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Home My WebLink About208-033• Image Project Well History File Cover Page 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. p2Q ~ - ~~~ Well History File Identifier Organizing (done) RE CAN olor Items: Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria Project Proofing BY: Maria ~;,~.,.a iuuumuiuui DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: ae~,~ ~a,~~ IIIIIIIIIIIIIIIIII OVERSIZED (Scannable) ^ Maps: . ~I Other Items Scannable by 1~ a Large Scanner ~O~ OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: Date: /s/ Date: lQ /~ uuiiiiiiiiimi Scanning Preparation _~, x 30 = BY: Maria Date: IO I I Production Scanning Stage 1 Page Count from Scanned File: (count does include cover eet} Page Count Matches Number in Scanning Pr paration: YES NO BY: Maria Date: ~ i ~ `~ /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ IIIIIII IIIIIIIIIIII Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Comments about this file: Date: pZ + ~ =TOTAL PAGES S /D (Count does not include cover sheet) /s/ Quality Checked 10!6!2005 Well History File Cover Page doc DATA SUBMITTAL COMPLIANCE REPORT 5/2412010 Permit to Drill 2080330 Well Name/No. PANTHERA 28-6-9 Operator UNION OIL CO OF CALIFORNIA API No. 50-223-20023-00-00 MD 2020 TVD 2020 Completion Date 4/11/2008 Completion Status P&A Current Status P&A UIC N REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey ~o DATA INFORMATION Types Electric or Other Logs Run: LWD (GR-Res, Son) (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Loo Loq Run Interval OH / Med/Frmt Numt~er Name Scale Media No Start Stop CH Received Comments C Las 16183 Sonic 158 1973 Open 5/1/2008 LAS data for Sonic, GR ~ C 16184'~See Notes Open 5/1/2008 Directional data; LWD and drilling mechanics data in LAS and PDS format Sonic 2 Col 150 2000 Open 5/1/2008 Sonic Vision, Best DT 1- Apr-2008 Induction/Resistivity 5 Col 200 1975 Open 5/1/2008 MD Vision Resisitivity Field 1-Apr-2008 Induction/Resistivity 2 Col 200 1975 Open 5/1/2008 MD Vision Resisitivity Field I' 1-Apr-2008 Induction/Resistivity 2 Col 200 1975 Open 5/1/2008 MD Vision Resisitivity Sonic Field 1-Apr-2008 Induction/Resistivity 5 Col 200 1975 Open 5/1/2008 MD Vision Resisitivity , Sonic Field 1-Apr-2008" Rate of Penetration 5 Col 200 1975 Open 5/1/2008 MDDrilling Process and mech with Time 1-Apr-2008 Rate of Penetration 2 Col 200 1975 Open 5/1/2008 MDDrilling Process and mech with Time 1-Apr-2008 Directional Survey 0 2020 Open C 16652/See Notes 0 0 Open 7/28/2008 Mudlog: data in LAS and PDF formats; Final Well Report in Word Format. DATA SUBMITTAL COMPLIANCE REPORT 5/24/2010 Permit to Drill 2080330 Well Name/No. PANTHERA 28-6-9 Operator UNION OIL CO OF CALIFORNIA API No. 50-223-20023-00-00 M 2020 TVD 2020 Completion Date 4/11/2008 Completion Status P&A Current Status P&A UIC N pt Report: Final Well R 0 0 Open 7/28/2008 Final Well Report, Table of Contents, Eqiup and Crew, Well Details, Geo Data, Drilling Data, Daily Rpeorts g Mud Log 2 Col 101 2019 Open 7/28/2008 MD Formation og Log Mud Log Mud Log 2 2 Col Col 101 101 2019 2019 Open Open 7/28/2008 7/28/2008 MD LWD Combo Log MD Gas Ratio og Mud Log 2 Col 101 2019 Open 7/28/2008 MD Drilling Dynamics Well Cores/Samples Information: Interval Name Start Stop Sample Set Sent Received Number Comments Cores and/or Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 3/21/2008. ADDITIONAL INFORMATION Well Cored? `~~I~ Daily History Received? /~ N Chips Received? ~`fiid--- Formation Tops V / N Analysis ~-a'-f^IV~ Received? Comments: Compliance Reviewed By: ~ Date: ~ _~ L_~ • MEMORANDUM State of AI as ka Alaska Oil and Gas Conservation Commission TO: Jim Regg, ~ ~~ ~u~,~,; DATE: September 21, 2009 P.I. Supervisor FROM: Chuck Scheve, SUBJECT: Location Clearance Petroleum Inspector Union Oil Co of California Panthera 28-6-9 PTD 2080330 ' Monday, September 21, 2009; I performed a Location Clearance Inspection of Union Oil Company of California (Union)'s exploratory well Panthera 28-6-9. This exploratory location was clean with no evidence of past drilling activity other - than the cellar area, which was mounded nicely to prevent ponding. SUMMARY: I made a Location Inspection of the Union abandoned exploratory well Panthera 28-6-9 and recommend this final location clearance be approved. `~ ` I i~ 1 f ~ I, _,. F~ li Imo' ~ i i ~ ( y 4 ~~ ~ ~4 1 ` t q ALASKA OIL Ai1TD GAS COI~TSERQATIOI~T C01~1Il~iISSIOI~T August 11, 2009 Ms. Faye Sullivan North Slope HES Coordinator Union Oil Company or California P.O. Box 196247 Anchorage, AK 99519-6247 Dear Ms. Sullivan: a'~~ SEAN PARNELL, GOVERNOR 7, ;~~ ~` 333 W. 7th AVENUE, SUITE 100 r° ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 The Alaska Oil and Gas Conservation Commission (Commission) completed location clearance inspections for Smilodon 9-4-9 (PTD 207-152) and Panthera 28-6-9 (PTD 208-033). Both exploration wells were drilled by Union Oil Company of California (Union) from temporary ice pads during February-March 2008. Location inspections were performed on August 6, 2008. A copy of the Commission's inspection report covering these two locations is attached. The Commission previously witnessed plug and abandonment operations on both wells, verifying compliance with the abandonment regulations and approved permit requirements. Inspections showed the Smilodon 9-4-9 and Panthera 28-6-9 locations to be in compliance with onshore location clearance requirements as stated in 20 AAC 25.170. The Commission requires no further work on the subject wells or locations. However, Union remains liable if any problems occur in the future with these wells. Sincerely, Cathy P. Foerster Comm ssioner Attachment MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~ P. I. Supervisor ~~ FROM: John Crisp, Petroleum Inspector ~i~~j u~ DATE: August 06, 2008 SUBJECT: Location Clearance Union Oil Co. of California Exploration Sites White Hills Project August 6, 2008: I traveled to Union Oil Company of California's Mastodon 6-3-9, Panthera 28-6-9 &Smilodon 9-4-9 Exploration drill sites for AOGCC Location Clearance Inspections. Smilodon 9-4-9 PTD 207-152: Mounding on the actual casing string cutoffs was good & there was no ponding in the well cellar. DNR inspected the drill sites before AOGCC Inspection. Mastodon 6-3-9 PTD 208-019: Mounding on the casing strings cellar was good. The area around the cellar had standing water that was no more than 8" deep. This will probably have no adverse effect on the actual mounding @ the cellar. AOGCC will request site inspection next year. ~/ Panthera 28-6-9 PTD 208-033: Site looked good & mounding was also good. Standing water outside of cellar looked to be natural due to low spots in tundra & rainwater. DNR inspected all locations prior to AOGCC inspections. Summary: I inspected Union Oil Co. of California's (Chevron) White Hills project Drill sites & reviewed photo's with Supervisor Jim Regg. Attachments: photos (6) August 2008 Location Inspections -Mastodon, Smilodon, Panthera Location Clearance Inspections August 6, 2008 Smilodon 9-4-9 (PTD 207-152 Mastodon 6-3-y (F' I U lUtf-U'ly x ~;~ . . . ,.w ,,,k,a~:,,~., ~~: ~. ~: t, ~`_ ' •~ w ~ a ~ ~ , ~. .,,•-. ..rr.:: _~.. ~ • August 2008 Location Inspections -Mastodon, Smilodon, Panthera 3 ~ ~ August 2008 Location Inspections -Mastodon, Smilodon, Panthera egg, ~~~~ ~ ~~~ From: Regg, James B (DOA) Sent: Monday, August 10, 2009 11:27 AM To: 'Henderson, Jennifer' Cc: Brandenburg, Tim C; Hammons, Darrell; Sullivan, C=aye Val; Quick, Mike [ASRC]; Pecci, Chris I Subject: RE: Well location clearance from season 1 and 2 Attachments: 2008-0806_Locations_Mastodon_Smilodon_PantheraJc. pdf Mastodon Attached is the inspection report covering the August 2008 location inspection at Mastodon 6-3-9 (also Smilodon 9-4-9; Panthera 28-6-9). While there was evidence of some mounding over the well/well cellar, the amount of water just at the well location justified additional inspection during 2009, thus the reason for not closing out the location inspection requirements. This year's inspection will determine if additional work is needed at Mastodon. Smilodon, Panthera No further work is necessary for Smilodon 9-4-9 and Panthera 28-6-9 based on information from inspections completed by AOGCC. I understand from your discussions with AOGCC Inspector Jeff Jones that Union plans to visit the Panthera location again since there was a conductor removed last winter from the undrilled Panthera 21- 6-9. The Commission will attempt to accompany Union on the site visits subject to inspector availability. Photo documentation would be acceptable in AOGCC's absence. Official correspondence will be sent to Union for Smilodon 9-4-9 and Panthera 28-6-9 as requested. Call if you have questions or concerns. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Henderson, Jennifer [mailto:JenniferHenderson@chevron.com] Sent: Friday, August 07, 2009 2:04 PM To: Regg, James B (DOA) Cc: Brandenburg, Tim C; Hammons, Darrell; Sullivan, Faye W; Quick, Mike [ASRC]; Pecci, Chris L Subject: Well location clearance from season 1 and 2 Jim, Chevron met with Jeff today to inspected the White Hills season 2 wells. We were unable to complete the clearance inspection due to weather. After further discussion with Jeff today he said Chevron will need to do more work on the Mastodon well. Per the letter attached from John Crisp dated August 11, 2008, Chevron was under the impression, Mastodon, Panthera and Smilidon were going to be closed out and no further work was required. Chevron never received any further correspondence that more work was required. Chevron would like to request a clearance location close out letter from you for at least Panthera and Smilidon. 13!10/2009 ~O~r X33 • ~ ,jam ~. ~!, ~h°>Ir,^~~ '~fo?ild lilts ~JlY4Cid; =~orrespon:~iei~ce `eq°a.de5d:i1?~ dddi'?:i°Jnar tIJ~s`i; Ci'? Ma~w;~d€~i~, Chevron is ~~vorl<ing a plan 'forward to Mill iii -the well a'i Musi<oxen and would like direction from ~1~GCC ir' we need to add more diri to Mastodon, Chevron will have 'the pads and well location 1:rom season 2 inspected once we complete the required work. Thank you Chevron North America Mid-Continent/Alaska Exploration and Production Company Environmental Specialist 907.263.7902 907.382.2908 ~~ ~ ~~ ?~, p^ 8/10/2009 CHEVRON Chevron U.S.A. REQUEST DATE P.O. Box 363 07/24/2008 Houston, TX 77236 11111 S. Wilcrest Houston, TX 77099 s H AOGCC P 333 W 7th Ave Ste 100 Anchorage, Alaska 99501 t United State America 0 Shipped Via: DHL N0.2008.07/24 ORIGINAL TRANSMITTAL OF CONFIDENTIAL DATA From: David Guthman Sent by: Norma Blake Panthera 28.6-9 API: 50-223-20023-00 QUANTITY DESCRIPTION AREA Survey Product REMARKS 1 EPOCH Final Well Report Mudlogging Data Panthera 28.6-9 EPOCH Final Well Report Mudiogging Data White Hills EPOCH Final Well Report Mudlogging Data 1 Paper Print Panthera 28-6-9 Mud Log Hard copy White Hills Paper Copy DATE SHIPPED VIA CHEVRON TRANS. NO AIR WAYBILL # 7/24/2008 DHL CH•2008724-0000 228305386653 PLEASE ACK QWLEDG ECEIPT OF 1~u3~kTERIAL BY SIGNING AND RETURNING COPX OR FA~If~IG TO (28'L) 5&1-3592 - -~ _ ~.~___ ---- - - Date ~~ ~~y~ ~~ ~n F'~~~5 ~nar>nnu i _ i • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, May 23, 2008 1:52 PM To: Walter Quay (Chevron) Subject: Panthera 28-6-9 (208-033) Walter, I am catching upon reviewing completion reports. Could you please provide operations reports with greater detail? ' The submitted reports do not have enough detail for me to effectively review. What I really need is the hourly. I know it may be a lot of pages, but it is what I need to do my work. Email is fine. Call or message with any questions. Tom Maunder, PE AOGCC Page 1 of 1 Maunder, Thomas E (DOA) From: Quay, Walter [ASRC] [WQuay@chevron.com] Sent: Thursday, May 29, 2008 11:18 AM To: Maunder, Thomas E (DOA) Subject: Panthera Time Log Summary.pdf Attachments: Panthera Time Log Summary.pdf Chevron May 5, 2008 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7~' Avenue Anchorage, Alaska 99501 Timothy C Brandenburg Drilling Manager Re: Well Completion Report and Log (Form 10-407) Exploration, Wildcat, Panthera 28-6-9 (PTD 208-033) Dear Commissioner: Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Fax 907 263 7884 f~E~~al~~ MAY 1 3 2 ~C Alaska Oil & Gas Cora. ~;~mmi.~isi0i Anchcra~e Enclosed for your review is the Well Completion Report (Form 10-407) for the Panthera 28-6-9 Exploration Well. The attachments include a summary of the daily drilling operations, directional survey, well as-built, wellbore diagram, and photos of the abandonment. The well has been plugged and abandoned as of April 11, 2008. Approval for the plug and abandonment work was given under sundry number 308-126 (Form 10-403). We request that this data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). If additional information is required, please contact either myself or Mr. Walter Quay at 263-7812. Sincerely, C_- ~,g Timothy C. Brandenburg ~. Drilling Manager TCB: stp Attachments: Form 10-407 Operations Summary Directional Survey As-Staked Survey Wellbore Diagram Photos (3) Cc: Well File Union Oil Company of California / A Chevron Company http://www.chevron.com ~~~ STATE OF ALASKA ~ MAY j ~ ZQ~$ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPOR~kA~1®c~a€~IS. ~ofrmissi~~ 1a. Well Status: Oil ^ Gas ^ Plugged Q Abandoned Q Suspended ^ zoaaczs.~os zonACZS.~~o GINJ^ WINJ^ WDSPL^ WAG^ Other^ No. ofCompletions:0 1b. Well Class: t1C Ot'a~ru Development ^ Exploratory^~ Service ^ StratigraphicTest^ 2. Operator Name: Union Oil Company of California 5. Date Comp., Susp., or Aband.: 4/11/2008 12. Permit to Drill Number: 208-033 3. Address: P.O. Box 196247, Anchorage, AK 99519 6. Date Spudded: 3/29/2008 ~ 13. API Number: 50-223-20023-00-00 . 4a. Location of Well (Governmental Section): Surface: 191' FNL & 850 FEL Sec. 28, T6N, R9E, Umiat Meridian 7. Date TD Reached: 3/31/2008 14. Well Name and Number: Panthers 28-6-9 ' Top of Productive Horizon: x' FSL & x' FEL Sec. 6, T3N, R9E, Umiat Meridian 8. KB (ft above MSL): 369.5. Ground (ft MSL): 349 . 15. Field/Pool(s): Total Depth: 204' FNL & 860 FEL Sec. 28, T6N, R9E, Umiat Meridian 9. Plug Back Depth(MD+TVD): Surface Exploration 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 514,375 ~ y- 5,795,581 Zone- 4 10. Total Depth (MD + TVD): ~ 2020'/2020' 16. Property Designation: ADL 390003 TPI: x- y- Zone- 4 Total Depth: x- 514,365 ~ y- 5,795,567, Zone- 4 11. SSSV Depth (MD + TVD): N/A 17. Land Use Permit: ADNR LAS 26542 18. Directional Survey: Yes ~ No (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1440' ' 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): LWD (GR-Res, Son) - 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 16 65 H-40 0 101 0 101 24 50 bbl (232 sx) 9 23. Open to production or injection? Yes ^ No Q 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: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate ~ Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity -API (corn): 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^~ ~ Sidewall Cores Acquired? Yes ^~ No ^ 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. Sidewall Cores: L ~.ti on M~° f.T' ~:.~~ 1~R fED C? ~~~ Form 10-407 Revised 2/2007 ` ONTINUED ON REVERSE ~' ~4'OS 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No ~ If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Base Permafrost 1440 1440 needed, and submit detailed test information per 20 AAC 25.071. Prince Creek "A" 1420 1420 Formation at total depth: Prince Creek 1420 1420 30. List of Attachments: Operations Summary, Directional Survey, As-Staked Survey, Wellbore Diagram, Photos (3) 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Walter Quay Printed Name: Tim Brandenburg Title: Drilling Manager ~~_. Signature: G--._- Phone: 263-7812 Date: 5/5/2008 /O ~/ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with 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 Level 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: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 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 • Chevron -Alaska Time Log Summary Sort _ -_-__. Well Name Field Name- APINWI- - - - Lease/Serial CHEVNO -, License NO /PropertyC Ong KB Elev (ftK8) Water Depth (R) i. PANTHERA26~-9 Exploration ;502232002300 ADL380003 LE3051 '208033 370.0 _--. SOUL Date Our(MSl ._ ._....- Ertl Date ~'~-_-_---AcCIriIY - - _ Bp/CsgSt -_ COmnerd..-- _..... . _ 3/24!2008 00.00 6.00 3/24/2008 06:00 'Rig Up /Rig Down" ., Rig down koomey lines. Nipple down 13 5/8" SM in one piece and set on trolley. Unbolt diverter ',spool, finish unwiring Top Drive. Disconnect service loop and Kelly hose. Blow down and disconnect mud pump lines in pump room. Lay down torque tube rails. ', Started moving Galena camp to Panthers location at 7:15 hrs. 3/24/2008 08:00. 8.00 1 324/2008 12:00 I Rig Up i RIg Down." i I PuU apart pie shed, fold down Drifters aide and off Drillers side wlndwaNs, finish service loop rig j I down, prep t0 scope down derrick Finish Geanrrtg. pits and breaking. tines fa Vanspart. Blow down ',. I ijsteam Nees ei ptts. .3/24/200812:00 6.OOI3/24/200818:00 ,Rig Up /Rig Down" I Install Nabors Tioga heater blowing in pump room. Pull front rig floor windwall. Install Top Drive in ' ' cradle and remove from rig floor. Fold down upper rear rig floor windwail and remove roof cap. ' I 'Remove insulated house from HPU. Blow down rig floor steam lines. Bridle up derrick raising lines ' and prepare to scope down same. Haul pipe shed, windwalls, gasbuster, Top drive, Roof caps to Panthers All Galena camp ands with the exception of the SDU in place wRh lights and heat at 13:15 hrs 3/24/2008 18:00 6 003/252008 00:00 ! Rig Up / t2ip: Down"' Finsh blowing dawn alt remaining steam lines and shut down [milers, drain hot well. Finish I ' I preparirrgand scope down demck. Continue tearing dawn mud pump rooms and pulling electrical I ~ ~c~s ttloughoutrig. Start setarting lines and kelly hose and preparing to lower derrick. 325/2008 00:00 700 3/25/2008 07:00 Rig Up /Rig Down"" Finish preying derrick and lower same. Finish tearing down mud pump rooms. Finish pulling electrical lines and rigging down steam lines. Shut down generator and rig down drillers doghouse. ' ' ', Finish pulling up all containment around rig and preparing for crane and trucks. 3252008 07:00 6.0013/252008 15.00 Rig Up f Rig Down"' 'i Set crane and load out off millers side doghouse, deWateririg tank, and mud pits. Reposition crane I I'i and bad out millers dog house, change house, auxiliary aced rig water tanks, stairs module. Move crane out of way and load out back end with bed trucks, mud pumps, VFD building, accumulator building, electrical building, hotwell house, boilers, generators, spacer buildings and utilidoors. SetI ~i ramp and position bed trades for draworks. Pull out demdc/maworks skid Load oul sub base. i ~, I .3/25/2008 15.00 ~ 3.00 3/25/200818.00 Rig Up / RIg Down"` Fold out herculite away from rig mats. Set cellar grating. Spot sub and align over hole. Set ramp { I ~ and position bed trucks. Install demick/draworks skid an sub base. ;3125/200818:00 6.0013/2812008 00:00 Rig Up /Rig Down'° ' 'Set in Water Tank, Auxiliary Water Tank, Stairway Module; 1 8 2 Mud Pumps. 1 8 2 Breezeways, ! Double stacked Mud Pits, Double Stacked Dewatering House, Utilidoor, 1,2 & 3 Generator 1 SetsBoi(ers, VFD Bkfg, Accumulator. DS Top Doghouse, Set Gas BusterlCtwke House Gose for i F ~. ~ Crane to stud up. Done with Trucks @23:30. Pipe Shed, Tntck Shop and Out Bkigs left to set in 13/262008 06:00 Rig Up /Rig Down" 3/26/2008 00:00 6 00 Spot crane, set ODS tool house, set BOP on trolly and place in sub, spot choke house and raise. I ' ', '. ', Power up back yard and fire up heaters. !toga, lights. air, and hydraulcs. Prep derrick and raise. '13/Z62008 06:00 ~ 6.0013262008 12:00 I Rig.Up /Rig Down'.' !Rig up wiles. Fuel rig. Fire and pressure up trailer lk1. Install site glass on h9 water tank. Raisei ~. " !bade side wind wall and draworks lid. Set stairs for yds. Work on insulating around rig. Continue '~ I i hooking ~ steam around rig. Prep derrick and scope same. II 3/26/2008 12 00 6.0013/26/200818:00 I Rig Up /Rig Down" ~ Work on Steam Lines. Install insulation around holes in rig. Unchain Blocks. Scope out Derrick ' ~ ' I ', Repair ail line on drawworks. Assist electrdion on electric lines. 1 boiler running start running steam . I I 'to rig. 328200818:00 I t3.00 3/272008 00 00 I Rig Up !Rig Down" Hook up Top Drive to blocks Install Front Winrhvall. Stand up DS windwall w/Crane. Continue to ~ ~~, i work on Steam Lines. Start installing Mud Lines in Pump House. Conttnue to Instal! secondary ~. [ 1 containment around rig and Truck Shop. I .3/2712008 00:00 6.0013/27/2008 06:00 Rig Up /Rig Down" l Bring boiler #2 on line and rig up steam to pits and rig floor. Raise drillers side, off drillers side, and draworiks wind walls. Tie back bridle lines. Hang service loop. Remove top drive cradle from rig '; ,floor. Pull out liner, lay rig mats, and set pipe skate. Continue working on containment around rig. , '3/2712008 06'00 I 6.00 3/271200812:00 !Rig Up !Rig Down" ~Fltiah hook up mud lines in transition and mud pump room. Sfeam and install hydraulic lines on I . service kx~p in demdc. Finish setting pipe trams. Install kicker on derrick guide plate for k811y hose i Move and must dewater tank to align shaker transition. Berm in and set flogs heater on pipe steeds. Start picking up torque tube. 3/27/2008 12:00 d 6 00 3/27/2008 18:00 I Rig Up /Rig Down" I Set and power up Epoch, AnamB, and Baroid. Spot Halliburton cement equipment. Finish plcking i up torque tube and hang. Install top drive extension system. Hook up demidk guy lines. Steam I ' I . 'suction valves in mud pits, air up boots on suction and discharge lines, install degasser discharge A I li line, and continue to prepare to bang on spud mud. Install and wire in Service Loop on Top Drive. 1312712008 t8:00 600 3/282008 00 00 {Rig Up /Rig down"` 'Nipple up Dtverier Adaptor Flange. InstaN @OP's on diverter Flange. Irestatt Torque Rari extenson i ~i 1 ~'`R ems" emove Y e s won adaptor flange Torque all ~ I 1 bolls. Grease Gripper on Top Dme. 'I 3/28/2008 00:00 6.001, 3/28/2008 06:00 Rig Up /Rig Down" , Install knife valve and diverter Nne, secure BOP stack, mstall PVC riser plpe, hook up accumulator I ~ ' mes o nu ar an va ve, Install choke, Kill, HCR, and valves. Thaw gun line in pR #8 Install) ', ~, ' '~ kelly hose, makeup saver sub. ' 3/28/2008 06:00 2.00 31282008.08:00 ' BOP Test. I ~ install 4" elevators, PtJ 1 joint of drill pipe t~fy,~ f,~_nctibn tee Functipn test knife valve and armular diverter system. Knife valve open m 40 seconds, annular ck>se in 48 seconds. Perform accumulator drawdown test. Initial pressure 2900 psi, tam off bosh recharge pumps and close annular. Pressure after closure pressure 1900. 30 seconds to recharge 200 psi with 1 pump, 1 min' ~ 55 sec to recharge to 3000 psi with 2 pumps. N@ bottle pressures 4(~ 2500- Test gas sensors on I I ~. ; ~, rig floor shakers and cellar with methane and H@S test gases. High alarm on H2s at shaker had to., I I tbaadjusted and retested. All inspection items passed. i, ACCEPT RIG ON PANTHERA @08:00. I f 3/28/2008 08:00 4.003/28200812:00 Rig Up /Rig Down"' ~ Take on 525 BBL mud. Hook up electric lines and rig up monkey board. Hang tongs and pipe i '.. '., '. '~; '. spinners. ' 3/281200812:00 ! 