL# KBU 42-7 CASING' 3.5", 9.3#, N-80 TREE CONDITION: good BENCHES OPEN: Module #1 SUMMARY OF OPERATIONS ..... CONTINUED FROM PAGE #1 ..... Module #3 Pumped 10 bbl minifrac on module #3. Promore gauge was temporarily disabled which hampered onsite analysis, but closure appeared much faster than the previous two modules indicating better permeability. Minifrac analysis suggests that we were actually leaking off to natural fractures (coal layer?) via pressure-dependent leakoff, and the actual formation permeability was poor (G > 5). Determined closure to be 0.75 psi/ft, which agrees with the first observed closure. Diesel minifrac was traced with chemical tracer and Sc-46 LZW tracer. Pumped 10 bbl pad with 5/5 Super Rheogel, then 26 bbl of 2 ppg of 16/20 Carbolite and 28 bbl of 4 ppg proppant. Proppant traced with 16/20 Sb-124 ZW tracer. Well screened out when the 4 ppg proppant hit the perfs. Placed approximately 2400 lbs of proppant in the formation (4?/0 of design), and approximately 10,000 lbs remain in the tubing. Attempted to flow back well without success. Module #4 Decided to fire module #4 to see if we couldn't displace proppant into that module. Fired guns, got confirmation that module #4 fired but it was not as clear cut as the previous firings. Attempted to displace sand laden fluid without success. Attempted to flowback one more time without success. Shut down frac operations, rigged down tree saver. MIRU 1-3/4" coil tubing. Vendor Equipment Daily Cost Cumulative Cost DAILY COST: $0 CUM: $0 REPORTED BY: G. Eller 010602.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 6/2/2001 FI LL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9203799 FIELD: Kenai Gas Field TUBING: N/A Clean proppant out of wellbore WELL # KBU 42-7 CASING: 3.5", 9.3#, N-80 TREE CONDITION: good BENCHES OPEN: SUMMARY OF OPERATIONS Pressure test coil tubing BOPE to 250/3000 psi with 3% KCI. Held safety and operations meeting. RIH circulating 3% KCI at 1.2 bpm taking returns to open top tank. Never tag up, but start getting proppant returns at about 5800'. Continue washing at 1.2 bpm while RIH at 12 fpm. Slow down in vicinity of module #4. Tag closed #4 flapper valve, as expected, at 6936' CTM. PU 40', set back down at same point to verify that we are on a flapper. Set down 3000 lbs weight and break through #4 flapper. Wash down an additional 50' to 6986' CTM. Increase pump rate to 2.0 bpm, circulate hole clean. POOH. RD coil tubing. Vendor Equipment Daily Cost Cumulative Cost DALLY COST: $0 CUM' $0 REPORTED BY: G. Eller O1 D603.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF I DATE: 6/3/2001 - page #2 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9203799 FIELD: Kenai Gas Field TUBING: N/A Frac module #4 through #7 WELL# KBU 42-7 CASING: 3.5", 9.3#, N-80 TREE CONDITION: good BENCHES OPEN: SUMMARY OF OPERATIONS ..... CONTINUED FROM PAGE #1 ..... Module 6 (continued) tracer and Sc-46 LZW tracer. Pumped redesigned frac as follows: 36 bbl pad with 5/5 Super Rheogel then a 12 bbl slug of 1 ppg proppant. Proppant slug passed through perfs without any problem. Pumped another 60 bbl of pad, then 65 bbl of 2 ppg of 16/20 Carbolite, 68 bbl of 3 ppg, 67 bbl of 4 ppg, 85 bbl of 5 ppg, and 88 bbl of 6 ppg proppant. Proppant traced with 16/20 Sb-124 ZW tracer. Displaced to the top perf with straight diesel. Placed approximately 52,400 lbs of proppant in the formation (100% of design) with 498 bbl of diesel, to recover. Shut down long enough to transfer diesel into frac tanks and additional proppant into Sand King. Fired module #7. Module #7 Fired guns of module #7. Pumped 18 bbl minifrac, observed closure at 0.62 psi/fi, G = 2.3, no 3ressure dependent leakoff, 600 psi of NWB friction. Diesel minifrac was traced with chemical tracer and Sc-46 17W tracer. Pumped redesigned frac as follows: 48 bbl pad with 5/5 Super Rheogel then a 12 bbl slug of 1 ppg proppant. Proppant slug passed through IPerfs without any problem. Pumped another 60 bbl of pad, then planned to pump 52 bbl ot 2 ppg of 16/20 Carbolite, 68 bbl of 3 ppg, 70 bbl of 4 ppg, 146 bbl of 5 ppg, and 121 bbl of d ppg proppant. About one-third of the way into the 5 ppg stage elected to go immediately ito 6 ppg because running short of available diesel. Even so, ran out of diesel after pumping 53,500 lbs of proppant. Proppant traced with 16/20 Sb-124 ZW tracer. Displaced to the top 3erf with straight diesel. Placed approximately 53,500 lbs of proppant in the formation (100% Df proppant pumped but only 76% of original design) with 493 bbl of diesel to recover. RD tree saver. Opened well to flowback approximately 45 minutes after shutting down frac ipumps. Well started with 800 psi SITP, quickly fell to zero when opened up. The well was ibarely flowing for the next 1.5 hours until it started to build some pressure. Well then flowing 14.5 MMCFD with 1350 psig FTP on a 24/64" choke. Total fluid recovery over the next few days .was 397 bbl. Total fluid pumped into the well is approximately 1784 bbl of diesel pumped iinto modules #1 through #7. Vendor Equipment Daily Cost Cumulative Cost DALLY COST: $0 CUM: REPORTED BY: G. Eller O10603.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 6/3/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9203799 FIELD: Kenai Gas Field TUBING: N/A Frac module #4 through #7 WELL# KBU 42-7 CASING: 3.5", 9.3#, N-80 TREE CONDITION: good BENCHES OPEN: SUMMARY OF OPERATIONS After yesterday's coil operation, module #4 is open and ready to accept fluid. Module #3 is still covered over with 100+ feet of proppant. The hole is loaded with 3% KCI. Pressure test frac lines to 7500 psi and held safety meeting. Module #4 Pumped 7 bbl minifrac on module #4 with the 3% KCI in the hole. Unlike the modules #1, #2, and #3, no sign of pressure-dependent leakoff here. Got closure at G=0.73 (good perm!) and 0.65 psi/ft gradient. Performed step-rate test and, unlike the previous modules, showed minimal near-wellbore friction. Displaced all remaining 3% KCI into module #4 with diesel in oreparation for module #5. Because hole was loaded with 3% KCI we have no chemical or 'adioactive tracers placed in module #4. Have 61 bbl of KCI to recover from this module. Module #5 Fired module #5 via control line. Pumped 10 bbl minifrac. Closure pressure showed signs of depletion compared to previous modules. Closure observed at 0.55 psi/fi, G=1.66. About 400 psi of total near-wellbore friction. Diesel minifrac was traced with chemical tracer and Sc-46 LZW tracer. Pumped 71 bbl pad with 5/5 Super Rheogel then a 12 bbl slug of 1 ppg oroppant. Proppant slug passed through perfs without any problem. Pumped another 60 0bi of pad, then 52 bbl of 2 ppg of 16/20 Carbolite, 108 bbl of 3 ppg, 141 bbl of 4 ppg, 117 bbl of 5 ppg, and 61 bbl of 6 ppg proppant. Proppant traced with 16/20 Ir-192 ZW tracer. Displaced to the top perf with straight diesel. Placed approximately 68,900 lbs of proppant in the formation (100% of design) with 621 bbl of diesel to recover. Shut down, fired module #6. Module #6 Fired guns of module #6. Attempted to break down perfs but unable to pump in. Believe we had some crossflow from module #5 which is plugging the module #6 perfs with proppant. Pressured up and backflowed well several times before able to adequately break down perfs. Pumped 18 bbl minifrac, observed an even lower closure pressure than the previous module suggesting even more depletion. Closure at 0.47 psi/ft, G = 0.80, no ~ressure dependent leakoff, minimal NWB friction. Diesel minifrac was traced with chemical .... CONTINUED ON PAGE #2 .... Vendor Equipment Daily Cost Cumulative Cost DALLY COST: $0 CUM: #REF! REPORTED BY: G. Eller 010605.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF I DATE: 6/5/2001 FI LL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9203799 FIELD: Kenai Gas Field WELL # KBU 42-7 TUBING: N/A CASING: 3.5", 9.3#, N-80 TREE CONDITION: good BENCHES OPEN: Clean out wellbore following frac operations SUMMARY OF OPERATIONS Prior to mobilizing coil, well had been flowing steadily at rates as high as 6 MMCFD. Liquid production and sand production had dropped to virtually nil, with total recovery to date of approximately 397 bbl. Judging by the volume of fluid recovered and the flowing )ressure, it was anticipated that perhaps only module #7 was providing the flow. ~/5/01 MIRU 1-3/4" BJ coil tubing and nitrogen. Hold operations and safety meeting. Pressure test BOPE to 3000 psi. SITP - 1900 psi. RIH with wash nozzle on coil tubing. Dry tag at 6500' CTM, corresponding to the #7 flapper valve at 6518' KB. Start circulating 3?/0 KCl water at 0.5 bpm and nitrogen at 450 SCF/min. Getting good returns at surface. Set down 3000 lbs on #7 flapper and break through. Continue circulating while RIH at 12 fpm. Do not set down on anything in the vicinity of the #6 flapper, so don't know whether it is broke or merely retracted. Continue to RIH. Set down at 6720' CTM, which is higher than expected for the #5 flapper. Have to work at it a while, but eventually break through and RIH. Set down next at 6743' CTM which is likely to be the #5 flapper. Able to break through and work past. Believe we are perhaps hanging up on pieces of broken flapper still lying in the tubing. Continue to RIH. Do not find any evidence of the #4 flapper which is to be expected since we broke that during coil operations on 6/2/01. Continue washing and break through the #3 flapper at 7150' CTM and the #2 flapper at 7314' CTM. Continue washing, but unable to get deeper than 7383' CTM. Circulate to clean the hole. Quit pumping 3% KCI and increase nitrogen rate to 750 SCF/min to purge the hole. POOH to 6450' and shut in the welt. RIH back across the flappers to make sure as best as is possible that they are all broke. Tag nothing. POOH, RDMO coil tubing. Re~3pen well to flow. Vendor Equipment Daily Cost Cumulative Cost BJ DALLY COST: $0 CUM: $0 REPORTED BY: G. Eller MARATHON OIL COMPANY~ DALLY WELL OPERATIONS RE~..., PAGE 1 OF 1 DATE: 6/9/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field WELL #: KBU 42-7 TUBING: 3 1/2 CASING: TREE CONDITION: Run Gauge Ring BENCHES OPEN: Complete WlRELINE CREW: Barrow/Doherty Hrs. 4 SUMMARY OF OPERATIONS Arrived in field, check in, discuss job Travel fo location Safety meeting: Slips, trips and falls R/U, pressure test WLV & Lub RIH w/2.25" GR to 7182' work to 7188' KB, sticky, cannot see Spangs, POOH R/D, secure well Tool String: RS, K J, 5' Stem, K J, 5' Stem, K J, O J, S J, 2' Stem, 2.25" GR Tool Cost: 2.25" GR $50.00 Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. W/L unit & crew $500.00 $500.00 Pollard Wireline Inc. 2.25" GR $50.00 $550.00 DALLY COST: $550.00 CUM: $550.00 REPORTED BY: Claude B. MARATHON OIL COMPANi' DALLY WELL OPERATIONS R~=~OF, PAGE 1 OF 1 DATE: 6/14/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: TUBING: Run Gauges Complete Kenai Gas Field WELL #: KBU 42-7 3 1/2" - 9.3 CASING: 9 5/8" TREE CONDITION: 3 1/2" EUE BENCHES OPEN: WlRELINE CREW: Gonzalez/Tomlinson Tested wire - 22, 23 turns Hrs. 12 SUMMARY OF OPERATIONS Left office for Marathon Oil, Kenai Gas Field, got equipment to well, cut off 100' of wire, tested wire - 22 turns R/U W/L, rig up test pump, tested Lub & BOP's to 4500 PSI, Valve on Pump in Sub leaking, remove Pump in Sub, retest to 4000 PSI - good test RIH w/Protechnics logging tool to 6642', did not pass, working tools, got down to 6740', did not pass, POOH, at 262' unable to come up, close BOP's, open Needle Valve, bleed off PSI, to about 800 PSI, came loose, POOH, again at 57', stop, trying to loose tools, cannot go up or down, Ithink Ice is in way, got tools loose by pumping Methanol POOH R/D W/L TOOL STRING: RS, K J, 5' Stem, K J, 3' Stem, K J, OJ all 1 1/2" Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. Unit & crew $1,500.00 $1,500.00 Pollard Wireline Inc. Fuel $26.74 $1,526.74 DALLY COST: $1,526.74 CUM: $1,526.74 REPORTED BY: Wayne Cissell MARATHON OIL COMPANt DATE: 6/15/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTH ER: DALLY WELL OPERATIONS R~rOF. PAGE 1 OF 1 FIELD: TUBING: Bailing sand Complete Kenai Gas Field WELL #: KBU 42-7 3 1/2 9.3 CASING: 9 5/8 TREE CONDITION: 3 1/2 EUE BENCHES OPEN: WlRELINE CREW: Gonzalez/Tomlinson Hrs. 12 SUMMARY OF OPERATIONS Left Office for KGF R/U W/L and stand-by RIH w/1 3/4" drive-down Bailer to 6741' working tool, POOH, got sample of sand RIH w/same to 6746', working tool, POOH, got 2 cups of sand RIH w/2 1/4" Bailer to 6747', working Bailer, POOH, no sand in Bailer RIH w/1 1/3" Bailer to 6747', working Bailer, POOH, got some sand RIH w/same to 6747', working Bailer, POOH, got some sand R/D W/L, return to Office Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. 1 3/4" Bailer $150.00 $150.00 Pollard Wireline Inc. 2 1/4" Bailer $150.00 $300.00 Pollard Wireline Inc. Unit & crew $1,500.00 $1,800.00 DAILY COST: $1,800.00 CUM: $1,800.00 REPORTED BY: S. Bookey MARATHON OIL COMPAN'~ DALLY WELL OPERATIONS REP~ PAGE 1 OF 1 DATE: 6/21/2001 FIELD: Kenai Gas Field WELL #: KDU 42-7 FILL DEPTH/DATE: 6740' 6-14-01 TUBING: 3 1/2" CASING: 9 5/8" DATE LAST WL WORK: 6/14/2001 TREE CONDITION: Good WORK DONE: Tag fill & Bail BENCHES OPEN: PRESENT OPERATION: Complete WlRELINE CREW: D. Pollard/Smith OTHER: Hrs. 6 SUMMARY OF OPERATIONS Arrived at Marathon Meet w/Supervisor Started R/U Did Hydro RIH w/2.30" GR to 6954', pulled heavy coming up, like I was dragging something, POOH came free at 6850' RIH w/2" Pump Bailer to 6954', w/t, had hard time pulling out of hole for first 50', POOH, empty Bailer Rig down Moved to KDU-2 Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. 6 of 12 hr min $750.00 $750.00 Pollard Wireline Inc. 2.3" Gauge Ring $50.00 $800.00 Pollard Wireline Inc. 2" Pump Bailer $150.00 $950.00 DALLY COST: $950.00 CUM: $950.00 REPORTED BY: Bob Bowen MARATHON OIL COMPANY !" DALLY WELL OPERATIONS PAGE 1 OF 1 DATE: 6/28/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: 7163' FIELD: TUBING: 6/21/2001 Ta~l fill, retrieve sample Complete Tested wire 22, 23, 22, and thread connections Kenai Gas Field WELL #: KBU 42-7 3 1/2 CASING: 9 5/8 TREE CONDITION: Good BENCHES OPEN: WlRELINE CREW: Gonzalez/Doherty Hrs. 6 SUMMARY OF OPERATIONS Left shop Arrive on location Discuss job, hold safety meeting, maint. On Units Move Units to well Check all thrads on Lub & Pump in Sub R/U W/L Stand-by for removal of Locked Valves Pressure test Lub, BOP's leak - fixed, retest - good RIH w/1.75 DD Bailer to 7162', wit to 7163', POOH, full Bailer ~k~.c~c. s~',,-~'~ R/D and move to KBU 33-7L Tool String: 1 3~4" RS, XO - 3/4 Pin x 5/8 Box, 1 12/" K J, 1 1/2" x 8' Stem, 1 1/2" O J, 1 1/2" SJ Vendor Equipment Daily Cost Cumulative Cost ! Pollard Wireline Inc. 6 of 12 hr min $750.00 $750.00 Pollard Wireline Inc. 1.75 DD Bailer $150.00 $900.00 ..... DAILY COST: $900.00 CUM: $900.00 REPORTED BY: S. Bookey .. / ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00072 Sidetrack No. Page 1 of 4 Company MARATHON OIL COMPANY Rig Contractor & No. Glacier Drilling/Rig gl Field KENAI GAS FIELD Well Name & Nol PAD 41-7/KBU 42-7 Survey Section Name 42-7 BHI Rep. WELL DATA Target TVD 5327.00 (fi) Target Coord. N/S -1179.02 Slot Coord. N/S -16.38 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W 652.50 Slot Coord. E/W 4116.17 Magn. Declination 20.920 Calculation Method Minimum Curvature Target Direction 0.00 Od) Build\Walk\DL per: 100ft[~ 30m[~ 10m[--] Vert. Sec. Azim. 150.10 Magn. to Map Corr. 20.920 Map North to: OTHER SURVEY DATA ~ Total Coordinate Build Rate Walk Rate Survey Survey Incl. Hole Course Vertical Build (+) Right (+) Comment Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Type fit) (da) (da) (ft) fit) (a) (a) (per 100 ft) Drop (-) Left (-) MWD 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Tie In Point ~AN-01 MWD 181.00 0.55 339.10 181.00 181.00 -0.86 0.81 -0.31 0.30 0.30 N/A 'T~-JAN-01 MWD 224.00 0.28 282.60 43.00 224.00 -1.13 1.03 -0.49 1.07 -0.63 N/A 19-JAN-01 MWD 284.00 0.31 256.60 60.00 284.00 -1.28 1.02 -0.79 0.23 0.05 N/A 208.40 120.00 403.96 0.05 -1.44 -2.40 2.00I 1.90 N/A 19-JAN-01 MWD 404.00 2.59 19-JAN-01 MWD 524.00 5.24 199.20 120.00 523.67 5.07 -9.00 -5.49 2.26 2.21 -7.67 19-JAN-01 MWD 613.00 6.96 197.40 89.00 612.16 11.38 -17.98 -8.44 1.94 1.93 -2.02 19-JAN-01 MWD 704.00 8.26 187.40 91.00 702.36 20.32 -29.72 -10.93 2.03 1.43 -10.99 19-JAN-01 MWD 825.00 8.76 167.60 121.00 822.05 36.02 -47.34 -10.07 2.44 0.41 -16.36 20-JAN-01 MWD 952.00 8.50 150.10 127.00 947.63 54.63 -64.92 -3.31 2.07 -0.20 -13.78 20-JAN-01 MWD 1074.00 8.44 135.60 122.00 1068.31 72.32 -79.13 7.45 1.75 -0.05 -11.89 20-JAN-01 MWD 1170.00 8.50 135.80 96.00 1163.26 86.01 -89.25 17.33 0.07 0.06 0.21 20-JAN-01 MWD 1293.00 9.07 131.10 123.00 1284.82 103.98 -102.14 30.97 0.74 0.46 -3.82 ~AN-01 MWD 1421.00 9.93 135.90 128.00 1411.07 124.22 -116.70 46.25 0.91 0.67 3.75 ~-a~JAN-01 MWD 1513.00 10.90 139.40 92.00 1501.55 140.46 -129.00 57.44 1.26 1.05 3.80 20-JAN-01 MWD 1610.00 13.04 136.80 97.00 1596.44 160.12 -143.94 70.90 2.27 2.21 -2.68 20-JAN-0 1 MWD 1706.00 14.07 143.80 96.00 1689.77 182.26 -161.26 85.20 2.02 1.07 7.29 24-JAN-01 MWD 1806.00 14.81 148.10 100.00 1786.61 207.12 -181.92 99.13 1.30 0.74 4.30 24-JAN-01 MWD 1899.00 15.86 148.00 93.00 1876.30 231.70 -202.79 112.15 1.13 1.13 -0.11 24-JAN-01 MWD 2024.00 17.81 148.90 125.00 1995.94 267.89 -233.65 131.08 1.57 1.56 0.72 24-JAN-01 MWD 2151.00 20.21 149.60 127.00 2116.01 309.25 -269.21 152.22 1.90 1.89I 0.55 24-JAN-01 MWD 2275.00 22.33 149.50 124.00 2231.56 354.24 -307.99 175.02 1.71 1.71 -0.08 24-JAN-01 MWD 2401.00 23.99 146.80 126.00 2347.40 403.75 -350.05 201.20 1.56 1.32 -2.14 24-JAN-01 MWD 2528.00 26.02 148.70 127.00 2462.49 457.38 -395.46 229.81 1.72 1.60 1.50 ~Ul~Vl~¥ UALUULATION AND FIELD WORKSHEET JobNo. 0450-00072 Sidetrack No. Page 2 of 4 Company MARATHON OIL COMPANY Well Name & No. PAD 41-7/KBU 42-7 Rig Contractor & No. Glacier Drilling/Rig #1 Survey Section Name 42-7 WELL DATA Field KENAI GAS FIELD BHI Rep. Target TVD Target Description Target Direction Date 24-lAN-01 -- IN-01 24-JAN4) l 24-JAN4) I 24-JAN-01 24-JAN-01 24-JAN-01 24-JAN-01 24-JAN-01 24-JA N-01 24-JAN-01 24-JAN-01 ~AN-01 AN-01 24-JAN-01 24-JAN-01 24-JAN-01 24-JAN-01 24-JAN4) 1 24-JAN-01 24-JAN4) 1 24-JAN-01 24-JAN-01 5327.00 (t0 0.00 (dd> Survey Depth 2590.00 2717.00 2841.00 2935.00 3028.00 3124.00 3218.00 3340.00 3403.00 3530.00 3593.00 3657.00 3752.00 3846.00 3910.00 3973.00 4034.00 4096.00 4159.00 4220.00 4283.00 4346.00 4409.00 4470.00 Target Coord. N/S -1179.02 Slot Coord. N/S Target Coord. E/W 652.50 Slot Coord. E/W Build\Walk\DL per: 100ft[~[ 30m[~ 10m~ Vert. Sec. Azim. SURVEY DATA Hole Course Vertical Direction Length TVD Section (dd) (ft) fit) 145.90 62.00 2518.21 484.53 148.20 127,00 2632.29 540.26 147.40 124.00 2743.72 594.61 147.10 94.00 2828.24 635.69 148.60 93.00 2911.72 676.66 147.50 96.00 2997.91 718.90 148.60 94.00 3082.35 760.17 151.50 122.00 3192.10 813.44 151.50 63.00 3248.84 840.81 150.60 127.00 3363.09 896.26 151.30 63.00 3419.73 923.85 151.30 64.00 3477.27 951.87 151.00 95.00 3562.79 993.24 150.20 94.00 3647.59 1033.79 152.20 64.00 3705.52 1060.98 151.10 63.00 3762.72 1087.38 150.20 61.00 3818.31 1112.50 150.30 62.00 3875.05 1137.49 150.60 63.00 3933.17 1161.79 151.20 61.00 3989.91 1184.19 150.60 63.00 4048.82 1206.53 149.40 63.00 4108.18 1227.63 149.60 63.00 4168.00 1247.39 152.20 61.00 4226,26 1265.46 -16.38 4116.17 150.10 Total Coordinate N(+) / S(-) E(+) / W(-) (ft) (f0 -418.33 244.49 -465.17 274.84 -511.20 303.82 -545.79 326.07 -580.51 347.89 -616.38 370.25 -651.42 392.10 -697.57 418.70 -721.64 431.77 -770.16 458.61 -794.28 472.01 -818.87 485.47 -855.10 505.43 -890.43 525.34 -914.26 538.45 -937.50 550.99 -959.40 563.30 -981.10 575.70 -1002.24 587.69 -1021.81 598.59 -1041.33 609.45 -1059.61 620.00 -1076.63 630.03 -1092.41 638.83 Grid Correction 0.000 Magn. Declination 20.920 Magn. to Map Corr. 20.920 Depths Measured From: RKB ~ MSL~ SS ~] Calculation Method Minimum Curvature Map North to: OTHER i Build Rate Walk Rate Build (+) Right (+) Commem Drop (-) Left (-) -0.03 -4.52 0.12 1.81 -0.21 4).65 0.13 -0.32 0.32 1.61 -0.39 -1.15 0.26 1.17 -0.47 2.38 0.49 0.00 -0.05 -0.71 0.37 1.11 4).36 0.00 -0.09 -0.32 -0.45 4). 85 -0.61 3.13 -0.56 -1.75 -0.95 -1.48 -0.82 0.16 -2.63 0.48 -1.03 0.98 -1.48 -0.95 -2.30 -1.90 -1.83 0.32 -1.52 4.26 ' llltlt_ l' SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00072 Sidetrack No.Page 3 of 4 '~ Company MARATHON OIL COMPANY Rig Contractor & No. Glacier Drilling/Rig gl Field KENAI GAS FIELD Well Name & No. PAD 41-7/KBU 42-7 Survey Section Name 42-7 BHI Rep. I~'r~ WELL DATA Target TVD 5327.00 (ft) Target Coord. N/S -1179.02 Slot Coord. N/S -16.38 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W 652.50 Slot Coord. E/W 4116.17 Magn. Declination 20.920 Calculation Method Minimum Curvature Target Direction 0.00 (da) Build\Walk\DL per: 100fi[~ 30m~] 10m[q Vert. Sec. Azim. 150.10 Magn. to Map Corr. 20.920 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) I E(+) / W(-) DL Build (+) Right (+) Comment Type (ft) (da) (dd) (ft) (fi) (ft), (a) (per 100 ft) Drop (-) Left (-) .. 2a-IAN-01 MWD 4531.00 15.65 151.90 61.00 4284.83 1282.47 -1107.45 646.81 1.84 -1.84 -0.49 ~ AN-01 MWD 4594.00 15.11 150.50 63.00 4345.57 1299.18 -1122.09 654.86 1.04 -0.86 -2.22 ~'~4-JAN-01 MWD 4657.00 14.21 152.20 63.00 4406.52 1315.11 -1136.08 662.51 1.58 -1.43 2.70 25-JAN-01 MWD 4721.00 13.26 150.60 64.00 4468.69 1330.31 -1149.42 669.78 1.60 -1.48 -2.50 254AN-01 MWD 4784.00 12.67 151.70 63.00 4530.12 1344.29 -1161.67 676.53 1.42 -1.37 1.75 25-JAN-01 MWD 4847.00 11.48 150.00 63.00 4591.76 1357.32 -1173.06 682.87 1.56 -1.46 -2.70 27-JAN-01 MWD 4909.00 10.65 151.70 62.00 4652.60 1369.22 -1183.44 688.67 1.44 -1.34 2.74 27-JAN-01 MWD 4972.00 9.28 150.40 63.00 4714.65 1380.12 -1192.99 693.94 2.20 -2.17 -2.06 27-JAN-01 MWD 5033.00 8.42 150.90 61.00 4774.92 1389.50 -1201.16 698.54 1.42 -1.41 0.82 27-JAN-01 MWD 5096.00 7.50 151.00 63.00 4837.31 1398.22 -1208.79 702.78 1.46 -1.46 0.16 28-JAN-01 MWD 5160.00 6.36 150.50 64.00 4900.84 1405.94 -1215.53 706.55 1.78 -1.78 -0.78 28-JAN-01 MWD 5222.00 5.36 147.00 62.00 4962.52 1412.27 -1220.95 709.82 1.71 -1.61I 28-JAN-01 MWD 5283.00 4.51 152.00 61.00 5023.29 1417.52 -1225.46 712.50 1.56 -1.39 N/A IAN-01 MWD 5346,00 3.60 154.20 63.00 5086.13 1421.97 -1229.43 714.52 1.47 -1.44 N/A · ~-2,¢-J AN-01 MWD 5408.00 3.63 149.70 62.00 5148.01 1425.87 -1232.88 716.36 0.46 0.05 N/A 29-JAN-01 MWD 5470.00 3.73 154.60 62.00 5209.88 1429.85 -1236.40 718.22 0.53 0.16 N/A 02-FEB-01 MWD 5595.00 3.60 155.50 125.00 5334.62 1437.82 -1243.64 721.59 0.11 -0.10 N/A 02-FEB-01 MWD 5721.00 2.64 153.10 126.00 5460.43 1444.65 -1249.83 724.54 0.77 -0.76 N/A 02-FEB-01 MWD 5847.00 0.97 157.30 126.00 5586.36 1448.60 -1253.40 726.26 1.33 -1.33 N/A 02-FEB~01 MWD 5976.00 0.88 163.70 129.00 5715.34 1450.65 -1255.36 726.96 0.11 -0.07 N/A 03-FEB-01 MWD 6102.00 0.79 152.80 126.00 5841.33 1452.45 -1257.06 727.63 0.14 -0.07 N/A 03-FEB-01 MWD 6226.00 0.88 160.10 124.00 5965.32 1454.25 -1258.72 728.34 0.11 0.07 N/A 03-FEB-01 MWD 6353.00 1.14 163.70 127.00 6092.30 1456.44 -1260.85 729.03 0.21 0.20 N/A 03-FEB-01 [ MWD 6479.00 1.14 180.90 126.00 6218.28 1458.73 -1263.31 729.36 0.27 0.00 N/A SURVEY CALCULATION AND FIELD WORKSHEET Job No. Company MARATHON OIL COMPANY Rig Contractor & No. Glacier Drilling/Rig #1 Well Name & No. PAD 41-7/KBU 42-7 Survey Section Name 42-7 WELL DATA 0450-00072 Sidetrack No. Page Field KENAI GAS FIELD BHI Rep. 4 of 4 Target TVD Target Description Target Direction 5327.00 0.00 (dd) Date 0~ r:EB-01 cEB-01 04-FEB-01 05-FEB-01 05-FEB-0 l 05-FEB-01 06-FEB-01 07 -F EB-01 07-FEB-01 07-FEB-01 Survey Dep~ 6604.00 6732.00 6859.00 6986.00 7113.00 7241.00 7368.00 7493.00 7523.00 7570.00 Target Coord. N/S -1179.02 Slot Coord. N/S Target Coord. E/W 652.50 Slot Coord. E/W Build\Walk\DL per: 100ft[~ 30m[~ 10m~ Vert. Sec. Azim. SURVEY DATA Hole Course Vertical Direction Length TVD Section (dd) (~ (~ 183.00 125.00 6343.26 1460.85 170.70 128.00 6471.24 1463.02 181.20 127.00 6598.22 1464.95 192.10 127.00 6725.20 1466.72 198.50 127.00 6852.18 1468.43 199.90 128.00 6980.16 1469.91 222.00 127.00 7107.15 1470.87 222.40 125.00 7232.13 1471.37 209.40 30.00 7262.13 1471.53 209.40 47.00 7309.13 1471.87 -16.38 Grid Correction 4116.17 Magn. Declination 150.10 Magn. to Map Corr. TomlCoordina~ N(+) / S(-) E(+) / W(-) (a) (~) -1265.80 729.28 -1268.23 729.40 -1270.35 729.57 -1272.56 729.28 -1274.90 728.65 -1277.03 727.91 -1278.69 726.96 -1279.90 725.87 -1280.21 725.64 -1280.78 725.32 0.000 20.920 20.920 Depths Measured From: RKB 1~ MSL[~ SS [~ Calculation Method Minimum Curvature Map North to: OTHER Build Rate Walk Rate Build (+) Right (+) Comment Drop (-) Left (-) 0.00 N/A -0.07 N/A -0.13 N/A 0.20 N/A -0.07 N/A -0.06 N/A -0.14 N/A -0.07 N/A 0.30 N/A LAST SURVEY IN 8 1/2 0.00 N/A PROJECTED TO BOTTOM tlPI: 50~133-20488 T-GL: 2050* 4TNF, NR~,14W111, 8~.FMWL, Sec. 7, lTreecxn = 3-1/2' EUE 8rd TOO (est.) - 5000' Promote downhole sensor @ 5549' MD (5289, TVD) w/7/16" electric cable (dual- armored, 7~strand conductor) to Wireline tagged fill @ 7163' MD 6/28/2001 KBU 42-7 .D_ri _vz~__..P_ip..e.: 20'~, '133 ppf, K-,55 to 117' SurPace Casinq: 13-3/8", 68 ppf, L-80 & 55, BTC @ 1750' 0' - 1099' - K-55 t099' - 1750' - L~80 Cmt w/734 sks of class G Int. Casin~: 9-5/8", 40 ppf, L~80, Cmt w/654 sks of case G BTC Pred. Tubinq: 3~1/2", 9.3 ppf, L- 80, EUE 8rd w?th 525" OD slotted couplings to 7518' Cmt w/875 sks of c ass G - 15 E×cape modules plac~ - Green control line n~,, o~n for methanot injection (6/3/01) - Red control line fires top 8 modul~ - Ce~mic flapper ~lv~ below ~ch m~ule Pe~: M~ule I - 7~* ~ 74~' (peff~ 3/11/01) M~ule 2 - 731¢ - 7329, (ped~ 6/1/O1) Module 3 - 7153' - 71~' (frso'd 6/1~1) M~ule 4 - 6943' - 6~3' (peR~ 6/1/01 ) M~ule 5 ~ 6746' - 67~ (frac'd 6/3/01) M~ule 6 - 6611' - ~21' (f~c'd 6~/01) M~ule 7 - 64~' - ~' (f~c'd 6/3/O1) M~u~ 8 - 6~' - 637~ Module 9 - 6271' - ~81' M~ule 10 - 6123' - 6133' Module 11 - 5941' - 5951' M~ule 12 * ~3' ~ 5873' Module 13 - 5805' * 5815' Module 14 - 5737' - 5747' Module 15 - ~6 - 5~6' TD - 7570' PBTD - 7453' yame & .umber: I KBU 42-7 ~ Kenai Gas Fie,d or Parish: Kenai J State/Prov. J__Alaska Country: ~(MD) J (TVD) /~ngle ~ ~.O? ~!n3 D~.pth J J __BHT: J Completion Fluid: J ¢d Completed: __ 2/14V2001 LPrepared By: J.G. Eller J Last Revison Date: J 7/12/2001 J ~%~ Wetlbore Diagram: KBU 42-7 as RIH ~;~:~ Alaska~ 'on Domesf. ,'oduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 February 27, 2001 Alaska Oil & Gas Conservation Commission Attn: Library - Lisa 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Via Certified Mail The following well data are enclosed: Marathon Oil Company KI.J 42-7 Final Mud Logging Report by Epoch, which includes Formation Log and Drilling Dynamics Log - Paper Copies CD Rom 1 Data: Epoch Mud Log Data (KU42-7.1as)" Dipole Sonic - CMR Processed / CD Rom 2 Data: PEX-AIT / PEX-AIT TVD ~ PEX-Density Neutron / PEX-Density Neutron TVD / CMR / DSI ? RFT/ Caliper-GR Run 2 × Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY Kaynell Zeman Exploration Aide Enclosures Certified Receipt: 7000 0520 0024 8742 7750 Received ~_ ~ Date: A subsidiary of USX Corporation Environmentally aware for the long run. MARATHON OIL COMPANY KU #42-7 KENA I GA S FIEL D, PA D 4 I- 7 Section 7- T4N-RI 1W, SM Kenai Peninsula, Alaska Januar 23 2001 Ralph Winkelman Sr. Logging Geologist Olga Popova Logging Geologist [:/EPOCH TABLE OF CONTENTS MARATHON OIL COMPANY KU ~12-7 KENAI GAS FIELD, PAD 41-7 Section 7-T4N. R11 W, SM Kenai Peninsula, Alaska TABLE OF CONTENTS ...................................................................................... 2 DRILLING AND FORMATION SUMMARY ......................................................... 4 LITHOLOGIC SUMMARY ................................................................................... 5 DALLY ACTIVITIES SUMMARY ........................................................................ 12 MUD RECORD .................................................................................................. 18 BIT RECORD .................................................................................................... 19 RIG ACTIVITY ................................................................................................... 20 SURVEY RECORD ............................................................................................ 21 FINAL LOGS ................................................................................... APPENDIX 1 MORNING REPORTS ..................................................................... APPENDIX 2 ~' ,I/IARATHON OIL COMPANY KTI~ ..,.;?.-1 OPPERATOR: WELL NAME: FIELD: REGION: LOCATION: BOROUGH: STATE: ELEVATION: APl NUMBER: OPERATOR: Operator Representatives: Company Geologist: CONTRACTOR: DRILLING RIG: Toolpusher: MUDLOGGING COMPANY: Logging Geologists: MUD COMPANY: Mud Engineers: MWD COMPANY: MWD Engineer: DIRECTIONAL COMPANY: Directional Driller: CEMENT COMPANY: WIRELINE COMPANY: WELL RESUME MARATHON OIL COMPANY KTU 42-7 KENAI GAS FIELD KENAI PENINSULA, ALASKA 37' FNL, 4118' FWL ~, ~ ~-llN, 2,3 SEC 7-T4N-RllW SM KENAI BOROUGH ALASKA RKB: 87.0' AMSL GL: 66.0' AMSL ~50-133-20488-00 MARATHON OIL COMPANY RICK GIDEON, DARRELL GREEN DAVID BRIMBERRY INLET DRILLING GLACIER DRILLING #1 GEORGE BREWSTER, MIKE LESLIE EPOCH WELL SERVICES, INC. RALPH WINKELMAN, OLGA POPOVA MI ROD MABEUS, BOB WILLIAMS BAKER HUGHES INTEQ STEVE STURGEON BAKER HUGHES INTEQ TOMM DUNN B&J SERVICES SCHLUMBERGER EPOCH 3 ~'~' JlARATHON OIL COMPANY KTI. J' _-1 DRILLING AND FORMATION SUMMARY PROSPECTUS The objective of Marathon's KBU 42-7 was to bring into production the gas sands of the middle Beluga Formation. BRIEF REVIEW OF ACTIVITY The drilling rig was MARATHON Glacier #1. Situated on Pad 41-7 In the Kenai Gas Field, the well was spudded January 19,2001 and reached a total depth of 7570' MD, (7309' TVD) on February 6, 2001.17 %" hole was drilled to 1760' MD and 13 3/8" casing was set at 1750' MD. 12 ¼" hole was drilled to 5590' MD and 9 5/8" casing was set at 5582' MD. 8 %' hole was drilled to total depth of 7570' MD, then final liner was set. There was a lost circulation zone encountered at approximately 4900' MD that resulted in mud losses and lost returns while drilling and while back reaming on wiper trips. While Sclumberger was running their RFT log at the completion of the well, it became stuck and had to be fished out of the hole at approximately 6000'. BRIEF DIRECTIONAL REVIEW KTU 42-7 was vertical to 400', where kick off was initiated at azimuth of 208°. Inclination was built at 2.5 deg/100'. Direction was turned to 133 deg by 1046' as per well plan. By 1500', direction was finally turned to 150 deg as per well plan. Inclination continued to build to 26 deg by 2500' and was held to 3912' as per well plan, then dropped angle back to vertical by 5800'. Final inclination was 0.79 deg with a 209.4 deg azimuth at T.D. LOGGING PROCEDURES Epoch Well Services provided RIGWA TCH 2000TM Drilling Monitoring services and DMLTM Mudlogging Service. Hydrogen flame ionization total gas and chromatograph detectors were employed to detect and analyze formation gases. Constant mud gas was generated by an air motor driven gas trap located at the shale shaker header box and extracted continuously from the trap to the unit by sample pumps. The gas trap was frequently cleaned and positioned to obtain optimum sampling, and the gas system was tested and calibrated on a regular basis. Cuttings samples were collected at regular 10' intervals as directed by Marathon's sampling program. EPOCH 4 t/~' ,ARATHON OIL COMPANY KTU ~ -1 LITHOLOGIC SUMMARY SAND (5600' - 5690') = NOTE ABUNDANT CEMENT CONTAMINATION FROM SHOE TO 5680';MEDIUM TO DARK GRAY OVERALL APPEARANCE WITH INDIVIDUAL GRAINS DOMINANTLY MEDIUMTO DARK GRAY TO MEDIUM GREENISH GRAYWHITE BLACK AND COLORLESS QUARTZ; FINE LOWER TO MEDIUM LOWER; ANGULAR TO SUBROUNDED DOMINANTLY SUBANGULAR; POOR TO MODERATE SORTING; UNCONSOLIDATED TO VERY LOOSELY CONSOLIDATED WITH LIGHT GRAY TO LIGHT GRAYISH WHITE, ASHY SUPPORTING MATRIX; SLIGHT TO MODERATELY CALCAREOUS; TRACE BLACK CARBONACEOUS MATERIAL. TUFFACEOUS CLAYSTONE (5690' - 5750') = LIGHT GRAY TO MEDIUM BROWNISH GRAY WITH LIGHT BROWN SECONDARY HUES; SOFT TO SLIGHTLY FIRM; IRREGULAR CUTTINGS; CLAYEY TO SILTY TEXTURE; EARTHY TO DULL LUSTRE; COMMON BLACK MICROTHIN CARBONACEOUS LAMINATIONS; NON-TO SLIGHTLY CALCAREOUS. SAND (5730' - 5790') = MEDIUM TO DARK GRAY OVERALL WITH INDIVIDUAL GRAINS DOMINANTLY MEDIUM TO DARK GRAY TO DARK GREENISH GRAY BLACK LIGHT TO MEDIUM GRAY COLORLESS; FINE LOWER TO VERY COARSE LOWER DOMINANTLY MEDIUM LOWER; ANGULAR TO SUBANGULAR; MODERATELY SORTED; UNCONSOLIDATED TO LOOSELY CONSOLIDATED WITH ASHY/CLAYEY SUPPORTING MATRIX. TUFFACEOUS CLAYSTONE (5790' - 5830') = LIGHT GRAY TO MEDIUM BROWNISH GRAY WITH LIGHT BROWN SECONDARY HUES; SOFT TO SLIGHTLY FIRM; IRREGULAR CUTTINGS; CLAYEY TO SILTY TEXTURE; F_ARTHY TO DULL LUSTRE; STICKY TO TACKY; HYDROPHILIC; EXPANSIVE WHEN HYDRATED; FAIR TO GOOD ADHESIVENESS COMMON BLACK MICROTHIN CARBONACEOUS LAMINATIONS; NON TO SLIGHTLY CALCAREOUS. SAND (5830' - 5920') = MEDIUM GRAY OVER ALL APPEARANCE WITH SLIGHT "SALT AND PEPPER"; INDIVIDUAL GRAINS DOMINANTLY MEDIUM TO MEDIUM DARK GRAY BLACK SCATTERED LIGHT GRAY AND COLORLESS LITHICS TRACE WHITE; RARE TRACE PALE RED FRAGMENTS; FINE LOWER TO VERY COARSE UPPER WITH TRACE LARGER BROKEN FRAGMENTS DOMINANTLY MEDIUM UPPER; ANGULAR TO OCCASlONALY SUBROUNDED DOMINANTLY ANGULAR TO SUBANGULAR; POOR TO MODERATE FAIR SORTING; DOMINANTLY UNCONSOLIDATED SCATTERED WELL CEMENTED HARD SILICIOUS SANDSTONE FRAGMENTS; COMMON LIGHT TO MEDIUM GRAY ASHY SUPPORTING MATRIX; NON TO SLIGHTLY CALCAREOUS. EPOCH 5 (/~' .,ARATHON OIL COMPANY KTU! SAND/SANDSTONE (5920'-6010') = LIGHT TO MEDIUM GRAY WITH COLOR VARIGATION TO LIGHT BLUSH/MEDIUM BLUSH GRAY; FINE UPPER TO COARSE UPPER OCCASIONAL VERY COARSE PREDOMINANTLY MEDIUM; SUBANGULAR TO SUBROUND; MODERATE FAIR DOMINANTLY POOR SORT; MODERATE SPHERICITY OVERALL; MOSTLY DISAGGREGATED BY BIT TO LOOSE SAND WITH A FEW HARD CUTTINGS; ASHY-CLAYEY MATRIX; SLIGHTLY CALCAREOUS; DOMINANTLY QUARTZ CLEAR/TRASPARENT TO SMOKY OCCASIONAL MILKY WHITE AND GREENISH COMMON CHALCEDONY; MINOR PINK SLIGHTLY ALTERED FELDSPAR BLACK HORNBLEND MICRO MICA ABUNDANT OF DARK LITHICS FRAGMENTS; CONSOLIDATED- LIGHT BROWNISH GRAY WITH PALE PINK HUE "SALT AND PEPPER" APPEARNCE; VERY FINE TO FINE GRAINED; WELL SORT; DOMINANTLY QUARTZ; GRAINED SUPPORTED; ARGIL CEMENT; VERY CALCAREOUS. COAL (6010' 6040') = DARK DUSKY BROWN TO BLACK; OCCASIONAL GRADING TO DARK BROWN CARBONACEOUS SHALE; FIRTO EASY SCORED; BRITTLE; SUBPLANAR TO CONCHOIDAL FRACTURE; BLOCKY TO IRREGULAR CUTTINGS HABIT; DULL TO EARTHY OCCASIONAL WAXY LUSTER; SMOOTH TO DENSE MATTE TEXTURE; THIN BEDDING. TUFFACEOUS CLAYSTONE (6040'-6090') = LIGHT GREENISH GRYLIGHT GRAY TO MEDIUM BROWNISH GRAY WITH LIGHT ORNG/PINK HUE; SOFT/PLIABLESTICKY; AMORPHOUS CUTTINGS HABIT; CLAYEYTO SILTY TEXTURE; DULL/EARTHY TO WAXY LUSTER; HYDROPHILIC; SLIGHT EXPANSIVE WHEN REHYDRATED; FAIR TO GOOD ADHESIVENESS; SUBMASSlVE APPEARANCE WITH INDISTINCT LAMINAE. SAND/SANDSTONE (6090' - 6190') = MEDIUM LIGHT GRAY/MEDIUM GRAY TO MEDIUM GRAY OCCASIONAL MEDIUM DARK GRAY WiTH BRSH HUE; OCCASIONAL VERY PALE ORANGE GRAY; FINE UPPER TO COARSE UPP RARE VERY COARSE; COARSE FRACTION COMMON DISAGREGAT TO LOOSE SAND; HARD CUTTINGS DOMINANTLY VERY FINE/FINE; FAIR TO POOR SORT; MODERATE SPHERICITY; GRAINED TO MATRIX SUPPORTED; SILICIOUS CEMENT SLIGHT TO VERY CALCAREOUS; DOMINANTLY OTZ CLEAR/TRASPRNT TO CLOUDY/SMOKY OCCASIONAL MILKY WHITE AND ORNG COMMON CHALCEDONY; ALTERED FLDSPAR; MINOR CRUNULATED BlOT AND MUSC SCALES BLACK HORNBLEND HYPERSTHENE; PLANTY TO FEW OF DARK LITHICS FRAGMENTS; CLEAR/POLISHED TO FROSTED/IMPACT GRAINED SURFACE; OCCASIONAL "SALT PEPPER" APPEARANCE; MASSIVE STRUCTURE. [::1 EPOCH 6 (/~,' ,ARATHON OIL COMPANY KTU~ .1 TUFFACEOUS CLAYSTONE (6190'-6240') = LIGHT BLUSH GRAY LIGHT GRAY TO MEDIUM BROWNISH GRAY WITH YELLOWISH HUE; SOFT/PLIABLE GRADING TO CALCAREOUSEREOUS TUFF; SECTILE/PLIABLE STICKY; IRREGULAR CUTTINGS HABIT; CLAYEY TO SILTY TEXTURE; DULL/EARTHY TO WAXY LUSTER; HYDROPHILIC; SLIGHT