7.001328200819:00 Rig Up /Rig. pawn" iTighten choke kill line valves and hoses. RU choke hose to choke mandold Change valves to mud' pumps. Strap and tally drill pipe,and HWDP. Dress shakers, change shaker motor weights m top 'i , motors on shakers #2 and #4, adjust centrifuge Rig up Epoch PVT system. Rig up bleeder choke ( j ~ on standpipe. 3/28/2008 21:00 l Rig Up /Rig Down" ..3/28/200819:00 2.001 Clean and organize rig. Service spinners, Hook up Epoch Flow Paddle, Repair cradked weld on , ' Landing on rig Floor. 3282008 21:00 j 3.00 f 3292008 00;00 ~ Drill Pipe -Pidt-Up /Lay Drift and Pick t~ 62 joints of 4" XT-39 Drift Pipe, Stand badk in dertick. Readjuit Ke1ty Hpse so it wtl1l 1 (Down 'lay by wind wall instead of middle of derick. 3/29!2008 00:00 1.50 3/29/2008 01:30 'Drill Pipe -Pick-Up /Lay 112 1 /4 ~ Drift, Pick up & Rack back 24 joints of HWDP. '..Down 329200801:30 !: 1.OOj3292006A2:30 BOP-Nipple Up -_-- I1~ 2114. _ LPickupandJnstailWearRing. ___ - - -- ~ ' Chevron -Alaska Time Log Summary Sort L' Well Name- - Field Name APINWI - .Lease/Banal - CHEVNO License NO /PropertyC Orig KB Elev (ftK8) Water Depth (ft) '~ PANTHERA28-6-9 Exploration 502232002300 'ADL380003 'LE3051 208033 370.0 -__--S[ert.DaBe--- '._Dur (his) T Entl Data _ _ pphfty _ _ ~ y a6/CSg.SZ. -____ ____- ___- __._.T__-__ ___ _.__ _.... ~ '. Comment 3/29/2008 02:30 3.00 3%29/2008 05:30 BHA - PU/MU" 12 1/4 Pick up 48" Tongs, Change out elevators, Hook up Pull Back cables and load cell Caliper BHA Pick up 12 1 /4" Bit, Straight Motor, X-Over, X-Over. 3Y1912008 05:30 1.50 i3/29/2008 07:00 'Circulate & Condfiion 12 1/4 ;Test Mud Lirtes and Mud Pump to 1700 psi: Lek Mud Pump suction. TtgMen retest. 3/29/2008 07:00 1.50'3/29/2008 08:30 Rig -Repair 12 1/4 #1 Mud Pump stroke counter not working, charge pump indicators on drillers console not working. ' Troubleshot problem. Discovered programming ercor in computer, requires reprogramming with Academy software. Able to monitor pump strokes with remote choke panel and visually monitor charge pump operations. 3/29/2008 08:30 1 6.OOi3/29/200814:30 jDrilling -Rotary (Wdh 121/4 ~"SPUD" 09:00, Drilff/102' to 186'. 900 psi 13 BPM TO 50 RPMS Motor 94 RPMS, WOB 1 SK I ;Motor) ~ Pump Pressire increased to 1500 psi at same pump rate, well not packvrg off penetration rate same. Continue to drill ahead to 27f `. 3/29/2008 14:30 ' 3.50 3/29/200818:00 Trip Out of Hole Pumping ~ 12 1/4 Attempt to circulate hole clean at 415 GPM, shakers would not clean up due to running gravel. 31291200818:00 :3/29/2008 19:00 3ras2ooa 20:00 , f '..3/29/2008 22:30 ' 3/30/2008 00:00 3/30/2008 04:00 3/30/200811;00 3/30/200813:30 31301200818:06 3!30/2008 23:30 3/31/200800:00 ~ 3/31 /2008 01:00 3/31/200816:00 3/31/200810:30 3/31/2008 49:30 3/31 /2008 20:00 3/31!2008 20:30 3/31/2008 21:00 3/312oos2z:~ j ..3/31 /2008 23:30 4!1!2008 00:00 4/1Y200800:30 4/12008 01;00 4/1/2008 04:00 419200610:00: ,4/1/2008 11:00 4/1200813:30 4/1/2008 14:30 a~1rzo061fa6o ', 4/1/2008 20:30 422008 06:00. '4/2/2008 01:00 1.00 329V200819:00 1.00.3/29/2008 20:00 2.50 31292008 22:30 1.50'3/30/2008 00:00 4.0013/3012008 04:00 7 00 3/30/2008 11:00 250 3/30200813:30 4.50 III 3/30/2008 18:00 5.50 3/302008 23:30 0.50 3/31/200800:00 1.003r3trzoo6 at;00 9.00 3/31/200810:00 0.50~3131tZ(XY8 10:30 9.00 3/31/200819:30 0.50~3/31/2W826:00 0 50 3/31/2008 20:30 0.50 3!31/21)08 zt;a) 1.50 i3/31/2008 22:30 1.00 3/31/200823:30 0.50(4/1/2008 00:00 .:0.50 4/12008 00:30 0.50 i, 4/1 /2008 01:00 3.004/12006 04:00 s.oo',a1/zooe 10:00 1.00~4It2008 11 D0 2.50 4/11200813:30 1.00{4/1/200814:30 ' 3.50,4/1/200818:00 a.so'4112006 20:30 3.50 i 4/2/2008 00:00 1.00(4/22008 01:00 9.00'..4/2/2008 10:00 4/21200810:00 i 45014/2/2008 14:30 4/2/200814:30 ~ 2.50(4/2/200817:00 BFIA -Handle." 'Rig -Service Rig:- Repaie 'BHA - PU/MU" BHA - Hanefe" Dolling -Rotary (With Motor) Rwg RepaT I Dolling -Rotary (With Motor) Drilling - Rotary (Wdh Minor} ..Circulate & Condition (Circulate 8 catditiorl Drilling -Rotary (With Motor) Rtg - Sernce Drilling -Rotary (Wdh Motor) (Circulate & CondAion Drilling -Rotary (With I Motor) Gircu~te & Gonddion Dolling -Rotary (With 'Motor) ~ cire ~ e«,dakxr Trip Out of Hole (Trip Out of }Iola Circulate & Condition I`fnp Out of Hole I' Trip Out of Hole Pumping (Trip Out of Hole ',BHA -Handle"' ~ BHA - PU/MU'"' '.Tripping In I Wash 8 Ream f Wash 8 Ream Flow check well and start trip out of hole. Tight spots a an ump an ro a e ou om 245' to conductor shoe at 102' pumping at 75 SPM 335 psi. Blow down top drive and I t2 1/4 ',Break bR Gteck out MotorClean suction and discharge screeru. ',12 1 /4 Academy technician reprogram computer system. Repair hydraulic hose on top drive service loop. 12 t/4 ilnstall bit, screw into motor and pump pressure still to high Break bit to lay down motor. found I I~~ St1b valve half waycbsed~: open saver sub valve, matte up bit retestmotor motor Pule 112 1 /4 PJSM, Start picking up BHA #2. 121!4 (Finish picking uP Ant3dnl LW4/MWD BHA. 12 1/4 60' 16' of fill . Drill 276' - 608'. Pump 14.2 BPM, 1560 PIS, 55 RPM, 10 WOB, PU 51, SO 51, ROT 51. MW 8. Vis 70 121/4 ITra/blestpat top drive failure. Hydraulics would not function. check hydraulics on topr drive and ~ ..(found no problem. Cttadc electronics and found broken wire in control box at sub. Repair same. During repair, 10.5 BPM: 890 PSI, 5 RPM to clean hole. '~.~ 12 1/4 ~'. Drfll f/608' to 85T. Pumping 14.3 BPM. 1780 psi. TD 80 RPM's. MV 96 RPM's, WOB 10-16K UP ' 'Surveying every other connection Flow Check on connections. AVROP. 55 FPH Pipe in ground t2 1/4. lOrilf f/85T to 1044'. Pumping 14.3 BPM, 1780 psi. TD 80 RPM's, Mtr 96 RPM's, WOB 10-16K UP 1 '~, Surveying every other connection. Flow Check on cornadions. AVROP: 34 FPH Pipe in ground 12 1/4 Circulate @7 13 BPM while changing out Swab reciprocate pipe and rotate @40 RPM's. 1 1121/4- :Circulate while replacing swab on mud:pump. 121/4 Drill formation f/1045' to 1494'. 14.2 BPM TD. ROT 95 RPM's Mtr 96 RPM's. WOB: 15K. Up Wt i 64K, Dwn Wt 64K, Rot Wt: 64K. Avg ROP: 50 FPH, Pipe in ground. 12 t/4 I Service Top Orive: 12 1/4 Drill Formation (11494' to 1960'. 14.2 BPM, Top Drive Rot: 95 RPM, Motor Rot: 96 RPM, WOB 15K, Avg ROP: 52 FPH Pipe in Ground. ~liaht seeoaae loss to formation. 12 1!4 ~ Circulate bottoms up to chuck samples 1920'-1960', Siky fine sand. Decision made tb drill deeper. 12 1 /4 Drill 1/1960 to 1980' 112 1!4 ~ Crculate bottans up, samples iburse sand. Decisrwt merle to doll deeper. 12 1 /4 ~ Drill 1980' to 2020'. Surface casing point (called by DSM, onsite Geologist and SuperintendenU at ', 2020'. ' 12 t/4 c~bidemariker Circulate well Gean. Gauge Hole Carbide shook! have been 4320 Strokes, { W ace was: es, ea as o s. rger tools. pumps morn or well -slight seepage noted. i 12 1/4Trip out of the hole to 1925'. drag 10k-15k. ' ~ 12.1 /4 Trip out of the Role 15' min, Pull to 1752', work through tight spots 15K overyull, 12 1l4 Schlumberger needed to downlink tool again. Circulate and communicate with tool, circulate ' ' bottoms up after downlinking (121/4 Trip out of the hole to 1286'. 15' per min for Schlumberger logs, work throught tight spots-Max I foverpu1115K j 12 1/4 Screw in Top Drive, Pump & Rotate out of the hole from 1286' to 24T, Pumping 3 BPM, and backreaming. 12 tM ITnp outw/2 stds trill Collars not circulating: { 12 1 /4 'Clean and Lay down BHA to Stabilizer above motor. Top Stabilizer packed solid with fortnauon - I just outside of fins visable. Remaining stabilizers 7/8 packed off. Bit had 1 jet plugged. We were ', able to unplug jet and cleaned all stabilizers. 112 t/4 (.Pick up Clean out BHA (No smart irony ~ 12 1/4 ,Trip in the hole to 710', Tag up, Establish circulation X10 BPM, wash in the hole. Attempted to trip I I ', ', in without pumping, kept tagging up. Had to rotate and clean hole. If we wash in the hole too fast 'BHA packs off and torques up. Continue wash and reaming to 1926'. 121/4 Wash-Down and Tag flit at 2003'. Pick up and increase purlp rate to 600GPM. started to rate at 48 RPM. Packed off, with na rehims 12 1/4 'Back Ream, attempt to Circulate. No returns. Rotate at 100 rpm. Work pumps rate up and down I with no successful returns. ,Start iniectinkl fluid into formation at +/-240 psi. Badk ream to 1926'. • Pumped away 120 bbls. I ' f Work Pipe i 121/4 ~ Work pipe from 1926' to 1919', 100 RPM, f3adk Ream, Pull 2-5 K aver and monitor Torque. Torque '' I very erratic, Climbing to 12. Sk ft/hss and stalling out. Turn pumps on periodically and clack for ~ return fluid level would stawty receded while walking pipe. Fill hole with Trip tardc. Work Pipe 12 1/4 At 1919' pull imo a tight spot stalling out top drive. Slacked off to attemp to regain rotation wdh no success. No movement up, down or rotate. No circulation. No success ge in-g~ie )ars~umper sumo Fire. Max pull 120K 60K over string wt. Set down all pipe weight. Work pipe until Baker Atlas '' ', '. Wireline arcived. I Fishing -General ~ 121M ~ Spot in Baker AOas Wireline Tnxik on Herculite and build sekxmtfery cordainment. PJSM Set equipment in Pipe Shed, Hang wireline sheave in dertick, Rig up kiDricator forFreepoim tools Torque up mto drillpipe. Picktp frrsepoint tools. :Fishing -Free PoinUBack 12 1 /4 PJSM, Run m the hole with Freepoint Tool Check for free pipe X1136', Pipe Free, RIH to 1230' 'Off ', Check Pipe Pipe Free, RIH to corcelate. Check Drill Collars, got hung up in Jars Pulled 3900 tools ' came free, tool weight was 1700. Pull into HWDP to 1719' Check_P_ ipe Free, Pull out of the hole 'with tools and lay down freepoint too s • Chevron -Alaska Time Log Summary Sort Well Name ~FIe10 Name APINWI Lease/Sane) iCHEVNO - License NO /PropertyC 'Orig KBElev (RKa) '. Water Depth (R) PANTHERA 2889 Exploration 502232002300. ADL380003 LE3051 208033.. ' 370.0 _. __-.-Start Dad -_ ___- ~_ Dur (hra) '~__ Entl Date , .._... _ .__A~'R1' _ _' ~sg.3z _~ .__ -___ _ ___._ __ __ -_.-__ Cefmment -- - - -- l 4/2/2008 1700 150 4/2/2008 1830 Work Plpee 12 1 /4 Standback wlreline lubncetar, Screw IMO dnllpipe, Work i 30K over and 30K under attain t to eg t Bum er Sub action no action Pull 170K on pipe let set to see if Jars wou bias o . en set string weight own to see if would bleed off. No Success. Make up Lubricator. 4C11200ti Y830 ; 2.00 i 4/2/2006 20;3U ~f ti5htrtg' - Free. PoirN/Back Y21/4 ~ Balcar Atlas rehead and build Pipe a~tting charge while. working pipe. PJSM Pk:king tqa ezpWSrves ~ i ' I 4/212 008 2 0:30 25014/2/2008 23:00 Fishing -Free Point/Back 12 1 /4 Make u Severin Char a Make up Lubricator, Run in hale with charge. Run in the hole slowly tool I Off '.not wanting o a . og collars (/1745' to 1600' had problems recording collars, check collar locator graph and verrfy collar locations. Get Char on de th of 1720' ,Pull i u to 80K Set off cha a '! !, Pipe weight dropped to 70K. Pulh ou e o e wI wtre me. arge a v 4/2/200823:00 i 1.OOj41312008 00:00 Fishing -Flee Pant/Back %12 Y/4 )Pick up off fish 120K up wei ht Worked pipe free. Final Up we M 90k. Trouble getting back a n ~ { Off' I r3own. 50 7'-'Bed c o s g .own E-line sheave hanging I '~ .from derrick 4/3/2008 00:00 2.50 4/3/2008 02:30 1 Fishing -Free PointlBack '~ 12 1 /4 I Rig down Baker Atlas Wireline equipment, !Off 41312008.02:30 { 1 00 4/312008 03.30 Circulat®& Conditiwt 121/4. Attempt to establish arcu~n: Pumping: away into formation. ~ 4/3/2008 03:30 0.50 4/3/2008 04:00 Circulate & Condition 12 1/4 Pump 40bb1 LCM pill MW: 9.2, VIS: 110, 5 ppb Walnut Hulls, 5 PPB Barafiber, Pumping 1.13 bpm before pumping PU Wt 55K SO Wt 45K, Rot: 48K, While pumping had to keep coming up hole with pipe Pulling up to 100K, TO increasing Could not po down when attempting to go down plugged off I ' flow. Finished pumping pill. 413(2008 04:00 4.501413/2008 08:30 Trip Out of HOB 112 1/4 'Tripped ouF of the hole. pumping 0 400 bpm for displac~meM. Left in twle 12 1 /4" bit, Motor. 12 _ i 1/4" Stab, XO, 2-7 1/4" NMDC's, XO. UNOCaI 6 1/2" steel DC, XQ Jars, 1 jt HWDP, Recovered ~ I . ~ '. cut joint of HWDP. ~ 4/3/2008 08:30 1.OO4/3/2008 09 30 (BHA -Handle"' 12 1/4 1 Cut Mule Shoe out of recovered HWDP, Clean floor. 4/3/20t~ 09 30 10.00 413/20081930 Wash & Ream 12 114 up 323' establish crrc 2 bpm increase rate ro 4 bpm Trip in the hole 5 stards and cirulate bottoms _ ',TIH to 64T Establish circulation m course sa~m returns. TtH to 962' establish circuattron 5 i. bpm increase to 8 bpm 300 psi, Heavy sand and slight gravel in urns. arc ea 0 7 { _ Attem t to establish circ Pi Iu ed off Pressure up to 1400 psi M blow out plug. ~. C rotate wn arcu a e 751 psi, no increased cuttings Attempt to make connection well U Tubed 25 bbls and still flowing. start circulating again. circulated 5 circulations j hen well unbaded gravel, increased rate to 16 BPM, Mixed 90 bbls High Vis Sweep. Pumped total 1, turns n h ~nt 15000 strokes 997 bbls no signs of sweep. no increase in re o s aker 4/3/2008 19:30 1.50 4/3/2008 21:00 i Circulate & Condition 1,12 1/4 11 Shutdown pump allow well to u tube Pull up 30' attempt to go down set 6K down pick up attempt to l I ', I Igo down set 4K down. Attempt to circulate pipe plugged. Blow out plug 1900 psi on drill pipe. I ',circulate well. 4/3/2008 21 00 1.50'.4/3/2008 22:30 Slug Pipe 12 1/4 'Pump Dry Pie pill Pull out of the tale 3 standspipe wet, 4th stand X1018' pipe came dry. Pull up Ii ~ I to 970'. 4/3/200822 30 15014/4/2008 0000 Trip Out of Hole 12 1/4 Reciprocate pipe From 970' to 950'. Did not attempt to circulation. 14/412008 00 00 450'14/4/2008 04:30 Circulate 8 Condition (121/4 Reciprogte pipe From 970 to 905'. As we were Reciprocating, we Started to tag up at 938' Set ~ 1 2k down. After reciorocatinD more we lost some caotmd and started to tag at 933' set down Sk 1 rack back the stand to 905' and pump 18 bbl Nut plug marker sweep. 127 gpm, 30 PSI. Calculated i ~ ~I Bottoms 5 1856 strokes. Sw returned at 5000 strokes. noticed nut plug to surface at up a I elect bottoms u lust 7 prc up n ssem I Ca ail P D 11 4/4/2006 04:30 1.SO4/4/2008 06:00 ( Trip Out of Hole 112 1/4 Trip out of the hole with Drill Pipe Lay down Mule shoe Pup. Clean Floor {i ', I,4/4/1008 06:00 :350'.4/4/2006 ~:~ `B1.1A -Handle" 12.114. ', Gather up subs, rerun bit 2-6 1!7' Drill Collars Caber and Strap. Pick up BHA : { ~,, 4/4/2008 09'30 LSO4/4/2008 11 00 Tripping In ! 12 1/4 .. Trip in the hole w/HWDP. and Drillpipe to 854' Tag up Set 6K down on fill i '~,, 414/20081Y:00 100 414/200612:00 I Wash 8 Ream 12 Y/4 and ream 854' to 91 .Pumping 16.2 BPM, Rotary 100 RPM's, Vis 95 in 110 out. Up Wt 42K, ' n Wt 4 of ill washed rigtN away no weight down. Circulate 30 min. Shut down 1 '. , pumps attempt to go in hole Tagged Up @886', 30' high. Pick up no overpull. Establish circulation (wash back to 918' circulate 30 min Shut down pumps. Attempt to go in hole tag up X886' again , 4/4/200812:00 B.OO4/4/2008 20:00 Circulate 8 Condition 112 1/4 Circulate moving pipe from 854' to 918' while pumping @12 BPM, Top Drive 32 RPM's, After 90 1 ' mins circulating Shut down pumps attempt to lower pipe into hole. Tagged cQ906'. 20' deeper Vis 1 1221 in vis out 157. Continue to build vis to 250. when vis was at 200 in 200 out shut pumps down ', '1 attempt to go in hole tagged (dt906'. Pick up no overpull start pumps. Vis 230 in 235 out shut ', ' pumplaTa~empt o~go m tore tag up 906' pick up no overpull. Vis @ 240 in 238 out shut pumps) down Attempt to go in the hole set down X906' pick up no overpull .Only washing bottom 30' of 1 1 stand where fill kee s cumin in. Vis 254 in 250 out. Shut off pumps a~Cert'~p eat~In Fiof 1a u 99 P concemin abandonment. Contacted Lou Grimaldi w/AOGCC @20:00 g 14141200820:00 I 4.170 415/200$ 00:00 Trip Out of Hote X121/4 Trip out of tale and lay dam mill pipe. Ley mown dr9l~ipa ovt of derrick 500' +I- at a timis. Total of I, 1655' of drill pipe. I I 1 4/5/2008 00:00 ! 2.50 i 4/5/2008 02:30 Dell Pipe -Pick-Up /Lay 112 1/4 Lay down dnll pipe f1500' to 100', Trip in the hole f/100 to 720'. Lay down drill pipe, 1 : Down 1 41512008 02:30 2.50114!5/2006 05:00 BHA - Handle`' 12114 lay down Jars, Drill Collars; Bit Clear flow of BHA toots. Emptying Mud Pits for morn for flud from { ,' Ioementjob. ''.. 4/5/2008 05 00 1 00 4I5/2008 06:00 1 BOP -Nipple Down 12 1/4 Pull Wear Bushing. ~ 14/5/2008 06:01) ! 2.00 4/512008 08;00 Drill Pipe -Pick-Up /lay Down i 121/4 Rig uP egwpmeM to nm 3 Y/2" Tubing. Strap and TaNy tttlaing. 1 4/5/2008 08:00 I 20014/5/200810:00 Dnll Pipe -Pick-Up /Lay 12 1l4 Pickup 29 joints of 31/2" 9.3# Tubing to 906', PU Wt 29K SO Wt 29K (Down 4/51200810:00 ~ 0.5014!5/2008 10:30 (Circulate & Condition; L}21/4 PJSM. Circuk~te weN: Bk>w dawn Top Drive. 4/5/2006 10:30 2.50!4/5/2008 13:00 Cement - Mix/Pump 12 1/4 '.Pump 5 bbls Water, Pressure Test Pump and Lines fo 2000 psi. Pump 15 bbls freshwater. Pump : 396 bbls of Type L Permafrost cement. Chase With 2 bbls of water. Total mud displace 1 I s .4/5/2006:13:00. ~i 1.00 4!512008 14:00. (Trip OuE of Hole I~ 11114 1 (Trip outof the trdlewitli 3112'! . T: .. full of centr3nt-wouklstar fafl. I ''.,4/5/2008 14:00 O.SO4/5/2008 14:30 .Tripping In I 12 1/4 ',Trip in the hole to 21 T. 4/5/200814:30 Y.OO41512008 Y530 Circulate & CondAion 1112:7/4 Establish circulation overflow line plugged off from cement thaEwes in 1lowbox from outside of 1 1 ~ 1 dMlpipe took returns over sttalcer to storage-tank. Coirlld not determine if cement was cira~lated 1 ~ 1 1 from 200'. Lay down 7 7omtsof tubing. 4/5/200815:30 ' 6.50:4/5/2008 22:00 Cement -Waiting" 12 1/4 , Wait on cement. Wash out BOP. Clean out Shakers. __ _ -- _ ____ Chevron -Alaska I, Time Log Summary Sort ', Well Name - Fieltl Name - _~ APINWI Lease/Serial CHEVNO L'cense No./Property C. Orig KB Elev (ftKB) Water Depth (ft) PANTHERA28-G-9 Exploration ',502232002300 'ADL380003 LE3051 208033 370.0 Start.De[e -_ A Dur (first l EM DaOS y_- _ _ ACivdY _.. 4/5/2008 22:00 __ 1.00 4/5/2008 23:00 Tripping In 4!5/2008 23;00 1 0014/6/2008 00::00 Trip put of Hole 4/6/2008 00:00 0.50', 4/6/2008 00:30 BHA -Handle"" 4~t2008 00:30 I 4 50 11 4/6/2008 05;00 I ~ Cement -Waiting"" ~ '4/6/2008 05:00 1 ~ 3.001,,4/6/2008 08:00 Circulate & Condition 4/fif2006 OB:00 i 1 50 4/6/2008 09:30.. Cement - MalPump I I 1 ' 4/6/2008 09:30 1.50 416/2008 11:00 Gradate & Condition 4/60200611.00 I U 501416/2008 11:30 ~ Trip Qul of Hole 4/6/2006 11:30 ! 3.50',4/5/2008 15:00 ..Cement -Waiting" 4/6/200815:00 i 1.00 4!6/200816:00 iTrippingin i 4/6/200816:00 8.001,4/7/200800:00 Cement-Waiting" 4?/2008 00:00 2.00 ~ 4!7/2006 02:00 (Cement -Waiting„ 4/7!2008 02 00 1.00'4/712008 03:00 Tripping In 4!712008 03:00 { 2.001417!2008 O5 00 DnH Prpe - Pk;k-tlp /Lay Down 4/7/2006 05:00 I 300 4/7/2008 08:00 ,Cement - Mix/Pump 4!7200808:00 ~ 1.0014/7/200809:00 `Circulate&Conditon 4/7/2006 09:00 2.00 4/7/2008 11:00 4RPZ008 11:06.. 0.7514172008 14'45 (Circulate & Condition 4/72008 11:45 0 75'4172008 12:30 Cement - Mix/Pump 4(/200812:30 j 0.50! 417/2008 13:00 I R~ Up l Rg Oawn" 4/72008 13:00 2.00 4/712008 15:00 I, Rig Up /Rig Down° ~I 12114 121/4 112 t/4 1..,12 1/4 ~ 121/4 P I { 12 1/4 X12114 12 1/4 ~ 12 1/4 12 1/4 121/4 12 1l4 12 1!4 '121/4 12 1!4 121/4 12 ?/4 121/4 Pump 2 bbls water to clear pump and lines. Break off Halib circ equip Stand back tubing. 121/4 Lay down:312" tubing 12 1/4 i Clean out BOP stack with citric water open 4" valves in cellar drain stack. function all rams and ~__ Comment _ _ _ _ _ : _ J Trip In Hole with 3 1Y2 Tbg Tag cement at 422' set down 2k Pull out: of hole Lay down 6 Joints. Stand bads 4 stands Break down XO's and Plug. Clean floor. Wait on'1" oementfrom lialib. The cement was on aTop Joti andbeingdeliveredfrom Prudhoe. I Clean Mtxi Tank #1&2 where returns. were. going when overboard flowfine plugged off. Condtact Denidk Inspection. Trip in the hole l0 405', Establish circulation and circ btms up. filled 501' with 396 bbls cement on ast pump stage. PJSM. Hookk up Haub circ equp. Pump 5 bbls water, Press test to 2900 psi. Pump 5 tNals water, 1 ' I Ptif2 sacks of red koolaid in first tub of cement Ntix and pum 251 bbls 10.7#~Ty~e "L"cemerrt, ~ ~. I BPM 70.85 psi, clear pump and lines w/2 bbls w~,~'i~4'i.+ cu Ts~ wM '.20.3 gals/sk. No cement to surface. Total mud displaced to surface 217bb1s 1' Trip out of the hole with tubing. Tubing pulled dry all the way out of the hole. TIH to 200'. establish circulation, circulated 133 bbls. no ce~ men( In reCums~"olfoms up sP'SuTd'6~34.5 bbls. iTrtp out of the how: Wait ort cement. ~ Wait on Cement. Pidk up 4'12" Btar1k Polled Sub;: Trip in fhe hole T~g;~295'. 251 t)bls Type 'L"Cement filled up I ~~~~ Wait on cement to arrive, Getting Antic Set Light cement from Schlumberger. Pickle #2 mud pump 'Clean pits WaitoriCemarittdGedelivered:.. :. Trip in the hole with 3 1/2" tubing. Tag cement high (dJ240'. Establish circulation. Lay down extra driE~ipe out of dertidc; Tnp In the hole to 215'. Rlg up Ha iburtoh: I PJSM, Pump 5 bbls water, Pressure test 2000 psi. Pump 5 bbls water, Mix and um 211 bbls of ' T e "L" Densit 10.7 Yield 4.15. Cement to Surface after 206 bb s semen . ump s ,water to c ear pump an rues. Ig own circulating lines. ul 1 stan tubing Q18T. Rtg up I I I circ lines, Start mixing and pumping Class "C:" cement Halib having trouble getting cement io mixer.! ', ,down for 25 min. Circulate out cement. establish circulation with rig pump. circulafed 35 bbfs unfit mud to surface, Shut dawn. Trip out of the hole standing back tubing. ~~. ~ Clean cement out of flow box, Clean out BOP stack with wash tool. drain stack function all rams .and annular and wash out. Clean out overboard PVC line. clean Flow. I '1 ~7T~_ttur bQ~' 60' start washinD in the hole got to 125' couln't oo env deeper. While circulating in Ittte hole circulating ouf partially set up cement Hook up Halliburton. '~ ,Mix and um T e "C" Permafrost Cement 15.6 Pum total of 91 bbls cement. Pumped job 3-5 bpm, got bade partially set cement t en mu om arai a ing en 2 b s of good cement. j ~' 4/720118 15:00 9.004/612006 00:00 I Rig Up /Rig Down"'. l12 N4 Rig down- Clear floor, start to nipple down stack, Flush # 1 Mud pump and pickle, Clean Pits ~ ', 4/8/2008 00:00 6.00.4/8/2008 06:00 ,Rig Up /Rig Down"" 1,12 1/4 ,Clean out cement from pits, flush fines with water, blow down Gnes m pits and pump room. Cleaning 1 '~ '', rig from floor to cellar. Remove choke and kill valves. ',, '1 4/8/2006 06 00 I 6.OOI4/812tm812:00 R+g Up f Rig Darvn" (t2 f/4 ~Ramove BOP from wellhead install on trolley and chain down same. Disconred Topdrive from I !, ~ ~ 1 T~`ii g1u~'r cement from pits '.4/8/2008 12:00 6.001418/2008 18:00 ,Rig Up /Rig Down" 12 1/4 Install transport bracing in pipe shed, rig down suction and discharge lines in pump room, pull were ' ~'~ ~'~ ~ sand prep pump room for transport.. continue pit cleaning. 4/8Y100t318:00 I 6.00 4/91200800:00 Rig Up I Rig Dawn"' 12 iJ4 Continue work in pump room, prep monkey board for rig down. Rig down torque tube raft extender , I ~ 1 I lay down torque tube rail Continue pit leaning. i4/9/2008 00:00 8.00 4/9/2006 06:00 Rig Up /Rig Down" 112 1/4 Install shaker shipping pins, remove guy wires from derrick, remove cameras from derrick board. 1 I Remove fastening turnbuckles from exterior of rig floor windwalls. Continue pR cleaning. Prep pipe ', shed for removal. Sucked water out of wellhead, cenfinned Carnets 8' below top of wellhead 14/fY20~.06:00 I 6 00 4/9/2008 12:00 `Rig Up !Rig Down"' ~ 121/4 ~Contirtue pit cleaning, chipping cement from pit #7. Pull pipeshed away Nom rig and tnxJc to I Smilodon. Suck out water from ng water tanks and bbw down water lines to pits and rig floor ~ Prepare pds for spld[irg 4/9/2008 12:00 6.004/9/2008 18:00 .Rig Up /Rig Down'" 12 1/4 I Remove BOP in one piece from cellar. Pull rig floor winkiwalls. service loop. Remove choke house '. '~ ', '. '.. and finish emptying rig water tanks 4/912006 18:00 ` 6.00 4/102008 00;00. I Rig Up f Rig Down"' 121/4 'Unpin Top Drive from blocks, install in cradle arld remove from rig floor: Scope down Derrick and ~ (remove board from same, shut down boilers and blow down steam lines. Sulk water out of #2 I 1 I boiler. Remove exterior lights hum pits. Rig down flowline, hopper lines. disconnect degasser 4/10/2008 00:00 4/102008 06:00 6.001, Rig Up /Rig Down" ~ 12 1/4 Rig down and remove drawworks and stairway roof caps. Pull degasser, finish rigging down cameras and pack up same. Secure cables in derrick, prepare to lower derrick, ruptured hydraulic ' 1, bleeder hose to ODS lowering ram, repair same. l '4110200806:00 ~ 6 00 4/1012008 12:00 'Rig Up / F2ig Down" i 121/4 remove dewatering unit breeie way pull pAs and ODS tooktouse out and load same ' (tower demidc I ( , , on s: rep' darrick for removal 4/10/200812:00 6.001,4/10/200818:00 Rig Up /Rig Down"" ~ 12 1/4 Prep denick for removal, unstring blocks, remove derrick and load same on trailer, prepare utdrty ', ' buildings for removal 4/10200818:00 I 6.00 4/11/2008 00:00 l Rig tJp /Rig Darn" 121/4 'Load Dogttotue; change house and erttire balk yard. All. rig camporte[s off the weft at 23:30 hrs. pull ', divener tee fromwetlhead. I ' 4/11/2008 00:00 6.00,4/11/2008 06:00 Rig Up /Rig Down'" 12 1/4 Rig down Shop, Cut off wellhead below 4" outlets, pick up mats, cut up herculite and throw away '' 'junk pieces, make up truck loads. 4/11/200806:00 ~ 6.00 4/1112b08 1200 i Rig UP 1 Rig Down'° 112114. 1 Tnxika Fjauling rqf loads. Make final cW on k:ondrrdor and instaN iderdification plate. Abartdortmertt I i Witnessing was waived by AOGCC Inspector John Crisp. t" j i ~ T fRig crew assisting tearing down Ayeska camp. Trucks hauling rig loads. 1 4/11/200812:00 6.00'', 4/11/2008 18:00 Rig Up /Rig Down" 12 1/4 Rig down Alyeska camp, continue hauling rig and junk loads from Panthers. Backfill Panthers cellar 2nd rig crew removing light and landings from rig equipment at Franklin Bluffs 4/11/200818:00. ~ 6.00 4/122008 00:00 Rig Up /Rig Down"" 12 114 ~ I Rigging down and trucking Alyeska camp. + - 35 toads left to !taut from Smibdon at 24:00: hours 4/122008 00:00 7.0014/12/2008 07:00 Rig Up /Rig Down" 12 1/4 No activ'Ry (Crew rest ) _._ t~afron I Chevron -Alaska Time Log Summary Sort ' Well Name Field flame - APIMM - - '. Lease/Banal ---CHEVNO License No.IPropertyC '~,Orig KB Elev (IlKB) Water Depth (ft) PANTHERA28~-9 ..Exploration .502232002300 'ADL380003 LE3051 .208033 370.0 MSSTart Gate - Dur (txs) i . _:. '. pro ___ -`~.~i.... 4112/20081&~ i S.OOf 4/13/100800:00 4/13/2008 00:00 7.OOI4/13/2008 07:00 4113/200807:00.. i 12.00~4/13J20081900 4/13/2008 19:00 ''. j S.OOI4/14/2008 00:00 4/14/200800:00 ~ 8.5011 4/1 4/20 0 8 0 8:30 4/14!2008 06:30 ', 12.0014/14/200818:30 4114/2008 18:30 5 504l15Y2008 00:00 4/15/2008 00 00 6.30 i 4/15/2008 06:18 4/15f2p08 06;18 12 00 4115/200818118 4/15/200818:18 5.50 4/152008 P3:48 M162008 00:00 j 6.00 4/16!2008 06:00 4/16/2008 06.00 4/16/2008 06:30 4/17/2008 00:00 4!17!2008 06'00 ~ 4/17/2008 06:30 0.50 4/16/2008 06:30 11.50:4/162008 18:00 1Z t/4 '~. PTSM with both views. Pull lights from components and store same. Prep subbase for splitting, prep derrick for splitting, prep drawworks for splitting. Assist setting up Alyeska camp at FB. Drain oil from #2 pump. Inspect crossheads on # 2 pump. Clean ice off of building skids. Clean ice and snow off pipe shed roof. Remove cattle chute from pipe shed. Remove exhausts from motors and ', boilers. Cap elecfrical and hydraulic lines. Road loader and stinger from Smilodon to Franklin Bluffs I '' f Rig t!p /Rig Down"` 121!4 I No activity (Crew rest) 12 1 /4 I No activity (Crews resting) f Rig Up /Rig Down" ,12 t/4 tBuikf contairsnent bean around Alyeska Camp fuel ra31F. Insulate camp; Split Sub base, Remove I ' 'BOP trolty, remove Rotary table, prep Denick to be spld. Prep # 2 mud pump to pull traction motor '~ I ~, module from Pump skid module, Service Mud pump #2. Break apart 13-5/8" BOP stack and send ~ ~.. ~. south to Kenai. Split drawworks skid apart. ~ '~, Continue chipping & melting Ice from. Smibdon pad and Panthers pad: i 12 1/4 No activity (Crews resting) ~. 1'2:1/4 ~No Aclivity (crew rest) I ' Rig Up /Rig Down"" 12 1/4 ,Spilt Derrick, VFD From Gen control, Generator #1 from Boiler #1, Generator # 2 from Boiler #2, ', Generator #3 from Fuel tank, Hot well From Koomie, all Load weights checked are under 40K. ',Service #1 Mud pump and Check Tolerance, Change out break actuator on Top Drive, weld ', Hammer seal on suction line mud pump # 1 1ii21/4 'f No AcGvily (crew rgst)` Rig Up /Rig Down" 12 1/4 No activity (rest Crew) "Rig Up 1 Rg Down" 12`1/4 i ~RSM (Lazenby) and DSM (Purugganan) changedouttoday went over plan f+cr~ward. Tacked over t plan forword wdh Don Fowler and Quick for Nabors completing rig staging and labor out by Friday. - I Continue to break down rig, line up to drain radiators and fluids will get Dean barrels to drain Imo for reuse. Remove Uadion motors. Gather up tools and equipment to put in tool cortex. ~~ 12 1/4 No activity Rest crews Rig UD / Rg Down" 12 1/4 No activity rest crew for night. Rig Up /Rig Down"' ~I12 1/4 PTSM ~, Rig Up /Rig Dawn" 12 1/4 Drain hydraulic oil F/HPUS, Orain oils in drawworks. Load skids and seaae loose parts on loads '. .Clean out units to prep for shipping. remove and plug plumbing on pumps, adjust all weights to i 6.0014/17/2008 06:00 I Rig Up / Rg Down"* 0 50 4/1712008 08:30 Rig Up! Rig Do+m" 7.0014/17/200813:30 i !,Rig Up /Rig Down"* 1812008 00100 ! 6.00 ~ 4!18/2008 06:00 'Rig Up /Rig Down" 18/2008 06:00 0.504/18/2008 06:30 i Rig UP I Rig Down" 18/2008 0630 ' 11.50 4/'1812008 18,00 Rg Up /Rig Down" .under 40K . Cruz winch truck view finished at 12:00, flew ord on 3:00 plane 12 1/4 ' No Activity Rest Crew 112 t/4 i PTSM with all on board ~ 12 1/4 'Cleaned and prep truck shop, disassemble truck shop for shipping. Drained all radiators into tote to '~ ship wRh rig. Located all oily waste and used oil to be shipped off. Chained down iron in iron rack. I I Secured items in units. Filled cortex with tools and office material prep for shipping to Kenai. Helped I, ,Alyeska camp shut all window covers. Crane crew will be finished in the moming, Peak will leave ',crane at Franklin Bluff. Nabors and Peak will park crane and loaders on liner material NAD will be ' '~, ~'~., done in the moming and catch the noon charter. 12 {f4 ~No erctivdy 12est view ~~~ 12 1/4 PJSM with all on board 12 t/4 'Crews finished chaining down loads, clean out office in Galena camp, load office supplies and I II malarial iMO twxes and put in cortex. Loaded cortex, NAD pickup, 2 ea mud boxes Nabors pans BOPlRings and ng hands duffel bags ship to Kenai. Larry Sliger and AK Telecom on site fimshed taking dam communications in Galena camp, all CVX owned equipment being slopped to Kenai { I OSK dock for storage. Doyon US ceaning Galena camp, wiN be out tomorrow am I rThts is the fmat report. J~1__ _ _ _ - - _ _ -_ ~ I .7 • pits. 4/7/2008: Wait on Cement. TIH to 215'. Pump 211 bbls of e L 10.7 ppg cment. Cement to surface after 206 bbls. Wash out Type L cement to 25'. Pump 91 bbls Type C. 27 bbls of good cement back to surface. LD Tubing nd cleaning pits and RD for Demob. 4/8/2008: Continue RD for Demob 4/9/2008: Continue RD. RELEASE RIG from Panthera 4/10/2008: Continue RD and Demob of Rig to Franklin Bluffs 4/11/2008: Cutoff Wellhead and install well identification plate. Witness ived by John Crisp. TOOH with bit. 4/5/2008: LD Drill pipe. PU tubing. Set cement lug from 906'. WOC. TIH & Tag cement @ 422'. 4/6/2008: Clean mud tanks 1 & 2 while waiting on C ss L cement. TIH to 405', Circulate B/U, pump 251 bbls on 10.7# class L cement, T H, TIH to 200', circ B/U, WOC. TIH and tag cement at 295'. Wait on SLB Arctic et Light cement to arrive, clean mud Panthera 28-6-9 Exploration Well Lower Foothills, White Hills Prospect O erati s Summar PTD No. 8-033 (All depths RKB unless labeled otherwise) ~ 3/24/2008: igging down and preparing to move to Panthera S~ Q~~~ ~~~~ 3/25/2008: ove rig from Mastodon to Panthera Set in and rig up rig ~~ 3/26/2008: Ri Up. 3/27/2008: Rig .Contacted John Crisp with AOGCC @10:05 AM, concerning Diverter test. 3/28/2008: Rig NUBOP. Diverter function test. Test gas detection system. Take on 525 bbl mu Tally drill pipe. Finish RU pits and dress shakers and centrifuge. Pick up DP and H DP. 3/29/2008: Complete R' Up. Spud well. Drill to 276'. PU BHA #2. 3/30/2008: Complete P f BHA. Drill to 608'. Repair Top Drive. Drill to 1044'. 3/31/2008: Drill to 2020', urface casing point called at 2020'. Circulate hole clean, started TOOH to 1925'. - 4/1/2008: TOOH, working t ough tight spots. Lay down MWD tools, M/U clean out BHA, TIH to 2003' -had to ash and ream. Hole Packed off at 2003', attempted to circulate and backream, backrea to 1926' with no circulation. Pumped away 120 bbls. 4/2/2008: BHA Stuck. Work Stuc Pipe. RU Baker Atlas WL. Run Freepoint. Run Severing charge and sever pipe in DP. TOOH with DP. 4/3/2008: Unable to Establish Circula 'on. TOOH. PU Mule shoe and OEDP. TIH Circulate BU every 5 stands. Tagged d Plugged Pipe @ 1227'. Clear Plug with 1400 psi. Circulate and attempt to clean a hole. Hole seems to be filling in. 4/4/2008: Reciprocate Pipe. Started Tagg up at 938 then 933. TOOH with OEDP and TIHwith bit. Attempt to wash and am. Progress to 854 to 918. Gain and lose hole. UNION OIL CO OF CALIFORNIA Panthera 28-6-9 50-223-20023-00 PTD # 208-033 Final Report Summary 1 • • • Chevron raninera purvey rcepvrt Report Date: 5-Apr-08 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: Chevron Vertical Section Azimuth: 1.000° Field: White Hills Chevron Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: Panthera /Panthera TVD Reference Datum: Rotary Table well: Panthera TVD Reference Elevation: 372.00 ft relative to MSL ~ Borehole: Panthera Sea Bed 1 Ground Level Elevation: 349.00 ft relative to MSL UWIIAPI#: 502232002300 Magnetic Declination: 22.546° Survey Name I Date: Panthera /April 2, 2008 Total Field Strength: 57580.199 nT Tort I AHD I DDI I ERD ratio: 2.114° 117.73 ft / 1.574 / 0.009 Magnetic Dip: 80.478° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: April 04, 2008 Location LatlLong: N 69 51 9.623, W 149 53 9.808 Magnetic Declination Model: BGGM 2007 Location Grid NIE YIX: N 5795581.000 ftUS, E 514375.000 ftUS North Reference: True North Grid Convergence Angle: +0.10697007° Total Corr Mag North •> True North: +22.546° Grid Scale Factor: 0.99990023 Local Coordinates Referenced To: Well Head L Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft (ft ft ft de 1100 ft ftUS r~ncro. nn ftUS C4 AO~C nn nl cn c~ n cow ~ni ~ nn c~ n Qnsz KIt U.UU V.VV V.UV -J/L.UV V.UV U.VV V.VV V.VV V.VV V.VV V.VV JI JJJV I.VV JItJ~J.VV Iv vJJI J.v~J vv ,t:i VV :i.VVV MWD 296.01 0.09 69.95 -75.99 296.01 0.08 0.23 0.23 0.08 0.22 0.03 5795581.08 514375.22 N 69 51 9.623 W 149 53 9.802 416.85 0.09 325.34 44.85 416.85 0.19 0.38 0.32 0.19 0.25 0.12 5795581.19 514375.25 N 69 51 9.624 W 149 53 9.801 540.53 0.06 140.19 168.53 540.53 0.22 0.41 0.33 0.22 0.24 0.12 5795581.22 514375.24 N 69 51 9.625 W 149 53 9.801 661.60 0.14 205.37 289.60 661.60 0.04 0.60 0.22 0.04 0.22 0.10 5795581.04 514375.22 N 69 51 9.623 W 149 53 9.802 783.72 0.10 146.89 411.72 783.72 -0.18 0.84 0.28 -0.19 0.21 0.10 5795580.81 514375.21 N 69 51 9.621 W 149 53 9.802 905.92 0.45 189.82 533.92 905.92 -0.74 1.41 0.77 -0.75 0.19. 0.31 5795580.25 514375.19 N 69 51 9.615 W 149 53 9.803 1034.42 0.72 208.02 662.41 1034.41 -1.96 2.71 1.98 -1.96 -0.28 0.25 5795579.04 514374.73 N 69 51 9.603 W 149 53 9.816 1164.27 0.79 212.60 792.25 1164.25 -3.45 4.42 3.62 -3.43 -1.14 0.07 5795577.57 514373.86 N 69 51 9.589 W 149 53 9.841 1292.17 0.80 216.70 920.14 1292.14 -4.93 6.19 5.34 -4.89 -2.15 0.05 5795576.11 514372.86 N 69 51 9.574 W 149 53 9.870 1420.67 0.98 224.67 1048.62 1420.62 -6.45 8.18 7.27 -6.39 -3.46 0.17 5795574.60 514371.55 N 69 51 9.560 W 149 53 1550.27 1.02 223.87 1178.20 1550.20 -8.10 10.44 9.46 -8.01 -5.04 0.03 5795572.98 514369.98 N 69 51 9.544 W 149 53 1678.57 0.89 223.26 1306.48 1678.48 -9.67 12.58 11.57 -9.56 -6.51 0.10 5795571.43 514368.51 N 69 51 9.528 W 149 53 9.994 1806.67 0.80 218.31 1434.57 1806.57 -11.12 14.47 13.44 -10.99 -7.75 0.09 5795570.00 514367.27 N 69 51 9.514 W 149 53 10.029 Last Survey 1936.71 0.91 221.29. 1564.60 1936.60 -12.63 16.41 15.38 -12.48 -8.99 0.09 5795568.51 514366.03 N 69 51 9.500 W 149 53 10.065 TD (Projected) - 2020.00 0.91 221.29 1647.88 2019.88 -13.64 17.73 16.70 -13.47 -9.87 0.00 5795567.51 514365.16 N 69 51 9.490 W 149 53 10.090 Legal Description: Northing (Y) fftUSl Easting (Xl fftUSl Surface : 5089 FSL 850 FEL S28 T6N R9E UM ~ 5795581.00 514375.00 BHL : 5076 FSL 860 FEL S28 T6N R9E UM - 5795567.51 . 514365.16 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Panthera\Panthera\Panthera\Panthera Generated 5/5/2008 2:14 PM Page 1 of 1 J • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION I 2-4-08 SAS KWA SHOW NEW PAD LOCATION AND CONFIGURATION W W ~ W ~ ~ ~ O - i ~ ~ ~ ~ '~ T i 7 N _~~ ~, . ~~ ` ~ \ J ER R ~ SCALE: PANTHERA ~ UK R ~ p 1" = 200' ~ ~ KUP . NOTES: ~ ~ / ~ -._ 1. COORDINATES SHOWN ARE NAD 27 T 6 N ALASKA STATE PLANE ZONE 4. 2. GEOGRAPHIC COORDINATES ARE NAD / T 5 N 27. / 3. ALL DISTANCES ARE GROUND. ~ ICE ROAD 4. ICE PAD IS ROTATED 70° EAST FROM NORTH. 5. VERTICAL DATUM IS ASSUMED. VICINITY MAP 1" = APPROX. 3 MI. 300' ~ PANTHERA ~~~500~ ` ~ LOCATED WITHIN PROTRACTED 0^ ~ ET5 ~ N SEC. 28, T 6 N, & R 9 E, N yNG ePSK sroRncE t UMIAT MERIDIAN. GP /,, ~ , ~ ~ ~, 190' F.N.L, 850' F.E.L. G„to a E~`` , ~ ~ / N LAT = 69°51'09.626" N ~ \;TwG"E" ~'~ ~ ~ ~ LONG = 149°53'09.816" W IOE~ ~ ` m ` Y = 5,795,581' . ~O ` ~ X = 514,375' ~ DRILL PIPE Z ;O ` ~ ~ PROPOSED 135' ACCESS O O -, ~ O MUD I ' ` - E ~ ROAD GG SrORA GE ~N D IG !ICKE p ~ LEGE ND ~ ~ iP S ~ ` ~ o~RjO 'CAMP ./ ~~ DENOTES SPILL TRAJECTORY '~~ ~° ~ 500 ~ STAKED CONDUCTOR LOCATION v~ ~7 0" / ICE P D LIMITS A LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS o ~ PANTHERA EXPLORATORY WELL 1 ~ ~ ~l AS-STAKED DRAWI NG WITH PAD CONFIGURATION UNION OIL OF CALIFORNIA INCLUDING CONTOU RS AND SPILL TRAJECTORY CADD FILE N0. DRAWING N0: SHEET: REV: PANTHERA 9-25-07 PANTHERA.dwg I OF I I i RKB-GL 23.00' GL 101' Csg 0' TOC 15.6 ppg 232 sx - 1^ RKB-MSL - MsL 372.00' _ -.. hI I' I 3^ Bottom Of Cement Plug 906' 1 2 Top Of Fish 3 / 1720 4 5 2,020' TD Panthers 28-69 White Hills Exploration 28,T6N,R9E,UM • to Drill#: 208.033 8 Serial#: ADL-390003 20023-00-00 lion Well Operator: Union Oil of Cal Ownership: Union Oil Company of California 100% GL-MSL: 349 Spud Date: 3/29/08 9:00 AM RKB-MSL: 372 Other: Spud Mar 2008; Plugged April 2008; Abandoned April 2008 ~c~ ,yNc., ~c,~,~a, - 200') SLB Arctic Set Lite -- 238) Type L Permafrost -- 421'1 Tme L Pertnafmst Zone L _„r ~''_'~ .m n, x i t s, j~. . r~ ;s r .3 ~,`~7 s `~ ... P,inth~ra V'am~~~~l~it~• ~' • ,~:~ ..~ r' ~ _ xF €<, .' ~~; K~1 [~. ~ ~ ~~ _ v ~~ i~.. Panthera Cutoff _, r, _. .. ,. ~ ..,M a IK ~jh; ~: ~~ jw.« ~3i~t .. • ~:.. X, i .. ~~ : ~ ~~ Mme' Panthera After Backfill CHEVRON Chevron U.S.A. P.O. Box 36366 REQUEST DATE Houston, TX 77236 04/29/2008 11111 S. Wilcrest Houston, TX 77099 s H AOGCC ~ 333 W 7th Ave Ste 100 P Anchorage, Alaska 99501 T United State America 0 Shipped Via: DHL No. Zoos-aa~2s ORIGINAL TRANSMITTAL OF CONFIDENTIAL DATA From: David Guthman Sent by: Norma Blake Panthera 28-6.9 API: 50.223.20023.00 QUANTITY DESCRIPTION AREA Survey Product REMARKS 2 (CD's) Panthera 28-6-9 Well Log Data - White Hills Well Data GD CD1. PDS and LAS Files Of Processed SonicVision Bit Run 1, Start: 158ft-1973ft. CD2. Drlg Mech Digital Data &PDS Logs LWD Form Eval dig data and PDS Log Directional S Data 7 Log Prints - Panthera 28-6-9 White Hills Well Data Log Schlumberger 1). BestDT Final Result SonicVision Prints 2).Vision Res MD Log Recorded Mode Field Print 1:240 3). Vision Res MD Log Recorded Mode Field Print 1:600 4). DRL Format Drlg Process and Mech (Depth) Log, Recorded Mode Fld Print, Surface and Downhole Data ~c~~-~3 5). TRP Format Drlg Process and Mech (Time) Log, Recorded Mode Fld "~= /~ ~3 Print, Surface and Downhole Data 6). VISION Resistivity -SONIC MD Log Recorded Mode Field Print 1:240 7). VISION Resistivity -SONIC MD Log Recorded Mode Field Print 1:600 1 Survey Report, Drilling and Measurements Fld -White Hills Documentation - Su ort Schlumber er DATE SHIPPED VIA CHEVRON TRANS. NO AIR WAYBILL # 4/29/2008 DHL CH-2008429-0000 27066679253 PLEASE ACKNO EDGE RECEIPT OF MATERIAL BY SIGNING AND RETURNING COP - 92 /i ~ r..~.....,.. Date f•1NY n ~ ~nnT_ Kaska Qii ~ Gas Cons. Commission Anchorage an9i~nnQ ~ _ i • !~~ ~ ~,~~~IDc~ ~~ l -- ~~. __ ..~__a~ _.~ Casing cut-off; cement to surface; Panthera 28-6-9 ' AOGCC waived witness of surface abandonment; Chevron photos document cement to surface, casing cut-off, and installation of marker plate w/correct information; Chevron contact is Abraham Purugganan, Drillsite Manager (abrahan~~chevron.com ) x ; ~ ~ ~ ~, ~~~ ~ ~ ~ ~ ~ ~~ -. _- ~~ q ~_ ~;~ :~ n ~ ~ ~ " ~ ~~ ~ r ~ ~_~ ~ ~~ • Marker plate installation; Panthera 28-6-9 2 Panthrea P&A cap pictures ~ • Page 1 of 1 Regg, James B (DOA) From: Crisp, John H (DOA) Sent: Friday, April 11, 2008 11:00 AM ~ ~~ ~, ~ `~`~~ To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA) Subject: FW: Panthrea P&A cap pictures Attachments: DSC01526.JPG; DSC01527.JPG; DSC01528.JPG; DSC01523.JPG; DSC01524.JPG; DSC01525.JPG From: Purugganan,Abraham [mailto:ABRAHAMP@chevron.com] Sent: Friday, April 11, 2008 10:13 AM To: Crisp, John H (DOA) Cc: Dunn, Tom [ASRC]; Harness, Evan; Fowler, Don P Subject: Panthrea P&A cap pictures «DSC01526.JPG» «DSC01527.JPG» «DSC01528.JPG» «DSC01523.JPG» «DSC01524.JPG» «DSC01525.JPG» Abraham K, Purugganan Drill Site Manager MidContinenbAlaska SBU Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501 Office 907-771-7451 Or 907-771-7452 (Rig 106, Panthrea) Office Cell 907-230-7262 FAX 1-866-647-2479 abrahamp@chevron.com CAI; puab Mail Confidential Footer Privileged/Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 230-7262. 4/14/2008 " `._. e._` .J ~ ~ ~~,, ~ f ~ ~. SARAN PAL/N, GOVERNOR CO~T~~~~~~0 n ~~+~ 333 W. 7th AVENUE, SUITE 100 1` li 1~0111~~•~~~ill~~•iii ----777 0l` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Brandenburg Drilling Manager UNOCAL PO Box 19647 Anchorage, AK 99519 Re: Exploration, Wildcat, Panthera 28-6-9 Sundry Number: 308-126 Dear Mr. Brandenburg: 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. Sincerely, ~~~ vv~~~ DATED this l day of April, 2008 Daniel T. Se~iount, Jr. Chair Encl. 2~ ^033 ,~a~v`.~v~. c -~,0~,~~ STATE OF ALASKA ~ APR 0 2008 ~ 8S4LASKA OIL AND GAS CONSERVATION COMMISSION ~ $ ,~~ APPLICATION FOR SUNDRY APPROVAL k Alaska Oil & Gas Cons. Commission 20 AAC 25.280 . _ _ ~ _ __ _ _ 1. Type of Request: Abandon^~ ~ Suspend ^ Operational shutdown ^ Perforate ^ Waiver 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: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ 208-033 • 3. Address: Stratigraphic ^ Service ^ 6. API Number: P.O. Box 19647, Anchorage, AK 99519 50-223-20023-00 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 ~ Panthers 28-6-9 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADN 42 if~~ ap~3 ~f'O$ 370 None 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): 2020' 2020 2020 2020 1720' Casing Length Size MD TVD Burst Collapse Structural Conductor 80 16 102 102 Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type: Packers and SSSV MD (ft): 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program^ BOP Sketch ^ Exploratory^ , Development ^ Service ^ 15. Estimated Date for 6-Apr-08 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ Plugged ^ Abandoned^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ ~,/~~ Commission Representative: ~GpQ~-g~~~ ~~K-~~ ~Gy 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Walter Quay 263-7812 Printed Name Tim Brandenburg Title Drilling Manager Signature ~ Phone 263-7657 Date 7-Apr-08 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ -' ~ a~ ^ Location Cl ea ^ Mechanical Integrity Test rance ~ - S~1e~i~~r aQ~ Plug Integrity ~ BOP Test ~` `` ~ ` ~5~'al''F ~ ~~S O~_ cV t0~ t~~~~ Other: ~n~~~~Ks~~ C'TO r ~ W ~~iS ~ ^^ v.)2~~ S~OJ`U ~~ a~~~ t~C`t~ . ~~~., l~PG ~ ~ 1QQ$ Subsequent Form Required: ~(' APPROVED BY COMMISSIONER THE COMMISSION Date: A d b pprove y: n R .9.~3 Form 10-403 Revised 06/2006 1,J ! ~ I G Submit in Duplicate Proposed Plugback Panthera 28-6-9 N DEPTH INFO DEPTH-RKB(23') ELEV-GL 349' HOLE FISH INFO MUD INFO CEMENT INFO CASI G MD TVD TVDSS DEPTH-RKB 23' 16" TOC 5' 65 Ib/ft, H-40 15.6 ppg Type C Welded 16" Conductor 102' 102' -102' 24" Permafrost Top of Type L 200' ~ -at~a r ~ rip,, ~u', ;S ,: ~ r :' _ `~ ~. - _ + ~ 11.7 ppg Type L 4 s e. , -°' r r Permafrost ~ ' ~ .~ ? ~ 200Yo Excess »- :x~ .^ka~.: .. , . ~ , f ~ _ r ~ »•. .~+'• < ~~ ~~ t 900' ~#.~"%~ ~ ` ~ ~ ~ - ~ Tao Of Fill ~ ,:~;i' ' ' ' - ' '' Top of Cement 1,320 1,320 -1,320 Base Permafrost 1,440' 1,440' -1,440' Top of Fish - 1,720' 1,720' -1,720' q I } ~ HWDP (Cut) Jars i` 1 Crossover ~6 ~. ~ { , ~ Spiral Drill Collar ~ ` I Crossover 9.3 ppg i ~ Water Based Mud NM Dnll Collar I NM Dnll Collar I NM Stabilizer f!