EXPANSIVE WHEN REHYDRATED; FAIR TO GOOD ADHESIVENESS; SUBMASSIVE STRUC WITH INDISTINCT LAMINAE. SAND/SANDSTONE (6240'-6325') = LIGHT TO MEDIUM GRAY WITHCOLOR VARIGATION TO LIGHT BLUSH/MEDIUM BLUSH GRAY; FINE UPPER TO COARSE UPPER OCCASIONAL VERY COARSE PREDOMINANTLY MEDIUM; SUBANGULAR-SUBROUND; MODERATE FAIR DOMINANTLY POOR SORT; MODERATE SPHERICITY OVERALL; MOSTLY DISAGGREGATED BY BIT TO LOOSE SAND WITH A FEW HARD CUTTINGS; ASHY-CLAYEY MATRIX; SLIGHTLY CALCAREOUS; DOMINANTLY OTZ CLEAR/TRASPARENT TO SMOKY OCCASIONAL MILKY WHITE AND GREENISH COMMON CHALCEDONY; MINOR PINK SLIGHTLY ALTERED FELDSPAR BLACK HORNBLEND MICRO MICA ABUNDANCE OF DARK LITHICS FRAGMENTS; CONSOLIDATED CUTTINGS - LIGHT BROWNISH GRAY WITH PALE PINK HUE; "SALT AND PEPPER" APPEARNCE; VERY FINE TO FINE GRAINED; WELL SORT; DOMINANTLY QUARTZ; GRAINED SUPPORTED; ARGIL CEMENT; VERY CALCAREOUS. CARBONACEOUS SHALE (6325'-6350')= DUSKY BROWN; FIRM TO EASY SCORED; BRITTLE; SUBPLANAR TO CONCHOIDAL FRACTURE; SUBPLANAR CUTTINGS HABIT; DULL TO EARTHY OCCASIONAL RESINOUS LUSTER; CLAYEY TEXTURE; THIN BEDDING STRUCTURE. TUFFACEOUS CLAYSTONE (6350' - 6370') = LIGHT TO MEDIUM GRAY WITH LIGHT BROWN TO LIGHT GRAYISH BROWN SECONDARY HUES; SOFT TO MODERATELY FIRM; IRREGULAR TO SUB-ROUNDED CUTTINGS; CLAYEY TO ASHY TEXTURE DULL TO EARTHY TO OCCASIONALY MICROSPARKLY LUSTRE; TRACE VISIBLE GLASS SHARDS; HYDROPHILIC; VERY EXPANSIVE WHEN HYDRATED FAIR TO GOOD ADHESIVENESS AND COHESIVENESS; NON TO SLIGHTLY CALCAREOUS; COMMON BLACK MICROTHIN CARBONACEOUS LAMINATION. EPOCH 7 (/-~' ,ARATHON OIL COMPANY KTU('!' SAND (6370' - 6470') = LIGHT TO MEDIUM GRAY WITH STRONG "SALT AND PEPPER" APPEARANCE; INDIVIDUAL GRAINS DOMINANTLY LIGHT TO MEDIUM GRAY DARK GRAY TO BLACK LIGHT GREENISH GRAY WHITE CLEAR/COLORLESS TO TRANSLUCENT; FINE LOWER TO VERY COARSE UPPER OCCASIONALY 3mm DOMINANTLY MEDIUM UPPER TO LOWER; ANGULAR TO SUBANGULAR LARGER LITHICS ARE SUBROUNDED; POOR TO FAIR SORTING; DISAGGREGATED TO RARE CEMENTED SANDSTONE; "SALT AND PEPPER" APPEARANCE; ANGULAR; LOWER MEDIUM; MODERATELY WELL SORTED; HARD; GRAYISH WHITE CEMENT; POOR TO MODERATELY CALCAREOUS; TRACE BLACK CARBONACEOUS MATERIAL. TUFFACEOUS CLAYSTONE (6480' - 6565') = LIGHT GRAY TO MEDIUM GRAY WITH LIGHT BROWN TO LIGH BROWNISH GRAY SECONDARY HUES; VERY SOFT TO OCCASlONALY SLIGHTLY FIRM; VERY STICKY; CLUMPY ROUNDED AMORPHOUS CUTTINGS; CLAYEY TO ASHY MATTE TEXTURE; DULL TO EARTHY TO OCCASIONALY MICROSPARKLY LUSTRE; RARE VISIBLE GLASS SHARDS PRESENT; HYDROPHILIC; VERY EXPANSIVE WHEN HYDRATED; GOOD ADHESIVENESS; FAIR TO GOOD COHESIVENESS; NON TO SLIGHT CALCAREOUS; CLAYSTONE IS SUPPORTING MATRIX FOR SAND; TRACE CALCITE PIECES;TRACE TO SCATTERED BLACK CARBONACEOUS MATERIAL. SAND (6565' - 6625') = LIGHT TO MEDIUM DARK GRAY TO MEDIUM GREENISH GRAY WITH STRONG "SALT AND PEPPER" OVERALL APPEARANCE; INDIVIDUAL GRAINS LIGHT TO DARK GRAY TO GREENISH GRAY BLACK SCATTERED WHITE LITHICS VERY LIGHT GRAY TO TRANSLUCENT; VERY FINE UPPER TO VERY COARSE UPPER DOMINANTLY MEDIUM LOWER; ANGULAR TO SUBANGULAR; MODERATELY WELL SORTED; DISAGGREGATED TO VERY LOOSELY CONSOLIDATED WITH LIGHT TO MEDIUM GRAY ASHY TO CLAYEY SUPPORTING MATRIX; NON TO SLIGHTLY CALCAREOUS; COMMON BLACK CARBONACEOUS MATERIAL; TRACE CALCITE FRAGMENTS. TUFFACEOUS CLAYSTONE/SlLTSTONE (6645"- 6700') = LIGHT TO MEDIUM GRAY MEDIUM BROWNISH GRAY WITH LIGHT YELLOWISH/PINK HUE; SOFT/PLIABLE STICKY; AMORPHOUS CUTTINGS HABIT; SMOOTH/CLAYEY TO VERY FINE ABRASIVE TEXTURE; DULL/EARTHY TO WAXY/RESINOUS LUSTER OCCASIONAL WITH SCATTERED SPAKLING FROM MICRO GRAINS; HYDROPHILIC; SLIGHTLY EXPANSIVE WHEN REHYDRATED; FAIR TO GOOD ADHESIVENESS; SUBMASSlVE STRUCTURE WITH INCIPIENT LAMINAE. EPOCH 8 CARBONACEOUS SHALE (6700'-6760') = DUSKY BROWN TO BLACK; FIRM BRITTLE; SUBPLANAR BREAK; DULL TO EARTHY OCCASIONAL RESINOUS LUSTER; SMOOTH TEXTURE OCCASIONAL WITH RANDOM NODULS; THIN BEDDNG/FlSSlLE APPEARANCE WITH COMMON LEAVES INPRINT ON BEDDING SURFACE. SAND/SANDSTONE (6760' - 6800') = MEDIUM TO DARK GRAY WITH MINOR "SALT AND PEPPER GENERAL APPEARANCE; INDIVIDUAL GRAINS DOMINANTLY MEDIUM TO DARK GRAY BLACK OCCASIONAL LIGHT GRAY TO TRANSLUCENT RARE WHITE AND LIGHT BROWN LITHICS; VERY FINE UPPER TO VERY COARSE UPPER WITH LARGE (5mm) BROKEN FRAGMENTS DOMINANTLY MEDIUM UPPER; ANGULAR TO SUBROUNDED DOMINANTLY ANGULAR LARGER LITHICS TEND TO BE MORE ROUNDED; POORLY SORTED; DOMINANT DISAGGREGATED; OCCASIONAL VERY HARD; WELL CEMENTED SANDSTONE; MODERATE TO STRONGLY CALCAREOUS; TRACE MOTTLED MEDIUM TO DARK GRAY TUFFS; SOFT; VERY ASHY; ABUNDANT CLAY THROUGHOUT; CLAY IS DOMINANT SUPPORTING MATRIX FOR SAND; TRACE TO SCATTERED BLACK CARBONACEOUS MATERIAL. TUFFACEOUS CLAYSTONE (6800'- 6900') = LIGHT TO MEDIUM GRAY WITH LIGHT BROWN SECONDARY HUES; SLIGHTLY FIRM TO OCCASlONALY MODERATELY HARD; SUBBLOCKY TO IRREGULAR CUTTINGS; STICKY AND CLUMPY AT TIMES; CLAYEY TEXTURE; DULL TO EARTHY LUSTRE; HYDROPHILIC; EXPANSIVE WHEN HYDRATED; FAIR TO GOOD ADHESIVENESS AND COHESIVENESS; SCATTERED BLACK MICROTHIN CARBONACEOUS LAMINATIONS; TRACE BLACK CARBONACEOUS PIECES THROUGHOUT. SAND/SANDSTONE (6900'-6950') - MEDIUM GRAY/MEDIUM BLUSH GRAY; FINE UPPER TO COARSE UPPER PREDOMINANTLY MEDIUM; SUBANGULAR-SUBROUND; MODERATE FAIR SORT MODERATE SPHERICITY OVERALL; COMMON DISAGGREGATED BY BIT ACTION TO LOOSE SAND; CONSOLIDATED CUTTINGS VERY HARD; VERY FINE GRAINED; SILICEOUS CEMENT; VERY CALCAREOUS GRAINED SUPPORT POINT CONTACT; QUARTZ ARENITE DOMINANTLY TRASPARENT/TRANLUSENT-SMOKY QUARTZ; INTENSIVELY ALTERED FELDSPAR; MINOR BLACK HORNBLENDE MICRO MICA, LITHICS FRAGMENTS; MASSIVE APPEARANCE. TUFFACEOUS CLAYSTONE/SlLTSTONE (6950'- 7000') - MEDIUM GRAY MEDIUM YELLOWISH GRAY; VERY SOFT/PLIABLE STICKY; WELL ADHESIVE/COHESIVE; AMORPHOUS CUTTINGS HABIT; EARTHY TO WAXY LUSTER WITH SPORADIC SPAKLING FROM MICRO MICA. EPOCH 9 (/~" .~ARATHON OIL COMPANY KTU~..-1 SAND/SANDSTONE (7060' - 7085') = LIGHTGRAY TO LIGHT GREENISH GRAY OVERALL;INDIVIDUAL GRAINS DOMINANTLY LIGHT TO MEDIUM GRAY LIGHT GREENISH GRAY WHITE TRANSLUCENT GRAY TRACE DARK GRAY TO BLACK LITHICS; FINE LOWER TO MEDIUM UPPER; ANGULAR TO SUBANGULAR; WELL SORTED; DISAGGREGATED TO VERY LOOSELY CONSOLIDATED WITH LIGHT GRAY TO GRAYISH WHITE ASHY TO CLAYEY SUPPORTING MATRIX; MODERATELY CALCAREOUS; TRACE BLACK CARBONACEOUS MATERIAL; TRACE ASHY TUFFS. TUFFACEOUS SlLTSTONE (7090'-7160') = LIGHT GRAY TO LIGHT BROWNISH GRAY WITH LIGHT BROWN SECONDARY HUES OCCASIONALY LIGHT TO MEDIUM BROWN; SOFT TO SLIGHTLY FIRM; IRREGULAR ROUNDED CUTTINGS; SITLY TO CLAYEY TO ASHY TEXTURE; DULL TO EARTH LUSTRE; ABUNDANT BLACK MICROTHIN CARBONACEOUS LAMINATIONS AND LARGER IRREGULAR FRAGMENTS; NON CALCAREOUS; COMMON LIGHT GRAY TO LIGHT GRAYISH WHITE ASHY TUFF; VERY CALCAREOUS. SAND/SANDSTONE (7160' - 7170') = SAME GENERAL CHARACTERISTICS AS ABOVE WITH SLIGHT INCREASE IN LIGHT GRAY TO LIGHT GRAYISH WHITE CLAYEY SUPPORTING MATRIX. TUFFACEOUS CLAYSTONE (7170'-7230') = LIGHT/MEDIUM GRAY MEDIUM BROWNISH GRAY WITH LIGHT YELLOWISH/PINK HUE; SOFT/PLIABLE STICKY; AMORPHOUS CUTTINGS HABIT; SMOOTH/CLAYEY TO VERY FINE ABRASIVE TEXTURE; DULL/EARTHY TO WAXY/RESINOUS LUSTER OCCASIONAL WITH SCATTERED SPAKLING FROM MICRO GRAINS; HYDROPHILIC; SLIGHT EXPANSIVE WHEN REHYDRATED; FAIR TO GOOD ADHESIVENESS; SUBMASSIVE STRUCTURE WITH INCIPIENT LAMINAE. SAND/SANDSTONE (7230' - 7250')= MEDIUM BROWNISH GRAY/MEDIUM GRAY; FINE UPPER TO COARSE UPPER PREDOMINANTLY MEDIUM; SUBANGULAR-SUBROUND; MODERATE FAIR SORT MODERATE SPHERICITY OVERALL; COMMON DISAGGREGATED BY BIT ACTION TO LOOSE SAND; CONSOLIDATED CUTTINGS VERY HARD; VERY FINE GRAINED; SILICEOUS CEMENT; VERY CALCAREOUS GRAINED SUPPORT POINT CONTACT; QUARTZ ARENITE DOMINANTLY TRASPARENT/TRANLUSENT-SMOKY QUARTZ; INTENSIVELY ALTERED FELDSPAR; MINOR BLACK HORNBLENDE MICRO MICA LITHICS FRAGMENTS; MASSIVE APPEARANCE. CARBONACEOUS SHALE = (7250'- 7290') = DUSKYBRN; FIRM BRITTLE; SUBPLANAR BREAK; EARTHY OCCASIONAL RESINOUS LUSTER; SMOOTH TEXTURE OCCASIONAL WITH RANDOM NODULS; THIN BEDDNG/FISSILE APPEARANCE WITH COMMON LEAVES INPRINT ON BEDDING SURFACE. EPOCH 1 o ~ .,ARATHON OIL COMPANY KTUi' COAL (7290'- 7340') = VERY DARK BROWN TO BLACK GRADING TO DARK BROWN CARBONACEOUS SHALE; FIRM TO EASY SCORED; BRITTLE; SUBPLANAR TO CONCHOIDAL FRACTURE; BLOCKY TO IRREGULAR CUTTINGS HABIT; DULL TO EARTHY OCCASIONAL WAXY LUSTER. TUFFACEOUS CLAYSTONE (7340' - 7350') =LIGHT GRAY TO MEDIUM GRAY WITH LIGHT BROWN TO LIGH BROWNISH/YELLOWISH GRAY HUES; VERY SOFT TO OCCASIONALY SLIGHTLY FIRM; VERY STICKY; CLUMPY ROUNDED AMORPHOUS CUTTINGS; CLAYEY TO ASHY MATTE TEXTURE; DULL TO EARTHY TO OCCASIONALY MICROSPARKLY LUSTRE; RARE VISIBLE GLASS SHARDS PRESENT; HYDROPHILIC; VERY EXPANSIVE WHEN HYDRATED; GOOD ADHESIVENESS; FAIR TO GOOD COHESIVENESS; NON TO SLIGHT CALCAREOUS; CLAYSTONE IS SUPPORTING MATRIX FOR SAND; TRACE CALCITE PIECES; TRACE TO SCATTERED BLACK CARBONACEOUS MATERIAL. COAL (7350'- 7400') = VERY DARK/DSKY BROWN TO BLACK GRADING TO DARK BROWN CARBONACEOUS SHALE; FIRM TO EASY SCORED; BRITTLE; SUBPLANAR TO CONCHOIDAL FRACTURE; BLOCKY TO IRREGULAR CUTTINGS; SMOOTH TEXTURE; RESINOUS TO GLASSY LUSTER. SAND (7460' -7490') = LIGHT GRAY WITH WEAK "SALT AND PEPPER" OVERALL APPEARANCE INDIVIDUAL GRAINS DOMINANTLY LIGHT GRAY TO LIGHT GREENISH GRAY FROSTED CLEAR TO TRANSLUCENT SCATTERED DARK GRAY TO BLACK LITHICS; FINE LOWER TO RARE COARSE LOWER DOMINANTLY FINE UPPER TO MEDIUM LOWER; ANGULAR TO SUBANGULAR; WELL SORTED; DISAGGREGATED TO LOOSELY CONSOLIDATED WITH WHITE TO LIGHT GRAY/MOTTLED ASHY SUPPORTING MATRIX; NON TO SLIGHTLY CALCAREOUS. SAND (7510'- 7570') - SAME GENERAL CHARACTERISTICS AS ABOVE WITH INCREASE IN ASHY TUFF. EPOCH 11 ~," .ARATHON OIL COMPANY KTU ~ _-1 DAILY ACTIVITIES SUMMARY 112212001 'Cut off 13 3/8" casing. Cut off and remove 20" flange. Make final cut on 13 3/8". Level and weld on Cameron well head, insulate and cool down. Attempt to test with nitrogen, have to re-weld 2 times. Clean mud system. Spot BOP stack and raise. Install panic line. Load 100 joints of 4" drill pipe on pipe racks. Load out Baker and Weatherford tools. Spot DSA and adapter spool in cellar. Test well head with nitrogen at 1000 psi (tested good). Nipple up BOP and related equipment. Set DSA. Install Koomey lines. Fill up lines, turnbuckles and choke and kill lines. Install riser and drip pan (modify same). Set mouse hole. Clean mud pits and refill with FIo Pro mud. Clean cement out of flowline "Y" at derrick shakers. Change out shaker screens. Function test BOP. Pick up test joint and make up test plug. 112312001 . Attempt to set test plug. Remove bell nipple and grind out inner weld. ID was 13 7/8" at weld, grind out to 13 %" ID. Set test plug. Rig up test equipment. Stack leaked, tighten bolts at DSA to adapter flange. Rig down bell nipple. Lift BOP stack. "No APl ring" installed between Weatherford spool and DSA. Nipple up BOP stack and related equipment. Rig up to test BOP at 250 Iow and 3000 psi high. Continue to test BOP and related equipment at 250 psi Iow and 3000 psi high. Install wear ring. Lay down test joint. Install 5: elevator inserts. Test 13 3/8" casing at 1500psi. "Tested good." Make up 12 ¼" drilling assembly and RIH. Surface test motor and MWD tool. Pick up and stand back 80 stands of 4" drill pipe for drilling to T.D. Circulate and condition thick mud in hole. RIH and tag float collar at 1703'. Drill out float collar at 1703'. Tag and drill cement at 1718' to float shoe at 1745', wash to bottom at 1760'. Drill new hole from 1760' to 1780'. Circulate bottoms up. Perform leak off test. EMW at 15.6 ppg. Displace mud system to flo-Pro. 1/2412001: Directional drill ahead from 1780' to 2238'. Actual slide time 2.5 hours. Actual rotating time 1.25 hours. Actual survey time 1.0 hours. Continue to drill ahead from 2237' to 3455'. Actual rotating time at 5.75 hours, actual slide time at 4.0 hours. Pump out of the hole to 13 3/8" casing shoe at 1750'. Tight at 2796' to 2142'. 112512001: Service rig and Tesco top drive. Circulate bottoms up. Adjust top drive torque tube (not over hole). RIH to 3455'. 28' of fill. Break circulation. Drill ahead from 3455' to 3658'. ART at 2 hours. AST at .5 hours. Continue drill ahead from 3658' to 4369'.. 112612001: Drill ahead 4369' to 4741'. Pump hi-vis sweep and pump out of hole to 3394'. RIH to bottom at 4741'. Drill ahead from 4741' to 4899' ART 1.5 hours. AST 2.5 hours. Circulate LCM sweeps. 100% total losses. Able to regain circulation 5 times. Build volume. Monitor well. Mud losses at 1 to 2 barrels per min. Total losses at 425 barrels. EPOCH 12 ~/~' .ARATHON OIL COMPANY KTU {' .1 112712001: POH from 4899' to 3394', no problems. Hole tight at 3394' to 3144'. Back ream and pump out of the hole with full returns. POH from 3144' to 13 3/8" casing shoe at 1750'. Drill string increased drag when going into shoe with BHA. Appears to be balled up. Circulate and build volume at 13 3~8' casing shoe. Build LCM pill at 15 ppb. RIH (staging in the hole). Break circulation at 2750', 3750', 4400', 4585', 4711', while bringing pump rate to drill rate. Tight at 4811', work thru area. Wash and ream to 4899' while pumpi.ng 1st LCM 30bbl pill (mud losses at 80 bbl). Work pipe at 4899' while pumping 2na LCM 40 bbl pill. Increase mud pumps to drill rate. Drill ahead from 4899' to 5205'. ART 1.25 hours. AST 6.75 hours (dropping angle per directional plan.) 112812001: Pull one stand, circulate and trouble shoot PLC problem with #2 mud pump. Directional drill ahead from 5205' to 5300'. Working to drop angle. Drill ahead from 5300' to 5559' ART 6 hours. AST 2.25 hours. Circulate hi-vis sweep. Level mast. POH back reaming tight from 5130' to 5025'. Loose returns at 5026'. Work pipe out of the hole. Normal upward drag at 135k, pull up to 210k. Pump at minimal rate while pulling out of the hole to keep drill string full and to prevent swabbing. Pipe pulling free at 4461' Break circulation with full returns. Monitor well. Pump small dry job at 4408'. Blow down surface equipment. POH with 4" drill pipe. 1/2912001: Continue POH with 4" drill pipe. Monitor well at casing shoe. POH with 5' HWDP. Pull MWD probe. Change 12 ¼" bits. Rig down bell nipple and move BOP bridge crane to ODS. Reinstall bell nipple and flow line. RIH to casing shoe with BHA and 4' drill pipe. Fill pipe. Remove old stabbing board and install new stabbing board. Change swab in #1 mud pump. Change shaker screens. RIH with 4" drill pipe to 4458'. Circulate bottoms up at 4458'. Wash and ream to 5080'. Circulate and working drill string to allow hole to clean up, "lost returns". Circulate LCM 60 barrel pill, spot and pull up above thief zone. Let LCM settle for 30 minutes. Total losses at 98 barrels. RIH thru thief zone at 4924' to 5025'. Wash and ream from 5080' to 5559' with full returns at 500 gpm. Drill ahead from 5559' to 5590', 9 5/8" casing TD. Circulate bottoms up. While pumping hi- vis sweep, allow cuttings to clean up at shakers. Short trip, POH to 4400'. Excessive drag from 5590' to 5275'. Monitor well. RIH to 5275'. Wash and ream from 5275' to 5590'. Monitor well for losses. Circulate and condition mud. 1130/2001: Continue to circulate and condition mud. POH to 5087' (wet) with 4" drill pipe. Pump and spot LCM pill across thief zone. POH, get above LCM pill. Break circulation. Pump very small dry job. Continue to POH with 4" drill pipe. POH with 5" HWDP. Lay down MWD collar, mud motor, string stabilizer and break off bit. Clear rig floor. Pull wear ring and set test plug. Change upper pipe rams to 9 5/8" and test to 3000 psi. Check door seals. Test good. Change out bales. Make up La Fleur casing fill up tool. Lay down test joint. Rig up back up tongs on drillers side. Fold down stabbing board. Adjust top drive torque tube. Rig up casing tongs, elevators, and slips. Hold pre-job safety meeting with all EPOCH 13 t/-~~'~ .ARATHON OIL COMPANY KTU i'. .1 personnel. Run 9 5/8" 40 lb L-80 casing per program. Circulate thru float equipment. RIH to 13 3~8" casing shoe, while monitor returns and losses. 2 bph losses. Circulate 9 5/8" volume and work pipe, 100k upward drag. 25k downward drag. 500 psi at 125 spm. Continue to run 9 5/8" casing to 3129'. Monitor returns, 2 bph losses. Circulate % bottoms up and work pipe, 150k upward drag, 80k downward drag, 640 psi at 125 spm. Continue to run 9 5/8" casing. 113112001 Continue to run 9 5/8" casing to 4400', 2 bph losses. Circulate bottoms up at 4400'. Work pipe, 200k upward drag, 125k downward drag, 120 spm at 651 psi. RIH with 9 5/8" casing to 4815'. Circulate and work pipe, 215k upward drag, 140k downward drag, 120 spm at 640 psi. RIH with 9 5/8" casing to 5180'. Break circulation and move fluid. 250k upward drag, 140k downward drag. RIH with 9 5/8" casing to 5567', tag fill. Circulate with full returns at 5567', 134 spm at 694 psi, 39% flow. Wash and work casing to bottom at 5575'. Condition mud and prepare for cement job at 5582', 134 spm at775 psi. Cement 9 5/8" 40 lb., L-80 buttress casing as follows while reciprocating. Pump 5 bbl water. Test surface lines at 3000 psi. Drop bottom plug. Mix and pump 40 bbl MCS 4D spacer with the following additives; 6 Ibs/bbl MCS-D, 30.8 Ibs/bbl bentonite, 92 Ibs/bbl Barite followed by 420 sacks of class "G" 12.5 ppg lead cement with a yield of 2.10 cu/ft per sack with the following additives; .3% bwoc calcium chloride, .4% bwoc CD-32, 1 gal/100 sack FP-6L, 2% bwoc sodium metasillicate followed by 234 sack of class "G" 15.8 ppg tail cement with a yield of 1.15 cu/ft per sack with the following additives; .3% bwoc CD-32, .6% bwoc FL-33, 1 gal/100 sack FP-6L. The top plug was dropped and 5 bbl water pumped to clear surface lines and then turned over to rig for displacement. A total of 4000 strokes were pumped at 5.9 bpm and losses started to occur, the pipe was then parked and the pumping rate was reduced to 3.9 bpm at 4600 strokes losses still becoming greater and the pumping rate was reduced again to 2 bpm at 5050 strokes for the remainder of the job. At 8588 strokes into the displacement no returns to surface occurred, a total of 8991 strokes were pumped and the circulating pressure at this time was 798 psi. The plug did not bump, and total losses at this point were 71 bbls. The pressure was bled down and the floats were checked, and were holding. Cement was in place at 11:27 A.M. All surface lines were flushed and blown down. Wait on cement. Rig down BOP and related equipment, prepare to lift stack and install emergency slips. Change pump liners to 4 %". Pick up 13.5/8" BOP and set casing slips with 185k on slips. Rough cut casing and lay down stub. Set BOP out of the way. Make final cut on casing and dress up same. Set tubing spool in place. 210112001: Tighten down tubing spool and attempt to test, leaking on inside of packoff, inject plastic and retest at 2100 psi for 15 min. Change out link's to short set. Nipple up BOP and related equipment. Install test plug. Test BOP and related equipment at 250 psi Iow and 3000 psi for high. Five failures occurred during test (1) upper pipe rams, (2) check valve on kill line, (3) H2S detector at rig floor, (4) LEL detector at bell nipple, (5) Koomey remote at drillers console would not function upper pipe rams. Changed out hoses with lower pipe ram EPOCH 14 ~-~" ,ARATHON OIL COMPANY KTU controls. All items repaired. Pull test plug and install wear ring. Rig up Schlumberger wire line services. Run CBL. RIH with log #1 to 5480'. POH logging. Rig down Schlumberger and clear rig floor. Log shows the following: no cement at 4130', Iow quality to 4460', 50% bond index down to 5480'. Test 9 5/8" casing at 2600 psi for 30 minutes. Adjust top drive torque tube. Blow down choke manifold. Pick up new 8 %" drilling bottom hole assembly. 210212001: Continue to pick up bottom hole assembly. Surface test MWD tool and mud motor. RIH with 5" HWDP. RIH with 4" drill pipe to 2512'. Fill drill string. Slip and cut 68' of I 1/8" drilling line. Service top drive and carrier. Adjust draw works mechanical brakes. Continue to RIH with 4" drill pipe. Break Circulation at 5402'. Wash and ream to 5481' and tag cement. Drill cement to 5495' and tag float collar. Drill float equipment. Drill cement to top of float shoe at 5582'. Wash and ream 12 %" rat hole to 5590'. Drill 8 %" hole from 5590' to 5610'. Circulate bottoms up and condition mud. Perform leak off test. EMW at 13.3 ppg. Drill ahead from 5610' to 6103'. 210312001: Continue drill ahead from 6103' to 6714'. Work tight hole at 6704'. Work drill string free and back ream and rotate thru complete stand. Drill ahead from 6714' to 6739'. 210412001: Wash out in mud line between mud pumps on tee. Work pipe, fill trip tank. Round up welding gear to patch tee. Work out of hole to 9 5/8" casing shoe. Pull first 6 stands normal. Upward drag at 145k. Work thru tight spots, up weight at 225k. Weld tee on mud line pump and rotate out of hole. Continue to back ream. Work pipe and POH to 9 5/8" casing shoe. Pull to 265k, normal upward drag at 145k after working thru area. Service rig and top drive. Tag fill at 6720'. Break circulation and wash to bottom at 6739' Drill ahead from 6739' to 6903'. Back ream every 15' due to hole conditions. Change swab in #2 mud pump. Drill ahead from 6903' to 6912'. Change swab in #2 mud pump. Drill ahead from 6912' to 7000'. Weld other side of tee on mud line between mud pumps. 210512001: Continue to weld tee and POH, back reaming to 9 5/8" casing shoe at 5582' Circulate bottoms up. Pump dry job and blow down circulating surface lines. Continue to POH with bit #4. Change out flow tee on mud line between mud pumps. POH with 5" HWDP and BHA. Break bit. Clear rig floor. Make up bit #5 and RIH with 5" HWDP. RIH with 4" drill pipe to 9 5/8" casing shoe. Break circulation and check MWD. Sewrvice rig and top drive. Continue to RIH with 4" drill pipe to 6850'. Wash and ream from 6850' to 7000' due to possible under gauge hole section. Continue to drill ahead from 7000' to 7288'. 210612001: Continue drilling from 7288' to 7570'. Circulate bottoms up. Back ream out of the hole to 6640'. Tight at 7343',7269', 6835'. Normal upward drag at 165k. Work pipe at 205k to 250k. Continue to POH to 9 5/8" casing shoe at EPOCH 15 5582'. Service rig. RIH to 7570', 4' of fill. Circulate and condition mud. Raise MW to 10.6 ppg. 210712001: Continue to circulate and raise mud weight to 10.6 ppg. POH to 6972'. Upward drag 5k above normal upward drag. No problems. Pump dry job and blow down surface circulating system. Continue to POH with 4" drill pipe for logging. Work hole section at 6435'. Clean up good. Continue to POH with 4" drill pipe. POH with 5" HWDP and BHA. Lay down directional tools. Clear rig floor. Test Tesco top drive upper and lower IBOP valves. Hold pre-job safety meeting. Rig up Schlumberger wireline services. Logging run #1, PEX and DSI. Logging run #2, CMR. 210812001: Continue logging run #2, CMR. Logging run #3, RFT. Work stuck logging tools at 6030'. Normal line weight at 3150 lbs. Pull up to 7000 lbs. Tools appear to have moved up hole 3'. No more movement. Head weight at 800 lbs. Line appears to be hung up. Cut and thread Schlumberger cable. Hang sheave at crown. Rig up to strip in the hole over E-line. Thread thru over shot, one stand of 5" HWDP and jars. RIH with 4" drill pipe stripping over E-line to 4720'. 210912001: Cable taking weight. RIH to 4806'. Unable to get slack pulled back to surface. Lay down single in mouse hole at 4775'. Pick up double. Pull cable weight. RIH to 4826'. Unable to get all slack out of cable, weights hitting top drive. POH with single and mouse hole at 4775'. Pull slack to rotary table. Change bales to long set. Remove weights from E-line. Make up hydraulic hoses for hydraulic elevators. Pick up singles and strip over cable to 5562'. Change saver sub to 4 % IF. Continue to RIH stripping over Schlumberger wire picking up singles from 5575' to 5997'. Rig up to circulate. Circulate bottoms up. Rig down circulating lines and blow down system. Fish for RFT tool at 6000' drill pipe measurement. POH laying down 14 joints 4" drill pipe. Stripping over wire to 9 5/8" casing shoe. Pump dry job and blow down lines. Rig up t-bar. Cut wire line. Tie square knot. Pull fish up to overshot. Change out bales and elevators. Re- head wireline to strip out of hole. POH stripping over wireline. 211012001: Re-head wireline to strip out of hole. Continue to POH with 4" drill pipe, stripping over wireline. POH stripping over 5" HWDP. Spool electric line to Schlumberger unit. Lay down RFT tools. Clear rig floor. Change out saver sub on Tesco top drive to HT-38 connection. Make up bit #5(RR) and BHA. RIH with 5" HWDP. Continue to RIH with 4" drill pipe to 2500'. Break circulation and fill drill string. Continue to RIH with 4" drill pipe to 9 5/8" casing shoe at 5560'. Break circulation at shoe. Continue to RIH with 4" drill pipe to 7530'. Break circulation. Wash to bottom at 7570'. Circulate and condition mud for casing escape system. POH to 9 5/8" casing shoe at 5582'. No problems with hole. RIH to bottom at 7570'. No problems. Circulate bottoms up and condition mud. Build 16 ppg pill. Rabbit last few of casing. Pump and spot 16 ppg weighted pill on bottom up to 7500'. EPOCH 16 211112001: POH to 9 5/8" casing shoe at 5582'. No problems. Pump dry job. Blow down all surface circulating lines. POH laying down 4" drill pipe. RIH with 4" drill pipe from mast. Continue to lay down 4" drill pipe. Lay down 5" HWDP and BHA. Clear rig floor. Pull wear bushing. Set test plug. Change out upper pipe rams to 3 W. Test choke manifold valves, HCR, inside choke valves, manual valves on kill line, annular, upper pipe rams and blind rams at 250 psi Iow and 3000 psi high. Hold pre job safety meeting with all personnel on location. Rig down rig tongs, pipe spinners and change out bales to long set. Pick up 75 ton "YT" elevators. Spot 45 ton crane and pipe racks for Tri-point perforation guns. Rig up Weatherford casing equipment. Rig up Promore and Tri-point perforation control lines. 211212001: RIH with 3 %" casing and escape system per program. 211312001: Continue RIH with 3 %" tubing. Circulate bottoms up. Cement in place. EPOCH 17 JKENAI PENNINSULA, AK JANUARY 21~2001 to FEBRUARY 6~ 2001 GLACIER DRILLING RIG #t APl Number- 50.t33'20488.00 : ! Depths: t760' to 7500' DATE DEPTH MW ViS PV YP GELS FL FC SOL OIL SD MBT pH AIk CI- Ca+ MD I TVD ~1/21-/01i 1-76~/¥~-4-2 ~ 8.~ 2 4.0 0/96 0.00 400 i 10~ 0 _ 1/22/01~ 1760/1742 I 8.85 2 4.0 0/96 0.00 400 i t00 1123101! t780/1760 I 8.90 1124101 345513296 ~- 9.30 1125101 '. 437114130 9.35 ~1261_~0__1:490014643 I 9.30 1127/01 520514945 [ 9.40 1128101 5559/5299 I 9.35 1129101 1/30/01 1/31/01 2/1/01 2/2101 213101 214101 215101 216/01 2/'7101 21810t 219101 559015330 i 9.25 559015330 ~:"-9-::~D-~ 559015330 5590/5330 ~ 9.40 6131/5920 ~ 9.70 6733/64731 10.00 7000/6850 i~ 9.90 7293/7032[ 10.15 757017309 i. 10.60 757017309 ! 10.60 757017309 i 10.60 757017309r 10.70 42 9 42 9 39 6 46 10 46 9 45 t2 49 14 60 14 53 15 52 14 62 14 61 14 46 13 53 16 45 15 51 15 55 22 65 22 62 19 65 19 2110101 757017309 ~r t0.75 62 ' 21 2111101 757017309 ~=~'~'~.~)-- 66 ' 22 2112101 757017309 }' 10.95 ! 66 ~ 20 i · 5 i 3/618 16.6 5 :..'_ 3/6/8 16.6 8 ~ 17_ .2 17 i9/1~ 8.9 25 [18/26/26; 11.0 5 I 2/515 6.2 11 I 3/7/11 5.5 24 ! 9121124 6.8 19 ~ 7.0 18_ ~101/8/23i. 7.6 24 !13/23/29B 9.3 24 ~~ 9.8 24 16127/32i 10.8 3O 19 21 18131133! 8.0 9116117 ! 7.8 8116/t7 ~ 7.5 22 9117118 22 10120121 16 7/16117 21 9118119 16 7/1611~ 19 18/17/22 18 ! 8117/19 6.6 7.5 6.9 6.6 6.4 6.3 7.2 2 4.0 0196 0.20 400 ! 160 2 7.0 1.192 0.05 2 7.5 .5192 0.30 7.0 8.0 7.5 7.0 7.0 8.0 7.0 9.0 10.0 10.0 10.5 12.5 13.0 13.0 t3.0 13.0 14.0 14.0 TR/93 TR/92 TR/93 TR/93 0/92 0/93 0/91 0/90 0190 0/89.5 0187.5 0/87 0~87 0187 TR/87 0186 0~86 0.50 12.5 8.0 0.50 12.5 8.0 0.50 t2.5 9.0 TR 7.5 9.0 TR 11.3 9.5 TR 10.0 9.5 ~ 8.8 8.5 TR i 7.5 T~:~~ TR ! 7.5 TR i 7.5 TR ; t0.0 TR J 10.0 0.25 [ 10.0 TR__~ t0.0 TR 7.5 8.3 8.0 9.2 8.7 9.1 0.40 = 0.05 0.00 0.0~ O= 0.00 0.00 0.10 0.35 .32000 ; · 560 '30000 i ~-32T 31000 ~2~2~2~2~2-8-~ 30000 280 30000 200 29000 240 27000 i 220 31500 680 33000 TR TR 0.15 0.15 0.15 0.15 TR TR 6,5 7.0 7.0 7.0 6.3 6.3 7.5 7.5 8.0 ;= 0.00 9.5 i 0.6~ 0_ 9.0 0.20 9.5 0.20 9.0 0.20 8.5 0.10 8.7 0.10 8.5 i TR ; ~ 30000! 200 28000 F--~-I-~--~ 26000 i~~- 31000 160 27000 160 27000 160 26000 160 25500 : [:l EPOCH KU 42.;7' KENAI.GAS FIELD · , ii i iii ii iiiiirl i i · i i i IKENAI PENNINSULA, AK BIT SIZE TYPE SER NO. JETS DEPTH DEPTH FTG HRS ROP WOB RPM PP GRADE # ,, IN OUT Avg Hi-Lo-Avg Hi-Lo-Avg Hi-Lo-Avg I - O - D - L - B - G - OT - R , I 17.5 STC MSDHC LN0624 18,t8,16,12 37 t760 1723 18.00 95.7 25 50.0 1360 3,3,wT,A,E,5, NO,TD , , 2 12.25 STC M0550DEL LR0134 16,18,20,16 1760 5559 3799 57.95 65.6 39-15-26 45.0 2200.1300-1900 6,4,BT,A,E,4,BU,TQ . RR3 12.25 RBI CLRGSP BZ335 18,18,20 5559 5590 31 0.70 44.3 32'23-29 45.0 2016-1710-1959 2,2,ER,A,E,0,NO,TD I , 4 8.5 RBI ClALRGSP BZ34t 16,18,14 5590 7000 1410 32.70 43.1 35-15-25 45.0 2300-1750-2150 3,3,WT,A,F,1/8,NO,TQ . 5 8.5 RBI ClALRGSP BZ339 16,16,14 7000 7570 570 17.80 32.0 33-14-25 45.0 2350-1950.2200 1,t,NO,A,E,1,NO,TD ,, ,, r , , ,, , RiG ACTIVITIES SUMMARy M/A H N i KTU42 7 · E ~c = _ _ n =c ~ n 01121 5.0 0.5 6.0 6.0 6.0 0.5 24.0 0922 1,0 10.0 13.0 24.0 01a3 1.5 7.6 2.5 1.0 5.0 4.0 1.0 0.5 1.0 24.0 0:~124 21.0 3,0 24.0 01125 2t.0 1.0 1.5 0.5 24.0 0926 14.5 2.5 5,0 2.0 24.0 01127 10.0 8.0 1,0 5.0 24.0 0928 t5.0 4,0 1.5 1.5 2.0 24.0 01129 1.0 5.5 4.0 5.5 2.5 2,0 3.5 24.0 01130 5.0 1.5 11.0 2,5 4,0 24.0 01131 4.0 8.0 6.0 6.0 24.0 02/01 t.0 3,0 7.5 7.0 1.0 4,5 24.0 02/02 14.0 2.5 1.0 2.0 1.5 1.5 1,5 24.0 02103 23.0 1.0 24.0 02/04 11.5 9.5 1.0 1.5 0.5 24.0 02/05 10.0 12.0 0,5 1.0 0.5 24.0 02/06 12.0 5.0 3.5 2.5 0.5 0.5 24.0 02/07 6.0 4.0 12.5 0,5 1,0 24.0 02/08 12,0 12,0 24.0 02/09 12.0 2,5 0.5 9.0 24.0 02/10 14.5 5.0 3.5 0.5 0.5 24.0 02/11 14.0 0.5 4.0 5,5 24.0 02/t2 2.0 0,5 21,5 2410 02/13 0.0 o2/14 o.O 02/15 0.0 02116 0.0 o2/17 o.o 02/18 0.0 02/19 0.0 TOTAL 154.5 100.0 15.5 46.0 15.5 2.5 4.5 0.0 0.0 31.0 0.0 46.5 12.0 2.0 6.0 8.0 18.0 29.0 2.0 2.0 13.0 5.0 0.0 39.0 552.0 % 2144 13.88 2.15 6.38 2.15 0.35 0.62 0.00 0.00 4.30 0.00 6.45 1.67 0.28 0.83 1.11 2.50 4.03 0.28 0.28 t.80 0.69 0.00 541 SURVEY CALCULATION AND FIELD WORKSHEET Job No. Company MARATHON OIL COMPANY Rig Contractor & No. Glacier Drilling/Rig #1 Well Name & No. PAD 41-7/KBU 42-7 Survey Section Name 42-7 WELL DATA 0450-00072 Sidetrack No. Page Field KENAI GAS FIELD BHI Rep. 1 of 4 Target TVD Target Description Target Direction Date ~ ~9-JAN-01 19-JAN-01 19-JA N-01 19-JAN-O 1 19-JAN-01 19-JAN-01 19-JAN-01 19-JAN-01 20-JAN-01 20-JA N-01 20-JAN-01 20-JAN-01 5327.00 (fl) 0.00 (dd) Survey Dep~ 0.00 181.00 224.00 284.00 404.00 524.00 613.00 704.00 825.00 952.00 1074.00 1170.00 1293.00 1421.00 1513.00 1610.00 1706.00 1806.00 1899.00 2024.00 2151.00 2275.00 2401.00 2528.00 Target Coord. N/S -1179.02 Slot Coord. N/S Target Coord. E/W 652.50 Slot Coord. E/W Build\Walk\DL per: 100ft[~ 30m[~ 10m [~ Vert. Sec. Azim. SURVEY DATA Hole Course Vertical Direction Length TVD Section (dd) (ft) (fl) 0.00 0.00 0.00 339.10 181.00 181.00 -0.86 282.60 43.00 224.00 -1.13 256.60 60.00 284.00 -1.28 208.40 120.00 403.96 0.05 199.20 120.00 523.67 5.07 197.40 89.00 612.16 11.38 187.40 91.00 702.36 20.32 167.60 121.00 822.05 36.02 150.10 127.00 947.63 54.63 135.60 122.00 1068.31 72.32 135.80 96.00 1163.26 86.01 131.10 123.00 1284.82 103.98 135.90 128.00 1411.07 139.40 92.00 1501.55 136.80 97.00 1596.44 96.00 1689.77 143.80 148.10 100.00 1786.61 207.12 148.00 93.00 1876.30 231.70 148.90 125.00 1995.94 267.89 149.60 127.00 2116.01 309.25 149.50 124.00 2231.56 354.24 -16.38 Grid Correction 4116.17 Magn. Declination 150.10 Magn. to Map Corr. 146.80 126.00 2347.40 403.75 148.70 127.00 2462.49 457.38 Total Coordinate N(+) / S(-) E(+) / W(-) (fl) fit) 0.00 0.00 0.81 -0.31 1.03 -0.49 1.02 -0.79 -I .44 -2.40 -9.00 -5.49 -17.98 -8.44 -29.72 -10.93 -47.34 -10.07 -64.92 -3.31 -79.13 7.45 -89.25 17.33 -102.14 30.97 124.22 -116.70 46.25 140.46 -129.00 57.44 160.12 -143.94 70.90 182.26 -161.26 85.20 -181.92 99.13 -202.79 -233.65 -269.21 112.15 131.08 152.22 175.02 201.20 229.81 -307.99 -350.05 0.000 20.920 20.920 Depths Measured From: RKB ~] MSL[-] SS E Calculation Method Minimum Curvature Map North to: OTHER Build Rate Build (+) Drop (-) Walk Rate Right (+) Left (-) 0.30 N/A -0.63 N/A 0.05 N/A 1.90 N/A 2.21 -7.67 1.93 -2.02 1.43 -10.99 Comment Tie In Point 0.41 -16.36 -0.20 -13.78 -0.05 -11.89 0.06 0.21 0.46 -3.82 0.67 3.75 1.05 3.80 2.21 -2.68 1.07 7.29 0.74 4.30 1.13 -0. I1 1.56 0.72 1.89 0.55 1.71 -0.08 1.32 -2.14 1.60 1.50 rll/glg R' , SURVEY CALCULATIONAND FIELD WORKSHEET JobNo. 0450-00072 Sidetrack No. Page 2__ of 4 II .' [ ! [4-'1 z/e-'~! Company MARATHON OIL COMPANY Rig Contractor & No. Glacier Drilling/Rig #I Field KENAI GAS FIELD W~'~a~ Well Name & No. PAD 41-7/KBU 42-7 Survey Section Name 42-7 BHI Rep. W-ELL DATA Target TVD 5327.00 (ft) Target Coord. N/S -1179.02 Slot Coord. N/S -16.38 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W 652.50 Slot Coord. E/W 4116.17 Magn. Declination 20.920 Calculation Method Minimum Curvature Target Direction 0.00 (dd) Build\Walk\DL per: 100ft[~ 30m [~ 10m [~ Vert. Sec. Azim. 150.10 Magn. to Map Corr. 20.920 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (fl) (dd) (dd) (ft) (ft) (fl) (fl) (per 100 fl) Drop (-) Left (-) '-JAN-01 MWD 2590.00 26.00 145.90 62.00 2518.21 484.53 418.33 244.49 1.98 -0.03 4.52 ' '"2"4-JAN-01 MWD 2717.00 26.15 148.20 127.00 2632.29 540.26 465.17 274.84 0.80 0.12 1.81 24-JAN-01 MWD 2841.00 25.89 147.40 124.00 2743.72 594.61 -511.20 303.82 0.35 -0.21 -0.65 -- 24-JAN-01 MWD 2935.00 26.01 147.10 94.00 2828.24 635.69 -545.79 326.07 0.19 0.13 -0.32 24-JAN-01 MWD 3028.00 26.31 148.60 93.00 2911.72 676.66 -580.51 347.89 0.78 0.32 1.61 24-JAN-01 MWD 3124.00 25.94 147.50 96.00 2997.91 718.90 -616.38 370.25 0.63 -0.39 -1.15 24-JAN-01 MWD 3218.00 26.18 148.60 94.00 3082.35 760.17 -651.42 392.10 0.57 0.26 1.17 ._ 24-JAN-01 MWD 3340.00 25.61 151.50 122.00 3192.10 813.44 -697.57 418.70 1.14 4).47 2.38 24-JAN-01 MWD 3403.00 25.92 151.50 63.00 3248.84 840.81 -721.64 431.77 0.49 0.49 0.00 ,_ 24-JAN-01 MWD 3530.00 25.86 150.60 127.00 3363.09 896.26 -770.16 458.61 0.31 -0.05 -0.71 24-JAN-01 MWD 3593.00 26.09 151.30 63.00 3419.73 923.85 -794.28 472.01 0.61 0.37 1.11 24-JAN-01 MWD 3657.00 25.86 151.30 64.00 3477.27 951.87 -818.87 485.47 0.36 -0.36 0.00 ~' lAN-01 MWD 3752.00 25.77 151.00 95.00 3562.79 993.24 -855.10 505.43 0.17 -0.09 -0.32 *-~-'1 AN-0 1 MWD 3846.00 25.35 150.20 94.00 3647.59 1033.79 -890.43 525.34 0.58 -0.45 -0.85 24-JAN-01 MWD 3910.00 24.96 152.20 64.00 3705.52 1060.98 -914.26 538.45 1.46 -0.61 3.13 -- 24-JAN-01 MWD 3973.00 24.61 151.10 63.00 3762.72 1087.38 -937.50 550.99 0.92 4).56 -1.75 -- 24-JAN-01 MWD 4034.00 24.03 150.20 61.00 3818.31 1112.50 -959.40 563.30 1.13 -0.95 -1.48 24-JAN-01 MWD 4096.00 23.52 150.30 62.00 3875.05 1137.49 -981.10 575.70 0.83 -0.82 0.16 -- 24-JAN-01 MWD 4159.00 21.86 150.60 63.00 3933.17 1161.79 -1002.24 587.69 2.64 -2.63 0.48 24-JAN-01 MWD 4220.00 21.23 151.20 61.00 3989.91 1184.19 -1021.81 598.59 1.09 -1.03 0.98 24-JAN-01 MWD 4283.00 20.30 150.60 63.00 4048.82 1206.53 -1041.33 609.45 1.51 -1.48 -0.95 24-JAN-01 MWD 4346.00 18.85 149.40 63.00 4108.18 1227.63 -1059.61 620.00 2.39 -2.30 -1.90 24-JAN-01 MWD 4409.00 17.70 149.60 63.00 4168.00 1247.39 -1076.63 630.03 1.83 -1.83 0.32 24-JAN-01 MV'~· 4470.00 16.77 152.20 61.00 4226.26 i 1265.46 -10" : 638.83 1.98 -1.52 4.26 SURVEY CALCULATION AND FIELD WORKSHEET Job No. Company MARATHON OIL COMPANY Rig Contractor & No. Glacier Drilling/Rig #1 Well Name & No. PAD 41-7/KBU 42-7 Survey Section Name 42-7 WELL DATA 0450-00072 Sidetrack No. Page Field KENAI GAS FIELD BHI Rep. 3 of 4 Target TVD Target Description Target Direction Date 24-JAN-01 -JAN-01 AN-01 5327 .IX} 0.00 (dd) Survey Dep~ (~) 4531.00 4594.00 4657.00 4721.00 4784.00 4847.00 4909.00 4972.00 5033.00 5096.00 5160.00 5222.00 5283.00 5346.00 5408.00 5470.00 5595.00 5721.00 5847.00 5976.00 6102.00 6226.00 6353.00 6479.00 Target Coord. N/S -1179.02 Slot Coord. N/S Target Coord. E/W 652.50 Slot Coord. E/W Build\Walk\DL per: 100ft[~ 30m~ 10m~ Vert. Sec. Azim. SURVEY DATA Hole Course Ve~ical Direction Leng~ TVD Section (dd) (R) (~) 