- '- ~ Mud Motor Top of Fill 2,003' 2,003' -2,003' ~_~ 12-1/4" Bit TD Hole Section 2,020' 2,020' -2,020' 12-1 /4" WBD Panthera Plugback Surface.xls 4/7/2008 Chevron u Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, AK 99519-6247 Fax 907 263 7884 RECEIVE Apri17, 2008 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7a' Avenue Anchorage, Alaska 99501 Re: Plug and Abandon Panthera 28-6-9 Exploration Well Dear Commissioner: APR Q 8 2008 Alaska Oil 8~ Gas Cons. Commission {~nChO~ag@ Attached for your approval is an Application for Sundry Approval (Form 10-403) for the above referenced well. This well was drilled to surface casing point of 2020', encountered hole problems on the clean out trip, sticking the drilling BHA. Subsequent attempts to free the BHA were unsuccessful, followed by severing the BHA(fish top of 1720') and attempting to set a plug to sidetrack around the severed BHA. The attempts to set the plug were unsuccessful as the hole conditions deteriorated, losing the hole back to 900'. Due to these deteriorating hole conditions and no viable way forward the decision to the abandon this well was reached. The attached P&A procedure received verbal approval on Apri14 as per the E-Mail stream attached. If additional information is required, please contact either myself or Mr. Walter Quay at 263-7612. Pertinent information attached to this application includes the following: 1. Form 10-403 Application for Sundry Approval 2. Abandonment Procedure 3. Wellbore Schematic 4. E-Mail Log or Oral Approval Sincerely, .._-_ ~ _ Timothy C. Brandenburg Drilling Manager Cc: Well File Union Oil Company of California / A Chevron Company http://www.chevron.com • E-Mail Log of Oral Approval From: Maunder, Thomas E (DOA) Sent: Friday, April 04, 2008 6:14 PM To: 'Quay, Walter [ASRC]' Cc: Brandenburg, Tim C; Harness, Evan; AOGCC North Slope Office Subject: RE: Panthera P&A • Walter, I have spoken with Commissioner Foerster and she has given her oral approval to proceed. Call me on the cell if you need anything. Better luck!! Tom Maunder, PE AOGCC From: Quay, Walter [ASRC] [mailto:WQuay@chevron.com] Sent: Friday, April 04, 2008 5:48 PM To: Maunder, Thomas E (DOA) Cc: Brandenburg, Tim C; Harness, Evan Subject: RE: Panthera P8cA I will work up the Sundry and will include the description of the ops to this conclusion. I would expect the plugging to start early tomorrow. Walter Quay From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, April 04, 2008 5:46 PM To: Quay, Walter [ASRC] Cc: Brandenburg, Tim C; Harness, Evan Subject: RE: Panthera P&A Walter, et al, This is as we discussed. When do you foresee the plugging beginning? As you know, a sundry is eventually required. You might include some description of what occurred to get to this point. I look forward to your reply. Tom Maunder, PE AOGCC From: Quay, Walter [ASRC] [mailto:WQuay@chevron.com] Sent: Friday, April 04, 2008 5:43 PM To: Maunder, Thomas E (DOA) Cc: Brandenburg, Tim C; Harness, Evan Subject: Panthera P&A Tom, Here is the P&A proposed for Panthera as we discussed via phone. I will confirm sacks of cement with Mark Wedman. «WBD Panthera Plugback Surface.pdfi> «PlugandAbandon.doc» Walter Quay WQuay@chevron.com Union Oil Company of California / A Chevron Company http://www.chevron.com Panthera P&A ~ ' Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, April 04, 2008 6:17 PM y~ To: 'Quay, Walter[ASRC]' ~v~~~~ Cc: 'Brandenburg, Tim C ; 'Harness, Evan'; AOGCC North Slope Office Subject: RE: Panthera P&A Walter, et al, One item I forgot. Have your Company Man stay in touch with the Inspector. Not sure he will be available for any of the cement placement, but be sure to call on the cutoff. Photos of the cutoff, plate and final weld up should be obtained. Thanks, Tom From: Maunder, Thomas E (DOA) Sent: Friday, April 04, 2008 6:14 PM To: 'Quay, Walter [ASRC]' Cc: Brandenburg, Tim C; Harness, Evan; AOGCC North Slope Office Subject: RE: Panthera P&A Walter, I have spoken with Commissioner Foerster and she has given her oral approval to proceed. Call me on the cell if you need anything. Better luck!! Tom Maunder, PE AOGCC From: Quay, Walter [ASRC] [mailto:WQuay@chevron.com] Sent: Friday, April 04, 2008 5:48 PM To: Maunder, Thomas E (DOA) Cc: Brandenburg, Tim C; Harness, Evan Subject: RE: Panthera P&A I will work up the Sundry and will include the description of the ops to this conclusion. I would expect the plugging to start early tomorrow. Walter Quay WQuay@chevron.com Office: 907-263-7812 Cell: 907-230-3961 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, April 04, 2008 5:46 PM To: Quay, Wa{ter [ASRC] Cc: Brandenburg,. Tim C; Harness, Evan Subject: RE: Panthera P&A 4/512008 Panthera. P&A ~ ~ Page 2 of 2 Walter, et al, This is as we discussed. When do you foresee the plugging beginning? As you know, a sundry is eventually required. You might include some description of what occurred to get to this point. I look forward to your reply. Tom Maunder, PE AOGCC From: Quay, Walter [ASRC] [mailto:WQuay@chevron.com] Sent: Friday, Apri104, 2008 5:43 PM To: Maunder, Thomas E (DOA) Cc: Brandenburg, Tim C; Harness, Evan Subject: Panthera P8u4 Tom, Here is the P&A proposed for Panthera as we discussed via phone. twill confirm sacks of cement with Mark Wellman. «WBD Panthera Plugback Surface.pdf» «PlugandAbandon.doc» Walter Quay WQuayt~chevron.com Office: 907-263-7812 Cell: 907-230-3961 4/5/2008 • • Panthers P&A Procedure 1. TIH with OEDP to 900' 2. Mix and Pump 415 sacks of 11.7 ppg Type L Permafrost Cement(Yield 4.1 S ft/sx). Desired TOC @ 200'. 3. POOH to 200'. Circulate and confirm cement is present 4. WOC for 12 hrs or until surface samples have sufficient support far surface plug. 5. Mix and Pump 350 sacks of 15.6 ppg type C Permafrost Cement(Yield .95 ftlsx). Desired TOC @ 5' below ground level. 6. Complete Surface abandonment with conductor cut and Well abandonment marker. i • Proposed Plugback Panthera 28-6-9 CASING DEPTH INFO DEPTH-RKB(23' ELEV-GL 349' HOLE FISH INFO MUD INFO CEMENT INFO MD TVD TVDSS DEPTH-RKB 23' 16" TOC 8' 68 Ibrtt H-40 15.8 ppg Type C Welded i8" Conductor 102' 102' -107 24" Permafrost Top of Type L 20a ' ;~ e, t" ,i ' [ : : -~ ti~. ' 11.7 PP9 TYPe L _y, +, ~~, •p ~~- . ~„`r-~" Permafrost t`.~ ~~"~~ ~. f ~. 200%6ccess ' ~{~• -~' ` ; ?r„ -,+ :~ • t. • .: 90a ~ - Too OF Fill Top of Cemerd 1,32a 1,32a -t,32a ; Base Permafrost 1,44a 1,44a -1,44a j. - ~~ Top of Fish 1,72a 1,72a -1,72a ~ HWDP (Cut) Jars Crmsover Spial prig Collar Crossover 9.3 ppg Wa[er Based Mud NM Dnl Collar NM Dri1 Coger NM SabiNzer Mud Motor i Top of Fill 2,003' 2,003' -2,003' 1~arr - - - - 12-1/4" BR TD Hole Section 2,02a 2,020' -2,02a - - ~2-~'4" WBD Panthera Plugback Surface.xls 4/4/2008 . ~,. Drilling & Measurements 2525 Gambell Street. Suite 400 Anchorage AK 99503 Tel (907) 273-1700 Fax (907)561-8317 Date: Well Name: Company: API Number: AFE Number: Location: Field: Rig: Drilling and Measurements Field Support: Drilling and Measurements Field Crew: SERVICES PROVIDED 07-Apr-2008 Panthers 28-6-9 Union Oil Company of California 50-223-20023-00 UWDAK-E8001 DRL X= 514,375.OOft US Y= 5,795,581.OOft US White Hills Nabors 106 Schlumberger Operations Manager: Julio Loreto Field Service Manager: Franklin Medina Cell Manager(s) Rene Franco Cell Engineer David Ziegahn Services Services Dates Depth Intervals Directional Survey Service 29-Mar-08 to O1-Apr-08 200 ft to 2020 ft PowerPulse* (Direction and Inclination) 29-Mar-08 to O1-Apr-08 200 ft to 2020 ft ARC* (Gamma Ray, Resistivity) 29-Mar-08 to O1-Apr-08 200 ft to 2020 ft sonicVISION* 29-Mar-08 to O1-Apr-08 200 ft to 2020 ft OPERATING STATISTICS Total MWD Pumping Time: 45.14 hr Total MWD Time Below Rotary: 62.5 hr Total MWD Depth Interval: 2020ft Total MWD Runs: 1 JOB PERFORMANCE Directional Total LWD Pumping Time: 45.14 hr Total LWD Time Below Rotary: 62.5 hr Total LWD Depth Interval: 2020 ft Total LWD Runs: 1 The final MWD survey point was 1936.71 ft with an inclination of 0.91 degrees and an azimuth of 221.29 degrees. A survey was straight line projected ahead to TD, making the final bottom hole location as follows: Measured Depth: 2020.00 ft True Vertical Depth: 2019.87 ft Displacement at Azimuth: 16.70 ft at 216.22 deg ~~`~ -~ • Formation Evaluation 12 1/4 inch Surface Hole: This section was drilled in using PowerPulse* (D&I), ARC (Resistivity, Gamma Ray) Real-time and Recorded Mode, sonicVISION* Service (Delta-T Compressional) Real-time and Recorded Mode. This run was drilled from 277 ft to 2020 ft. Once tools were on surface, recorded data was dumped and final memory logs were created and were available on InterACT for download. SonicVISION* was run in Real-time and Recorded mode, data from memory was processed by Schlumberger DCS, and was available on InterACT for download. Schlumberger's IWW system was used to send real-time surface and down-hole data to InterACT for the run. After TD 12.25 in section, LWD tools were laid down and then RIH with clean out BHA. This clean out BHA was lost in hole and a decision was made to Plug and Abandon the hole. Schlumberger Oilfield Services -Drilling & Measurements appreciates the opportunity to provide Union Oil of California with MWD and LWD services. Sincerely, Rene Franco Cell Manager Schlumberger Drilling & Measurements 2 :~ ..~ Panthera 28-6-9 Survey Report Report Date: April 5, 2008 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: Chevron Vertical Section Azimuth: 90.000° Field: White Hills Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure /Slot: Panthera /Panthera TVD Reference Datum: Rotary Table Well: Panthera TVD Reference Elevation: 372.0 ft relative to MSL Borehole: Panthera 28-6-9 Sea Bed I Ground Level Elevation: 349.000 ft relative to MSL UWVAPI#: 50-223-20023-00 Magnetic Declination: 23.053° Survey Name /Date: MWD /March 29, 2008 Total Field Strength: 57518.734 nT Tort /AHD / DDI / ERD ratio: 2.114° / 17.69 ft / 1.573 / 0.009 Magnetic Dip: 80.478° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: March 29, 2008 Location Lat/LOng: N 69 51 9.623, W 149 53 9.808 Magnetic Declination Model: BGGM 2005 Location Grid N/E Y/X: N 5795581.000 ftUS, E 514375.000 ftUS North Reference: TNe North Grid Convergence Angle: +0.10697007° Total Corr Mag North -> True North: +23.053° Grid Scale Factor: 0.99990023 Local Coordinates Referenced To: Well Head ~ Projected to TD 296.01 0.09 69.95 296.01 0.22 0.08 0.22 0.23 69.95 0.03 325.34M SLB_MWD-STD 416.85 0.09 325.34 416.85 0.25 0.19 0.25 0.32 53.11 0.12 140.19M SLB_MWD-STD 540.53 0.06 140.19 540.53 0.24 0.22 0.24 0.33 47.41 0.12 205.37M SLB_MWD-STD 661.60 0.14 205.37 661.60 0.22 0.04 0.22 0.22 80.04 0.10 146.89M SLB MWD-STD 783.72 0.10 146.89 783.72 0.21 -0.19 0.21 0.28 131.35 0.10 189.82M SLB_MWD-STD 905.92 0.45 189.82 905.92 0.19 -0.75 0.19 0.77 165.92 0.31 208.02M SLB_MWD-STD 1034.42 0.72 208.02 1034.41 -0.28 -1.96 -0.28 1.98 188.07 0.25 212.60M SLB_MWD-STD 1164.27 0.79 212.60 1164.25 -1.14 -3.43 -1.14 3.62 198.42 0.07 216.70M SLB_MWD-STD 1292.17 0.80 216.70 1292.14 -2.15 -4.89 -2.15 5.34 203.75 0.05 224.67M SLB MWD-STD 1420.67 0.98 224.67 1420.62 -3.46 -6.39 -3.46 7.27 208.43 0.17 223.87M SLB_MWD-STD 1550.27 1.02 223.87 1550.20 -5.04 -8.01 -5.04 9.46 212.17 0.03 223.26M SLB_MWD-STD 1678.57 0.89 223.26 1678.48 -6.51 -9.56 -6.51 11.57 214.27 0.10 218.31M SLB_MWD-STD 1806.67 0.80 218.31 1806.57 -7.75 -10.99 -7.75 13.44 215.20 0.09 221.29M SLB_MWD-STD 1936.71 0.91 221.29 1936.60 -8.99 -12.48 -8.99 15.38 215.79 0.09 221.29M SLB MWD-STD 2020.00 0.91 221.29 2019.88 -9.87 -13.47 -9.87 16.70 216.22 0.00 --- Projected to TD Survev Tvae: Non-Def Survey Survev Error Model: SLB ISCWSA version 24 *** 3-D 95.00% Confidence 2.7955 sigma Survevina Prog: MD From (ft 1 MD To (ft 1 EOU Frea Survev Tool Tvoe Borehole -> Survev 0.00 23.00 Act-Stns SLB_UNKNOWN-Depth Only (defau Panthera 28-6-9 -> MWD 23.00 296.01 Act-Stns SLB_UNKNOWN (default tool used) Panthera 28-6-9 -> MWD 296.01 2020.00 Act-Stns SLB MWD-STD Panthera 28-6-9 -> MWD DDToolBox Ver SP 2.1 Bld( users ) \\\MWD Generated 4/9/2008 5:19 PM Page 1 of 1 Schlumberger ~~~~~~ Panthers. 28-6-9 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, Apri103, 2008 4:10 PM To: 'Quay, Walter (ASRC]' Cc: Brandenburg, Tim C Subject: RE: Panthers 28-6-9 (208-033) Walter and Tim, Thanks for the information. Walter thanks for calling at a reasonable hour too. Your plan looks appropriate. I have informed Commissioner Foerster and she has given her oral approval to proceed. Good luck with the operations. Tom Maunder, PE AOGCC From: Quay, Walter [ASRC] [mailto:WQuay@chevron.com] Sent: Thursday, April 03, 2008 1:54 PM To: Maunder, Thomas E (DOA) Cc: Brandenburg, Tim C Subject: Panthers 28-6-9 Page 1 of 1 Tom, As per our conversation last night: The Panthers well drilling BHA became stuck at 1919', while cleaning out the hole to run surface casing at 2020'. Subsequent efforts to free the BHA were not successful. The drill string was severed in the HWDP. The plans at that point, were to place a cement plug with the severed string. However, the hole would not circulate. The Drill String was tripped out. The present operation is tripping in with a OEDP to proceed with the cement plug from the top of fish to the permafrost for a kickoff and sidetrack arount the fish. See attached diagram. «WBD Panthers Plugback Surface.pdh> Walter Quay WQuay a~chevron.com Office: 907-263-7812 CeIL 907-230-3961 4/3/2008 Proposed Plugback Panthera 28-6-9 DEPTH INFO DEPTH-RK8(23') ELEV-GL 348' HOLE FISH INFO MUD INFO CEMENT INFO CASING MD ND TVDSS DEPTH-RKB 23' 16" RKB 0' 0' 372' 651b/R, H-40 Welded 16" Conductor 102' 102' 270' 24" MSL 372' 372' 0' Top of Cement 1 320' 1 320' -948' •I ~ . - T rl~", . SurracelKick off Pkw , , , 1 r__ , , k},~ ~ . '.' ~ ;~ ~, ~" . , 87.5 Bbls, 455 sx ' r" ~, ,~ ~ - • Base Permafrost 1,440' 1,440' -1,068 t ~ ~~ , 16.4 ppg t,.-.~ h M i ~ ,. ° 1.08 R3/sx ° f... Jo- r"r . •; ,~' f . i• ~ i ~ ' 0°F ~ ;;\~ .i..•`F `3 • BHST = 5 Top of Fish 1,720' 1,720' -1,346' HWDP (Cut) Jars Crossover • Spiral Drill Cellar ~ ti Crossover 8.3 ppg Water Based Mud NM OriA Collar NM DriX Collar NM SIeMAzer Mud Motor ~° Top of Fill 2,003' 2,003' -1,631' -~ ~ ' ~ ~}~ ~:-,:;:;F;F - , 12-V4" Bit TD Hole Section 2,020' 2,020' -1,648' ~`~' - - - - 12-1/4" WBD Panthera Plugback Surtace.xis 4/3/2008 ~fi"~brt`~~1'r '~ ~ Chevron -Alaska Weekly Operations Report a~~ ~~~~ PANTHERA 28-6-9 1502232002300 Drilling -Original Original Hole Jobs _ lyre -_- i ~-ai --_ AFE V~. t ,r.: ~~~ .___._ I °L~C rd Dade OC En,J I Drilling - Ongmal Dnll ; U W DA... I _____ _ ~ 3i24i~u0tt J _ _ _ _ i ~ i- - - -- , Daily Operations 3!27!2008 Operatiorts Summary Rig Up. Contacted John Crisp with AOGCC @10:05 AM, concerning Diverter test. 3l28/20D8 viper a4vr a Sur w i iar y Rig Up. NUBOP. Diverter function test. Test gas detection system. Take on 525 bbl mud. Tally drill pipe. Finish RU pits and dress shakers and centrifuge. Pickup DP and HWDP. 3I29/2D08 viper Con ~I tE Rini U~, -~,~ 1 :~:~~II Drill i~.,:"~,' DU 6'H~V';2 3/30/2008 Com let. P ~ p U r BH', Drill to 608'. Repair Top Drive. Drill to 1044'. 3/31(2008 viper ~ 1 Drill Ir, ~ ~~_'f inl,ir_;, , ii i ;,~, i t allot/ ,~l ~ 20' ".i~ ulaG h ,I -6; it darleri Tr~rDI I I_r 1'~D~~' 4/112008 ~pereuuns Sunrrnery TOOH, working through tight spots. Lay down MWD tools, M/U clean out BHA, TIH to 2003' -had to wash and ream. Hole Packed off at 2003', attempted to circulate and backream, backream to 1926' with no circulation. Pumped away 120 bbls. 1 412!2008 Panthera Hole Size Change ~ • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, March 28, 2008 10:24 AM To: 'Quay, Walter [ASRC]' Cc: Brandenburg, Tim C Subject: RE: Panthera (208-033) Hole Size Change Walter and Tim, This is not an issue. I remember our discussing it previously. Keep me informed as to the decision process. It is possible that a sundry may not be necessary. Tom Maunder, PE AOGCC From: Quay, Walter [ASRC] [mailto:WQuay@chevron.com] Sent: Friday, March 28, 2008 9:55 AM To: Maunder, Thomas E (DOA) Cc: Brandenburg, Tim C Subject: Panthera Hole Size Change Tom, As per our conversation, the ops plan for Panthera hole size is being revised to drill 8-3/4" vs 8-1/2" hole size for the bottom interval. This is to facilitate the option of running a 7" liner and leaving the well suspended after this years drilling season and coming back in subsequent drilling seasons for further evaluation in this well. The 1/4" greater tolerance of the 8-3/4" is needed as the previous 2 wells drilled (Smilodon & Mastodon) with 8-1/2" hole have very gauge hole. It is probable that some difficulty in running and cementing the 7" in the 8-112" hole would be encountered and the 1/4" is an effort to mitigate some of this difficulty. The decision to run the 7" and suspend or continue with the 3-1/2" P&A will be made upon drilling and evaluation of this well. In either case a Sundy (403) will be submitted. Attached is the probable P&A and Suspend wellbore diagrams. «3 Panthera 28-6-9 Well Bore.pdf» Walter Quay WQuay@chevron.com Office: 907-263-7812 Cell: 907-230-3961 3/28/2008 • WH Well #3 P&A Panthera 28-6-9 DIR I LWD FORM DEPTH-RKB(21' Est. Et. GL 349' HOLE CASING MUD INFO MWD MD TVD TvD-SS DEPTH-RKB 21 SIZE SPECS Cement Info INFO 0' 0' 370' 16" Top ofSfc Cmt Plug 5' S' 365' 65 Ib/ft, L-80 16" Conductor 101' 101' 269' N/A N/A LWD/GR/RES/Sonic 9-5l8" Bridge Plug 225' 225' 145' Surtace Csa MSL 370' 370' 0' 9-5/8" Lead Slum 401bs/ft Bbls, sx Wellbore Stability L-80, BTC-M 10.7 ppg Lost Circulation ID. = 8.835" 4.15 ft3/sx Hole Cleaning Int. Yeld 5750 psi Casing Sections Collapse 3090 psi Casing Wear Base Permafrost 1 43T 1,437 1 06T iop of Tail Cement + Sonic Inter. Casing Lead Slum Wellbore Stability 3-1/2" Bbls, sx Lost Circulation 9.3 Ibslft 12.5 ppg Hole Cleaning Microlke L-80, IBT-M 2.36 ft3/sx Torque 8 Drag Top Lower Ugnu 2,635' 2,635' -2,265' ID.=2.992 Casing Sections IM. Yeld 10,160 psi Top West Sak D 2,951' 2,951' -2,581' Colapse 10,530 psi Tail Slum Bbls, sx 15.8 ppg 1.15 ft3/sx Top West Sak A-1 13,267' 3,267' I -2,897' Top Coleville 3,954' 3,954' -3,584' RCI Sampling 3-112" Csg ~ 4,191' 14,191' I-3,821' I 8-3/4" 85° F I WaterO Based P 3 Panthera 28-6-9 Well Bore.xis 3/27/2008 • WH Well #3 Suspend Panthera 28-6-9 DIR 1 LWD FORM DEPTH-RKBI21' Est. EI. GL 349' HOLE CASING MUD INFO MWD MD TVD TVPSS DEPTH-RKB 21 SIZE SPECS Cement Info INFO 0' 0' 370' 16" Top ofSfc Cml Plug 5' 5' 365' 651b/ft, L-80 76" Conductor 101' 101' 269' N/A N/A LWD/GRlRES/Sonic 9-5/8" Bridge Plug 225' 225' 145' Surface Csg MSL 370' 370' 0' 9-5l8" Lead Slum 40 Ibs/ft Bbls, sx Wellbore Stability L-80, BTC-M 10.7 ppg Losl Circulation ID. = 8.835" 4.15 ft3/sx Hole Cleaning Int. Yeld 5750 psi Casing Sections Collapse 3090 psi Casing Wear ise Permafrost 1,43T 1,437 -1,067 u ~p of Tail Cement m Of Kill String 1,848' 1,848' -1,478' Tail Slum 60 Bbls, 291 sx ip of Liner Hanger 1,750' 1,750' -1,380' 15.8 ppg Packer Assbly 1.16 ft3/sx 9.0 -10.0 ppg 518" Casing Point 2,000' 2,000' -1,630' 12-1/4" 60 ° F Water Based M + Sonic Inter. Casino Lead Slum Wellbore Stability 7" Bbls sx Lost Circulation 26" 12,5 ppg Hole Cleaning L-80, BTC-M 2.36 ft3/sx Torque & Drag Top Lower Ugnu 2,635' 2,635' -2,265' ID. =6.276 Casing Sections Int. Yield 7240 psi Top Wesl Sak D 2,951' 2,951' -2,581' Collapse Tail Slurtv 5410 psi Bbls, sx 15.8 ppg 1.15 ft3/sx Top Wesl Sak A-1 3,26T 3,267 -2,697 Top Coleville 3,954' 3,954' -3,584' RCI Sampling Top of 7" LC -4100 9.0 - 9.4 PP9 7" Liner 4,191' 4,191' -3,821' 8-3/4" 85° F Water Based Mud 3 Panthera 28-6-9 Well Bore.xis 3/27/2008 • i 1 t ~ d ~ ~ - 333 ~"~~ SARAH PAUN, GOVERNOR ~ L~~ ~ ~ ~~ ~ ~is[s-7~ OI~ ~ ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA'1'IO1~T COMnII5SI01~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Tim Brandenburg FAx (907) 27s-7542 Drilling Manager Union Oil Company of California PO Box 196247 Anchorage, Alaska 99519 RE: Exploration, Wildcat, Panthera 28-6-9 Union Oil Company of California Permit No: 208-033 Surface Location: 190 FNL, 850 FEL, SEC. 28, T6N, R9E, UM Bottomhole Location: 190 FNL, 850 FEL, SEC. 28, T6N, R9E, UM Dear Mr. Brandenburg: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit iri the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. A mudlog and samples are required for this remote exploratory well. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals below conductor pipe and 10' sample intervals through target zones. A Sundry Notice (Form 403) must be submitted in advance of the planned surface abandonment. It is not possible to approved abandonment as part of the permit to drill. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a Permit No: 208-019 Page #2 of 2 representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerel Daniel T. Seamount, Jr. Chairman s ?` DATED this Z ~ day of March, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ ~ ~Z~+~~i~E STATE OF ALASKA MAR 0 5 2008 ALASKA OIL AND GAS CONSERVATION COM ISSION PERMIT TO DRILL ~~~~~, 0~ $ Gas Cons. Commission ~n Any ~ti nn~ 1 a. Type of Work: 1 b. Current Well Class: Exploratory ^~v Development Oil ^ 1 c. Specify if well is proposed fo . Drill ~ - Redrill ^ Stratigraphic Test ^ Service ^ Development Gas ^ Coalbed Methane ^ Gas Hydrates ^ Re-entry ^ Multiple Zone ~ Single Zone ^ Shale Gas ^ 2. Operator Name: Union Oil Company of California 5. Bond: Blanket Q Single Well ^ 11. Well Name and Number: Bond No. 086S1035154066CM Panthers 28-6-9 • 3. Address: 6. Proposed Depth: 12. Field/Pool(s): PO Box 196247, Anchorage, Alaska, 99519 MD: 4191 TVD: 4191 Exploration • 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 190' FNL, 850 FEL, Sec 28, T6N, R9E, Umiat Meridan ADL 390003 - Top of Productive Horizon: 8. Land Use Permit: 13. Approxi ate Spud Dat Sec 28, T6N, R9E, Umiat Meridan 850 FEL 190' FNL ADNR LAS 26542 ;~ ~t9 2/23/2008 , , Total Depth: 9. Acres in Property: 14. Dis anc to Nearest 190' FNL, 850 FEL, Sec 28, T6N, R9E, Umiat Meridan 5701 ' Property: 21,000 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surfacer x- 514,375 y- 5,795,581 ~ Zone- ASP 4 (Height above GL): 370.0 feet msl Within Pool: None 16. Deviated wells: Kickoff depth: feet o$ 17. Maximum Anticipated Press ess psig (see 20 AAC 25.035) La ~ ` Maximum Hole Angle: degrees • Downhole: IS~S it .S' Surface: /3 t~ L /°";• 18. Casing Program: Specifications Top -Setting Depth -Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Augere~d 16 65 N-80 Weld 80 0 0 101 101 As Required to Surface 12-114 9-5/8 40 L-80 BTC 1979 0 0 2000 2000 Lead: 279 bbls (378 Sx) of PF • - type L @ 10.7 ppg (4.15ft/sc) @ (250% excess) ,,~, ^ " Tail: 45 bbls (220 sx) of G @ 1~' ~;~ ~ 15.9 ppg (1.16 ft/sx) (40% ,~~( ,°1~~ Excess) • 8-1/2 3-1 /2" 9.3 L-80 IBT-M 2441 0 4191 4191 261 bbls (40 % Excess) 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structu ra I Surface Intermediate Production Liner Perforation Depth MD (ft): N/A Perforation Depth TVD (ft): N/A 20. Attachments: Filing Fee ^ BOP Sketch Q Drilling Program 0 Time v. Depth Plot ~ Shallow Hazard Analysis Property Plat ^~ Diverter Sketch ^~ Seabed Report ^ Drilling Fluid Program ^~ 20 AAC 25.050 requirements ^ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Walter Quay Printed Name Tim Brande urg Title Drilling Manager Signature ~ Phone 263-7812 Date 3/4/2008 Commission Use Only Permit to Drill ~ ~ 3.3 Number: ~^ ~7 API umber: 2 ~ /y~~ 50- ~.~•7 ~ li~'~-~Z~ ~~ Permit Approval p Date: Qp See cover letter for other requirements. If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained in shales: Conditions of approval : Samples req'd: Yes ~ No ^ Mud log req'd: Yes ~ No ^ HZS measures: Yes []~ No ^ Directional svy req'd: Yes ^ No [~ ~ ~ • ~~ ~ST ~.~ ~ ~ ~ inat iti f cv'd ~hGc(• ~ 3•S.o8 ~ ~ ~c.~ ~A,~aS~O"~SC.