151.90 61.00 4284.83 1282.47 150.50 63.00 4345.57 1299.18 152.20 63.00 4406.52 1315.11 150.60 64.00 4468.69 1330.31 151.70 63.00 4530.12 1344.29 150.00 63.00 4591.76 1357.32 151.70 62.00 4652.60 1369.22 150.40 63.00 4714.65 1380.12 150.90 61.00 4774.92 1389.50 151.00 63.00 4837.31 1398.22 150.50 64.00 4900.84 1405.94 147.00 62.00 4962.52 1412.27 152.00 61.00 5023.29 1417.52 154.20 63.00 5086.13 1421.97 149.70 62.00 5148.01 1425.87 154.60 62.00 5209.88 1429.85 155.50 125.00 5334.62 1437.82 153.10 126.00 5460.43 1444.65 157.30 126.00 5586.36 1448.60 163.70 129.00 5715.34 1450.65 152.80 126.00 5841.33 1452.45 160.10 124.00 5965.32 1454.25 163.70 127.00 6092.30 1456.44 180.90 126.00 6218.28 1458.73 -16.38 Grid Correction 4116.17 Magn. Declination 150.10 Magn. to Map Corr. Total Coordinate Build Rate N(+) / S(-) E(+) / W(-) Build (+) (~) (f0 Drop (-) -1107.45 646.81 -1122.09 654.86 -1136.08 662.51 -1149.42 669.78 -1161.67 676.53 -1173.06 682.87 -1183.44 688.67 -1192.99 693.94 -1201.16 698.54 -1208.79 702.78 -1215.53 706.55 -1220.95 709.82 -1225.46 712.50 -1229.43 714.52 -1232.88 716.36 -1236.40 718.22 -1243.64 721.59 -1249.83 724.54 -1253.40 726.26 -1255.36 726.96 -1257.06 727.63 -1258.72 728.34 -1260.85 729.03 -1263.31 729.36 0.000 20.920 20.920 Depths Measured From: RKB ~] MSL[] SS Calculation Method Minimum Curvature Map North to: OTHER Walk Rate Right (+) Left (-) -1.84 -0.49 Comment -0.86 -2.22 -1.43 2.70 -1.48 -2.50 -1.37 1.75 -1.46 -2.70 -1.34 2.74 -2.17 -2.06 -1.41 0.82 -1.46 0.16 -1.78 -0.78 -1.61 -5.65 -1.39 N/A -1.44 N/A 0.05 N/A 0.16 N/A -0.10 N/A -0.76 N/A -1.33 N/A -0.07 N/A -0.07 N/A 0.07 N/A 0.20 N/A 0.00 N/A SURVEY CALCULATION AND FIELD WORKSHEET Job No. Company MARATHON OIL COMPANY Rig Contractor & No. Glacier Drilling/Rig #1 Well Name & No. PAD 41-7/KBU 42-7 Survey Section Name 42-7 WELL DATA 0450-00072 Sidetrack No. Page Field KENAI GAS FIELD BHI Rep. 4 of 4 -- Target TVD Target Description Target Direction Date 03-FEB-01 -FEB-01 5327.00 0.00 (dd) Survey Depth 6604.00 6732.00 6859.00 6986.00 7113.00 7241.00 7368.00 7493.00 7523.00 7570.00 Target Coord. N/S -1179.02 Slot Coord. N/S Target Coord. E/W 652.50 Slot Coord. E/W Build\Walk\DL per: 100ft[~ 30mQ 10m~ Vert. Sec. Azim. Hole Course Direction Length TVD (da) fit) fit) 183.00 125.00 6343.26 170.70 128.00 6471.24 181.20 127.00 6598.22 192.10 127.00 6725.20 198.50 127.00 6852.18 199.90 128.00 6980.16 222.00 127.00 7107.15 222.40 125.00 7232.13 209.40 30.00 7262.13 209.40 47.00 7309.13 -16.38 Grid Correction 4116.17 Magn. Declination 150.10 Magn. to Map Corr. SURVEY DATA Total Coordinate Vertical Section N(+) / S(~ E(+) / W(-) (~) (~ 1460.85 -1265.80 729.28 1463.02 -1268.23 729.40 1464.95 -1270.35 729.57 1466.72 -1272.56 729.28 1468.43 -1274.90 728.65 1469.91 -1277.03 727.91 1470.87 -1278.69 726.96 1471.37 -1279.90 725.87 1471.53 -1280.21 725.64 1471.87 -1280.78 725.32 Build Rate Build (+) Drop (-) 0.00 4).07 4).13 0.20 -0.07 4).06 4).14 -0.07 0.30 0.00 0.000 20.920 20.920 Depths Measured From: RKB ~] MSLQ SS Calculation Method Minimum Curvature Map North to: OTHER Walk Rate Right (+) Left (-) N/A N/A N/A N/A N/A N/A N/A N/A Comment N/A LAST SURVEY IN 8 1/2 N/A PROJECTED TO BOTI'OM VIII. OTHER INFORMATION DIRECTIONAL PLAN DESC MD TVD INCL SOUTH AZIM COORD EAST COORD VERT SECTION RKB 0 0 0 KICKOFF 725 725 0.0 build @ 2.5 deg/100ft BU ILD/TU RN 1045 1044 8.0 BUILD/TURN 1391 1383 15.0 HOLD 1755 1726 23.5 DROP 3912 3704 23.5 END DROP 5478 5227 0 TD 7751 7500 0 POTENTIAL INTERFERENCE: WELL DISTANCE (ft.) No interference exists. 0 0 133.0 0 133.0 15 160.0 74 150.0 181 150.0 926 0 1200 0 1200 DEPTH (MD) 0 0 0 0 16 21 49 89 102 208 532 1068 690 1384 690 1384 page 8 n:\drlg\kgf~wells\kbu 42-7\427prog.xls Daily Report Page 1 of 1 KU 42-7 REPORT FOR DARREL GREEN DATE Jan 24, 2001 TIME 00:00:00 DAILY WELLSlTE REPORT DEPTH 1780 YESTERDAY 1760 24 Hour Footage 20 EPOCH PRESENT OPERATION= DRILLING CASING INFORMATION 13 3/8" @ 1750 DEPTH SURVEY DATA 1760 INCLINATION AZIMUTH VERTICAL DEPTH 15.15 144.50 1742.02 BIT INFORMATION NO. SIZE TYPE Nl~r2 12 114" STC M0550DEI DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.0 VIS 45 PV FC SOL 5 SD MWD SUMMARY INTERVAL 1760 TO TD TOOLS GAS SUMMARY(units) DITCH GAS 25 @ CUTTING GAS 0 @ METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT UTHOLOGY DAILY ACTIVITY SUMMARY S/N 167.4 121 6 0 735 JETS INTERVAL CONDITION REASON IN OUT FOOTAGE HOURS T/B/C PULLED 1750 20 I NC HIGH LOW AVERAGE CURRENT AVG @ 1769 50.0 @ 1780 115.3 50.0 ft/hr @ 1768 85 @ 1763 110.2 96.9 amps @ 1766 2 @ 1780 4.6 2.1 Klbs @ 1780 0 @ 1780 0.0 0 RPM @ 1777 634 @ 1763 709.0 697 psi DEPTH: 12 YP 19 FL 11.6 Gels 11/20/23 CL- 0.5 OIL MBL pH 8.0 Ca+ CCI HIGH LOW AVERAGE 1770 5 @ 1761 18.4 TRIP GAS= 1780 0 @ 1780 0.0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 0 @ 1780 0 @ 1780 0.0 CONNECTION GAS HIGH= 0 @ 1780 0 @ 1780 0.0 AVG= 0 @ 1780 0 @ 1780 0.0 CURRENT 0 @ 1780 0 @ 1780 0.0 CURRENTBACKGROUND/AVG 17/18 0 @ 1780 0 @ 1780 0.0 LITHOLOGY/REMARKS GAS DESCRIPTION TEST B.O.P.E.; RIH WITH HWDP; PU AND MU 50 STANDS DP; DRILL OUT FLOAT COLLAR; DRILL NEW HOLE F/1760 TJ1780; CIRCULATING; DRILLING AHEAD. Epoch Personel On Board= 3 Report by: Olga Popova Daily Cost file://C:~narathon~20010123.htm ~/,~a/n ~ ua.y Report Page 1 of 1 KU 42-7 REPORT FOR DARREL GREEN DATE Jan 25, 2001 TIME 00:00:00 CASING INFORMATION 13 3/8" ~ 1750 SURVEY DATA DEPTH 3340 DALLY WELLSITE REPORT EPOCH DEPTH 3455 YESTERDAY 1780 24 Hour Footage 1675 PRESENT OPERATION= CIRCULATING INCLINATION 25.61 AZIMUTH VERTICAL DEPTH 151.5 3192.20 BIT INFORMATION NO. SIZE NB~ 12 114" TYPE STC M0550DE{ SIN JETS INTERVAL IN OUT FOOTAGE 1760 1695 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 8.9 VIS FC SOL HIGH LOW 445.9 @ 3171 28.9 @ 1866 o @ @ 37 @ 3001 1 @ 2439 0 @ 3455 @ 3455 1779 @ 3398 596 @ 1781 DEPTH: 39 PV 6 YP 8 FL 4 SD 0.5 O~L MBL MWD SUMMARY INTERVAL 1780 TO TD TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY HIGH LOW AVERAGE 39 @ 1989 5 @ 2464 15.9 0 @ 3455 0 @ 3455 0.0 CHROMATOGRAPHY(ppm) 10263 @ 1989 1006 @ 2464 3390.7 0 @ 3455 0 ,@ 3455 0.0 0 @ 3455 0 @ 3455 0.0 0 @ 3455 0 @ 3455 0.0 0 @ 3455 0 @ 3455 0.0 LITHOLOGY/REMARKS DAILY ACTIVITY SUMMARY DRILL TI 3455; POOH T/SHOE @1750; CIRCULATING. HOURS AVERAGE 170.5 22.9 1446.3 CONDfTION T/B/C ~NC CURRENT AVG 113.5 27.6 1664 17.2 Gels 7/16/16 CL- pH 9.0 Ca+ REASON PULLED fi/hr amps Klbs RPM psi CCI TRIP GAS= WIPER GAS= 47.5 SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 13/20 GAS DESCRIPTION Epoch Personel On Board= 3 Daily Cost 2270 Report by: Olga Popova file://C :hnarathonL20010124.htm 1/25/01 KU 42-7 REPORT FOR DARREL GREEN DATE Jan 26, 2001 TIME 00:00:00 CASING INFORMATION 13 3/8"@ 1750 SURVEY DATA BIT INFORMATION NO. SIZE NB~2 12 114" DEPTH 4159 TYPE SYCM0550DEI DALLY WELLSITE REPORT DEPTH 4369 YESTERDAY 3455 24 Hour Footage 914 SIN INCLINATION 21.86 JETS INTERVAL IN OUT 1760 AZIMUTH 150.60 FOOTAGE 2589 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 8.9 VIS FC SOL 39 4 HIGH LOW 378.2 @ 3585 10.0 0 @ 4306 @ 39 @ 4180 6 @ 0 @ 4306 @ 1899 @ 3966 1474 DEPTH: PV 6 YP 8 SD 0.5 OIL 3984 4306 3708 4306 3519 EPOCH MWD SUMMARY INTERVAL 3455 TO TD TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY HIGH 61 o @ 12562 @ 12 @ o @ o o @ LOW AVERAGE 4004 7 @ 3467 26.1 4306 0 @ 4306 0.0 CHROMATOGRAPHY(ppm) 4004 1506 @ 3467 5352.2 4064 1 @ 4179 0.2 4306 0 @ 4306 0.0 4306 0 , @ 4306 0.0 4306 0 @ 4306 0.0 i LITHOLOGY/REMARKS DAILY ACTIVITY SUMMARY DIRECTIONAL DRILLING PRESENT OPERATION= DRILLING HOURS AVERAGE 97.4 25.5 1729.6 VERTICAL DEPTH 3933.12 CONOITION T/B/C INC CURRENT AVG 79.8 24.5 1755 FL 17.2 Gels 7/16/16 CL- MBL pH 9.0 Ca+ REASON PULLED ftJhr amps Klbs RPM psi CC/ TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 25/28 GAS DESCRIPTION Epoch Personel On Board= 3 Daily Cost 2270 Report by: Olga Popova file://C:~narathon~20010125.htm 1/26/01 MARATHON OIL COMPANY I KU 42-7 I 1/26/2001 Daily Report Page 1 of 1 KU 42-7 REPORT FOR DARREL GREEN DATE Jan 27, 2001 TIME 00:00:00 CASING INFORMATION SURVEY DATA DAILY WELLSlTE REPORT EPOCH DEPTH 49OO YESTERDAY 4369 24 Hour Footage 531 PRESENT OPERATION= BUILDING MUD VOLUME DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4721.00 13.43 150.6 4468.62 BIT INFORMATION NO. SIZE TYPE NB~ 12 314 STC M0550DEL DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.35 VIS 46 FC SOL 7.5 INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1760 3120 38.3 38.3 HIGH LOW AVERAGE CURRENT AVG 236.1 @ 4589 15.9 @ 4872 75.0 106.1 fi/hr 0 @ 4900 0 @ 4900 0.0 0.0 amps 39 @ 4443 10 @ 4614 27.6 29.8 Klbs 0 @ 4900 0 @ 4900 0.0 0 RPM 2221 @ 4860 1340 @ 4522 1932,0 1823 psi DEPTH: PV 9 YP 25 FL 11.0 Gels 18/26/26 CL- SD OIL MBL pH 9.5 Ca+ CCI MWD SUMMARY INTERVAL 3455 TO TD TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY HIGH 85 o @ 17232 0 0 0 0 LOW AVERAGE 4496 7 @ 4677 27.8 TRIP GAS= 4900 0 @ 4900 0.0 WIPER GAS= 10 CHROMATOGRAPHY(ppm) SURVEY= 4479 -1 @ 4899 5695.2 CONNECTION GAS HIGH= 4900 -1 @ 4899 -0.1 AVG= 4900 -1 @ 4899 -0.1 CURRENT 4900 -2 @ 4899 -0.1 CURRENT BACKGROUND/AVG 13/17 4900 -2 @ 4899 -0.1 LITHOLOGY/REMARKS GAS DESCRIPTION DIRECTIONAL DRILLING; LOST RETURNS @ 4869' LAGGED DEPTH; 4900' BIT DEPTH AT CNX; ADD LCM; E~UILDJNG MUD VOLUME. Epoch Personel On Board= 3 Report by: Olga Popova Daily Cost 2270 file://C :LmarathonL20010126.htm 1/27/0 Daily Report Page 1 of 1 KU 42-7 REPORT FOR DARREL GREEN DATE Jan 28, 2001 TIME 00:00:00 CASING INFORMATION 13 3/8" @1750 DEPTH SURVEY DATA 5096 DAILY WELLSlTE REPORT DEPTH 5205 YESTERDAY 4900 24 Hour Footage 305 EPOCH PRESENT OPERATION= DRILLING INCLINATION AZIMUTH VERTICAL DEPTH 7.50 1.51.00 4837.31 BIT INFORMATION NO. SIZE TYPE NE4f2 12 314" STC M0550DEL SIN INTERVAL CONDITION REASON JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1760 3425 44.4 ~NC DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP ,PRESSURE DRILLING MUD REPORT MW 9.3 VIS FC SOL MWD SUMMARY INTERVAL 4900 TO TD TOOLS 45 7 180.0 0 4O 0 2122 PV SD HIGH LOW AVERAGE CURRENT AVG @ 5152 15.2 @ 4966 66.2 27.7 fi/hr @ @ amps @ 4961 21 @ 4919 32.3 34.3 Klbs @ @ RPM @ 5016 1009 @ 4901 1919.9 1.902 psi DEPTH: 12 YP 5 FL 6.2 Gels 2/5/5/ CL- TR OIL MBL pH 9.5 Ca~. CCI GAS SUMMARY(units) HIGH · DITCH 'GAS 1'81 CUTTING GAS 0 @ METHANE(C-I) 33004 'ETHANE(C-2) 0 PROPANE(C-3) 0 BUTANE(C-4) 0 PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL LIYHOLOGY .... LOW AVERAGE ,5t,56 10 @ 4962 53.0 TRIP GAS= 5191 0 @ 5191 0.0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 5156 2146 @ 4962 9841.7 CONNECTION GAS HIGH= '5191 0 @ '5191 0.0 AVG= 5191 0 @ 5191 0.0 CURRENT 5191 0 @ .519t 0.0 CURRENT t3ACKC-~.OUND/AVG 35/70 5191 0 @ 5191 0.0 LITHOLOGY/REMARKS GAS DESCRIPTION PRESENT LITHOLOGY DAILY ACTIVITY POOH TO SHOE @1750; CIRCULATE AND BUILD MUD VOLUME; RIH FROM 1750; TIGHT @ 4811; PUMP 30BBLS SUMMARY LCM; REAM TO 4899; PUMP 30 BBLS LCM; SWEEP; DRILLING AHEAD. Epoch Personel On Board= 3 ~epor~ 13y: L)Jga ~'opova Daily Cost 2270 fite://C :hnarathonk200 t 0 t 27.htm t/28/01 Daily Report Page t ot't KU 42-7 REPORT FOR DARREL GREEN DATE Jan 29, 2001 TIME 00:00:00 CASING INFORMATION 13 3/8" @ 1750 DEPTH SURVEY DATA .5283 DALLY WELLSlTE REPORT DEPTH 5559 YESTERDAY 5205 24 Hour Footage 354 INCLINATION AZIMUTH 4.51 1.52.00 EPOCH PRESENT OPERATION= TRIP OUT VERTICAL DEPTH .5023.29 BIT INFORMATION NO. SIZE N E,~r2 12 314" DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP ,PRESSURE DRILLING MUD REPORT MW 9.4 VIS FC SOL MWD SUMMARY INTERVAL 5205 TO TD TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS TYPE STC, M0550DEL 49 PV 8 SD HIGH 1.51 @ o @ METHANE(C-1 ) 29730 · ETHANE(C-2) 14 PROPANE(C-3) 11 BUTANE(,C-4) 0 PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL SIN JETS INTERVAL IN OUT FOOTAGE 1760 5559 3799 HIGH LOW 168.8 @ 5214 8.6 @ 5302 o @ 5559 o @ 5559 39 @ 5259 5 @ 5536 o @ 5559 o @ 5559 2050 @ 5514 1-501 @ .5538 DEPTH: 14 YP 11 TR OIL HOURS 54.8 LOW AVERAGE 5480 11 @ 5346 50.3 5559 0 @ 5559 0.0 CHROMATOGRAPHY(ppm) 5480 2396 @ 5335 9785.3 '5486 1 @ '5519 1.6 5494 1 @ 5518 0.5 ,5559 0 @ .5559 .0.,0 5559 0 @ 5559 0.0 LITHOLOGY/REMARKS CONDITION REASON T/B/C PULLED AVERAGE CURRENT AVG 47.7 46.8 It/hr 0.0 0.0 amps 26.3 28.5 'Klbs 0.0 0 RPM 1,907.2 2005 psi FL 5,5 Gels 3/7111 CL- MBL pH 8.5 Ca+ CCI TRIP 'GAS=- WIPER GAS= SURVEY= CONNECTION GAS HIGH: AVG= CURRENT CURRENT BACKGR. OUND/AVG 1.9/22 GAS DESCRIPTION ,.. LITHOLOGY PRESENT LITHOLOGY DALLY ACTIVITY SUMMARY DIRECTIONAL DRILLING; POOH @ 5559 FOR NEW BHA. Fqaooh Personel On Board= 3 Daily Cost 2270 Report by: Olga Popova file ://C: -~narat.hon~2.00 t-0 t 2 8..htm t/29/0 t Dally Report Page 1 of 1 KU 42-7 REPORT FOR DARREL GREEN DATE Jan 30, 2001 TIME 00:00:00 CASING INFORMATION 13 3/8" ~ 1750 DEPTH SURVEY DATA 5470 DALLY WELLSITE REPORT EPOCH DEPTH 5590 YESTERDAY 5559 24 Hour Footage 31 PRESENT OPERATION= CIRCULATING INCLINATION AZIMUTH VERTICAL DEPTH 3.73 154.60 5209.88 BIT INFORMATION NO. SIZE TYPE RRNB4t3 12 3/4" RBI CLRGSP S/N JETS INTERVAL CONDITION REASON IN OUT FOOTAGE HOURS T/B/C PULLED 5559 31 0.7 INC DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.35 VIS FC SOL MWD SUMMARY INTERVAL 5559 TO TD TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS I N TE R VAL LITHOLOGY PRESENT LITHOLOGY DALLY ACTIVITY SUMMARY HIGH LOW AVERAGE CURRENT AVG 139.0 @ 5569 12.3 @ 5579 64.8 36.9 fi/hr 0 @ 5590 0 @ 5590 0.0 0.0 amps 32 @ 5585 23 @ 5574 29.4 27.3 Klbs 0 @ 5590 0 @ 5590 0.0 0 RPM 2016 @ 5566 1710 @ 5583 1959.7 1910 psi DEPTH: 60 PV 14 YP 24 FL 6.8 Gels 9/21124 CL- 7.5 SD TR OIL MBL pH 8.5 Ca,' CCI HIGH LOW AVERAGE 90 @ 5570 18 @ 5590 52.9 TRIP GAS= 0 @ 5590 0 @ 5590 0.0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 17202 @ 5570 3592 @ 5585 10081.4 CONNECTION GAS HIGH= 14 @ 5567 1 @ 5582 6.8 AVG= 5 @ 5567 1 @ 5575 1.3 CURRENT 0 @ 5590 0 @ 5590 0.0 CURRENT BACKGROUND/AVG 50/52 0 @ 5590 0 @ 5590 0.0 L ITHOLOGY/R E MAR KS GAS DESCRIPTION POOh; CHANGE BIT; P/U BHA; CHECK FLOAT; rlH WITH HWDP TO 4458; CBU @ 4458; REAM FROM 4458 TO 5080; CIRCULATE, LOST CIRCULATION; SPOT 60 BBLS LCM; POOH TO 4950; LOST 98 BBLS TOTAL; RIH TO 5080; REAM FROM 5080 TO 5559; DRILL TO 5590; CBU; POOH TO 4400; RIH TO 5273; REAM FROM 5273 TO 5590; CIRCULATE, COND. MUD, MIX LCM PILL. Epoch Personel On Board= 3 Report by: Olga Popova Daily Cost 2270 file://C:hnarathonX20010129.htm 1/30/01 Daily Report Page 1 of 1 KU 42-7 REPORT FOR DARREL GREEN DATE Jan 31, 2001 TIME 00:00:00 DAILY WELLSlTE REPORT gl EPOCH DEPTH 5590 YESTERDAY 5590 24 Hour Footage 0 PRESENT OPERATION= RUN CASING CASING INFORMATION 13 3/8"@ 1750 -- DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5470 3.73 154.60 5209.88 BIT INFORMATION NO. SIZE TYPE RRNB#3 12 3/4" RBI CLRGSP INTERVAL CONDITION SIN JETS IN OUT FOOTAGE HOURS T/B/C 5559 31 0.7 REASON PULLED DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.35 VIS FC SOL MWD SUMMARY INTERVAL TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS TO TD METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY 60 7.5 HIGH LOW AVERAGE @ @ 5579 @ @ @ @ DEPTH: PV 14 YP 24 FL 6.8 Gels 9/21/24 CL- SD TR OIL MBL pH 8.5 Ca+ CURRENT AVG fL/hr amps Klbs RPM psi CCI HIGH LOW AVERAGE @ @ TRIP GAS= @ @ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= @ @ CONNECTION GAS HIGH= @ @ AVG= @ @ CURRENT @ @ CURRENT BACKGROUND/AVG LITHOLOGY/REMARKS GAS DESCRIPTION DALLY ACTIVITY SUMMARY CIRCULATE, COND, MUD, MIX LCM PILL; CHANGE RAMS; RIG UP CASING TOOLS; RUN CASING. Epoch Personel On Board= 3 Daily Cost 2270 Report by: Olga Popova file://C :LmarathonL20010129.htm 1/31/01 DALLY WELLSlTE REPORT KU 42-7 REPORT FOR DARREL GREEN DATE Feb 1, 2001 DEPTH 5590 TIME 00:00:00 YESTERDAY 5590 24 Hour Footage 0 CASING INFORMATION 13 3/8" @ 1750 DEPTH SURVEY DATA 5470 TYPE SIN RBI CLRGSP 52 PV 7 SD EPOCH BIT INFORMATION NO. SIZE RRNB#3 12 314" DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3O VIS FC SOL MWD SUMMARY INTERVAL TO TD TOOLS GAS SUMMARY(units) DITCH GAS - CUTTING GAS METHANE(C-I) ETHANE(C-2) ..... PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY DALLY ACTIVITY SUMMARY PRESENT OPERATION= INSTALL TBG SPOOL; N/U B.O.P.S JETS HIGH INCLINATION AZIMUTH VERTICAL DEPTH 3.73 154.60 5209.88 INTERVAL CONDITION IN OUT FOOTAGE HOURS T/B/C 5559 31 0.7 LOW AVERAGE CURRENT AVG 5579 DEPTH: 14 YP 18 FL 7.6 Gels 10/18D3 CL- TR OIL MBL pH 8.0 Ca+ REASON PULLED fi/hr amps Klbs RPM psi CCI HIGH LOW AVERAGE @ @ TRIP GAS= @ @ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY-- @ @ CONNECTION GAS HIGH= @ @ AVG: @ @ CURRENT @ @ CURRENT BACKGROUND/AVG LITHOLOGY/REMARKS GAS DESCRIPTION · RUN 9 5/8 CSG TI4000; CBU; RIH T/4811; CBU; RIH T/5176; CBU; RIH; FILL @ 5567; WASH T/5580; CIRCULATING + COND; CEMENT CSG @ 5582;BLOW D. CMT LINE; CMT JN PLACE @ 11:27 PM; SET CSG SLIPS; CUT CSG; SET TBG SPOOL; N/U B.O.P.S. Epoch Personel On Board= 4 Report by: Olga Popova Daily Cost 2270 file://C:~narathonL20010129.htm 2/1/01 KU 42-7 REPORT FOR DARREL GREEN DATE Feb 2, 2001 TIME 00:00:00 DAILY WELLSITE REPORT DEPTH 5590 YESTERDAY 5590 24 'Hour Eootage 0 INCLINATION AZIMUTH 3.73 154.60 EPOCH CASING INFORMATION 13 3/8" ~ 1750 9 5/8" (~, 5590 DEPTH SURVEY DATA 5470 PRESENT OPERATION= PICK UP BI-la VERTICAL DEPTH 52.09..88 BIT INFORMATION NO. SIZE TYPE SIN RRN~f3 12 314" RBI CLRGSP DRILLING PARAMETERS RATE- OF' PENETRATION SURFACE TORQUE i WEIGI~q' ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.30 VIS 52 PV FC SOL 7 SD MWD SUMMARY INTERVAL TO TD TOOLS JETS INTERVAL IN OUT FOOTAGE 5559 31 HIGH LOW AVERAGE DEPTH: 14 YP 18 FL 7.6 TR OIL MBL HOURS 0.7 CONDITION T/BIC CURRENT AVG REASON PULLED fi/hr amps KJbs RPM psi Gels 10/18/23 CL- pH 8.0 Ca+ CCI GAS SUMMARY(units) DITCH GA_S CUTTING GAS METHANE(C-1 ) ETHANE{C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY HIGH LOW AVERAGE (~ I~ TRIP GAS= @ @ WIPEr GAS= CHROMATOGRApHY(ppm) SURVEY--.. ~ @ CONNECTION GAS HIGH= @ @ AV~ ~ @ CURRENT @. @. CURRENT BACKGROUND/AVG. LITHOLOGY/REMARKS GAS DESCRIPTION DALLY ACTIVITY SUMMARY REMOVE LONG BALLS; INSTALL DOUBLE STNS ADAPTER; INSTALL SHORT BAILS; SET TEST PLUG; TEST VALVES;TEST BOPS; CHANGED PiPE RAMS; SET WEAR RING; RJU E-LINE; RUN CCL - CBL; TEST CNG; BLOW DOWN CHOKE; P/U BHA. Epoch Personel On Board= 4 Report by: Olga Popova Daily Cost 2270 file://C :XrnarathonX20010129.htm 2/2/01 Daily Report Page I of 1 KU 42-7 REPORT FOR DARREL GREEN DATE Feb 03, 2001 TIME 00:00:00 %11 · II e.--K--lm.~t,.~l I a...-- I ~,,e'--I VI · ! DEPTH 6089 YESTERDAY 5590 24 Hour Footage 499 CASING INFORMATION 13 3/8" (~31750; g 5/8" ~ 5590 DEPTH SURVEY DATA 5470 BIT fNFORMATION NO. SIZE TYPE S/N RRNB#4 8.5" RBt C1VARGSP DRILLING PARAMETERS RATE OF PENETRATION 285.0 SURFACE TORQUE 0 WEIGHT ON BIT 44 ROTARY RPM PUMP PRESSURE 2019 DRILLING MUD REPORT MW 9.4 VIS 61 PV FC SOL 7 SD VIWD SUMMARY INTERVAL TOOLS 5590 TO TD GA~ ~UMMARY'(uni'ts) HiGH DITCH GAS 197 CUTTING GAS 0 @ EPOCH METHANE(C-I) 39370 ETHANE(C-2) 39 PROPANE(C-a) 12 BUTANE(C-4) 0 PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL INCLINATION 3.73 INTERVAL JETS IN OUT 16,16,14 5590 HIGH LOW @ 5638 11.1 @ 6019 6 @ 6014 1222 DEPTH: 14 YP 24 TR OIL PRESENT OPERATION= DRILLNG AZIMUTH vERTiCAL [aEPTH' 154.60 5209.88 5601 CONDITION FOOTAGE HOURS T/B/C 499 11.2 AVERAGE CURRENT AVG 57.4 90.8 6088 25.2 23.5 5592 1832.4 1883 FL 9.8 Gels 13/23/28 CL- MBL pH 8.0 Ca+ REASON PULLED ft/hr amps Klbs RPM psi CCI LOW' AVERAGE 5863 10 @ 5603 38.2 TRIP GAS= 6089 0 @ 6089 0.0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 5863 448 @ 5603 7594.3 CONNECTION GAS HIGH= 5642 1 ' @ 5944 2.9 AVG= 5881 1 @ 5892 0,a CURRENT 6089 0 @ 6089 0.0 CURRENT BACKGROUND/AVG 20/25 6089 0 @ 6089 0.0 LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAYSTONE/SILTSTONE; SAND/SANDSTONE; TRACE COAL PRESENT LtTHOLOGY TUFFACEOUS CLAYSTONE/SILTSTONE = 60-70%; SAND/SANDSTONE = 30-40%; TRACE COAL DAILY ACTIVITY SUMMARY RIH; CBU; DIRECTIONAL DRILLING. Epoch Personel On Board= 4 Daily Cost 2760 Report by: Olga Popova ! file://C:hnarathonX20010202.htm 2/3/0t Dally Keport ~'age I o~ ~ KU 42-7 REPORT FOR DARREL GREEN DATE Feb 04, 2001 TIME 00:00:00 DAILY WELLSITE REPORT DEPTH 6714 YESTERDAY 6089 24 Hour Footage 650 INCLINATION AZIMUTH 1.14 180.90 CASING INFORMATION 13 3/8" ~ 1750; 9 5/8" ~5590 DEPTH SURVEY DATA 6479 EPOCH PRESENT OPERATION= TRIP OUT VERTICAL DEPTH 6218.28 BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT RRNE4t4 8.5" RBI C1VARGSP 16,16,14 5590 HIGH LOW 252.5 @ 6275 10.7 o @ @ 39 @ 6261 11 o @ @ 2333 @ 6538 1595 DEPTH: VIS 46 PV 13 YP 24 FL SOL 9 SD 0.25 O~L MBL 6089 TO TD DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.7 FC MWD SUMMARY INTERVAL TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 584 @ 6610 13 @ 6149 88.6 CUTTING GAS 0 @ 6714 0 @ 6714 0.0 CHROMATOGRAPHY(ppm) METHANE(C-I) 115518 @ 6610 2606 @ 6149 17117.5 ETHANE(C-2) 84 @ 6607 1 @ 6683 10.2 PROPANE(C-3) 40 @ 6607 1 @ 6666 3.1 BUTANE(C-4) 0 ~ 6714 0 <~ 6714 0.0 PENTANE(C-5) 0 ~ 6714 0 ~ 6714 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS CONDITION T/B/C INC CURRENT AVG 17.0 FOOTAGE HOURS 1149 25.7 AVERAGE 6279 48.7 6328 25.1 6141 2158.8 10.8 22.7 2140 REASON PULLED fi/hr amps Klbs RPM psi Gels 16/27/32 CL- pH 9.2 Ca+ TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 47/90 GAS DESCRIPTION LITHOLOGY TUFFCEOUS CLAYSTONE/SILTSTONE; SAND/SANDSTONE; TRACE CARBONACEOUS SHALE PRESENT LITHOLOGY SAND/SANDSTONE 50-60%; TUFFCEOUS CLAYSTONE/SILTSTONE 40-50o/o i DAILY ACTIVITY SUMMARY DRILL AHEAD; PUMP DOWN; POOH @ 6739 FOR NEW BHA Epoch Personel On Board= 4 Daily Cost 2760 Report by: Olga Popova file://C:XtnarathonX20010203.htm ! 2/4/01 KU 42-7 REPORT FOR DARREL GREEN DATE. Feb 05, 2001 TIME 00:00:00 DAILY WELLSlTE REPORT D[EPTH 7000 YESTERDAY 6714 '24 'Hour Footage 286 INCLINATION 0,88 CAS]NG INFORMATION 13 3/8" ~'f750': 9' 5/8@ 5582 DEPTH SU R-V E~ D-ATA' 6859 EPOCH P~_~E.NT OPerATION= TRfF, OUT AZIMUTH VERTICAL DEPTH 181.20 6598.22 ~iT iNforMATION NO. SIZE RRNB#4' 8.5" RBI CIARGSP JETS 16, 16, 14 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEI~3FIT'ON ROTARY RPM PUMP PRESSURE DRILLING-MUD-REPORT MW 10.0 VIS FC SOL 53 10 1.!0,8 0 0 2283 PV SD HIGH 6989 @ 6764 DEPTH: 16 TR iNT~,VAL CONDiTioN ~,EASON tN OUT FOOTAGE HOURS T/B/C PULLED 5590' 1'435 32.7 INC MWD SUMMARY INTERVAL 6714 TO TI:) TOOLS GAS SUMMARY(units) ':DITCH :C_~S CUTTING GAS · METHANE(C-1 ) 'ETHANE(C,-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HIGH '2a5 @ 0 @ 46700 (~. '3'1 '@ 17 @ o @ o @ HYDROCARBON SHOWS INTERVAL LOW AVERAGE CURRENT AVG ~i 2',~ ~ 6837 43,0 74,3 ff/h..r ~ amps '1'1 -@ -69~29 -27.2 -28.~ 'KIDs @ RPM 969 @ 6971 2167.8 2179 p~i YP 30 FL B. 0 Gels 18/31133 CL- OIL MBL pH 8.7 Ca* CCI LOW AVERAGE '6998 1'5 '@ "6769 "80/3 TRIP'GAS= 6999 0 @ 6999 0.0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 6945 3109 (~ 6769 13688.7 CONNECTION GAS HIGH= 6945 '1 @ '6912 6.1 AVG= 6945 1 , @ 6912 2.3 CURRENT 6999 0 @ 6999 0.0 CURRENT BACKGR'OUND/AVG 41/84 ,.6.999 . 0 ~ 6999 0.Q LITHOLOGY/REMAR KS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAYSTONE/SILTSTONE; SAND/SANDSTONE; COAL INTERBEDDING WITH CARBONACEOUS SHALE PRESENT TUFFACEOUS-CLAYS-TONEJStLTS-TONE-30-40 %; SAND/SANDS-TONE- 40~50%? COAL INTERBEDDINGNVtTH- 'L"ITt.:.[OCOGY -CA-~RBONA-CEO~ SHALE 1020% DALLY 'A~T',~V'!TY SUMMARY DRILL TO 6739; ~ACK REAM OUT TO CASING'SHOE ~ 5582; 'SER¥'ICE 'RIG; 'RtH TO 6739; 'DR~LL TO 7000; ~iA(~K ~,M OUT. Epoch Personet On_ _Roar_.. d; 4 Daity.C~t..276O- Report by: Olga Popova file://C :XanarathonL20010204. htm 2/5/01 Daily Report Page 1 of 1 KU 42-7 REPORT FOR DARREL GREEN DATE Feb 06, 2001 TIME 00:00:00 DAILY WELLSITE REPORT DEPTH 7288 YESTERDAY 7000 24 Hour Footage 288 INCLINATION 0.97 EPOCH CAStNG INFORMATtON 13 3/8" ~1750 9 5/8" ~ 5582 DEPTH SURVEY DATA 7241 PRESENT OPERATION= DRILL AHEAD AZIMUTH 199.90 VERTICAL DEPTH 6980.16 BIT INFORMATION NO. SIZE NB~ 8.5 DRILLING PARAMETERS · RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.9 VIS FC SOL MWD SUMMARY INTERVAL 7000 TO TD TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS TYPE RBI C1ALRGSP 45 10 SIN INTERVAL PV SD JETS IN OUT .., 16; 16; 14 7000 231..9 0 33 0 2456 HIGH 660 @ o @ HIGH LOW @ 7074 14:7· @ 7182 18 @ 7187 1414 @ DEPTH: 15 YP 19 TR O~L METHANE(C-I) 129611 @ ETHANE(C-2) 99 PROPANE(C-3) 39 BUTANE(C-4) 22 PENTANE(C-5) 0 @ HYDROCARBON SHOWS INTERVAL LOW 7077 15 @ 7002 7288 0 @ 7288 CHROMATOGRAPHY(ppm) 7077 3232 @ 7002 7077 1 , @ 7183 7076 1 @ 7213 7076 1 @ 7085 7288 0 @ 7288 FOOTAGE 288 LITHOLOGY/REMARKS 7184 HOURS 6.9 AVERAGE 58.4 7197 33.6 7288 2758.1 FL 7.8 MBL AVERAGE 134.7 0.0 26672.7 16.6 7.1 1.0 0.0 CONDITION T/BIC CURRENT AVG 26..2 29.7 1414 REASON PULLED ft/hr amps Klbs RPM psi Gets 9116/17 CL- pH 9.1 Ca+ CCI TRIP GAS= 108 WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 82/106 GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAYSTONE/SILTSTONE; SAND/SANDSTONE; COAL PRESENT LITHOLOGY TUFFACEOUS CLAYSTONE/SILTSTONE 40-70%; SAND/SANDSTONE 20-40%; COAL 0-20% DAILY ACTIVITY SUMMARY BACK REAM OUT TO SHOE; POOH FOR NEW BIT; RIH @ 7000; DRILL AHEAD Epoch Personel On Board= 4 Daily Cost 2760 Report by: Olga Popova file://C :XrnarathonX20010206.htm 2/5/01 L~mly Report Page 1 ot'l KU 42-7 REPORT FOR DARREL GREEN OATE Feb 07, 2001 TIME 00:00:00 DAILY WELL$1TE REPORT DEPTH 7570 YESTERDAY 7288 24 Hour Footage 282 CASING INFORMATION 13 3/8" ~ 1750; 9 5/8" ~ 5582 DEPTH INCLINATION AZIMUTH SURVEY DATA 7368 0.79 222.00 EPOCH PRESENT OPERATION= CIRCULATE VERTICAL DEPTH 7107.15 BIT INFORMATION NO. SIZE NB#5 8.5 ! DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 10.6 VIS FC SOL MWD SUMMARY INTERVAL 7288 TO TD TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS TYPE C1ALRGSP 51 10.5 HIGH 335 @ o @ INTERVAL S/N JETS IN OUT FOOTAGE HOURS 16X16X14 7000 570 17.8 HIGH LOW AVERAGE 214.2 @ 7487 9.5 @ 7459 39.6 0 @ 7570 0 @ 7570 0.0 32 @ 7569 14 @ 7371 25.0 0 @ 7570 0 @ 7570 0.0 2537 @ 7489 1414 @ 7288 2464.3 DEPTH: PV 15 YP 21 FL 7.5 Gels SD TR OIL MBL pH METHANE(C-I) 70753 ETHANE(C-2) 51 PROPANE(C-3) 33 BUTANE(C-4) 8 PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL CONDITION REASON T/BIC PULLED CURRENT AVG 69.0 fi/hr 0.0 amps 30.5 Klbs 0 RPM 2522 psi 8116117 CL- 8.0 Ca+ CCI LOW AVERAGE 7402 19 @ 7515 102.5 TRIP GAS= 104 7570 0 @ 7570 0.0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 7324 3798 @ 7515 20869.3 cONNECTION GAS HIGH= 7324 1 , @ 7569 12.9 AVG= 7324 1 @ 7561 5.2 CURRENT 7484 1 @ 7492 0.4 CURRENT BACKGROUND/AVG 70/101 7570 0 @ 7570 0.0 LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAYSTONF_JSILTSTONE; SAND/SANDSTONE PRESENT LITHOLOGY TUFFACEOUS CLAYSTONE/SILTSTONE 60%; SAND/SANDSTONE 40%; CARBONACEOUS SHALE - TRACE. DAILY ACTIVITY DRILL TO 7570; CBU; BACK REAM TO 6640; POOH - PUMP OUT OF HOLE TO 6464; POOH TO 5582; SERVICE RIG; SUMMARY RIH; CIRCULATE AND COND MUD; RAISE MUD WT UP TO 10.6 PPG;CONT CIRCULATE. Epoch Personel On Board= 4 Daily Cost 2760 Report by: OIga Popova file://C:hnarathon~20010206.htm 2/7/01 Marathon Well KBU 42-7 Subject: Marathon Well KBU 42-7 Date: Wed, 31 Jan 2001 16:32:28 -0600 From: "Betty J Veldhuis" <BJVeldhuis@marathonoil.com> To: tom_maunder@admin.state.ak, us, Greg_Noble@blm.gov CC: PKBerga@marathonoil.com Tom and Greg: Pete Berga asked me to send you this note. Finished cementing 9 5/8" casing on Well KBU 42-7. Calculated volume need to get cement to 3200' MD was 132 bbls. Pumped a total of 205 bbls (50% excess). Lost 71 bbls of fluid. Depending on actual hole size, we may be close to 3200' MD. The top of pay on this well looks like 4600' MD (Sterling). This is intermediate casing. The production string will be cemented up into the 9 5/8" casing. Any production of the Sterling at 4600' would require a workover. I (Pete) normally wouldn't run a bond log here for any remedial work but would run it during the workover. Betty I of 1 2/10/01 7:59 AM KBU 42-7 cementing program Subject: KBU 42-7 cementing program Date: Tue, 30 Jan 2001 15:30:54 -0600 From: "Betty J Veldhuis" <BJVeldhuis@marathonoil.com> To: tom_maunder@admin.state.ak.us, gnoble@ak, bim.gov CC: PKBerga@marathonoil.com Pete Berga asked me to send this note to you; AOGCC and BLM: Marathon would like to change the approved cementing program for the 9 5~8" casing on well KBU 42-7 due to fluid losses experienced while drilling the 12 1/4" hole section. Please direct questions to Craig Young; phone #564-6310; pager #231-3937. We will be cementing tonight or early tomorrow. Permitted: 250 sacks, 12.8 ppg lead and 520 sacks 15.8 ppg tail. Cemented interval 5575' - 3200'MD Requested: 420 sacks, 12.8 ppg lead and 235 sacks 15.8 ppg tail Cemented interval 5575'- 3200' MD Betty 1 Of 1 2/10/01 7:59 AM MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KBU 42-7 18-Jan-01 19-Jan-01 20-Jan-01 21-Jan-01 22-Jan-01 23-Jan-01 24-Jan-01 25-Jan-01 26-Jan-01 Rig up drilling equipment. Finished PJU drilling equipment. N/U and test diverter. P/U and stand back ddllpipe. BHA. Spud well at 10:30 1/19/01. Ddlled from 37' - 1230'. Drilled from 1230'- 1760'. CBU. Wiper trip. CBU. POOH, PJU and started running 13 3/8" casing, Finished running and cementing casing. N/D diverter. Cut casing and prep to weld wellhead. Installed wellhead. N/U stack. Cleaned mud pits and took on Fio-Pro mud. N/D and installed APl ring. N/U and tested stack. Finished testing BOPE. Tested casing, BHA. P/U ddllpipe. RIH. Drilled out and tested shoe, Displaced spud mud. Drilled 1760' - 2238'. Drilled 2237' to 3455'. Wiper trip to shoe. Ddlled to 3658', Drilled 3658' - 4660'. ii" MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KBU 42-7 27-Jan-01 28-Jan-01 29-Jan-01 30-Jan-01 31-Jan-01 1-Feb-01 2-Feb-01 Ddlled 4646'-4741'. Wiper trip. Drilled to 4899'. Lost returns. Pumped LCM and POOH to shoe, Build mud volume, Staged in hole pumping LCM pills. Drilled from 4899' to 5300'. Drilled from 5300'to 5559'. CBU. POOH. BHA. RIH. RIH to 4458'. CBU. Reamed to 5080', Lost returns. Spotted LCM pill, Reamed to 5559'. Drilled from 5559' to 5590'. CBU. Wiper trip to 4400'. CBU. POOH. POOH. L/D BHA. R/U and run 9 5/8" casing. C & C mud, Circulate and condition. Cemented 9 5/8" casing. WOC. N/D. Set slips, Installed tubing spool. N/U BOPE, N/U and tested BOPE. Ran CBL. Top of cement at 4130' MD. Tested casing to 2600 psi, RIH. Started drilling cement at 5481'. MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KBU 42-7 3-Feb-01 Drilled shoe track. Drilled from 5590' to 5610'. CBU. Tested shoe to 13.3 ppg EMW. Drilled to 6265'. 4-Feb-01 Drilled from 6265' - 6739'. Wiper trip to shoe. 5-Feb-01 Finished wiper trip to shoe. Drilled from 6739' to 7000'. Trip for bit. 6-Feb-01 Continued to POOH. Changed bit. RIH to 9 5/8" casing shoe. Break circulation. Continued to RIH to 6,850'. Washed and reamed to bottom at 7,000'. Drilled ahead to 7,404'. 7-Feb-01 Drilled ahead to 7570. Cimulated bottoms up. Back reamed out of the hole to 6640'. Continued to POOH to 5583'. RIH to 7570'. Circulated and conditioned mud, Raised mud weight to 10.6 ppg. POOH. 8-Feb-01 POOH. BHA. R/U and log w/DSI - CMR - RFT in 3 runs. 9-Feb-01 Log with RFT. Tool stuck at 6030' (Probe). Strip over e-line. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS n:\drlg\kgt~43-6x rd'C, OG CC02~ 1. Type of Request:. Abandon Alter Casing Change Approved Program Suspend Operation Shutdown Repair Well Plugging X Pull Tubing Variance Re-enter Suspended Well Time Extension Stimulate Perforate Other 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface At top of Productive Interval 37'FNL, 4118'FWL, Sec. 7, T4N, R11W, S.M. At Effective Depth At Total Depth 5. Type of Well: Development X Exploratory Stratigraphic ~ Service 6. Datum Elevation (DF or KB) 87 feet 7. Unit or Property Name Kenai Unit s. Well Number KBU 42-7 9. Permit Number 99-25 10. APl Number 50-133-20488 11. Field/Pool Kenai Gas Field / Beluga 12. Present Well Condition Summary Total Depth: measured true vertical feet feet Plugs (measured) Effective Depth: measured true vertical feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented Measured Depth True Vertical Depth true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) N/A RECEIVED DEC 05 2000 Alaska 0il & Gas Cons. Commission Anchorage 18. Attachments Description Summary of Proposal X Detailed Operations Program BOP Sketch X 14. Estimated Date for Commencing Operation 1/1/2001 16. If Proposal was Verbally Approved Name of Approver Date App roved 15. Status of Well Classification as: Oil Gas X Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. /,%_ Signed U~~--~" ~~ ~;r~ig Young Title Sr. Drlling Engineer 564-6310 - / % /~- ~ ~o. co~,ss,o..~ON.~ Conditions of Approva~,,___...N~ Comm~ion so r pr~_~ntative may witness Plug Integrity BOP 'l-E~t ~ Location Clearance Mechanical Integrity Test~ Subsequent Form Required 10- L~I~'~ ORIGINAL SIGNED' Approved by Order of the Commission D Taylor Searnoum Commissioner Form 10-403 Rev. 06/15/88 ORIGINAL Date 12/'1/2000 Date Proposed Changes to KBU 42-7 Drilling Program 1. Marathon proposes to change the approved cementing program on the 13 3/8" surface casing to as follows: . . Type: Class G + 20% Spherelite + 20% multipurpose additive + 1 gps foam preventer + 1% accelerator + 0.3% dispersant + 1.5% calcium chloride Weight: 12.00 PPG Yield: 2.5 cu. ft./sack Mix Water: 10.84 gal./sack Volume: Will circulate cement to surface Compressive Strength Time(hrs) 500 psi 7:17 hrs 2208 psi 24 hrs 2490 psi 72 hrs The 9 5~8" intermediate casing will be cemented in a single stage with 250 sacks of 12.8 PPG lead slurry followed by 520 sacks of 15.8 PPG tail slurry. The planned top of cement will be 3200' MD. Well KBU 2_/7' is currently permitted as a tubingless completion with dual strings of 3%" tubing strings cemented in 8 %" open hole. Marathon proposes to run a single string of 3 %" tubing cemented in an 8 %" hole. As a part of the Excape completion process, the 3 %" tubing string will be equipped with externally mounted perforating guns. Control lines will be run back to the surface and exit out a side outlet of the tubing head with a pack-off system. 4. The volume of cement used for the 3 %" string will increased to approximately 900 sacks to bring the top of cement to 5700' MD. . Due to the control lines with the Excape perforating system, Marathon proposes to change the approved BOPE by removing the lower single gate preventer. A drawing of the proposed BOPE system is attached. After cementing, it will be necessary to pick up the BOP stack to run the control lines out the side outlet on the tubing spool and install the pack-off. There is not enough clearance with the BOP's to pick them up high enough to install the control line system. With the lower single gate removed, the process of installing the control line will be safer. It should also be noted that the BOPE will still meet the regulatory requirements if the lower single gate BOP is removed. RECEIVED DEC 0 5 2000 Alaska 0il & Gas Cons. Commission Anchorage Marathon Oil Well KBU 42-7 BOP Stack IFIow Nipple IFIow Line 13 5/8" 5M Annular Preventer 13 5/8" 5M Double Ram Preventer k J Pipe Ram I 3 1/8" 5M Manually ~ IBlind Ram I 13 1/8" 5M HydraulicallyI Operated Valves I ~<~ IOperated Valve LLL~ x~L~ x~gLl~I II°~,°'elI~LLL~ x LLL] 3 1/8" 5M Manually Operated Valve RECEIVED DEC 05 2000 Alaska Oil & Gas Cons. Commission Anchorage X. POTENTIAL HAZARDS Well KBU 42-7 To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the drillers dog house. The man on the brake(driller or relief driller) is responsible for shutting the well in(BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC or BLM inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. Gas sands will be encountered from +/- 3602' tvd/3800'md to total depth of the well. These sands will range from normal pressured to severly depleted and lost circulation and differential sticking are potential hazards. The Flopro mud system that will be used to drill the well will help reduce these risks and lost circulation materials will be on location. There are no well interference hazards. page 10 n:\drlg\kgf~wells\kbu 42-7\427prog.xls TONY KNOWLE$, GOVEFINOFI ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Julv 27, 1999 P. K. Berga Drilling Superintendent Marathon Oil Company P O Box 196168 Anchorage, AK 99519-6168 Re~ Kenai Unit KBU 42-7 Marathon Oil Company Permit No: 99-025 Sur Loc: 37'FNL, 4118'FWL, Sec. 7, T4N, R1 IW. SM Btmholc Loc. 1237'FNL, 4808'FWL, Sec. 7, T4N. RI lW, SM Dear Mr. Berga: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations arc made. Annular disposal is not authorized for this well. Authorization may be granted following receipt and Commission approval of Form 10-403 containing information required by 20 AAC 25.080. Blowout prevention equipment (BOPE) must bc tested in accordm~cc with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given bv contacting the Commission at 279-1433. ~Robert N. Cl~~r]~stc~son. P.E. ' ' Chairman BY ORDER OF THE COMMISSION dlffEnclosurcs CC~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Alask~, .]ion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 May 6, 1999 Mr. Robert N. Christenson, P.E. Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: Annular Disposal Request for Wells KBU 33-6 and KBU 42-7 Dear Mr. Christenson: In response to your letter of April 22, 1999, we request that you do not hold the drilling permits for wells KBU 33-6 and KBU 42-7 any longer. We will pursue the annular disposal through an Application for Sundry Approval at a later date. Sincerely, P. K. Berga Drilling Superintendent A subsidiary of USX Corporation Environmentally aware for the tong run. ALAS~ OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 22, 1999 P.K. Berga Drilling Superintendent Marathon Oil Company PO Box 196168 Anchorage, AK 99519-6168 Re: Annular Disposal Request for Wells KBU 33-6, Dear Mr. Berga: Thank you for your recent Applications for Permit to Drill for wells KBU 33-6 and KBU 42-7 in the Kenai Gas Field. Blair Wondzell' s notes indicate that you may want to dispose of waste via annular injection in these two wells. Authorization for annular disposal of drilling waste may be requested with the application for these Permits to Drill or by a subsequent Application for Sundry Approval. In either case, 20 AAC 25.080 requires the applicant to provide certain information to the Commission (copy of regulation attached). If you would like the request to conduct annular disposal operations to be evaluated with the Applications to Drill we can hold the applications until the necessary information is received. However, if you would prefer to seek that authorization at a later time please let us know and we will continue processing these permits. Sincerely, Robert N. Christenson, P.E. Chairman slh/enclosures L/.! STATE OF ALASKA .,.~r A _,,,.A OIL AND GAS CONSERVATION CO,v,,,,,.¢SION PERMIT TO DRILL 210 AAC 25.005 g:\cmn\drlg~sterling~su44-10~,ogccptd.xl~ la. Type of Work Drillr~ Re-Drillr-"] lb. Type of well. ExploratoryF'] Stratigraphic Test[-'--] Development oilr--] Re-Entry~ DeepenF-] servicer---~ Development Gas[-~ Single Zoner'~ Multiple Zone[-~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool MARATHON OIL COMPANY 87' KB feet Kenai Gas Field/Beluga 3. Address 6. Property Designation P. O. Box 196168, Anchorage, AK 99519-6168 A-028142 4. Location of Well at Surface 7. Unit or Property Name 11. Type Bond (see 20 AAC 25.025) 37'FNL, 4118'FWL, Sec. 7, T4N, R11W, S.M. Kenai Unit Blanket Surety At top of Productive Interval 8. Well Number Number 1237'FNL, 4808'FWL, Sec. 7, T4N, R11W, S.M. KBU 42-7 5194234 At Total Depth 9. Approximate Spud Date Amount 1237'FNL, 4808'FWL, Sec. 7, T4N, R11W, S.M. 8/1/99 $200,000 12. Distance to Nearest 13. Distance to Nearest Well 14. Number of Acres in Property 15. Proposed Depth (MDandTVD) Property Line 12500 feet 640 feet 6000 7751' MD/7500' TVD feet 16. To be Completed for Deviated Wells 17. Anticipated Pressure (see 20 AAC 25.035 (e) (2)) Kickoff Depth 725 feet Maximum Hole Angle 23.5 ~' Maximum Surface 2559 psig at Total Depth O'VD) 7500' 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 133 K-55 PE 80-100' 0' 0' 80-100' 80-100' 17-1/2" 13 3/8" 61 K-55 BTC 1763' 0' 0' / 1754' 1726' 1150 sx 12 1/4" 9 5/8" 40 L-80 BTC 5870' 0' 0' 5578' 5327' 250 sx 1 st 300 sx 2nd 8 1/2" Dual 3 1/2" 9.3 L-80 EUE 8rd 8065' 0' 0' 7751' 7500' 670 sx Kenai Unit well KBU 42-7 will be directionally drilled to an estimated total depth of 775~' MD, 7500',,~l~l~'~fmm t. he.. existing Kenai Gas Field pad 41-7. The production interval will be cased with dual 3.5" strings cement;;d ir~"~;~'~ run to surface. Marathon's drilling rig will be used to drill and complete this well. The following documents a're Drilling Program, Area Maps, Location Map, Structure Map, Surface use plan, Directional Maps, Mud pit drawing and Blowout Prevention Equipment drawings. ,20. Attachments Filing FeeL~J Property Plat~ X ~ BOP SketchL~J Diverter SketchL~ Drilling ProgramL~j Drilling Fluid Program[~"] T,me vs Depth Plot~"] Refraction Analysis[-'] Seabed Report[-'q 20 AAC 25.050 Requirements~"] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed P.K. Berga ///~r~ Title Drilling Superintendent Date 3/18/1~99 Commission Use Only :Permit Number IAPI Number I^Pproval Date I See Cover Letter by order of '~" ,¢~ ?-- ,~ ~" Approved by ,.,,o~r-.t~AL SIGNED BY Commissioner the Commission Date Form 10-401 Rev. 12-1-85 Robert N. Christens' Submit in Triplicate R~e_~s~er 1996 MISCE~OUS BOARDS 20 AAC 25 is amended by adding a new section to article I to read: 20 AAC 25.080. ANNULAR DISPOSAL OF DREZ.J2qG WASTE. (a) A person may not disr~ose of dr/liNg waste throu~ the annular space of a well unless author/zed by the commission under this section. An operator may request authorization for such a disposal in an application for a Permit to Drill (Form 10-401) or an Application for Sundry Approvals form 10-403). (b) A request for authorization under this section must include (1) a designation of the well that will receive drilling waste; (2) the depth to the base of freshwater aquifers and permafrost, if present; (3) the depth and th/ckness of the receiving zone and the coniNng zone, and sufficient information to demonstrate cortfinement; (4) a list of all publicly recorded wells within one-quarter mile, and all publicly recorded water wells within one mile, of the well that will receive drilling waste; (5) an estimate of the maximum volume and density of waste slurry to be disposed; (6) a description of any waste sought to be determined as dr/Iling waste under (h)(3) of this section; (7) an estimate of the maximum anticipated pressure at the outer casing shoe during disposal operations and calculations showing how this value was determined; (8) details that show that the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost if present, and cemented with sufficient cement to provide zone isolation; Register , 1996 MISCELLANEOUS BOARDS (9) details that show that the inner and outer casing strings have sufficient strength in collapse and burst to withstand the anticipated pressure of disposal operations; and (10) any additional data required by the commission to confirm containment of drilling waste. (c) The commission will, in its discretion, authorize disposal of drilling waste through the annular space of a well permitted under AS 31.05.090 if it determines that (1) the waste will be contained in a suitable receiving zone; (2) the disposal will not (A) contaminate freshwater, (B) cause drilling waste to surface; (C) impair the mechanical integrity of the well used for disposal; or rD) damage a producing or potentially producing formation or impair the recovery of oil or'gas from a pool; and (3) the disposal will not circumvent 20 AAC 25.252 or 20 AAC 25.412. (d) Unless the operator demonstrates, by written application, that it is imprudent to comply with a limitation established in (1) - (4) of thi~ subsection, the commission will not authorize disposal of drilling waste (1) in a volume greater than 35,000 barrels through the annular space of a single well; (2) for a period longer than one year through the annular space of a single well; (3) into a hydrocarbon-beating strauan; Register , 1996 MISCELLANEOUS BOARDS (4) through the annular space of a well not located on the same drill pad or platform as the drilling operation generating the drilling waste. (e) In addition to any other conditions that thc commission in irs discretion imposes on a case-by-case basis, an authorization to dispose of drilling waste under this section is subject to the following conditions: (1) if drilling waste appears above the confining zone, the operator shall immediately cease disposal, notify the commission, and take appropriate remedial action; and (2) if the commission notifies the operator that disposal operations pose a threat to safety., oil or gas recovery, or freshwater, the operator shall immediately cease disposal and take appropriate remedial action as approved or required by the commission. (f) For each well authorized for disposal under this section, the operator shall report to the commission in writing (1) the date and the method by which the annulus was closed if closed at the end of the disposal operations, or the condition of the annulus if left open for future disposal operations; and (2) the total volume of drilling waste disposed of, by the following categories: (A) the aggregate of all drilling wastes described in (h)(1) of this section; (B) the aggregate of all drilling wastes described in 0a)(2) of this section; and (C) each substance determined to be a drilling waste under (h)(3) of this section. A report under this subsection is required when a Well Completion or Recompletion Report and Log (Form 10-407) or Report of Sundry Well Operations (Form 10-404) for plugging the well is required to be filed for the well, or no later than 30 days after the disposal authorization expires, whichever occurs first. (g) The provisions of 20 A. AC 25.252 and 20 AAC 25.402 - 20 AAC 25.460 do not apply to the disposal of drilling waste authorized under this section. R.e~i~er 1996 ,.MISCELLANEOUS BOAKDS (h) In this section, "drilling waste!' mean~ the following substances, unless identified as a hazardous waste in 40 C.F.K. Part 261' (1) drilling mud, drilling cuttings, reserve pit fluids, cement-contaminated drilling mud, completion fluids, and formation fluids associated with the act of drilling a well permitted _. under 20 AAC 25.005; (2) drill rig wash fluids and drill rig dome._~stic w_aste water__; and (3) other substances that the commission determines upon application are wastes associated with the act of drilling a well permitted under 20 AAC 25.005. (i) For purposes of this section, in AS 31.05.030(e)(2), "oil or gas well" means a well permitted under AS 31.05.090 other than a water well associated with oil or gas exploration and production. (Eft. / / , Register ) Authority: AS 31.05.030 DRILLING AND COMPLETION PROGRAM MARATHON OIL COMPANY ALASKA REGION WELL: KBU 42-7 PAD: 41-7 SLOT: NA REVISION NO.: 0 SURFACE LOCATION: TARGETS Middle Beluga FIELD: Kenai Gas Field AFE No.: 9203799 TYPE: Development. DATE: 3/18/99 37' FNL, 4118' FWL, Sec. 7, T4N, R11W, S.M. 1237' FNL, 4808' FWL, Sec. 7, T4N, R11W, S.M. BOTTOMHOLE LOCATION: 1237' FNL, 4808' FWL, Sec. 7, T4N, R11W, S.M. KB ELEVATION: GL ELEVATION: 87 ft. mean S.L. (est.) 66 ft. mean S.L. I. IMPORTANT GEOLOGIC HORIZONS: FORMATION DEPTH(MD) DEPTH(TVD) Sterling 3800 3602 Upper Beluga 4934 4685 Middle Beluga 5579 5328 Lower Beluga 6337 6086 T¥onek 7428 7177 II. ESTIMATED FORMATION TOPS AND CONTENT: FORMATION DEPTH (M D) DEPTH (TVD) Sterling 3800 Upper Beluga 4934 Middle Beluga 5579 Lower Beluga 6337 Tyonek 7428 TD 7751 POTENTIAL CONTENT 3602 gas/water 4685 gas/water 5328 gas/water 6086 gas/water 7177 gas/water 7500 gas/water page 1 g:\cmn\drlg\kgf\wells\kbu 33-6\427prog.xls III. WELL CONTROL EQUIPMENT DIVERTER SYSTEMS The diverter system will consist of a 20" X 3000 psi annular preventer and a 16" O.D. nonbifurcated vent line. The vent line valve will be full opening and integrated with the annular in the fail safe design as stipulated in 20AAC 25.035. The vent line will be a minimum of 75' from any source of ignition. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 13-5/8" x 5000 psi annular preventer, a 13-5/8" x 5000 psi double gate ram type preventer with blind rams in the bottom and pipe rams in the top, a 13-5/8" x 5000 psi drilling spool (mud cross) with 3-1/8" x 5000 psi outlets, and a 13-5/8" x 5000 psi single gate ram type preventer with pipe rams. The choke manifold will be rated 3-1/8" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor- boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mudpits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. WELLHEAD SYSTEM STARTING FLANGE: 20 3/4" 3M Flange top x 20" weld on bottom. CASING HEAD: 13 5/8" 5000 psi top x 13 3/8" sow bottom with base plate for 20". CASING HEAD: TUBING HEAD: 11 "-5000 psi top xl 3 5/8" - 5000 psi bottom. CHRISTMAS TREE: 3 1/8" - 5000 psi dual christmas tree including two master valves, one flow tee, one wing valve and one swab valve. page 2 g:\cmn\drlg\kgf\wells\kbu 33-6\427prog.xls IV. CASING PROGRAM: CASING DESCRIPTION TYPE SIZE SET SET HOLE WT. GRADE THREAD FROM TO(md/tvd) SIZE CONDUCTOR: 20" 133 ppf K-55 PE Surf 80-100/80-10 Driven SURFACE: 13 3/8" INTERMEDIATE 9 5/8" 61 ppf K-55 BTC Surf 1754'/1726' 17 1/2" 40 ppf L-80 BTC Surf 5578'/5327' 12 1/4" PRODUCTION: 3 1/2" x 3 1/2" 9.3 ppf L-80 EUE 8rd Surf 7751 '/7500' 8 1/2" CASING DESIGN SIZE WEIGHT GRADE SETTING FRAC GRD FORM PRSS DESIGN FACTORS DEPTH,TVD ~ SHOE ~) SHOE MASP TENS COLL BURST 13 3/8" 61 ppf K-55 9 5~8" 40 ppf L-80 3 1/2" x 9.3 ppf L-80 3 1/2" 1726' 11.5 800 603 10.61 1.29 3.39 5327' 14.0 2520 1900 4.99 2.45 1.70 7500' 15.2 3393 2559 2.80 7.99 3.97 All tubulars are new. page 3 g:\cmn\drlg\kgf\wells\kbu 33-6\427prog.xls V. CEMENTING PROGRAM SURFACE: 13 318" 1754'/1726' 'LEAD SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: 12.8 ppg. 2 cu. ft./sk ""~' hrs:min 50 % in open hole. 650 sks. TAIL SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: 1263 ft. 15.8 ppg. 1.15 cu. ft./sk gal/sk hrs:min 50 % in open hole. 500 sks. RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED ! 1, Remove thread protectors and visually inspect connections, 2, Make up float shoe and 1 shoe joint. Check float. Fill pipe until circulating. 3, M/U stabin float collar, (Baker-lok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing and centralizers. M/U circulating head. Test lines. 6. Circulate until no gain in circulating efficiency is made, 7. Run inner cementing string with stabing sub and centralizer. Baker has false rotary and slips. , g. 10. 11. 12. 13. 14. 15. Pump spacer as follows: Mix and pump lead slurry. To be designed. Mix and pump tail slurry. Displace cement. Sting out. Check floats. POOH with inner string. WOC N/D diverter. Weld on casing head and N/U blowout preventers. Test BOPE. Run wear bushing. page 4 g:\cmn\drlg\kgf\wells\kbu 33-6\427prog.xls V. CEMENTING PROGRAM (continued) PRODUCTION 9 5/8" @ 5578'~5327' LEAD SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: Stage 1 5170 ft. 12.8 ppg. 2.00 cu. ft./sk gal/sk hrs:min 50 % 100 sks. Stage 2 3900 ft. 12.8 ppg. 2.0 cu. ft./sk gal/sk hrs:min 50 % 200 sks. TAIL SLURRY: Class "G" + required additives. TOP OF CEMENT: 5600 ft. WEIGHT: 15.8 ppg. YIELD: 1.1 5 cu. ft./sk WATER REQ,: gal/sk PUMPING TIME: hrs:min EXCESS (%): 50 % ESTIMATED VOLUME 150 sks. 4925 ft. 15.8 ppg. 1.15 cu. ft./sk gal/sk hrs:min 50 % 1 O0 sks. RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections, 2. Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3. M/U float collar. (Baker-lok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing. M/U cementing head, install bottom plug and test all lines. 6, Circulate and reciprocate until no gains in circulating efficiency is made, 7. Drop bottom plug and begin pumping spacer, 8. Pump spacer as follows: To be designed. 9. Mix and pump lead slurry, 10. Mix and pump tail slurry. Drop top plug. 11. Displace cement. Reciprocate as long as possible. 12. Bump plug w/500-1000 psi over final circulating pressure. Check floats. 13. WOC 14. P/U BOP stack. Set slips. N/U tubing spool. N/U BOP stack. 15. Test BOPE. page 5 g:\cmn\drlg\kgf\wells\kbu 33-6\427prog.xls V. CEMENTING PROGRAM (continued) PRODUCTION 3 1/2" x 3 1/2" 7751'/7500' LEAD SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: ft. PPg. cu. ft./sk gal/sk hrs:min % sks. TAIL SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME 5700 ft. 15.8 ppg. 1.15 cu. ft./sk gal/sk hrs:min 25 % over caliper log, 670 sks. RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3. M/U float collar. (Baker-lok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing. M/U cementing head and test all lines. 6. Circulate and reciprocate until no gains in circulating efficiency is made. 7. Drop bottom plug and begin pumping spacer. 8. Pump spacer as follows: To be designed 9. Mix and pump tail slurry. Drop top plug. 10. Displace cement. Reciprocate as long as possible. Land tubing hanger. 11. Bump plug w/500-1000 psi over final circulating pressure. Check floats. 