~1 Ca> Other: `",~- t~ U `'~12C'~~ ~1~ o ccctt=P~~~~ ~~ ~a~ ~D ~e t •~-~ /~/ ~ ~ APPROVED BY THE COMMISSION COMMISSIONER f / DATE: , ` /~ 3•Zf •08 Form 10-401 Revised 12/2005 Submit in Duplicate ORIGINAL • i Ct~g~vron Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, AK 99519-6247 Fax 907 263 7884 March 4, 2008 ~~~ ~ ~~~ D Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7~` Avenue MAR 0 5 2008 Anchorage, Alaska 99501 J (~ $~ ~ Ct)ft3. C0~'Nr11SS10t1 Re: Application for Permit to Drill Panthera 28-6-9 Exploration Well 4 ~~ _ ~' Dear Commissioner: r Enclosed for approval is a Permit to Drill (form 10-401) for Union Oil Company Of California to drill the Alaska North Slope White Hills Exploration well, Panthera 28-6-9. Subject to AOGCC approval, it is intended to drill Panthera 28-6-9 following the drilling of Mastodon 6-3-9 with Nabors 106E rig. Mastodon is presently drilling in the surface interval. An anticipated spud date is March 19, 2008. A variance from requirements of 20 AAC 25.035, to utilize a diverter vent line diameter of 12" is requested. This is smaller than the planned surface hole of 12-1/4". A similar request was approved for Smilodon 9-3-9 and Mastodon 6-3-9 wells with Nabors 106E rig. The AOGCC is requested to treat as confidential all information included in the Application for Permit to Drill as information in these documents is drawn from research and data proprietary to Union Oil Of California a wholly . owned subsidiary of Chevron Corporation. If additional information is required, please contact either myself or Mr.Walter Quay at 263-7812. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill - 2 Copies 2. Well Program 3. Wellbore Schematic 4. Drilling Fluids Program 5. Directional Program 6. As Staked Location Plat 7. Days Vs Depth Drilling Plot 8. MASP Calculation & Casing Design 9. Diverter, BOP and Choke Manifold Schematics 10. Shallow Hazard Analysis Sincerely, C_ Timo y C. Brandenburg Drilling Manager Cc: Well File Union Oil Company of California / A Chevron Company ~ ~ `G' N A L http://www.chevron.com Drilling Department Panthera 28-6-9 Well Plan Summary Surface Location: X = 514,375' Y = 5,795,581 . As-Staked 190' FNL, 850' FEL, Sec. 28, T6N, R9E UM Target Location: X = 514,375' Y = 5,795,581 To U nu 190' FNL, 850' FEL, Sec. 28, T6N, R9E UM Top West Sak X = 514,375' Y = 5,795,581 190' FNL, 850' FEL, Sec. 28, T6N, R9E UM Bottom Hole Location: X = 514,375' Y = 5,795,581 190' FNL, 850' FEL, Sec. 28, T6N, R9E UM The well approaches within 21,000' of the nearest Gnevron Wnite hens lease ime. Estimated Start Date: 03/19/2008 Operatin da s to com lete: 25 MD: 4191' • TVD: 4191 ' Formation Markers: Elev. GL: 349' RKB: 20.5 • Formation To s MD -RKB TVD -RKB TVD-GL Comments Base Permafrost 1437' 1437 1416 To Prince Creek A 1848 1848 1827 To LowerU nu 2635 2635 2614 Top West Sak D 2951 2951 2930 Top West Sak A-1 3267 3267 3246 Top Coleville 3954 3954 3933 Est. TD 4191 4191 4170 Drill thru Mal uk #1 E uiv. Zone of 4850' to 4900' Carina Program: Hole Size Csg/ Tb O.D. Wt/Ft Grade Conn Length Top MD/TVD Btm MD/TVD rkb Au ered 16" 65# 80 80' GL 101' 12-1/4" 9-5/8" 40.0# L-80 BTC 1979' GL 2000'/2000' 8-1 /2" 3-1 /2" 9.3# L-80 I BT-M 2441 ' 1750/1750 4191 /4191 Mud Program: 12-1/4" Surface Hole (0-2000'): Fresh Water Mud Initial Value Final Value Densit 8.5 9.0-9.4" Funnel Viscosity 200-300 70-150 seconds Yield Point 30-40 20-30 cP Plastic Viscostiy (lb/100 10-30 25-35 s 10 second Gel Strength 10-15 10-15 Ib1100 s 10 minute Gel Strength 20-40 20-40 Ib/100 s H 9-9.5 9-9.5 API Filtrate cc Unrestricted <12 8-1/2" Production Hole (2000' - 4191'): Fresh Water Mud - 6% KCL/PHPA/Clayseal Initial Value Final Value Densit 8.7 9.3 Max Funnel Viscosity seconds 40-65 40-65 Yield Point (cP) 15-25 15-25 Plastic Viscostiy. (Ib1100 s 6-24 10-18 10 second el 4-8 4-8 10 minute el 6-13 6-14 H 9-9.5 9-9.5 API filtrate <4 <4 Solids % 0 <6 Hydraulics: Surface Hole: 12-114" Interval GPM Mfg Bit Pump PSI ECD ppg- Nozzles TFA emw in2 0'-2000' >600 Hu hes MX-L1X 1800 9.7 13/15/15/15 0.65 Production Hole: 8-1 /2" Interval GPM Mfg Bit Pump PSI ECD ppg- Nozzles TFA (in ) emw 2000' - 4191' 450 Reed DS619S-A3 2400 9.6 6 x 12/32" H calo Logging Program: Lo in While Drillin Hole Size Services ~ Run 1 0-surf cs LWD: GR/Res/Sonic/Directional ' Run 2 surf cs -TD LWD: GWRes/EcoSco e/Sonic/Directional Run 3 Mud Lo in Services 0-SUrf CSg mudlogger required from surface to TD 0-TD Bagged samples of cuttings every 30 feet, with 10 ft samples caught from sandstones and other potential reservoirs from surface to TD (both legs); three washed and dried cuts, one unwashed cut. Corin Hole Size Services surf cs -TD 50 rota sidewall cores Open Hole Logging Hole Size Services Run 1 8-1/2" GR/CN/ZDL/XMAC ' Run 2 8-1/2" MREX Run 3 8-1/2" RCOR Run 4 $_1/2" RCI(MDT Type Formation Sampler & Pressure) Run 5 g_1/2" VSP Minimum checkshot Integrity Testing: Test Point Depth Test Type EMW Surface Casing Shoe At least 20 feet but not more than LOT Estimated 12.5 ppg EMW. 50 feet of new formation Take the test to Leak Off Cement Calculations: Casina Size 19-5/8" Surface Basis: Lead: Based on conductor set at 101', 1336' of annulus in the permafrost @ 250% excess, + 63' of annulus below the ermafrost 40% excess. Tail: Based on 500' o en hole volume + 40% excess + 85' shoe track volume. Total Cement Volume: Lead 279 bbl / 1568 ft / 378 sks of Permafrost Type L at 10.7 ppg and 4.15 cf/sk. Tail 45 bbl / 255ft / 220 sks of Premium 'G' at 15.9 ppg and 1.16 cf/sk. Production/Abandonment Liner: Casin Size 3-1/2" Liner Basis: Lead: Based on landing collar 100' below the liner hanger, 40% excess volume in OH from shoe to surface shoe, 250' of liner lap inside surface casing + 100' of excess above the liner top (DP Total Cement Volume: Lead 1233 bbls / 1312 fts / 405 sks of Premium Cement with Econolite at 11.2 ppg and 3.24 cf/sk Well Control: Surface hole will be drilled with a diverter. The MASP is 1396 psi. (See Attached) The intermediate/production hole well control equipment (of at least 3000 psi working pressure) consisting of will be equipped with pipe rams, blind rams, and an annular preventer will be installed and is capable of handling the MASP pressure. Based upon the planned casing test of 2000 psi for casing integrity considerations, the BOP equipment will be tested to 2500 psi. Disposal: ~ Cuttings Handling: Cuttings generated from drilling operations hauled to an approved . disposal facility. • Fluid Handling: All Mud and Used drilling and completion fluids and other Class II wastes hauled to an approved disposal facility. Wastes Handling See the Comprehensive Waste Management plan for all details on Waste Handling. Excess/Used Liquid Mud & Excess Cement Returns Used liquid mud will be stored in a heated tank farm on the Smilodon location for disposal. Cement returns and wash will be taken to a citrate treated vac skid to be hauled to the used mud tank farm, where it will be blended with used mud to dilute the cement concentration for annular disposal. Fluid will be hauled overland by Steigers and marcep trailers with affixed 90bb1 vac skids. Once at Franklin Bluffs, the fluid would be transferred into a large (250 bbl) highway vac truck for transportation to a disposal site in GPB. Drill cuttings Drill cuttings will be processed by the rig solids control equipment to remove as much liquid from them as possible. The "dry" cuttings will be stored in an ice containment pit on the pad. NO LIQUIDS ARE ALLOWED IN THE CONTAINMENT PIT. The drill cuttings with be stored in the containment pit until: 1) they are backhauled to Deadhorse via Cat 730 ejector trucks with tundra tires to an approved disposal area, or 2) they are processed on site by a grind and inject plan for subsurface disposal. • Summary of Drilling Operations Pre-Rig Work: 1. Set and cement 16" conductor 2. Install cellar Rig Operations: 1. Nipple Up the 13-5/8" BOP diverter spool and riser in diverter mode. Function test diverter system. Provide the AOGCC at least 48 hours notice of each BOPE function pressure test so that a commission representative can witness the test 2. MU 12-1/4" drilling assembly. Drill surface hole to approximately 2000' (-600' below the permafrost). Drift the drillpipe to 2.4" min. ID for the stab-in dart. 3. Run and cement the 9-5/8", 40.0# surface casing back to surface. A Stab-in cementing system will be utilized. 4. RU the BOPE in BOP Mode and test to 250/2500 psi. Provide the AOGCC at least 48 hours notice of each BOPE function pressure test so that a commission representative can witness the test 5. MU 8-1 /2" drilling assembly and RIH to float collar. Test the 9-5/8" casing to 2000 psi for 30 minutes. 6. Drill out shoe joints and new formation greater than 20' and less than 50'. Perform the Leak Off Test. 7. Drill ahead to planned TD 8. Circulate and condition hole and perform wiper trip to surface casing shoe. POOH and stand back BHA. 9. RU Open Hole Wireline and run Logging Suite. 10. Run and cement the 3-1/2" P&A String. Test liner and packer to 2000 psi. ~--•-- ~--~~'~ 11. TOOH and LD drill pipe. 12. Complete surface abandonment of well, including the "Well Abandonment Marker". 13. Rig down and move off ~~ ~~ • White Hills Well #3 Panthera 28-6-9 DIR I LWD FORM DEPTH-RKB~21') Est. EI. GL 349' HOLE CASING MUD INFO MWD MD TVD ND-ss DEPTH-RKB 21 SIZE SPECS Cement Info INFO 0' 0' 370' 16" Top ofSfc Cmt Plug 5' 5' 365' - 65 Ib/ft, L-80 • 16" Conductor 101' 101' 269' N/A N/A LWD/GR/RES/Sonic 9-5/8" Bddge Plug 225' 225' 145' Surface Csa MSL 370' 370' 0' 9-5/8" Lead Slurry 401bs/ft Bbls, sx Welibore Stability L-80, BTC-M 10.7 ppg Lost Circulation ID.=6.635" 4.15 K3/sz HOIB Cleaning Inl. Yield 5750 psi Casing Sections Collapse 3090 psi Casing Wear Base Permafrost 1,437' 1,437' -1,067' Top of Tail Cement Top PC A 1,848' 1,848' -1,478' i Tail Slum 60 Bbls, 291 sx Top of Liner Hanger 1,750' 1,750' -1,380' 15.8 PP9 & Packer Assbly - __ u s ft3/sx 3-1 /2" LC 1,850' 9.0 -10.0 ppg 9-518" Casing Point 2,000' 2,000' -1,630' 12-1/4" 60 ° F Water Based Mud LWD/GR/RES/EcoSocp +Sonic Inter. Casino Lead Slum Wellbore Stability 3-1/2" Bbls, x Lost Circulation 9.3 Ibs/K 11.2 ppg Hole Cleaning L-80, IBT-M 3.24 k3/sx Torque & Drag Top Lower Ugnu 2,635' 2,635' -2,265' ID. =2ss2 Casing Sections ~ Int. Yield 10,160 psi Top West Sak D 2,951' 2,951' -2,581' ~ Collapse 10,530 psi Tail Slum Bbls, sx ,l 15.8 PP9 1.15 ft3/sx Top West Sak A-1 3,267' 3,267' -2,897' Top Coleville 3,954' 3,954' -3,584' RCI Sampling .. 8-1/2" 9.0 - 9.4 PP9 3-112" Csg• 4,191' 4,191' -3,821' 8-1/2" 85° F Water Based Mud ' 3 Panthera 28-6-9 Well Bore.xls 2/29/2008 • Halliburton saROlo Chevron Mud Program White Hills Well #3 Panthera Baroid Mud Program Halliburton Baroid Name (Printed). Signature Date Originator Dave Soquet Reviewed by Dave Higbie Customer Approval Walter Quay Version No: Date: 1.0 March 3, 2008 Panthera v1.0 1 2/18/08 • Halliburton BAROID Chevron Mud Program Panthera General Discussion This exploration well will be drilled from an ice pad south of Kuparuk. Due to the remote location, waste management is critical on this well. A 12 '/" surface hole will be drilled vertically to a depth of 2,000' • where 9-5/8" casing will be set and cemented. An 8'/z" production hole will then be drilled vertically to a depth of 4,191'. After an extensive logging program, the well will be P&A'd. Spud the well with a conventional gel-based spud mud system. Our primary focus for surface hole drilling operations will be adequate mud weight for well control and sufficient mud viscosity and flowrates for efficient hole cleaning. A new 6% KCI/PHPA/Clayseal system will be used for the production interval. This mud is formulated with several mechanisms to provide effective wellbore stabilization and minimize waste: ionic inhibition (KCI), polymer encapsulation (PHPA), and anionic bonding (Clayseal). This will also facilitate the drilling of a gauge hole. Special Considerations: i. While gas hydrates are unlikely, maintain a sufficient quantity of Driltreat (lecithin) to accomplish a 2 '~ ppb treatment in the event gas hydrates are noted. Contact the Technical Representative prior to any additions of Driltreat. ii. Lime and zinc carbonate should be on location for H2S contingency (@1 pallet No Sulf and 2 pallets lime). iii. Maintain an adequate barite supply (and other necessary products) to increase the mud weight of the current circulating volume by 1.5 ppg at any time (@1500 sx barite on location at all times). iv. Due to the remote nature of this location, maintain an adequate supply of LCM and the other mud additives, which may be required to support this drilling program. v. Sticky clays were problematic thought the Smilodon well. Maintain DriI-N-Slide/Condet at a total concentration of ~1 % to minimize screen blinding and the agglomeration of the clays. vi. Reduce the potential for hole erosion/destabilization, hold the jet velocity below 200 fps while achieving pump rates to deliver AV's around the drill pipe in the 150-200 fpm range. vii. Some shale instability has been noted on offset wells (maintain tight filtrate control/mud weight). viii. Obtaining good logs and fluid samples are a key component of this drilling program. Maintaining low filtrate and using the inhibitive mud system will limit fluid invasion and help drill a gauge hole. ix. Maintain an adequate supply of STEELSEAL should losses be observed. String 3-5 sx/hr immediately after noting losses. Again, this will improve the post well fluid samples by limiting drilling fluid invasion. Well Specifics: Casin Pro ram MD TVD Foota e 12 %" hole 9 5/8" Casin 2,000' 2,000' 2,000' 8 %2" Hole 4-1/2" liner 4,191' 4,191' 2,191' Panthera v1.0 2 2/18/08 • Halliburton BaROi~ Chevron Mud Program Surface Interval: 12'/4" to -2,000'; Spud Mud Mud Proaerties Initial Value Final Value Densit 8.5 9.0-9.4* Funnel Viscosity (seconds) 100-200 70-150 Yield Point cP 30-40 20-30 Plastic Viscosiiy (Ib/100 st) 10-30 12-25 10 second Gel Strength (Ib/100 sf) 10-15 10-15 10 minute Gel Strength (Ib/100 sf) 20-40 20-40 H 9-9.5 9-9.5 API Filtrate cc Unrestricted <12 *Weight increase due to natural progression of solids. A weight up is not programmed. Surface Interval The surface interval of this well will be drilled with a conventional spud mud as formulated below: Base Formulation: Fresh Water - .982 bbl/bbl Aquagel - 25 ppb X-Tend II - .1 ppb (250 viscosity) Caustic soda - .2 ppb (pH 9-9.5) Spud the well with maximum flow rates (600 gpm minimum assuming 12'/" hole w/4" drill pipe) to ensure good cuttings transport. Target an initial YP in the 30-40 range with a 100-200 viscosity. After penetrating the upper gravels and the permafrost, gradually reduce the funnel viscosity to ca. 70-150 sec as the hole allows. Reduce the API FL to under 12 cc/30 min with additions of Dextrid. At interval TD, pump a high viscosity or Barolift sweep and condition the mud for running casing. Once the casing is landed, pre-treat the system for cement with a minimum of 0.5 ppb citric acid and 1.0 ppb bicarb. Add 0.25-0.5 ppg Barathin to thin mud to target properties. (Converse with the cementers to see what properties they have based there design on). With an initial mud density of 8.5 ppg, please note the other issues of concern as listed below: 1. Make sure all members of the drilling team are aware of the potential of encountering gas hydrates. 2. A mud weight increase is not currently programmed for drilling the gas hydrate interval of the well, if encountered. 3. If gas hydrates are noted, treat the system with 2.0 ppb of Driltreat (Lecithin) and %z% by volume DriI-N-Slide. Some defoamer additions may also be necessary to help the gas break out. 4. Maintain the mud as cool as possible (under 75°F if possible). Efforts to keep the fluid cool include mudding up with cold water and diluting the mud with cold water. Panthera v1.0 3 2/18/08 • Halliburton saROID Chevron Mud Program ~ Mud maintenance issues for this interval of the well are as follows: 1. Use Aquagel and X-Tend II for viscosity and YP requirements. Initially target a viscosity of 300+, allowing it to gradually decrease as the permafrost is exited. 2. Use Dextrid for API filtration control. No filtrate control is planned initially, but drop the fluid loss to the 12 cc range prior to exiting the permafrost. 3. Hold the pH in the 8.5-9.5 range with caustic soda. 4. DriI-N-Slide/Condet additions will be required to minimize screen blinding. Maintain a total concentration of 1 % v/v. 5. Control penetration rates based upon the ability of the surface system to process the drilling mud. 6. Daily additions of X-Cide 207 will be necessary to control bacterial action after adding Dextrid. 7. Minimize dilution requirements and keep the mud as clean as possible through aggressive use of solids-control equipment. 8. Once casing is on bottom, thin the mud with Barathin to minimize channeling and improve the cement job. A strong focus on minimizing waste needs to be in place before and while drilling all sections of this well. Do not jeopardize the integrity of the fluid system; however, all efforts need to be made to this end. Allow the pit volume to deplete prior to TD on the surface hole. This will leave more room in the pits for displaced mud when cementing. Ensure all solids control equipment is working properly prior to spudding. Utilize shakers, desanders/desilters, mud cleaners and centrifuge(s) to reduce solids and reduce dilution. No processes should take place that will lead to a build up of low gravity solids in the mud. On an example well, some of the centrifuge under-flow was returned to the mud system. This led to a fines build up and the resultant required dilution was excessive. The personnel were trying to reduce waste but wound up causing additional waste. Build and maintain the system with COLD water. All attempts to keep the temperature of the mud <75°F should be made. Normal surface hole viscosities should be adequate for this vertical well. Maximum flow rates should be used to ensure good cuttings transport. Target an initial YP in the 30-40 range then adjust as dictated by the actual hole cleaning requirements of the well. However, do not hesitate to quickly raise the viscosity if hole cleaning problems develop. Aquagel additions should be utilized to provide rheological support as needed. Utilize high viscosity sweeps to supplement the hole cleaning capabilities of the system. On Smilodon, it was noted that adequate flowrates were not achieved due to shaker screen blinding. Maintain DriI-N-Slide/Condet at a total concentration of ~1 % to minimize screen blinding and the agglomeration of the clays. It is important to exercise caution to minimize the potential for creating a situation of lost circulation. Tripping speeds and casing running speeds should be slowed to reduce the effects of surge pressures on the formation especially with this elevated rheology. Do not attempt to run casing if the well is not in stable condition. Pumps should be "staged" on line slowly to avoid surging the hole and the pipe rotated to break the mud's gels before turning the pumps on. Panthera v1.0 4 2/18/08 Halliburton BaROIO Chevron Mud Program Production Interval: 8'/z" to 4,191'; 6% KCI/PHPA/Clayseal Mud Properties Initial Value Final Value Densit 8.7 9.3 max " Funnel Viscosity (seconds) 40-65 40-65 Yield Point cP 15-25 15-25 Plastic Viscostty (Ib/100 st) 6-14 10-18 10 second el 4-8 4-8 10 minute el 6-13 6-14 H 9-9.5 9-9.5 API filtrate <4 <4 Solids % 0 <6 * Unless hole conditions dictate otherwise Base Formulation: Fresh Water - 0.905 bbl KCI - 20 Ibs (30-32K ppm chlorides) EZ Mud DP - 0.75 Ibs (.15 ppb in initial mix) Clayseal - 0.84 gal (none in initial mix) Dextrid - 3 Ibs (API filtrate of 8-15 cc initially) Barazan-D - 1-2 Ibs (as required for an initial 35 YP) KOH - 0.1-.25 Ibs (pH = 9-9.5) DriI-N-Slide - 1.0% v/v Aldacide-G - 0.25 Ibs (X-cide 207 for rig maintenance) Baracor 700 - 1 ppb Barascav D - 0.5 ppb (to be added at the rig when first circulating) ** Use Barite for any needed weight ups on this well. NOT drill solids. Gradually increase the EZ Mud DP until the full 0.75 ppb is reached. Once the full EZ Mud concentration is reached, begin to gradually add Clayseal to a final concentration of 0.84 gal/bbl. Ensure the shakers can handle a flowrate of 450 gpm at all times while increasing the EZ Mud and Clayseal concentrations. Once the full concentrations are achieved, maintain them until interval TD. Decrease the API filtrate to <4 cc/30 for the interval using Dextrid and/or PAC L. Keep low gravity drilled solids to a minimum (<6% by volume if possible). Maintain the MBT at <12 ppb through dilution and solids control. Maintain the pH between 9.0-9.5 with KOH. Daily additions of Aldacide G/X-cide 207 should be made to control bacterial action. The chloride level should be kept in the 28-34K range through additions of KCI. The EZ Mud concentration should be maintained at .75 ppb. A 15-25 YP should be maintained using Barazan D+. Extremely sticky clays were noted on the Smilodon well. Maintain ~1 % DriI-N-Slide in the system to combat screen blinding from sticky clays. Condet additions can also be made to combat screen blinding and clay agglomeration. Mud plant support is available for this well. All efforts must be made to keep the mud system in good shape and maintain the mud weight as low as possible. Should whole mud dilution be needed, contact the mud plant well in advance to plan for any needed whole mud requirements. Panthera v1.0 5 2/18/08 • Halliburton eaROID Chevron Mud Program On an offset well, Amethyst #1, shale splintering was noticed which required a weight up to 10.5 ppg. Proper drilling practices should be employed to minimize mechanical disturbance in this interval. If splintered shale is seen at the shakers, consider weighting up a minimum of .4 ppg and maintain this weight until TD. Additions of Baranex and Barotrol at 4 ppb and 2 ppb respectively are recommended, as well. Check with the geologists prior to Baranex or Barotrol additions to ensure it will not affect their sample and/or testing. Special efforts should be made to keep ECD's and surge/swab pressures to a minimum. This will reduce the chances of lost circulation and also reduce damage to the exposed shales. If seepage losses are noted while drilling the sands, immediately string in STEELSEAL at 3-5 sx/hr. Obtaining good logs and fluid samples are key goals of the well. Tight hole can be anticipated for the first time tripping through new hole after it has been drilled. If backreaming becomes necessary, extreme caution must be used to avoid the potential for packing off and stuck pipe. Extended circulating times may be required to remove cuttings from the hole and minimize cuttings loading in the annulus. Panthera v1.0 6 2/18/08 Chevron Panthera (P1) Proposal Report Date: March 4, 2008 Survey I DLS Computation Method: Minimum Curvature / Lubin ski Client: Chevron Vertical Section Azimuth: 90.000° Field: White Hills Chevron Vertical Section Origin: N 0,000 ft, E 0.000 ft Structure 1 Slot: Panthera /Panthera TVD Reference Datum: Rotary Table Well: Panthera TVD Reference Elevation: 369.50 ft relative to MSL Borehole: Panthera Sea Bed I Ground Level Elevation: 349.00 ft relative to MSL ^ UWIIAPI#: 50223xxxxx00 Magnetic Declination: 22.546° Survey Name I Date: Panthera (P1) /March 4, 2008 Total Field Strength: 57580.220 nT Tort 1 AHD I DDI I ERD ratio: 0.000° 10.00 ft / 0.000 10.000 Magnetic Dip: 80.478° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: April 04, 2008 Location Latllong: N 69.85267292, W 149.88605784 Magnetic Declination Model: BGGM 2007 Location Grid NIE YIX: N 5795581.000 ftUS, E 514375.000 ftUS North Reference: True North Grid Convergence Angle: +0.10697007° Total Corr Mag North -> True North: +22.546° r,.~,~ c~aia Faffn.• n ga44nro~ Local Coordinates Referenced To: Well Heatl • Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face DifficuRy ft de d ft ft ft ft ft de de 1100 ft Index ftUS ftUS n nn n nn a~o~Ga~ nn . ~~ez~~ nn N RA R59R79A9 \A/ 1dQ RRRnF7R4 RKt3 u.uu u.vu u.uu -ooa.au v.v~ v.vu ~.~~ ~..,~ -- ......, ....... ...........,. .,.. .,. ._._.-- ••--• ---- --- - - ------ 100.00 0.00 0.00 -269.50 100.00 0.00 0.00 0.00 -- 0.00 0.00 5795581. 00 514375.00 N 69. 85267292 W 149. 88605784 16" Conductor 101.00 0.00 0.00 -268.50 101.00 0.00 0.00 0.00 -- 0.00 0.00 5795581. 00 514375.00 N 69. 85267292 W 149. 88605784 200.00 0.00 0.00 -169.50 200.00 0.00 0.00 0.00 --- 0.00 0.00 5795581. 00 514375.00 N 69. 85267292 W 149. 88605784 300.00 0.00 0.00 -69.50 300.00 0.00 0.00 0.00 --- 0.00 0.00 5795581. 00 514375.00 N 69. 85267292 W 149. 88605784 MSL 369.50 0.00 0.00 0.00 369.50 0.00 0.00 0.00 - 0.00 0.00 5795581. 00 514375.00 N 69. 85267292 W 149. 88605784 400.00 0.00 0.00 30.50 400.00 0.00 0.00 0.00 --- 0.00 0.00 5795581. 00 514375.00. N 69. 85267292 W 149. 88605784 500.00 0.00 0.00 130.50 500.00 0.00 0.00 0.00 -- 0.00 0.00 5795581. 00 514375.00 N 69. 85267292 W 149. 88605784 600.00 0.00 0.00 230.50 600.00 0.00 0.00 0.00 --- 0.00 0.00 5795581. 00 514375.00 N 69. 85267292 W 149. 88605784 700.00 0.00 0.00 330.50 700.00 0.00 0.00 0.00 --- 0.00 0.00 5795581. 00 514375.00 N 69. 85267292 W 149. 88605784 800.00 0.00 0.00 430.50 800.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69. 85267292 W 149 .8860578 900.00 0.00 0.00 530.50 900.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69. 85267292 W 149 .8860578 1000.00 0.00 0.00 630.50 1000.00 0.00 0.00 0.00 -- 0.00 0.00 5795581 .00 514375.00 N 69. 85267292 W 149 .88605784 1100.00 0.00 0.00 730.50 1100.00 0.00 0.00 0.00 -- 0.00 0.00 5795581 .00 514375.00 N 69. 85267292 W 149 .88605784 1200.00 0.00 0.00 830.50 1200.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69. 85267292 W 149 .88605784 1300.00 0.00 0.00 930.50 1300.00 0.00 0.00 0.00 -- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149 .88605784 1400.00 0.00 0.00 1030.50 1400.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149 .88605784 Base Perm 1437.00 0.00 0.00 1067.50 1437.00 0.00 0.00 0.00 -- 0.00 0.00 5795581. 00 514375.00 N 69. 85267292 W 149. 88605784 1500.00 0.00 0.00 1130.50 1500.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149 .88605784 1600.00 0.00 0.00 1230.50 1600.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149 .88605784 1700.00 0.00 0.00 1330.50 1700.00 0.00 0.00 0.00 -- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149 .88605784 1800.00 0.00 0.00 1430.50 1800.00 0.00 0.00 0.00 -- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149 .88605784 WeIlDesign Ver SP 2.1 Bld( do~AOx_100) Panthera\Panthera\Panthera\Panthera (P1) Generated 3/4/2008 12:17 PM Page 1 of 2 Comments Measured Inclination Azimuth Sub-SeaTVD TVD Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft d d ft ft k k ft d de 1100 k Index ftUS ftUS IOpIJGA 7tf4tf.UU U.VU U.UU 74/C.OV 7646.UU l/.UV U.VU V.VV -- v.vV v.vv J/>wo/. vv JIYJ/J.VV vVJ. VJGV/GJG vv I+.~. vvuvJ/v+ 1900.00 0.00 0.00 1530. 50 1900.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 88605784 9-5/8" Csg Pt 2000.00 0.00 0.00 1630. 50 2000.00 0.00 0.00 0.00 -- 0.00 0.00 5795581. 00 514375.00 N 69. 85267292 W 149. 88605784 2100.00 0.00 0.00 1730. 50 2100.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 88605784 2200.00 0.00 0.00 1830. 50 2200.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 88605784 2300.00 0.00 0.00 1930. 50 2300.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 88605784 2400.00 0.00 0.00 2030. 50 2400.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 88605784 2500.00 0.00 0.00 2130. 50 2500.00 0.00 0.00 0.00 -- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 88605784 2600.00 0.00 0.00 2230. 50 2600.00 0.00 0.00 0.00 -- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 88605784 Top Lower Ugnu 2635.00 0.00 0.00 2265. 50 2635.00 0.00 0.00 0.00 -- 0.00 0.00 5795581. 00 514375.00 N 69. 85267292 W 149. 88605784 2700.00 0.00 0.00 2330. 50 2700.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 8860578 2800.00 0.00 0.00 2430. 50 2800.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 8860578 2900.00 0.00 0.00 2530. 50 2900.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 88605784 Top West Sak D 2951.00 0.00 0.00 2581. 50 2951.00 0.00 0.00 0.00 --- 0.00 0.00 5795581. 00 514375.00 N 69. 85267292 W 149. 88605784 3000.00 0.00 0.00 2630. 50 3000.00 0.00 0.00 0.00 -- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 88605784 3100.00 0.00 0.00 2730. 50 3100.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 88605784 3200.00 0.00 0.00 2830. 50 3200.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 88605784 Top West Sak A-1 3267.00 0.00 0.00 2897. 50 3267.00 0.00 0.00 0.00 -- 0.00 0.00 5795581. 00 514375.00 N 69. 85267292 W 149. 88605784 3300.00 0.00 0.00 2930 .50 3300.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 88605784 3400.00 0.00 0.00 3030 .50 3400.00 0.00 0.00 0.00 -- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 88605784 3500.00 0.00 0.00 3130 .50 3500.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 88605784 3600.00 0.00 0.00 3230 .50 3600.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 88605784 3700.00 0.00 0.00 3330 .50 3700.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 88605784 3800.00 0.00. 0.00 3430 .50 3800.00 0.00 0.00 0.00 -- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 88605784 3900.00 0.00 0.00 3530 .50 3900.00 0.00 0.00 0.00 -- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149. 88605784 Top Coleville 3954.00 0.00 0.00 3584. 50 3954.00 0.00 0.00 0.00 -- 0.00 0.00 5795581 .00 514375.00 N 69. 85267292 W 149. 88605784 4000.00 0.00 0.00 3630 .50 4000.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149 .88605784 4100.00 0.00 0.00 3730 .50 4100.00 0.00 0.00 0.00 -- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149 .88605784 TD / 3-1/2" Csg 4191.00 0.00 0.00 3821 .50 4191.00 0.00 0.00 0.00 --- 0.00 0.00 5795581 .00 514375.00 N 69 .85267292 W 149 .8860578• Legal Description: Northing (Y) fftUSl Easting (X) fftUSl Surface : 5089 FSL 850 FEL S28 T6N R9E UM 5795581.00 514375.00 BHL : 5089 FSL 850 FEL S28 T6N R9E UM 5795581.00 514375.00 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Panthera\Panthera\Panthera\Panthera (P1) Generated 3/4/2008 12:17 PM Page 2 of 2 ,; Chevrt~n ALL Panthera (P1) FIELD White Hills Chevron 6TRUDTDRE Panthera Magnetic Parzme~ers ace NAD2]Alaska Slale Planes, Zone 04, U5 Fael scellaneous Motlal'. BGGM 200] Bi0. 604]6° Latm ~N69519.623 Norlfl'mg'. 5]95581.00 flU5 :+0.1069]00]° SMN: Pantbea MlRef: Rotary Tabk: (369.SOfl above MSL) 49539808 Ealing: 5143]500 f1U8 8fale Fact: 0.9999002348 Plan: Pantberz (Pt) Srvy Bale: Marcb 04, 2006 -1000 -500 0 500 1000 0 500 1000 1500 O O ~. 2000 N R H 2500 3000 3500 4000 .. - - n ase Penn _ ,. ,. ,. ., _ a ~ _ e a e .. e e e .. .. .. ''-ap PC Ae e a >, n n ,,.~ .. a ,~~ ~°°. °° 8-518" Csg P[ . .° . 0 500 1000 1500 2000 2500 3000 3500 4000 1000 -500 0 500 1000 Vertical Section (ft) Azim = 90°, Scale = t (in):500(ft) Origin = 0 N/-S, 0 E/-V r~ r REV DATE BY CK APP DESCRIPTION REV DATE BY CK PP DESCRIPTION I 2-4-OS SAS KWA SHOW NEW PAD LOCATION AND CONFIGURATION W W L~ ~ ~ ~ ~ O ., _ -- ~ ~ ~ . ~ T 7 N r~ ~. ~ER R\ ~ SCALE: " ' PANTHERA ~ UK /KUPAR 1 = 200 \ ~ NOTES: .~ / / . ~ _ ._ ~ ~ 1. COORDINATES SHOWN ARE NAD 27 T 6 N ALASKA STATE PLANE ZONE 4. 2. GEOGRAPHIC COORDINATES ARE NAD T 5 N 27. 3. ALL DISTANCES ARE GROUND. ~ ICE ROAD 4. ICE PAD IS ROTATED 70° EAST FROM NORTH. 5. VERTICAL DATUM IS ASSUMED. VICINITY MAP 1" = APPROX. 3 MI. 300' . PANTHERA ~5po' $ 0 N LOCATED WITHIN PROTRACTED E tS 7p - SEC. 28, T 6 N, & R 9 E, SMG gPSKE .` 'N STORAGE \ UMIAT MERIDIAN. cP ~,` ~ , ~ ~. ~ U, ~ 190' F.N.L, 850' F.E.L. " ' `, O'~\ ~ TO pEN y o N 09.626 LAT = 69°51 s E `\11NicK ~~i ~ ~ ~ LONG = 149°53'09.816" W ~~E~ ~ ~ ..., ~ `~" Y = 5,795,581' y ~ ~ ~ X = 514,375' ~ DRaE PIPE O PROPOSED ~ ~ 35' ACCESS N`O ~ \~ ~ R OAD O O O '~ MUD I ' ~~ / ` GG STORAGE ~ AGE ~iGKENED ° ~ LEGEND ~ R'PP0 zaMP o • s ~, \ ~,/ ~ DENOTES SPILL TRAJECTORY ` ',, ~ t/, ~ 500 / ,' ~ STAKED CONDUCTOR LOCATION. za~~0a ` /% S D LIMITS P ICE A LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS PANTHERA EXPLORATORY WELL 1'~ 1 ~ AS-STAKED DRAWING WITH PAD CONFIGURATION UNION OIL OF CALIFORNIA INCLUDING CONTOURS AND SPILL TRAJECTORY CADD FILE N0. DRAWING N0: SHEET: REV: PANTHERA 9-25-07 PANTHERA.dwg I OF I I Panthera Depth vs. Time 0 1000 2000 w ,~ 3000 a A 4000 5000 6000 Panthera Actual -+-Panthera Plan 12-1 /4" Hol 9-5/8" Casing -1 /2" Hole DeMob Logging i i 0 5 10 15 20 25 30 35 Time (Days) Maximum Anticipated Surface Pressure Calculation Panthera 28-6-9 White Hills Exploration Assumptions: 1. Based on offset drilling data & G&G evaluation and analysis, the pore pressure gradient is predicted to be a a normal 0.433 psi/ft gradient from surface to planned total depth at 4685' TVD BRT. 2. The M.A.S.P. during drilling operations will be governed by the 9-5/8" shoe frac gradient, and is calculated based on a full column of gas between the 9-5/8" shoe and the surface. With the shoe for Smilodon at 2000' TVD, the Leak-off is anticipated to be -12 ppg EMW. 3. The M.A.S.P. during production operations will be the estimated SIBHP minus the gas hydrostatic pressure between TD & the surface. M.A.S.P. Drilling 8-1/2" Hole at 4191' TVD Max. pore pressure at T.D. = 4,191 ft. x 0.433 psi/ft = 1815 psi - M.A.S.P. = 1815 psi - ( 0.1 psi/ft x 4191 ) = 1396 psi Calculation & Casing Design Factors Panthera 28-6-9 White Hills Exploration WELL: Panthera 28-6.9 FIELD: White Hills DATE: 4-Mar-08 DESIGN BY: W. Quay Sect. 1 12 1/4" hole MUD WT. 9.5 PPG MASP= 0 Diverter Sect. 2 8 1/2" hole MUD WT. 9.3 PPG MASP= 1,396 psi TENSION MINIMUM COLLAPSE COLLAPSE WEIGHT TOP OF STRENGTH PRESS @ RESIST. MINIMUM DESCRIPTION W/O BF SECTION TENSION WORST CASE BOTTOM w/o TENSION WORST CASE MASP YIELD WORST CASE SECTION CASING ; BOTTOM TOP LENGTH WT. GRADE THREAD LBS LBS 1000 LBS SF TENSION PSI" PSI SF COLL. PSI*" PSI SF BURST 1 9-5/8" 2,000 0 2000 40 L-80 BTC 80,000 80,000 916 11.45 904 3,090 3.42 1,641 5,750 3.50 TVD 2,000 0 2 3-1/2" 4,191 0 4191 9.3 L-80 IBT 38,976 38,976 207 5.31 1,534 10,530 6.86 2,356 10,180 4.32 TVD 4,191 0 * Collapse pressure is calculated; Normal Pressure Fluid Gradient for external stress (.452 psi/ft) and the casing evacuated for the internal stress (0 psi/ft) ** See attached sheet for calculation of MASP i~ Diverter Schematic Date - October 17, 2007 Location - White Hills -North Slpe Rig - Nabors 106E Stack: Size - 13 5/8" Pressure Rating - 5000 PSI ~, i ~., i t. I. ~.. ~. ~:Li,t;: i >1I rr-.a yI 1 `~~ ~~ { ~I J i iY~ ».:.'3 iy Annular: Hydril 13-5/8" GK Double Gate BOP Deactivated Drilling Spool Single Gate BOP Deactivated Knife Valve: 12" Diverter Line LEAK OFF TEST PROCEDURE 1. Clean out the rathole below the shoe, and drill 20' of new hole. Circulate and condition mud. 2. Pull the drill string into the shoe. Rig up to observe annulus pressures. 3. Close the pipe rams and pump down the drillpipe at a slow rate (1/4 - 1/3 BPM) if exposed formation is permeable. Anon-permeable formation should be step tested to a predetermined pressure. 4. Measure the volume pumped and plot annulus pressure-vs-cumulative volume pumped. Compare annulus pressure to drill pipe pressure and confirm both are the same. Record and plot pressure versus volume pumped. The pumps should be shut down immediately upon indication of leak-off. Record the inital, shut down pressure and the pressure after 1, 2, and 3 minutes. 5. Release pressure and record the volume of fluid recovered in the trip tank The point "B" shown in the attached graph at which the plot of drillpipe pressure stops increasing equally as the volume is pumped is called the P.I.T. limit, Leak Off, or pressure integrity test limit. The leak-off pressure is calculated as follows: Leak-off (EMW) = Mud weight in hole + P.I.T. (PSI) (0.052) X (shoe depth in TVD ft.) This equivalent mud weight should be made known to all drilling personnel to ensure it is not exceeded. See the drilling procedure for guidelines on expected LOT's or pressure integrity test limits for each casing shoe. SURFACE PRESS. TYPICAL PIT PLDT [psi] NOTES: Point "A" will have some variance until the system begins to pressure up. Point "B" is the leak off and is abbreviated LOT. Point "C" is known as the injection pressure and is usually dependent on rate. Point "D" is known as the fracture closure pressure and may not stabilize if permeable formations are exposed. VOLUME PUMPED SHUT-IN-TIME [BBLS], [MIN] North Slope Alaska White Hills Prospect SHALLOW HAZARD ANALYSIS PANTHERA 27-6-9 MidContinent/Alaska BU Chevron North America Exploration and Production Company 11111 S. Wilcrest Houston, TX 77009 CHEVRON ACREAGE `' 1~'hite hills -. ~ ,., cl-.x n~o°;, ~' i __ ~~.- -_ ,' _- - _ ; ,~ %' tr<,_ .11awf ~ ; ~uc:a>s, Union Oil Company of California (UOCC), a wholly owned indirect subsidiary of Chevron Corporation currently has leased approximately 20 x 40 sq miles of acreage on the Central North Slope of Alaska (Fig 1). UOCC ' holds 100% working interest in the field which is bounded by the National Petroleum Reserve of Alaska (NPRA) to the West, the Trans-Alaska Pipeline (TAPS) to the East, Kuparuk River and Prudhoe Bay Fields to the North and the Brooks Range Foothills to the South. STRaTicRaPHV & RESERVOIR OBJECTIVES ~ ram .Era __~i~= ;, .. _ ~- --T- -~ x ._~ i _ ._ _ _ - _M~~._ ~. - ~. i ~ I - _. '. 'fin ~~..~~ _ ~._ .z I , _ T ~ ~ - -- -- I -11 _.~~ I `x 1 6 ' i . j1,I . ~.. ' W ~:r ---- ~ ~~ T~r~~Sl~_ ~T - :~ ~ P E K'~fil'~.a~ _ `. ~~--: U II . 1~ . ~ ~ ~ ~~ ~l' FEh,~J~S rL,',L. ~li~4f, ~ri ~ C,r~-u:~~ ~t~~ ~ ~~~ _ ~~ _ ~i ~:~ _. ~ -" "... - - - - _ Fig 2: White Hills Stratigraphy The Panthers 27-6-9 well will target reservoir objectives in the shallow Tertiary through Upper Cretaceous (Mastrictian) stra a~referred to as the Saganivriktok, Prince Creek, Ugnu and West Sak Formations bounded at the top by the permafrost and down to a total depth of approximately 5000 ft MD. Overall, the sequence records aregressive-transgressive cycle starting with the West Sak (Schrader Bluffl shallow marine prograding shelf sands, overlain by Ugnu fluvial-deltaic and then Non-marine Prince Creek and Sagavanirktok clastic strata. (From USGS Open-File Report 2005-1182) 2 ,r-i ~ , t :~ "~ 1 :2 rs, __ 17111 .... y PRINCE CREEK FORMATION Sagavanirktok Group and Prince Creek Formation The Panthera 27-6-9 well will spud in Tertiary generally upward-coarsening Sagavanirktok siltstones, fine to very-fine grained sandstones, interbedded bentonitic mudstones with minor lignite horizons, and gravels deposited under shallow marine to non-marine conditions. Below the Sagavanirktok Group are undifferentiated Prince Creek coarse clastic strata, comprised of gravels, coarse lithic sands, lignites, and siltstones. The Prince Creek sandstones typically exhibit 8-30% clay content, with porosities to 38% and permeabilities to several darcies. UGNU FORMATION Ugnu Sands The Early Paleocene Ugnu Formation consists of upper-fine to medium and coarse grained lithic sandstones, siltstones, bentonitic shales, lignites, and some gravels deposited in anon-marine delta plain environment. The sandstones are poorly indurated to unconsolidated, with porosities exceeding 35% and to several darcies permeability. Heavy oil saturation is common 30 miles to the north in Kuparuk River, Milne Point, and Prudhoe Bay fields. WEST SAK FORMATION West Sak Sands The West Sak consists of a shallowing upward shallow marine sequence comprised of very fine-grained, single and amalgamated hummocky cross-stratified sandstone beds. The formation is typically characterized by fine to medium-grained, unconsolidated but well sorted sands interbedded with siltstones, mudstones, and coals. The West Sak sands were deposited in a shoreface to proximal shelf environment. Lower West Sak members were deposited in a lower shoreface to inner shelf setting by storm-generated waves and currents, both the upper and lower members showing good continuity both in the subsurface in areas with good control and in the outcrops to the southwest and south. The Panthera 27-6-9 well will TD at the base of the West Sak Formation at approximately 5000 ft MD. --_ ~----- i~ a °: r::2tar~tS STRUCTURE Fig 3: Pre-stack time migrated 2D White Hills 2D seismic line (wg82-30); dip direction The regional structure on the top of the West Sak in the vicinity of the Panthera 27-6-9 well is a monocline that strikes north-south and dips eastward at between 1 ° and 2°. The reservoir occurs at relatively shallow depths within the West Sak core area, with the top of the "D" sand being located at between -2536 and --2801 feet subsea. To the west of the core area the top of the West Sak shallows until it intersects the base of the permafrost at about 1,000 feet subsea to the west of Panthera 27-6-9. The Panthera structure consists of aNorthwest-Southeast trending closure with stratigraphic and dip related traps. The structure is thought to have both permafrost and temperature seals. The structure shows distinctive depositional fairways for sand accumulation based on 2D seismic, surface geology, and magnetic data. The structure sub-outcrops at certain places throughout the field allowing regional correlation between 4 9 the source rock and target formations. The primary reservoir objectives include gas in the Prince Creek, Ugnu and West Sak formations. GEOPHYSICAL DATA QUALITY ~~ -- ~, . _, _~ l _ . .. . --L I _ _ .'._..,. t Fig 4: Approximate mapped extent of poor quality 2D seismic data _.. ~1.. .. - - - ~~ +Y _... ... it ~4 It 5 ~~ ~~l' u..-.- Chevron has an extensive grid of 2D spec data. With our working interest participation in the Kuparuk and Prudhoe Bay fields, we have obtained as much well data and 3D seismic as we are entitled too in order to characterize the White Hills area south of the current main producing fields. Currently, our key 2D lines through the White Hills prospective area have undergone several stages of reprocessing. In 2002, GeoTrace produced apre-stack migration data set which was later reprocessed by 5 ft ~:3 F,f :1 f:f'3ve~~r: i~`¢ Unocal in 2005 to attempt to apply newer noise reduction techniques. However, after the merger with Chevron, and high grading of the White Hills prospective area, it was decided to try and increase the signal to noise ratio of the data further by applying Chevron's proprietary noise attenuation technique. This was in effort to enhance the image in a large swath of low frequency, poor quality data (Fig2). This poor data zone is coincident with a large portion of the Chevron acreage on the Central North Slope. 2007 DATA ACQUISITION The drilling program for the White Hills area was developed from both geologic and geophysical data sets. The results of the various reprocessed datasets were evaluated and it is clear that the current data quality is not sufficient to determine potential shallow hazards and completely validate well location placement. In the winter of 2007 (Jan 5-Feb 11) nine 2D lines, approximately 170 sq miles as outlined on Fig 3, were acquired over the White Hills area by CGGVeritas. The survey was designed to tie the current proposed well locations in a North-West -- South-East strike direction with two long North -South tie lines. Every attempt was made to avoid water bodies whenever possible due to the potential statics issues that ice lakes have on seismic data. C;? °~ i ~~ ~_. F _~ .~ - ~-_ ~t< °~, K~ :,~ ,~~ ~: F~ ~,~ - -~~ ~ r< Fig 5: Chevron 2007 2D seismic acquisition lines; acquired by CGG Veritas r ~ .1:~.;~:j tts .:;etr~ ass POTENTIAL SHALLOW HAZARDS { ~~_~, t Pat ''1,~ Fig 6: Alaska North Slope Gas Hydrate Energy Resources, USGS Open File Report 2004-1454; by Timothy Collett f Permafrost is expected to 1000 ft below the surface and there is the possibility that gas hydrates could be present although not expected. The current known accumulations of Gas Hydrates (Fig 6) do no appear to be present in the White Hills prospective area. A few coal layers are possible in the permafrost. The 2D pre-stack time migrated line, tying the Cirque wells (Fig 7a, b), shows a high amplitude reflector at the base of permafrost and bounded by faults. We suspect that this well blow out is possibly due to shallow gas. 7 i1 Fig7a: Cirque -Hot Ice tie line ~,r .... , ~...... _ .~~ M. n e-- -., .,y .. «.., s ;ev ..,.. r.. .. -. >. .. ,.. . ~ o ... '.. a wvv .».. .. ...-.~ ~ .„~;, . s ~ sM •• .». ~ v ~W. y ~~ : ~. r+~ .-. _ - .. .. - ~ ~, _ .. ,. ~ . ... a . ,...rr . ., Y ~. ~_• ^. - ,. a *~». cis ",_ . g...~ .. ~ ,~ .. ,. n_ +e. r~ _ a _ ~ .+ ..,+... .... r ... w... .. M .;~. ~. Y .,s r ~~Mt: .~ s. .4 i A'.:.r .~ ~ :;sty r. '. Fig 7b: Cirque tie line (magnified image) 8 3, £k4's;ii 8'~•4'i.:J it 1'.: r"y t~ f The present 2D seismic data quality is poor. In particular, the Central Depth Points (CDPs), which are on the Panthera 27-6-9 well seismic line, are coincident with ice lakes at the time the data was acquired (although not on the well location). Ice lakes pose a significant challenge when processing and interpreting seismic data because of statics issues which diminish the image quality and frequencies in that section (Fig 8). With the current state of the seismic, it is difficult to truly asses the potential for shallow hazards. I~x~ I ~ikr ., .. .... .. - ,. y - ~ ,,* , , . ~. .. p ~~. ~"~w ... .. ` .. °. ~V~ollbutt~_>n _'~-b-`~ ~ Pi~~e~ioc ~t~ite. I .~~ w Fig 8: Pre-stack time migrated White Hills 2D seismic line (ukd82-8); dip direction 9 i.'a~~~.ka eta°_::.~:u-cr>S • Fig 9: Pre-stack time migrated White Hills 2D seismic line (prk84-20); dip direction Lastly, by projecting the Panthera 27-6-9 well to line prk84-20 (approximately 2.7 miles SW) there appears to be another possible shallow hazard. Immediately below the permafrost, there is a loss of amplitude strength which might indicate a gas hydrate. However, this line is also of very poor seismic quality to truly asses all possible hazards. """~" The newly acquired (2007) 2D seismic, acquired to tie the wells and help identify possible shallow hazards, is anticipated to be completed by early summer 2007. The expectation is to review the data as soon as it is completed for any shallow hazards which may not be identifiable on the current pre-stack time migrated dataset. GEO-PRESSURE /VELOCITY ANALYSIS Checkshot and VSP data is sparse in the White Hills area. However, there is sufficient data to generate a velocity field (Fig. 8) across the region which indicates that we should not encounter any velocity anomalies. The permafrost zone has higher velocities as expected and the transition beneath the frozen, lower velocity base is quite distinctive. 