12. WOC page 6 g:\cmn\drlg\kgf\wells\kbu 33-6\427prog.xis VI. MUD PROGRAM MUD PROPERTIES DEPTH DEPTH WEIGHT VISCOSITY WATER MUD FROM TO TVD ppg sec/qt LOSS TYPE 0' 1726' 8.6-9.0 80-250 15-30 Freshwater gel 1726' 5327' 8.6-9.0 42-80 < 12 Frreshwater/gel/LCM 5327' 7500' 9.0-9.5 50-70 < 8 FLO PRO/KCL MUD EQUIPMENT The solids control equipment will consist of two flowline cleaners and the MI centrifuge van. Included will be equipment to dewater the underflow from the mud processing equipment to allow for disposal of the cuttings and solids by slurrification and injection into the disposal well at the KGF. VII. LOGGING, TESTING, AND CORING PROGRAMS LOGGING PROGRAM CONDUCTOR: No logging is planned for this interval. SURFACE: No logging is planned for this interval. PRODUCTION: RUN//1' AITIDSIILDT/CNLIGR. RUN //3' RFT/GR. RUN //2: AIT/MSFL/LDT/CNL/NGT. RUN #4: MSCT/GR. COMPLETION: Gamma ray/CCL. MUD LOGGING The well will be mud logged from 1754' md(casing point) to TD at 7751' md. CORING PROGRAM Side wall cores will be taken during the logging program. TESTING PROGRAM No open hole tests are planned for this well. Each string will be pre and post frac tested. page 7 g:\cmn\drlg\kgf\wells\kbu 33-6\427prog.xls VIII. BOTTOMHOLE PRESSURES AND POTENTIAL HAZARDS See attached sheet for anticipated bottomhole pressures for all sands. Lost returns are possible. Hydrogen sulfide gas has not been encountered in any well in the Kenai Gas field IX. OTHER INFORMATION DIRECTIONAL PLAN SOUTH DESC MD TVD INCL AZIM COORD EAST COORD VERT SECTION RKB 0 0 0 0 0 KICKOFF 725 725 0.0 133.0 0 build @ 2.5 deg/100ft BUILD/TURN 1045 1044 8.0 133.0 15 BUILD/TURN 1391 1383 15.0 160.0 74 16 49 21 89 HOLD 1755 1726 23.5 150.0 181 102 208 DROP 3912 3704 23.5 150.0 926 END DROP 5478 5227 0 0 1200 532 69O 1068 1384 TD 7751 7500 0 0 1200 690 1384 POTENTIAL INTERFERENCE: WELL DISTANCE (ft.) No interference exists. DEPTH (MD) page 8 g:\cmn\drlg\kgf\wells\kbu 33-6\427prog.xls X. DRILLING PROGRAM CONDUCTOR: Drive 20" conductor to +-100 ft. RKB. Weld starting flange to drive pipe. Move in and rig up rotary drilling rig. Nipple up 20" diverter, diverter valve, and 16" diverter line. Function test diverter and diverter valve. SURFACE: Drill a 17 1/2" hole to 1754' md/1726' tvd per the directional plan. Run and cement 13 3/8" casing. WOC. Cutoff 13 3/8" and 20". Weld on 13 3/8" SOW by 13 5/8" 5M wellhead. N/U 13 5/8" 5M BOP'S. Test BOP'S and choke manifold to 250/3000 psi. Set Wear bushing, Test surface casing to 1500 psi. INTERMEDIATE Drill out float equipment and make 5-10' of new hole. CBU. Test shoe to leak off. Estimated EMW is 11.5 ppg. Drill 12 1/4" directional hole to 5578' md/5327' tvd as per directional plan. Lost circulation is possible through this entire interval. Make wiper trip. Run and cement 9 5/8" casing. WOC. N/U 13 5/8" 5M x 11" 5M head. Test BOPE to 250/5000 psi. Set wear bushing. Test casing to 2600 psi. PRODUCTION: Drill float equipment and 10' of new formation w/8 1/2" bit. CBU. Test shoe to leak off. Estimated EMW 14 ppg. Drill a 8 1/2" hole from 5600' to 7932' per the directional program. Log. Make a wiper trip. Pull wear bushing. Run dual 3 1/2" casing strings and land hanger in tubing head. Cement. Bump plug with 1875 psi. WOC. COMPLETION: Set BPV's in hanger. N/D BOPE and N/U dual tree. Test tree to 5000 psi. Perforate and frac each string as per program. page 9 g:\cmn\drlg\kgf\wells\kbu 33-6\427prog.xls NOTES: MASP CALCULATIONS: Surface casing: 13 3/8" MASP = Injection pressure at shoe + S.F. - Hydrostatic pressure of gas column. MASP = (11.5 ppg + 1.0 ppg) x .052 x 1726' - (.115 x 1726') MASP - 1122psi- 199psi MASP = 923 psi. Intermediate casing: 9 5/8". MASP = Injection pressure at shoe + S.F. - Hydrostatic pressure of gas column. MASP = (14.0 ppg + 1.0 ppg) x .052 x 5327' - (.115 x 5327') MASP = 4155 psi- 613 psi MASP = 3542 psi. Production casing: Dual 3 1/2" strings. MASP = Formation pressure at pay - Hydrostatic pressure of gas column. MASP = 9.0 ppg x.052x7250'-(.115x7250') MASP - 3393 psi- 834 psi MASP -- 2559 psi. CEMENTING. The cementing of the 9 5/8" casing may or maynot be done in stages. The actual procedure and amount of cement will be determined once the severity of lost cirulation is determined. CASING. One side of the 3 1/2" x 3 1/2" dual production strings will have 2 7/8" run in open hole and the other string will be all 3 1/2". page 10 g:\cmn\drlg\kgf\wells\kbu 33-6\427prog.xls Marathon Oil Well KBU 42-7 Diverter Flow line 20 3/4" 3M Diverter IDiverter Spool I 6" Automatic Hydraulic Valve Marathon Oil Well KBU 42-7 BOP Stack IFIow Nipple 13 5/8" 5M Annular Preventer IFIow Line 13 5/8" 5M Double Ram Preventer [Pipe Ram I 3 1/8" 5M Manually Operated Valves [13 5/8" 5M Cross 13 518" 5M Single I Ram Preventer I I IBlind Ram1 -- 13 1/8" 5M Hydraulically IOperated Valve I , 13 1/8" 5M Manually I IPipe Ram I IOperated Valve I ii Marathon Oil Well KBU 42-7 Choke Manifold 12 9/16" 10M Swaco I Hydraulically Operated IChoke 3 1/8" 5M Manually Adjustable Choke : I ., t~.4.- - -~ _ I /"~ ---- I ~-6~ PT A-G~ PT ~ I I ~ I ' I /~-%~ 6 X 5 ~G X 5 6 X 5 ~ '6 X 5 I b ~/p~.~,._14' 14' 14' ,_~ ~" 14' '- _ _ Ii I ~_~// ~= .... .~_ t~-.. ~ ~ ........... I _. I ~~. . .... ~'~~~ ....... . · , J · ~. · ~,....... _ _ .-. _ . .. ,,, ~ ,- ~-~ ~ ~ ...... ~ , .. ''i ................. ~ ~ ~ ........... ................... , ....... . ..... ._ ,, .,, ~ .~ _ , ............. ,, , , :MARATHON Oil Company : Structure: Pad 41-7 Well: KBU~.2-7 Fleld: Kenal Gas Field Laos'lan : Kanal Peninsula. Alaska 400 800 1200 1600 2000 5600 4000 4400 4800 5200 5600 6OOO 6400 6800 7200 7800 EsUmoted RKB 87' KOP 2.50 5.00 7.50 DLS: 2.50 deg per 100 ft 10.85 12.97 15.20 1 7.49 19.82 22.19 EOC - 15 3/8 CSG Pt Maximum Angle 23.50 Deg Begin Angle Drop 22.17 20.67 19.17 17.67 16.17 14.67 13,17 11,67 10.17 8.67 7.17 5.67 4.17 2.67 1.17 End Angle Drop TGT - T/ Mid Beluga -, TGT - SE BH ID - 7 CSC Pt ~, East (feet) -> 0 1 O0 200 ;300 400 500 600 700 i I I I I I I I I t I I I I I I KOP Begin Right Turn Begin Left Turn 150.10 Azimuth 1384' (To T.D.) Plane of Proposal DLS: 1.50 deg per 100 ft L9 5/8 CSG Pt EOC - 13 3/8 CS{; Pt o 400 BO0 1200 1600 Verfical Section (feel) -> Azimuth 150.10 with referenda 0.00 N, 0.00 W from sial ~KBU42-7 Begin Angle Drop TOT - T/ Mid Beluga TGT - SE BH - 0 1 O0 20O 500 400 0 500 500 7OO I V 80O 900 1000 1100 1200 WELL PROFILE DATA BgKER HUGHES INTEO ID :907-267-6621 i',l A R 17'99 12:13 No .003 P .02 PARATIION Oil Compan~ Pad 41- 7 KBU42.7 slot ~¥J~U42- 7 Kenai Gas Fiold Peninsula, Alaska PROPOSAL L ISTIBG by Baker Hughes INI'EQ Your ref ; KBU42-7 Verslon~ Ou~ ref : prop334~ License : Date printed : 17-Mar-gg Date created ; 2-Mar.99 Last revised : 17.Mar-99 Field is centred on r~O 27 33,151,w353 16 7.223 Structure is centred on 270goB,300,2362070.Olo,ggg,oOOOO.N Slot location is n6O 27 33,gO2,w151 14 46.272 Slot Grid coordinates are N 2361974.310, E 2750~3.220 Slot local cooratnates are 16,38 S 4116.3,7 E Projection type; alaska · Zone 4, Spheroid: Clarke - 1866 Reference North is True Nortl~ BRKER HUGHES INTEG ID:907-267-6621 bAR 1'7 '99 12'14 No.O03 P.03 PA&qTHON 0il Company Pad 41- 7.KBU42- 7 Kenai Gas Fleld. Kenal Peninsula, AlasKa Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0,00 0,00 0.00 0,00 100,00 0.00 132,00 I00.00 200,00 0,§0 133.00 200,00 200.00 0.00 133.00 200.00 400.00 0,00 133,00 400,00 PROPO~L L[STING Page Your ref: KBU42-7 Version#2 Last revised : 17-~ar.99 9ogleg ~eg/JOOft Sect 0,00 N O.O0 W 0.00 0.00 O.OD N 0.00 W 0.00 0.00 0.00 N 0,00 W 0.00 fl.O0 O.OO N D.O0 W 0.00 0,00 0.00 N 0.00 W 0,00 0.00 580,00 0,00 133,00 500,00 0,00 N 0,00 W 0,00 O.O0 680,00 0,00 133,00 600.00 0,00 ~ 0.00 W 0.00 0.00 700,00 0,00 133.00 700,00 0,00 N 0,00 W 0.00 O,O0 725,00 0,00 133.00 725,00 0,00 N O.O0 W 0.00 O,O0 825.00 2.50 133.00 824.97 1.49 S 1.60 E 2.50 2.08 925.00 5.00 133.00 924.75 5.05 S 6.38 £ 2.50 8.34 10~5,00 7,50 133,00 1024,14 13.37 S 14.~ F 2,50 18.74 1045.00 8,00 133.00 1043.96 15.21 $ 16.3]E ~,50 21,32 110~,00 8.92 139.94 1098.36 21.09 S 21.86 E 2.50 29.17 1200.00 10.85 149,29 1196.88 35.11 S 31.66 E 2.50 46.22 1300.00 12,97 155.74 1294,73 53.44 S 41.07 E 2,50 66,80 1391,08 15.00 160.0~ 1383.~1 73.83 S 49.31 E 2.50 88.58 1400.00 35.20 159.63 1391.72 76.01 S 50,11 E 2.50 90.87 1500.00 17.49 156.03 1487.67 102.04 S 60.78 E 2.50 118.75 1600,00 19.82 153,24 1582.,41 130.91 S 74.52 E 2.50 !50.63 1700,00 22,19 151,03 1675,76 162.58 S 91.21 E 2.50 186.45 1764.39 23,50 150.00 1725,88 180.96 S 101,70 E 2.50 207.57 2000.~0 23,50 150.00 1951.13 265.76 S 150,66 E 0,00 305,49 2500,00 23.50 150,00 2409.68 438,39 S 250.32 E 0,00 504.82 3000,00 23,50 150,00 2868.23 611.02 S 349.98 E O.O0 704,15 3500.00 23.50 150.00 3326.77 783.65 S 449.64 E 0.00 903.49 3911.~ ~3.50 150.00 3704.19 925,74 S 531.67 E 0.00 1067,56 4000,00 22,17 15~.00 3285.72 955.47 S 54~.83 E 1,50 1101.88 4100.00 20.67 150.00 3(378.81 987.10 S 567.09 E 1.50 1138.40 4200.00 19.17 150,00 3972.83 1016,60 S 584.12 E 1,50 ]17~.46 4300.00 37,67 150.00 4067.70 1043,96 S 599.92 E 1.50 1204.06 4400.00 !6.17 150.00 4163.37 1069,16 S 614.47 E 1.50 1233.16 4500.00 14.67 150.00 4259.77 1092.19 S 627,76 E 1,50 1259.74 4600.00 13.17 150.00 4356.83 1113.02 S 639,78 i 1.50 1~83,80 4700.00 11,67 150.00 4454.49 1131.64 S 650.54 E 1.50 1305,30 4800.00 10.17 150.00 4552.68 1148.04 S 660.01 E 1.50 1324.24 4900,00 8,67 150.00 4651.33 1!62,22 S 668.19 E 1.50 1340.60 5000.00 7,17 150,00 4750.37 1174,15 S 675,07 E 1.50 1354,38 5100.00 5.67 150.00 4849.74 1t83,83 S 680,66 E 1.50 1365,56 5200.00 4.17 150.00 4949.37 1191.25 S 604.95 E 1.50 1374.3.3 KOP Begin Rqght Turn 8egtn Left lurn EOC - 13 3/8" CSG Pt Begin Angle Drop 9380,00 2,67 150.00 5049.19 1196,41 S 687.93 E 1.50 1380,09 5400.00 ~.17 150.00 5149,13 1199,31 S 689,60 E 1.50 1383.44 5477,88 0,0~ 0,00 5227.00 1200.00 S 690.00 E 1,50 1384,~3 EK~ Angle Drop 5500,00 0.00 O.OO 5249,12 1200.00 S 590.00 E O.O0 ~384,23 5577,07 0,00 O.O0 5326.99 1200,00 S 6,o0.00 E D,O0 1384.23 9 ~/8' CSG Pt 5577.88 0.00 0.00 53~7.00 1200.00 S 690,00 E 0.00 1384,23 6000,00 0,00 0.00 5749.12 1200.00 S 690,00 E 0.00 1384.23 6800.00 0.00 0.00 6249.12 1200.00 S 690.00 E 0.00 1384.23 7000,00 0.,00 0.00 6740,12 1200.00 S 690.00 E 0.00 1384,23 7500.00 0,00 0.00 7249.12 1200.00 S 690.00 E 0.00 1384.23 TGT · T/ ~lid Beluga All data is in feet unless otherwise stated. ~oordtnates from slot ~KOkl4?..7 ~nO TYO fro~ Cst. RKB (87.00 Ft above mean sea level). Bottom hole distance is ~38~,~3 on ~zimuth 150.10 degrees fP~ wellhead. Total ~ogleg for wellpath is 49.23 degrees. Vertical section is f~om H 0.00 W O.DO on ~zimuth C60.10 degro~,s. Calculation u.~os the ~intmum curvature method, Pre.~ented by B~ker Hughes INT5Q BAKER HUGHES INTEQ ID:907-267-6621 MAR 1 ? '99 12:1~ No.O0~ P .04 HARATHON 0i 1 Company Pad ~Jl. 7. KBU42- 7 Kenai Gas F~eld,Ken~i Peninsula, Alaska ,~e~sured Inclln, Azimutl~ True VePt R £ C T A I~ G II L A R Depth Degrees Degrees Depth C 0 OR 0 I ~ A T E S PROPOSAL LISTII~G Page ~ Your ref : KBd¢2-7 Version Last re¥iseu : 17,Pier-g9 Dogleg Vert Deg/lOOft Sect 7500.88 0,00 0,00 7250.00 1200.00 S 690.00 E 0.00 13B-1,23 TGT - SE Bi( 7750.80 O.O0 0.00 7500.00 1200,00 S ogo,o0 E 0.00 1384.23 TD · 7" CSG Pt All data is I n feet unless otherwis¢~ stated, Coordinates 'from slot ~1(BU42-7 and TUD fro~ E=t, RF,~ (87.00 Ft above nman sea level), Bottom I)ote distance is 1384,23 on azimuth 150,10 degrees from wellhead, lotal Dogleg for wellpath is 49,23 degr'~e~, Vertical section is from N 0.00 W 0.00 on azimuth ]50.10 degree~, C~lcuiatlon uses the minimum curvature, method, Presented by flaker Hughes ! . ' 1' I / ,% '% 1000 ft. 0:kBeluga Sands 1998\AFE\Well 42-7\42-71oc.doc DLB 03/15/99 KBU 42-7 Location Kena, Gas Field Alaska Region Top Lower Beluga CI = 100 feet 3/99 KBU 42-7 ESTIMATED TOPS AND PRESSURES' 3~15/99 LOWEST PRESSURE LOWEST TOP SSTVD TVD GRAD. PRESSURE STERLING A8 3515 3602 0,08 288 A9 3547 3634 0.08 291 Al0 3590 3677 0.08 294 All 3650 3737 0.08 299 B1 3704 3791 0.08 303 B2 3753 3840 0.08 307 B3 3825 3912 0.08 313 I]4 3878 3965 0.08 317 B5 4057 4144 0.31 1285 C1 4353 4440 0.08 355 C2 4521 4608 0.08 369 HIGHEST PRESSURE HIGHEST GRAD. PRESSURE 0125 991 KBU 41-7 BELUGA Ul 4598 4685 0,08 375 0.11 515 U2 4644 4731 0.08 378 0.11 520 U3 4694 4781 0.08 382 0,11 526 U4 4710 4797 0.08 384 0.11 528 U5 4732 4819 0.08 386 0,11 530 U6 4796 4883 0.44 2149 U7 4844 4931 0.08 394 0,11 542 U8 4906 4993 0.08 399 0.11 549 U9 4933 5020 0.08 402 0.11 552 UIO 4999 5086 0.08 407 0.11 559 Ull 5121 5208 0.08 417 0.11 573 U12 5192 5279 0.08 422 0.11 581 U13 5219 5306 0.44 2335 M1 5241 5328 0,2 1066 0,44 2344 M2 5277 5364 0,44 2360 M3 5309 5396 0.2 1079 0,44 2374 M4 5378 5465 0.44 2405 M5 5511 5598 0.2 1120 0.44 2463 MS 5605 5692 0.2 1138 0.44 2504 M7 5634 5721 0.44 2517 M8 5680 5767 0.2 1153 0.44 2537 M9 5700 5787 0.44 2546 M10 5750 5837 0.44 2568 Mll 5766 5853 0,44 2575 M12 5784 5871 0.44 2583 M13 5798 5885 0.2 1177 0.44 2589 M14 5872 5959 0.2 1192 0.44 2622 M15 5981 6068 0.44 2670 LI 5999 6086 0.46 2800 L2 6007 6094 0.46 2803 L3 6047 6134 0.18 1104 0.46 2822 L4 6128 6215 0.18 1119 0.46 2859 L~6 6238 6325 0.46 2910 L7 6308 6395 0.46 2942 L8 6374 6461 0.46 2972 L9 6397 6464 0.18 1167 0.46 2983 L10 6480 6567 0.18 1182 0.46 3021 L11 6650 6737 0.18 1213 0.46 3099 L12 6695 6782 0.18 1221 0.46 3120 L13 6771 6858 0.18 1234 0.46 3155 L14 6821 6908 0.18 1243 0.46 3178 L15 6937 7024 0.46 3231 L16 6893 6980 0.18 1256 0.46 3211 L17 6942 7029 0.18 1265 0.46 3233 L18 7017 7104 0.18 1279 0.46 3268 TYONEK 7090 7177 0.46 3301 72-8 7113 7200 0.37 2664 0.46 3312 73-1 7203 7290 0.37 2697 0.46 3353 TOTAL DEPTH 7300 7387 x x x X X X NEARBY BELUGA COMPLETIONS KBU 13-8 KBU 31.7RD KBU 31-7 x x x x x x x x x x x x x CASING POINT *Middle and Lower Beluga depletions possible in zones identified by "X" in the nearby wells. Sterling and Upper Beluga depletions expected across the field. KDU 4RD KBU 33-7 CONTROL Used this hodzolls slmctl, lt'~ Used U. Beluga midpoint structure and KBU 41-7 well Used M. Belugastructure and KBU 41-7 well Used ~ Beluga Stucture and KBU 41-7 well · Used Top Tyonek Stucture and KBU 41-7 well o:~eluga Sands 1998~AFE\Wel142-7~42-7tops.xls DLB 3/18/99 13 T. 6N. I '~29 t,,: 28¥-. ::. : 'I - "-~f' ' . --U~:-' ':" '-: -I..:?. .... ~ ' ---"' -- - I '! ~ ............................... : ;, I "' . [ [ " t .... "' ' ¢ " : ~ ;'-... : ' ' I ; ~:. . L I 0 [ ~..' Unit Bou~darF ~'"'"i [ ' "¢~' Strips . ~' :,: ~:.:; .:, --- . : , / 1' i'.:.'.., ~ ....... s .... · . I [ '- " -'"':~2 -' "' I - ... -. / I...'" w,,,,_ ._ ---. ..... ::...... Ir , - _ .... / I. ":~ '--- - ........ ~ ~ I ' .. ' ' '~ - ' ' ' - ' "-- '"'" / . I //' . ' ..... ' - / I * I .... -- ~ ..'- ._ --'- t ~.~ !..:'~ I ..... . . *, :.m;~ ~ . - - ,,. , ~ ~; I ] ..;; ' .. · ~ · , ~::...:., ~ . , ..... .::-- /'= ~ i ..' ". ~ I :, .;~ . · f ,. ~ I ~ ' ~-~ . , , . ~ . , ' / .::;i' I : , (: ~ ,x ' -..2~x :- ..-.'. a ~ ..................... ~~..i.~, ¢~ . -~.~:kN..~:-%~ _ /"'::.: ~';:: ' 1. -'. .~ ~ I ' ,:. .....:~.,:: ~.. ....:. ~ '~ ~ ,~" . .' · :. -:. · 7.:.~. t . - ~ - :"' ' ".':.'..'" ' I - ~ - .... . . /~ ' "-' ' 7'~ ~ [ ~ ~: L.-. · .. . .... , ./....' /~.---:' t. ,,- _ ~.y.%~..: ., . . . ' I ." 29: ~'"'i .... i:. .:..-.~.::;'2~ ~26 :?:"' / -: ...--:::. ~.-.-., . ~, ,~ ~,:'--,,~ ' ' I ""- ~ ~ i' - ~-/ -. '-,.: .... : '%:7~¢ ...... :.. -' 7 ~-%- _~ /.-' ~ .".i ........ ' " ':: :r . - ""--.!.. ',-- - '~.q i. -' ' .... "~ :, ?x.-" .-: ,, . , '-N',.~;SY :':'." > ,, .... . ; _,'~..~o° i '"~'~)" ~'i ' ..... / ':'-' "~"' .. , .... .~,---'--~ ~ ~::: '1.~.. ~ MARATHON OIL OOMPANY ............. ~ ....r ...... ~ -~--~ --~-- ~'~----~-~ -- m " ~ ' /" ~ ; .... ~ '~-.~:~;"~ · KENAI GAS FIELD - ~ ' -, t :.. ' //~=~ .. - 31 ~ ,~ 32 :' ,.'~'~ :: ~3-'Lak~/-',.:/ ~'~{'l. T. SN. 6709000m. N 60~30, 2 370 000 FEET T 5N TAN. 25' 4'e I DETAIL 1'-,40' ~ DETAIL %,~ / PAD I PAD ~ Y. · , 17 [ 18 1) im 'me ~ m~me ~'~ mmm mmm ~ 2) ~~ ime~ m ~ 0.~ Mr ~m Uo~-ANl' mamm ,,m,a, dt ! I .Ilrithon 011 ¢ompmny GAS F1E~D PAD AS-~UILT ~ KIMAI GA~ IIII.D PAD 4'1-1' i ,4,~7 ~ o (30 I o Alaska .,ii' ,ion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 March 18, 1999 Mr. Dave Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: Kenai Unit KBU 42-7 Dear Mr. Johnston: Enclosed is the application for permit to drill the referenced well. Please advise if additional information is required. Sincerely, P. K. Berga Drilling Superintendent PKB:nrs N:~DRLG\KGF~WELLS~kbu33-6~aogccclt. doc Enclosure A subsidiary of USX Corporation Environmentally aware for the long run. FORM'3202 REV~ 4/9~7 Marathon Oil Company Pay to the':orderof: ANCHORAGE ALASKA ......... ,. , ".. '". ,': '..' ...... ,;, 'Z..i,!;i!i::.':;Z,,?:r],.!,',:Z',.,i,i~Z?,~,!:'.',]:,~:i~':.,;:,Z,, ,,'..i: 'Z, ,, :i,i.:,~",',.::,.~'.'.','. ..--_3Q~P.O:'.r;CUpine_D~4..~e ................................................................... A~_c ho.~age,,?A .1 as k.a_ _. 995,0:.~.~3192__ Pay: 't'r One hundred and no/100 / VOID AFTER 160 DAYS THE AMOUNT IN NUMBERS MUST MATCH THE AMOUNT IN WORDS ..' ' . ' ' '":':. "' : ' :" .... --.-.DOLLARS NATIONAL BANK OF ALASKA / ~~tla~13~OilCompany.._ ANCHORAGE. ALASKA By_..~-~'_..~._..__.,~__. _~_.~r,.~~r.,-~,.~. ..... ~/~ AUTHORIZED S:GN/~rURE I1' 0 0 ~- =& ~ ~m ,m m: ]. 2 S 2000 S ?m:O m. ll'O Marathon Oil Company P.O. Box 196168 ALASKA 99519-6168 NON-REPORTING 100% REPORTABLE INTEREST Kenai Unit KBU 42-7 WELL PERMIT CHECKLIST FIELD & POOL .z.../_Z./~_ ~'~' ? ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. · .-.-- , 13. ENGINEERING APPR DATE COMPANY~~.~/ WELL NAME~'~_~ _~ ~.~-' 7 PROGRAM: exp_ INIT CLASS /"~., / Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from ddlling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in ddlling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductorstdng provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive hodzons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to _~~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... , , dev ~' redrll ~ serv wellbore seg __ ann. disposal para req_ GEOL AREA _,~"2-.,,2~_ UNIT# ON/OFF SHORE N ~N Y N ~ N N N N N N 29. Is presence of H2S gas probable ................. Y GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N ~ 31. Data presented on potential overpressure zones ..... · · Y./N~' 32. Seismic analysis of shallow gas zones ............. AJ~R D/~TE ) 33. Seabed condition survey (if off-shore) ............. / Y N ~ ~//'~-//. ~4. Contact name/phone for weekly progress reports [explorator~nly] Y N A~NULAI~ DISPOSAL 35. With proper cementing records, this plan ~t)-('~b,0 -~ (A) will contain waste in a suitable receiving zone; ....... Y NI APPR DATE (B) will not contaminate freshwater; or cause drilling waste . . . Y to surface; ) '' ' ' - (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will notdamage producing formation or impair recovery from a Y NI ~ /¢ ~,2,,'~5¢.~ c//,'r"/~,=/ ~"7'¢ ~'~'~ pool; and ) . _ -" / / ' ' (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. .. Y GEOL(j~,~¢':~ ENGINEERING: UlC/Annular COMMISSION' '1~'. ef ..... .z~..~ .~*_y_ ~. ~w.4~l~.~/ ~'~._ · ..... ' · .~ ~- _J! · O Z O ITl '\ c:\msoffice\wordian\diana\checklist