10 r ' .., . CHECKSH£~TS Time vs IIsl~th _I . ~~1_ ~~, ha~,c pcrnlafi~ust - - ~ _, 5::'~-Ht~l'S~»~i `T N _~ _.. ~~elth~aiar-s~-1 ~~ _~. lkt~ik=f I -- Cix~ue»i - - -. ~ z - = z= - ~- ` - -:lmethv&3s~S ND E}epth (ftj below T ~ datum ^ ^ Fig. 8 Checkshot and VSP Velocity Field across the White Hills and Surrounding Areas The Wolfbutton 25-6-9 is the most proximal checkshot to the proposed Panthera 27-6-9 well. We expect similar velocities as shown in (Fig 9) on the Interval Velocity (Vint) vs Depth plot; Interval Transit Time (ITT) vs Depth. The plots show the expected faster velocities through permafrost and slower velocities through the zone of interest. From the velocity analysis, we expect a normally pressured regime through the Prince Creek, Ugnu, West Sak formations, and Colville zone. 11 ~ ;a;:i':~F:~ Ptc~.;~d'iri;t:a MUD WEIGHT $c SHALE RESISTIVITY ANALYSIS 3 key wells which delineate the White Hills area and Smilodon prospect are the Malguk #1, Wolfbutton 25-6-9, and Ruby State #1. These wells were used in addition to the checkshot and VSP data to examine the possibility of pressure and velocity anomalies. In Fig (10) Mud Weight (MW) in ppg were plotted vs depth for the 3 wells. The graphs indicate that drilling was balanced through our zone of interest where MW increased with depth. The Malguk well shows an anomaly at 2977 ft which coincides with top of the west sak pay interval; the well was cased at this point. / 12 Fig 9. Wolfbutton 25-6-9: Time vs Depth, Vint vs Depth, ITT vs Depth ~ ' Malguk #1 Rshale ohm-m 100 10 1 0 ~~. _. ~'~x 2000 Nt`v~ I~>li ~- x - ----- ---- -- ~ 4000 LL f t 6000 y O \\ O _,-x 8000 . ~- __ _-- x \~~~~~ - 10000 f ,._.,a ---~: 12000 8.8 9 9.2 9.4 9.6 9.8 10 10.2 10.4 Mudweight ppg Mudweight and Shale Resistivity versus Measured Depth plot for the Malguk #1 well. Mudweights were increased from 1200' to casing point due to oil - and gas shows in the mudstream. Note that the shale resistivity trend indicates a normally pressured section down to approximately 10,000 feet, where a higher pressured regime is indicated. 13 • 100.00 I Wolfbutton #25-6-9 Rshale ohm-m 10.00 1.00 --- L 0.00 IZ~Ii 2000.00 4000.00 6000.00 8000.00 10000.00 12000.00 I 8.00 8.50 9.00 9.50 10.00 10.50 11.00 I Mudweight ppg i Mudweight and Shale Resistivity versus Measured Depth plot for the Wolfbutton #25-6-9 well. The shale resistivity trend indicates a normally pressured section at least down ~/ to 8,000 feet. \1\1- - 14 a w a.~~.~.~ ,,=.>~2U~~:~~ Prepared by: Dave Buthman Geologist /Technical Team Lead Alaska New Ventures Team MidContinent /Alaska BU (281) 561-3401 buthbdb(a~chevron.com • Monique Velasquez Sr. Exploration Geophysicist Alaska New Ventures Team MidContinent /Alaska BU (281)561-4958 moni uevelas uez chevron.com 15 FW: Notice of Ownership for White Hills Leases -- AOGCC Page 1 of 2 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Friday, March 07, 2008 4:49 PM To: 'Quay, Walter [ASRC]' Cc: Quick, Mike [ASRC]; Stanek, Judy A; Buthman, David B; Saltmarsh, Arthur C (DOA) Subject: RE: Notice of Ownership for White Hills Leases -- AOGCC Walter, Mike and Judy: Thanks for your help on this. The Notice of Ownership forms for the White Hills leases must be signed, proof of signatory authority far whomever signs must be attached, and the signed form and attachment must be sent to AOGCC for our records. I will be out of the office next week, so please contact Art Saltmarsh at 793-1230 if you have any questions. We'll need them before the Panthera permit can be approved. Thanks, Steve Davies AOGCC From: Quay, Walter [ASRC] [mailto:WQuay@chevron.com] Sent: Thursday, March 06, 2008 3:12 PM To: Davies, Stephen F (DOA) Cc: Quick, Mike [ASRC]; Stanek, Judy A; Buthman, David B Subject: FW: Notice of Ownership for White Hills Leases -- AOGCC Steve, Here is additional information as requested on the White Hills Lease ownership. I will be out of the office until March 17th with Mike Quick (279-7900} as my alternate. Walter Quay WQuay@chevron.com Office: 907-263-7812 Cell: 907-230-3961 From: Stanek, Judy A Sent: Thursday, March 06, 2008 2:15 PM To: Quay, Walter [ASRC] Cc: Quick, Mike [ASRC); Buthman, David B; Martin, Shannon W Subject: RE: Notice of Ownership for White Hills Leases -- AOGCC Wa Ite r, I have attached the AOGCC's Change of Ownership form {unsigned) for ADL 390003 and the approved assignments showing how Union Oil Company of California became 100°/a Working Interest Owner. Do you want to forward these to Steve Davies or do you want me to contact him to see if this is adequate. I'm pretty sure this should work. Union Oil Company of California was the original owner of ADL 389986 so there should be no need to compete this form. Also attached is Exhibit A of the lease showing it's location. «ADL 390003 AOGCC Notice of Ownership.xls» «ADL390003 Forsgren to Union Oil.pdf» «ADL390003 Bachner to Union Oil.pdf» «ADL390003 Fedderson to Union Oil.pdf» «Document.pdf» 3/8/2008 FW: Notice of Ownership for White Hills Leases -- AOGCC Judy Judy Stanek Land Specialist Chevron North America Exploration and Production 909 West 9th Ave., Anchorage, AK 99501 Tel 907-263-7963 Fax 907-263-7698 stanekj@chevron.com From: Quay, Walter [ASRC] Sent: Thursday, March 06, 2008 10:09 AM To: Stanek, Judy A Cc: Quick, Mike [ASRC]; Buthman, David B Subject: Notice of Ownership for White Hills Leases -- AOGCC Page 2 of 2 Judy, As per our conversation this morning, I have a request from the AOGCC(Steve Davies 793-1224) for a Notice of Ownership form for Panthera and Mastodon.. Possibly for Smilodon and any other wells we are planning. The criteria being this is required for any leases that Union Oil Company of California did not buy the lease in a lease sale, but obtained from some other entity(such as some other company or individual). This request is high priority as this issue was discovered in the Panthera Drilling Permit application review by Steve Davies. This permit will be needed in a bit over 10 days from now. The attached note from Vince LeMieux is still current for the five locations for this year. « Message: Land information » Walter Quay WQuay@chevron.com Office: 907-263-7812 Cell: 907-230-3961 3/8/2008 FW: Notice of Ownership for White Hills Leases -- AOGCC Page 1 of 2 i ~ Davies, Stephen F (DOA) From: Quay, Walter [ASRC] [WQuay@chevron.com] Sent: Thursday, March 06, 2008 3:12 PM To: Davies, Stephen F (DOA) Cc: Quick, Mike [ASRC]; Stanek, Judy A; Buthman, David B Subject: FW: Notice of Ownership for White Hills Leases -- AOGCC Attachments: ADL 390003 AOGCC Notice of Ownership.xls; ADL390003 Forsgren to Union Oil.pdf; ADL390003 Bachnerto Union Oil.pdf; ADL390003 Fedderson to Union Oil.pdf; Document.pdf Steve, Here is additional information as requested on the White Hills Lease ownership. I will be out of the office until March 17th with Mike Ouick (279-7900} as my alternate. Walter Quay WQuay@chevron.com Office: 907-263-7812 Cell: 907-230-3961 From: Stanek, Judy A Sent: Thursday, March 06, 2008 2:15 PM To: Quay, Walter [ASRC] Cc: Quick, Mike [ASRC]; Buthman, David B; Martin, Shannon W Subject: RE: Notice of Ownership for White Hills Leases -- AOGCC Walter, I have attached the AOGCC's Change of Ownership form {unsigned} for ADL 390003 and the approved assignments showing how Union Oil Company of California became 100°I° Working Interest Owner. Do you want to forward these to Steve Davies or do you want me to contact him to see if this is adequate. !'m pretty sure this should work. Union Oil Company of California was the original owner of ADL 389986 so there should be no need to compete this form. Also attached is Exhibit A of the lease showing ifs location. «ADL 390003 AOGCC Notice of Ownership.xls» «ADL390003 Forsgren to Union Oil.pdf» «ADL390003 Bachnerto Union Oil.pdf» «ADL390003 Fedderson to Union Oil.pdf» «Document.pdf» Judy Judy Stanek Land Specialist Chevron North America Exploration and Production 909 West 9th Ave., Anchorage, AK 99501 Te1907-263-7963 Fax 907-263-7698 stanekj@chevron.com 3/8/2008 FW: Notice of Ownership for White Hills Leases -- AOGCC Page 2 of 2 From: Quay, Walter [ASRC] Sent: Thursday, March 06, 2008 10:09 AM To: Stanek, Judy A Cc: Quick, Mike [ASRC]; Buthman, David B Subject: Notice of Ownership for White Hills Leases -- AOGCC Judy, As per our conversation this morning, I have a request from the AOGCC(Steve Davies 793-1224) for a Notice of Ownership forrrt for Panthera and Mastodon.. Possibly for Smilodon and any other wells we are planning. The criteria being this is required for any leases that Union Oil Company of California did not buy the lease in a lease sale, but obtained from some other entity(such as some other company or individual). This request is high priority as this issue was discovered in the Panthera Drilling Permit application review by Steve Davies. This permit will be needed in a bit over 10 days from now. The attached note from Vince LeMieux is still current for the five locations for this year. « Message: Land information » Walter Quay WQuay@chevron.com Office: 907-263-7812 Cell: 907-230-3961 3/8/2008 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMII~ION NOTICE OF OWNERSHIP* 20 AAC 25.022 1. Name of Current Owner of Record: Union Oil Company of California 2. Address: Attn: Land Manager P.O Box 196247 Anchorage, AK 99519-6247 3. Notice is hereby given that the above named owner Q ,landowner , of record for the oil and gas property described below has assigned or transferred interest in the property indicated below: Property Designation: ADL 390003 Legal description of property: Field or Unit: T. 6 N., R. 9 E., UMIAT MERIDIAN, ALASKA SECTION 19, UNSURVEYED, ALL, 618.00 ACRES; SECTION 20, UNSURVEYED, ALL, 640.00 ACRES; SECTION 21, UNSURVEYED, ALL, 640.00 ACRES; SECTION 28, UNSURVEYED, ALL, 640.00 ACRES; SECTION 29, UNSURVEYED, ALL, 640.00 ACRES; SECTION 30, UNSURVEYED, ALL, 620.00 ACRES; SECTION 31, UNSURVEYED, ALL, 623.00 ACRES; SECTION 32, UNSURVEYED, ALL, 640.00 ACRES; SECTION 33, UNSURVEYED, ALL, 640.00 ACRES; Property plat attached 4. Effective date of assignment or transfer: 5. Percentage interest assigned or transferred: 4/1 /2006 100% 6. Assignee or Transferee (new owner): Union Oil Company of California Address: 7. Assignor or Transferor (existing owner): James Andrew Bachner, Keith C. Forsgren, and David G. Fedderson -See Attached Assignments Address: 8. Assignor or Transferor hereby certifies that the foregoing is true and correct (attach Power of Attorney or other evidence of authority of person signing): Signature: Date: Printed Name: Title: "This form is required to be filed with the Alaska Oil and Gas Conservation Commission within 15 days after a person becomes owner of a property pursuant to 20 AAC 25. 022 and upon all subsequent changes in ownership. Form 10-417 Rev.12/2005 ~~a~C~ 0~ aC~~G~ DEPARTMENT OF NATURAL RESOURCES DIVISION OF OlL AND GAS March 20, 2006 FRANK H. MURKOWSKI GOVERNOR 550 WEST 7~ AVENUE, SUITE 800 ANChIOR,4GE, ALASKA 99501-3560 PHONE: (907) 269-8800 FAX.- (907) 269-8938 ,~ ~~ Assignor: Keith C. Forsgren P.O. Box 870529 Wasilfa, AK 99687-0529 Assignee: Union Oil Company of California Attn: Land Manager P.O. Box 196247 Anchorage, AK 99519-6247 Oil and Gas Leases ADL's 389994, 389995, 389996, 389999, 390001, 390002, 390003, 390004, 390005, 390006, 390007, 390008, 390009, 390019, 390023 Assignment Applications Approved The Director approved applications for assignment of 10.0 percent working interest in the above leases from Keith C. Forsgren to Union Oil Company of California on March 20, 2006, effective April 1, 2006. Keith C. Forsgren retains 0.10 percent overriding royalty interest the above leases. These assignments are approved as to the working interest only and do not constitute approval or acceptance of any stipulations or attachments to the assignment instrument. Approved assignments are enclosed. Dianna Lewis Natural Resource Specialist Enclosures DL/dl(369994-2 "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." i ~ DO&G 25-84 LEASE ADL, 390003 (LEASE ASSIGNMENT) EFFECTIVE DATE Revised 12/01 OF LEASE 9/1/2002 DNR #10-1 13 Is this lease producing? __yes X ^no STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS ASSIGNMENT OF INTEREST IN OIL AND GAS LEASE The undersigned assignor Keith C. Forsgren. , whose address is P.O. Box 870529. Wasilla. AK 99687-0529, as owner of 10.00% percent of the lease's working interest does hereby assig-1 to Union Oil Company of California ,the assignee, whose address is _ P.O. Box 196247. Anchorage, AK 99~ 19-6247 , l . 10.00% percent working interest; 2. 0.00 percent overriding royalty interest. 3. The assignor is retaining 0 percent of the lease's working interest. 4. The assignor is retaining .100% percent of overriding royalty interest. 5. LANDS AFFECTED by this assignment of interest (Attach Exhibit A if necessary) T _ , R ~ Meridian, Alaska SEE EXHIBIT A containing 5701 acres, more or less. The Notification Lessee for the purpose of receiving any and all notices from the State of Alaska in connection with the lease will be: Name Union Oil Comnanv of California Attn: Kevin A. Tabler, Land Manager Address: P.O. Box 19624 City, State, Zip Anchorage, AK 99519-6247 We, the undersigned, request the approval of this assignment application. We attest that this application discloses all parties receiving an interest in the lease and that it is filed pursuant to 11 AAC 82.605 and 11 AAC 82.615. We further attest that all parties to this agreement are qualified to transfer or hold an interest in oil and gas leases pursuant to 11 AAC 82.200 and 11 AAC 82.205. Whether approved in whole or in part, the assignee agrees to be bound by the provisions of said lease. // ~ ~' Assignor's Si afar D~ gn ate 1 Keith C. ForsQren Assignor's Name (Print or Type) & Title Company Name THE UNITED STATES OF AMERICA ) Qualification File # )SS. STATE OF ALASKA ) This certifies that on the l~~ day of _ f f ~ 2005, before me, a notary public in and for the State of Alaska, duly commissioned and sworn, personally appeared ~. eta} ~AC~'-n2Y Pd 14 , to me known and known to me to be the person described in, and who executed the foregoing assignment, who then after being duly sworn according to law, acknowledged to me under:oatb, that he executed same freely and voluntarily for the uses and purposes therein mentioned. WITNESS,~I~$ '~icial seal the day and year in this certificate first above f written. _ ~R_~%`~ .ti TARy; ~a = ~ ~ L 1 C ota Public ~; ~` G~ = ti A y mmission expires: I ' ;. ,,, _ Oi= Pte- ~` scts~^iat~ ~ 3-31-os gnee's Signature Date Kevin A. Tabler. Attornev-in-Fact Assignee's Name (Print or Type) & Title Union Oil Company of California Company Name THE UNITED STATES OF AMERICA } }SS. STATE OF ALASKA ) Qualification File # 6 This certifies that on the 3 l day of 2005, before me, a notary public in and for the State of Alaska, duly commissioned and sworn, personally appeared Kevin A. Tabler, Attorney-in-Fact, to me known and known to me to be the person described in, and who executed the foregoing assignment, who then after being duly sworn according to law, acknowledged to me under oath that he executed same freely and voluntarily for the uses and purposes therein me `\~{IIi~~SS my hand and official seal the day and yeaz in this certificate first above written. ~\~`'i'~, ~^jq ~//'/// ~.~'o i NOTARY ~: = tart' Public -a} ~ PUBLIC ~ .* My Commission expires: ~. /5'~-Djo '~ 0 F A\-P~~~ ~(t,11141~~Q\t~ APPROVAL The foregoing assignment is ap~roved as to the lands described in item 5 thereof, effective as of the date set forth. below. _ _ _ __.- . _. \ William D. Van Dyke, Acting Dircc o Division of Oil & Gas, DNR, State of Alaska Effective Date of Assignment • ADL 390003 Exhibit A Lease Assignment Legal Description T. 6 N., R. 9 E., UMIAT MERIDIAN, ALASKA SECTION 19, UNSURVEYED, ALL, 618.00 ACRES; SECTION 20, UNSURVEYED, ALL, 640.00 ACRES; SECTION 21, UNSURVEYED, ALL, 640.00 ACRES; SECTION 28, UNSURVEYED, ALL, 640.00 ACRES; SECTION 29, UNSURVEYED, ALL, 640.00 ACRES; SECTION 30, UNSURVEYED, ALL, 620.00 ACRES; SECTION 31, UNSURVEYED, ALL, 623.00 ACRES; SECTION 32, UNSURVEYED, ALL, 640.00 ACRES; SECTION 33, UNSURVEYED, ALL, 640.00 ACRES; THI5 TRACT CONTAINS 5,701.00 ACRES, MORE OR LESS. D ^ ~ ~ ~ FRANK H. MURKOWSKI U GOVERNOR DEPARTMENT OF NATURAL RESOUKCES 55o wESr ~T" AvENUF surrE aoo ANCHORAGE, ALASKA 99501-3560 DIVISION OF OIL AND GAS PHONE: (90~ 269-8800 FAX: (907) 269-8938 March 20, 2006 Assignor: J. Andrew Bachner P.O. Box 82130 Fairbanks, AK 99708 Assignee: Union Oil Company of California Attn: Land Manager P.O. Box 196247 Anchorage, AK 99519-6247 Oil and Gas Leases ADL's 389994, 389995, 389996, 389999, 390001, 390002, 390003, 390004, 390005, 390006, 390007, 390008, 390009, 390019, 390023 Assignment Applications Approved The Director approved applications for assignment of 85.0 percent working interest in the above leases from J. Andrew Bachner to Union Oil Company of California on March 20, 2006, effective April 1, 2006. J. Andrew Bachner retains 0.850 percent overriding royalty interest the above leases. These assignments are approved as to the working interest only and do not constitute approval or acceptance of any stipulations or attachments to the assignment instrument. Approved assignments are enclosed. ~Cl/~Q~n~r ' Dianna Lewis Natural Resource Specialist Enclosures QUdIl389994-1 "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." • ll0&G 25-84 LEASE ADL 390003 (LF,ASE .ASSIGNMENT) EFFECTIVE DATE Revised i 2/0l OF LEASE 9/1;2002 DNR t#10-I 13 Is this lease producing? _yes __X_no STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS ASSIGNMENT OF INTEREST IN OIL AND GAS LEASE The undersigned assignor J. Andrew Bachner. whose address is P.O. Box 82130. Fairbanks. AK 99708, as owner of 85.00% percent of the lease's working interest does hereby assign to Union Oil Company of California ,the assignee, whose address is P.O. Box 196247, Anchorage, AK 99519-6247 , 1. 85.00% percent working interest; 2. _ 0.00 percent overriding royalty interest. 3. The assignor is retaining 0 percent of the lease's working interest. 4. The assignor is retaining .850% percent of overriding royalty interest. 5. LANDS AFFECTED by this assignment of interest (Attach Exhibit A if necessary) ,r . R _ Meridian, Alaska SEE EXHIBIT A containing 5701 acres, more or Less. The Notification Lessee for the purpose of receiving any and all notices from the State of Alaska in connection with the lease will be: Name Union Oil Comoanv of California Attn: Kevin A. Tabler. Land Manager Address: P.O. Box 19624 City, State, Zip Anchorage, AK 99519-6247 We, the undersigned, request the approval of this assignment application. We attest that this application discloses all parties receiving an interest in the lease and that it is filed pursuant to 1 I AAC 82.605 and I 1 AAC 82.615. We further attest that all parties to this agreement are qualified to transfer or hold an interest in oil and gas leases pursuant to 1 1 AAC 82.200 and I i AAC 82.205. Whether approved in whole or in part, the assignee agrees to be bound by the provisions of said lease. ll ~ `~ ` /~ . % - ---.~t._._, d~signo Signature J. Andrew Bachner Assignor's Name (Print or Type) & Title y~~-es Date Company Name THE UNITED STATES OF AMERICA ) Qualification File # )SS. STATE OF ALASKA ) This certifies that on the (a.~' day of , 2005, before me, a notary public in and for the State of Alaska, duty commissioned and sworn, personalpeared J. Andrew Bachner, to me known and known to me to be the person described in, and who executed'the foregoing assignment, who then after being duly sworn according to law, acknowledged to me under oath >i~~ same freely and voluntarily for the uses and purposes therein mentioned. WITNESS my hand anc~,>~i~t;se~d year in this certi ate first above written. ~~ N~T~'~ • =~ otary Public Y~ ` ~. ~,~~ ~ *` My Commission expires: /~-fY d .f ''~,~ pr ......P~P~~ ~~~~~~///i IIl~41t1N\\\~\\\ 3- 31-©S~ tgnee's Signature Date Kevin A. Tabler. Attornev-in-Fact Assignee's Name (Print or Type) & Title Union Oil Com~uty of California Company Name THE UNITED STATES OF AMERICA ) )SS. STATE OF ALASKA ) Qualification File # 6 This certifies that on the 3 ! ~ day of ~~ , 2005, before me, a notary public in and for the State of Alaska, duly commissioned and sworn, personally appeared Kevin A. Tabler, Attorney-in-Fact, to me known and known to me to be the person described in, and who executed the foregoing assignment, who then after being duly sworn according to law, acknowledged to me under oath that he executed same freely and voluntarily for the uses and purposes therein mentioned. WITNESS m .hand and official seal the day and year in this certificate first above written. \,,~\~~\\~4~~t~Er~nlr~;ti ~~\~`~~ •A S rgtii~~y ARY ~ = I~dtary Public _ ~ NAT IC ' ~~ My Commission expires: ~ /~- ~ ~ ~• PUBL ~,,~~qr,~' o ~ •'a~,a ~~. -~~~mlIWA1~RDVAL The foregoing assignment is approved as to the lands described in item 5 thereof, effective as of the date set forth below. _.. \ -- .~~] Effective Date of Assignment ~~ William D. Van Dyke, Acting Director Division of Oil & Gas, DNR, State of Alaska ADL 390003 Exhibit A Lease Assignment Legal Description T. 6 N., R. 9 E., UMIAT MERIDIAN, ALASKA SECTION 19, UNSURVEYED, ALL, 618.00 ACRES; SECTION 20, UNSURVEYED, ALL, 640.00 ACRES; SECTION 21, UNSURVEYED, ALL, 640.OOACRES; SECTION 28, UNSURVEYED, ALL, 640.00 ACRES; SECTION 29, UNSURVEYED, ALL, 640.00 ACRES; SECTION 30, UNSURVEYED, ALL, 620.00 ACRES; SECTION 31, UNSURVEYED, ALL, 623.00 ACRES; SECTION 32, UNSURVEYED, ALL, 640.00 ACRES; SECTION 33, UNSURVEYED, ALL, 640.00 ACRES; THIS TRACT CONTAINS 5,701.00 ACRES, MORE OR LESS. FRANK H. MURKOWSKI (y O ~ ~ ~ GOVERNOR DEPARTMENT OF NATURAL RESOURCES 550 WEST T~`AVENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 DIVISION OF OIL AND GAS PHONE: (907) 269-8800 FAX: (907) 269-8938 March 20, 2006 Assignor: David G. Feddersen P,O. Box 10027 Fairbanks, AK 99710 Assignee: Union Oil Company of California Attn: Land Manager P.O. Box 196247 Anchorage, AK 99519-6247 Oil and Gas Leases ADL's 389994, 389995, 389996, 389999, 390001, 390002, 390003, 390004, 390005, 390006, 390007, 390008, 390009, 390019, 390023 Assignment Applications Approved The Director approved applications for assignment of 10.0 percent working interest in the above leases from David G. Feddersen to Union Oil Company of California on March 20, 2006, effective April 1, 2006. David G. Feddersen retains 0.050 percent overriding royalty interest the above leases. These assignments are approved as to the working interest only and do not constitute approval or acceptance of any stipulations or attachments to the assignment instrument. Approved assignments are enclosed. Dianna Lewis Natural Resource Specialist Enclosures D Vd1/389994-3 "Develop, Conserve, and Enhance 1Vatural Resources for Present and Future Alaskans." DO&G 25-84 (LEASE ASSIGNMENT) Revised 12/O] DNR #10-113 LEASE ADL 390003 EFFECTIVE DATE OF LEASE 9/1/2002 Is this lease producing? _yes _X,no STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS ASSIGNMENT OF INTEREST IN OIL AND GAS LEASE The undersigned assignor David G. Feddersen. whose address is P.O. Box 10027. Fairbanks, AK 99710, as owner of 5.00% percent of the lease's working interest does hereby assign to Union Oil Compan~of California ,the assignee, whose address is P O Box 196247 Anchorage AK 99519-6247 > 1. ___. SAU% percent working interest; 2. 0.00 percent overriding royalty interest. 3. The assignor is retaining 0 percent of the lease`s working interest. 4. The assignor is retaining .050% percent of overriding royalty interest. 5. LANDS AFFECTED by this assigtunent of interest (Attach Exhibit A if necessary) T , R Meridian, Alaska SEE EXHIBIT A containing 5701 acres, more or less. The Notification Lessee for the purpose of receiving any and ali notices from the State of Alaska in connection with the lease will be: Name Union Oil Company of California Attn: Kevin A. Tabler, Land Manager Address: P.O. Box 19624 City, State, Zip Anchorage AK 99514-6247 We, the undersigned, request the approval of this assignment application. We attest that this application discloses al( parties receiving an interest in the lease and that it is filed pursuant to 11 AAC 82.605 and l 1 AAC 82.615. We further attest that alt parties to this agreement are qualified to transfer or hold an interest in oil and gas leases pursuant to 11 AAC 82.200 and l 1 AAC 82.205. Whether approved in whole or in part, the assignee agrees to be bound by the provisions of said lease. • i Assignor's Signature Date j David G. Feddersen Assignor's Name (Print or Type) & Title Company Name THE UNITED STATES OF AMERICA ) Qualification File # )SS. STATE OF ALASKA ) This certifies that on the ~_day of ~/ ~ 2005, before me otary ublic in and for the State of Alaska, duly commissioned and sworn, perso Ily appeared , OIt f/ 4 to me known and known to me to be the person described in, and who executed the foregoing assignment, who then after being duly swom according to law, acknowledged to me under oath that he executed same freely and voluntarily for the uses and purposes therein mentioned. WITNESS my hand,a~oifaEial seal the day and year in this certificate fast above written. ' + • ~ O T ~ ~ Y ~ ary Public ~' U B ~ 1 C I~ Commission expires: - ~ `b uhf\_..- ~~ . `°= e's Signature Date Kevin A. Tabler, Attorney_in-Fact Assignee's Name (Print or Type) & Title THE UNITED STATES OF AMERICA ) )SS. STATE OF ALASKA ) Union Oil Company of California Company Name Qualification File # 6 This certifies that on the ~_day of ~'"?~-c/~- , 2005, before me, a notary public in and for the State of Alaska, duly commissioned and sworn, personally appeared Kevin A. Tabler, Attorney-in-Fact, to me known and known to me to be the person described in, and who executed the foregoing assignment, who then after being duly swom according to law, acknowledged to me under oath that he executed same freely and voluntarily for the uses and purposes therein mentioned. WITNESS t~"'~~r% fficial seal the day and year in this certificate first above written. `\~~`\~„~N..A_ ST/y~~~ NO~+~ ~ '~ ~ N ary Public Y ~ ,` My Commission expires: Z /`f - Q The foregoing assignment is approved as to behw. +` `~ - .~ William D. Van Dyke, Acting Direcro Division of Oil & Gas, DNR, State of Alaska 0 in item 5 thereof, effective as of the date set forth F;:; Effective Date of Assignment ADL 390003 Exhibit A Lease Assignment Legal Description T. 6 N., R. 9 E., UMIAT MERIDIAN, ALASKA SECTION 19, UNSURVEYED, ALL, 618.00 ACRES; SECTION 20, UNSURVEYED, ALL, 640.00 ACRES; SECTION 21, UNSURVEYED, ALL, 640.00 ACRES; SECTION 28, UNSURVEYED, ALL, 640.00 ACRES; SECTION 29, UNSURVEYED, ALL, 640.00 ACRES; SECTION 30, UNSURVEYED, ALL, 620.00 ACRES; SECTION 31, UNSURVEYED, ALL, 623.00 ACRES; SECTION 32, UNSURVEYED, ALL, 640,0:0 ACRES; SECTION 33, UNSURVEYED, ALL, 640.00 ACRES; THIS TRACT CONTAINS 5,701.00 ACRES, MORE OR LESS. Exhibit ~ AD!_ 3901008 . - ,. ~ , e j a ,~ `z- - _ °~~ ` ~- `-, ~~~., ~~_.. 1 ~~b' ~ ~~~ _ , -~ ,1 t) _ - t ., `~ ` - - +-{~ ...~ ~J A~l `"t ~ J., ~Y ~~~ ~ i.,,. I ~ :,.}..: N 1 i ) ~ ~...7.~ ~'i...J JV C~ ^ ~Q ~~., ~ [ 17 -.. .. ` ~_...-r`.." .~ ,~~ \ v _ _ ~ ~ ~j n7t ~ r~ /J~ 3 ` ! y ~ _ ~L .-_. ~ ~ .- dr.- i3 . f .i _,_ ~ ,~ -- ~-~i ~ ~~ ~. ~~~ ~ ('` 1~ l_? ~ .mot. ~'' ~ ~ `' .. r'.. II J te ~ ~ / ~r~~t ~~2~~~-Q~~~ T. 6 N., R. 9 E., Uatiat Mericilan, filaska Section 19, Unsurueyed, Ali. 6#8.001 aces; Section 24, Unsurveyed, All, f~0.~ acres; Sec#ion 21, Unsurvey~~l, All, S4~?,0Q acres; ~ct3t~n 28, lJnsurveyed, Ali, 6~t7.{}0 acres; Sectian ~9, i.lnsurve~ed, AIC, 640.(}x} ages; Section 80, l~nsurveyed, All, fi~0.00 acres; Section 8i, Jnsurve~+ed, AI(, 628.00 acres; Section 32, Elns~rveyed, All, 640.00 acres; Section 38, t~nsurvsyed, fill, b40.C0 acres: phis tract contains 5,70.00 acres mare ar less. PiliVl!F~ VI~IIVId!Illp TRANSMITTAL LE~~~~TTER CHECKLIST WELL NAME / a.l~t.~7c~ra~ ~' ~~ - PTD# ~~ "~ 33 Development Service Explorato Str ' ''Y atigraphic Test Non-Conventional Well FIELD: - POOL: Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHgT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. ,API No. 50- API number - - are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), alt records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples .are first caught and !0' sample intervals throu h tar et zones. Non-Conventional Well please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for (name of well) until after (Comaany Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. _ (Comuanv Namel must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & Pool _ ___ _ Well Name: PANTHERA 28-6-9 ____ _ Program EXP_ _____ ___ Well bore seg ^ PTD#:2080330 Company UNION IL CO OF ALIFORNIA - _ Initial Class/Type _ EXP 1 UN GeoArea 890 ___ _ Unit _ On/Off Shore On Annular Disposal Administration ~ 1 Permit.feeatkached__. __ __.._ _-___.-_____ NA--- -- - ---------------- --------- ~ 2 Lease numberappropriat_e -. --- _____________ __ Yes - --_ Entire well inADl390003--_-.-.. -_-_-.-____ __... 3 Unique well-name and number . - - - - - - - - - - - Yes - . 4 Well located in a_defined-pool- - - - - - - - - - - -- - - - - - - No- . - Ex lorato well- p ry 5 Well ocated proper di_slance. f[om drilling unit_boundary _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ Yes - - _ _ 6 Well located proper distance. from other wells_ - Yes Nearest well_is about-3 miles east.(Wolfbutton-25-6-9a - - - - - - .. - _ 7 Sufficient acreage.ayail_able in drilling unit- - - Yes 8 If_deviated, is-wellbore plat-included - - - - - - - _ _ _ _ _ _ _ _ __ _ _ _ _ _ Yes - - - - _ 9 Operator only affected party - - - - - - - - - - Yes Need Notice-of Ownership --Re-quested from-Walter Quay 3/6. Received 3120/0$ 10 Operator has_appropriate bond in force - Yes i 11 Permit can be issued without conservation order _ _ Yes - - _ _ _ - _ _ - _ Appr Date I 12 Permitcan be issued without administrative-approva_I Yes 13 Can permit be approved before t5-day wait_ - - _ .. - Yes - - SFD 3/2112008 14 Well located wdhin area and strata authorized by Infection Order # (put_1O# in-comments)-(For NA- - i 15 Allwells-within 114 mile area of review identified (For service well gnly) - - - - - - - - - - - - - NA- _ - - ' 16 Pre-produced injector; duration of pre production Less than 3 months-(Far service well only) - NA- 17 _N_onconven, gas conforms to AS31.05,030(j,1.A),(j 2.A-D) . - - - _ .. NA. - - - - - - --- -- 18 Conductor stung provided Yes Engineering X 19 Surface casing protects all known- USDWs _ _ NA - - No &ubsurf_ace water sources in area.- Surface casing ~7Q0'-below-permafrost.- ' 20 CMT vol. adequate-to circulate on conductor & surf csg - Yes 21 CMT-vol-adequate_to tie-in long string to surf cs-g Yes 22 CMT-will cover all know_n-produciive horizon_s_ - . _ - - _ _ _ _ _ - . - Yes _ _ - - - - - - - - - 23 Casing designs adequate for C, T, B &. permafrost- - Yes 24 Adequate tankage-or reserve pit Yes Rig equipped wish steel pits. No reserve pit planned.- Hauling to approved disposal wells planned. 25 If_a-re-drill, has-a 10-403 for abandonment been approved NA- 26 Adequate wellbore separation-proposed Yes No wells roximate, p X27 If_diverter required, does it meet regulations. - - - - Yes 12-1/4".hole-planned, Rig equipped_with 12".div_erter line. -This-h_as been zpproved previously. - - - - .. - - D t 28 _D_rilling flujd-program sc-hematic.& equip list adequate- . - - - - _ - _ - Yes Maximum expected fomlaiion pressure 8,4-EMW, MW planned up to 9.3 ppg or as needed. - - - . . Appr a e TEM 3!20/2008 29 BOPEs, dothey meet regulation - - Yes _ _ X30 _B_OPE-press rating appropnate; test to-(put prig mcomments)- - - - - Yes - _ MA$P calculated at 1396psi. 250_Qpsi BOP testplanned. - - 31 Choke-manifold complies wfAPl RP-53 (May 84) Yes 32 Work will occur. without operation shutdown- _ - - _ Yes _ _ - X 33 Is presence_of H2$ gas-probable. No- .. H2S has not-been reported in offset wells. Mud should preclude H2S on rig.- Rig has sensors and alarms. - 34 Mechanical condition of wells within AQR verified (Forservice well only) _ _ - _ - - - - - - - NA_ - - - - - _ . _ - _ 35 Permit. can be rssued w!o hydrogen sulfide measures No- - Exploratory well: H2$ not expected, but.Rrecaution advised.-Rig will have-sensors; mitigating chemicals onsite- Geology 36 !]ata.presented on potential overpressure zones _ .. - - - - - - - - -- - - - - -- - - Yes - - - - - - -Normal-pressure gradient expected based on offset wells & velocity data.- - - - - - - - - - - - - - _ - - - - - - - - - - 37 ofshallow gas zones Seismicanalysis Yes - Data quality are_p_oor. Gas hydrates may beencount_e[ed.- Mud r_o ram addresses miti ation measures, p9 9 Appr Date _ SFD 3!8!2008 38 Seabed condition survey (ifoff-shore) - ... _ _ _ NA - _ _ _ 39 I Contact name/phone for weekly-progress reports-[exploratory only] - _ Yes Tim-Brandenburg 263-7812- _ Geologic Date: Engineering Date Public Date Commissioner: /Commissione Commissioner li~~ic~~ 3-z/~ t~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • FINAL WELL REPORT MUDLOGGING DATA PANTHERA 28-6-9 Provided by: '~ 1 Approved by: David Buthman Compiled by: Larry Resch Harry E Bleys • Distribution: June 18, 2008 Date: April 8, 2008 ~6~,~~ ~~~(oS ~ Chevron Panthers 28-6-9 • TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW . 1.1 Equipment Summary ........................ 1.2 Crew ................................................. 2 WELL DETAILS ...................................... 2.1 Well Summary .................................. 2.2 Hole Data ......................................... 3 GEOLOGICAL DATA .............................. 3.1 Mudlog Summary ............................. 3.2 Connection Gas Summary ............... 3.3 Trip/Wiper Gas Summary ................ 3.4 Sampling Program/Sample Dispatch 4 DRILLING DATA ..................................... 4.1 Daily Activity Summary :.................... 4.2 Surveys ............................................ 4.3 Bit Record ........................................ 4.4 Mud Record ...................................... 5 MORNING REPORTS ............................. Enclosures 2"/100' Formation Log (MD) 2"/100' LWD / Lithology Log (MD) • 2"/100' Gas Ratio Log (MD) 2"/100' Drilling Dynamics Log ..3 ..3 ..3 ..4 ..4 ..4 ..5 ..5 10 10 10 11 11 15 15 16 17 EPOCH { Panthera 28-6-9 MUDLOGGING EQUIPMENT & CREW • • 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments Casing Pressure Cable to 1502 transducer for BOP tests onl . 0 Com uter -Drill Floor Monitor Azonics 0 Computer -Pit Monitor Azonics Intermittent Occasional overheatin . Com uter for Com an Man Ri watch Remote HP Com a 0 Com uter for Mud En ineer Ri watch Remote HP Com a 0 Com uter for Tool usher Ri watch Remote HP Com a 0 Computers for Mudloggers (4) Data editing, Rigwatch Master, and Ri watch Remote all HP Com a 0 Ditch gas QGM Agitator (Mounted in possum belly) Flame ionization total gas & chromato rah . .5 hrs Replaced agitator in gas trap. Hook Load / Wei ht on bit Drillin Line Sensor on Ri Floor 0 Mud Flow In Derived from Strokes/Minute and Pum Out ut-PLC feed 0 Mud Flow Out Flow line Sensor 0 Pit Volumes, Pit Gain/Loss 10 radar it sensors 0 Pum Pressure Stand i eTransducer-PLC feed 0 Pum stroke counters 2 2 roximi sensors 0 Rate of penetration Crown Fast Sheave proximity sensors 0 RPM PLC feed 0 Tor ue PLC feed 0 Wits In (LWD Data) Schlumberger LWD Computer to Ri watch Master Com uter 0 1.2 Crew Unit Type Arctic Unit Number ~ ML014 Years experience as Mudlogger .2 Days at wellsite between rig up and rig down of logging unit. Mudloggers Years Days Sample Catchers Years Days Technician Days Har Ble s. 7 08/12 Josh Dubowski .5 06/10 Steve Forrest 2 Lar Resch 5 12/12 EmilO itz .25 06/10 EPOCH Chevron Panthera 28-6-9 • 2 WELL DETAILS 2.1 Well Summary Well: Panthera 28-6-9 API Index #: 50-223-20023-00 Field: White Hills Project Surface Co-Ordinates: 190' FNL 850' FEL Sec. 28, T6N, R9E UM Borough: North Slope Primary Targets: State: Alaska Primary Target Depth: Multiple Rig Name /Type: Nabors 106E/Artic Double TD Depth: 2019'MD, Spud Date: March 29, 2008 Ground Elevation: 370.0 ft MSL TD Date: March 31, 2008 KB Elevation: 390.5 ft MSL Days Drilling: 3 TD Formation: Schrader Bluff Completion Status: Plug and Abandon Days Evaluating: None Classification: Exploration • 2.2 Hole Data Maximum Depth Mud Shoe Depth FIT Hole TD Dev. Casing/ Section MD TVD Formation Weight o. (inc) Liner MD TVD (ppg) ft (ft (ppg) (ft) (ft) Conductor 88 88 Permafrost - - 16" 88 88 N/A 12 %4" 2119 2119.79 Schrader Bluff 9 3 0.91 none • EPOCH • Chevron Panthera 28-6-9 3 GEOLOGICAL DATA 3.1 Mudlog Summary 101' to 2019' MD (85.01' to 1889.915 TVD) Drill Rate (ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 408.8 7.3 72.0 5 0 0.6 (103'-160') SAND/CONGLOMERATE SAND PEBBLES/SANDSTONE =light gray to medium gray to dark gray overall color; quartz versus shales, siltstones, claystone and coals are 50/50 in ratio in samples quartz in sands to conglomerates are fine to coarse and angular to sub angular; sandstone is sub angular to sub rounded and pebbles are sub round to rounded; sphericity is very low in sands and very high in pebbles; quartz is translucent clear to an amber translucence with opaque dominantly grayish white color. (160'-240') CLAYSTONE =Light gray to light medium gray color; mushy to malleable consistency; sectile to malleable tenacity; irregular fracture; lumpy rounded blocky cuttings habit; smooth clayey texture with sands of upper fine to pebble sized entrained; shiny waxy luster; thin to thick structure; no gas or oil indicators; no fluorescence; trace background gas. (240'-276') SAND/CONGLOMERATE SANDS PEBBLES AND SANDSTONE _ Dominantly quartz in all sands, conglomeratic sands pebbles, and sandstones; quartz clear glass like to translucent amber color, to grayish white opaque; angular fine upper to sub rounded coarse to rounded pebbles with scattered angular grains. (290'-310') COAL =Dull black; dark gray black to brownish black; moderately firm to pulpy with blocky cuttings habit; generally wet; cuttings ooze when compressed; poorly developed with dull to sub vitreous luster in part; often with random yellowish brown organic fragments; earthy in part; no evidence of out gassing. (280'-380') COARSE PEBBLE CONGLOMERATE AND CONGLOMERATIC SAND =Well rounded pebbles with fair to moderate sphericity generally ranging whole from 5-10mm in diameter; larger pebbles indicated with fresh fracture surfaces; sand is predominately white, grayish white, translucent to transparent quartz with abundant medium to dark gray mafic and reddish orange to dark reddish brown grains; angular to rarely subangular with moderate sorting and poor sphericity; no visible oil stain; 10-20% brownish yellow to dull yellow mineral fluorescence; no reaction to solvent. EPOCH Chevron Panthera 28-6-9 (380'-480') SAND/CONGLOMERATE SAND, AND PEBBLES = Clear to amber to green translucent quartz to a clean yellow white opaque color; fair to well sorted lower to upper medium sized sand grains with 60 - 70 % quartz and 10 - 30% similar sized cuttings of shales, siltstones with calcite, green stone, black carbonaceous material possibly coals fallen from above and rarer pyrites; slight surfaceabrasions in cuttings; a slight dull red orange fluorescence from coals; no fluorescence from sands or cut; no gas or oil indicators. (480'- 600') SAND/CONGLOMERATE SAND/SAN[~STONE/PEBBLES = Clear to green to amber translucent to grayish white opaque in dominant 70 -80% quartz with accessories of coal, siltstone, shale and calcite; sands and conglomerate sands are angular to sub rounded and verily well sorted with pebbles sub rounded to rounded; sand conglomerates and pebbles increase to 40% at bottom of sequence; sandstone has white kaolinite or dark brown argillaceous matrix in a grain supported non calcareous cuttings; sandstones are indurated and show poor to slightly fair visual porosity; white kaolinite sandstones have a slight dull greenish orange fluorescence; no cut except for bright fluorescence from solvent; only trace gas background. (600'-660') SAND/CONGLOMERATE SAND ANQ PEBBLES =Dominantly quartz pale white opaque to translucent clear, amber, green and soft yellow color; poorly sorted unconsolidated sands and conglomerate sands Wvith increase of pebbles in the lower sequence; angular to sub angular sands; sub angular to sub rounded conglomerates; weathered pebbles sub rounded to rounded; back ground gases trace; no fluorescence or cut except bright solvent fluorescence, slight oil shins; no oil indicators. (660' - 780') SAND/CONGLOMERATE SAND/ PEBBLES = Clearto amber, to greenish, to light brown translucent to soft opaque reds, yellow, bluish grays and white opaque color; unconsolidated poorly sorted sands are angular to 'sub angular; sub angular conglomerate sands; quartz is dominant at 50-60 %; calcite replacement and quartz substitutions prevalent in motley colors with accessories of chert, calcite, pyrite, carbonaceous material, lithic fragments, some coal, possibly glauconite as green stone along with shales and siltstone makeup 30 to 40 %; pebbles are still present in sub rounded to rounded with some angular cuttings; no fluorescence or cut; gas',background is trace; with few oil stains and little to no oil or gas indicators. (780'-900') CONGLOMERATE =Dominantly 4-8rrnm diameter well rounded pebbles with fair sphericity; larger diameter is indicated by fresf~ fracture; sample is varicolored light to dark grayish black, very light gray to grayish white, grayish orange, light brown (often translucent), pale yellowish green to light green. Sand is overwhelmingly translucent to transparent, milky white quartz with various arrhounts of clastic fragments of colors indicated above, coarse to very coarse angular` grains, rarely subangular with poor sphericity and fair to moderate sorting; rarely consolidated; occasionally grain supported with very light pale yellowish brown to yellowish gray argillaceous/limonitic matrix; fair to good visible porosity in part; rare dull yellowish green; yellow orange and bright yellow mineral florescence; no visible oil stain, no reaction to solvent. 6 EPOCII~II Chevron Panthera 28-6-9 (900'-930') COAL =Brownish black to olive black; black; soft, moderately firm in part; immature; woody/pulpy; very wet and oozes water when compressed; irregularly shaped cuttings with golf ball and larger sized cavings common over shaker; generally appears as raw charcoal in larger samples; organic features common with platy to sub fissile fracture along growth rings; this coal corresponds nicely with significant drop in drill rate and increased torque; no evidence of out gassing. (900'-1050') PEBBLE CONGLOMERATE =variety of medium to dark gray, light olive gray, white, grayish orange to pale yellowish brown, pale green well rounded pebbles with fairto poor sphericity; abundant flat to elongated well weathered pebbles; continued many large irregular fragments with sharp edges from bit fracture; interbedded with coarse angular unconsolidated sand. Interval beginning to exhibit traces of light yellowish brown to dark yellowish gray, mushy clay; rare dull yellow mineral fluorescence; no visible oil stain or solvent reaction. (1050'-1230') CONGLOMERATIC SAND =White to milky grayish white, translucent to transparent, translucent yellowish brown quartz with abundant medium to dark gray to grayish black lithic fragments; larger fragments and smaller pebbles often banded with possible source rock intrusion; generally coarse to very coarse grain, often upper medium grain; generally angular with poor to moderate sphericity in part; commonly subangular to subrounded with moderate sphericity; poor to fair sorting; pebble size notably decreasing; with thinly interbedded earthy Coal/Carbonaceous Claystone =yellowish brown to pale yellowish brown; brownish gray to brownish black; amberto yellowish brown oil stain visible in 1140-1200 sample interval; 30% bright yellow to gold fluorescence; immediate bluish white stream cut with bright bluish white residue ring; 1170-1200 interval as above with fluorescence decreasing to 20%; approximately 10% florescence in 1200-1230 sample interval with similar cut characteristics as indicated. (1200'-1230') CARBONACEOUS CLAYSTONE =Light pale brown to yellowish brown; very soft; mushy to flakey in part; very hydrophilic with poor adhesion and cohesion; earthy in part with abundant irregular carbonaceous detritus; often sandy; generally not silty; less than 10% dull gold fluorescence; bluish white stream cut. (1230'-1290') SAND =Unconsolidated; milky gray to white, translucent to transparent, transparent light brown and pale yellowish brown, minor medium gray occasional reddish orange grains; medium to lower coarse subangular grains; generally fairto occasionally good sphericity and moderate sorting; with abundant tar/bitumen =black to very dark brown black; no visible oil stain nor oil in samples; 20-30% dull orange yellow fluorescence; very slow dull yellow cut. (1290'-1410') SAND/CONGLOMERATE SAND/ PEBBLES =Loose unconsolidated sands are diminishing and conglomerate sand and pebbles are increasing with quartz at 50-60 in sands with accessories of shale, chert, calcite, and green stone; a few oil stains in 1350 ft. sequence that had bright yellow orange fluorescence with a light greenish slow streaming cut; quartz is dominantly grayish white with clear translucent to some amber colors; sands, conglomerate sands poorly sorted and angular to sub angular; pebbles are 7 EPOCH CfievrOn Panthera 28-6-9 sub rounded to rounded and mostly quartz and shales with some chert; background gas 1 unit; drill rate dropped off in black to brown woody carbonaceous material of immature material going grading to coal, mostly a lignite with obvious wood portions. (1410'-1440') CARBONACEOUS MATERIAL AND COAL= Brown and black to shiny vitreous black blocky tabular to rectangular to flaky cuttings; wood origin by obvious wood grain appearance; soft wood to hard brittle tenacity; blocky splintery to irregular fracture; smooth ridged laminated texture; thick to thin laminations and evident plant growth rings structure; no fluorescence or cut; gas background 0-3 units; rock bit rate of penetration slows down in carbonaceous materials and coals. (1440'-1560') CLAYSTONE= Light gray with brown hues to medium gray with brown green hues; mushy malleable consistency sectile malleable tenacity; irregular fracture with a smooth to segmented texture due to volcanic ash and glass; poorly adhesive and cohesive; hydrates readily and washes quickly away; none responsive to hydrochloric acid; loose unconsolidated sands entrained of medium upper and lower grain size; thin structure; gas background still just trace to 1 unit; no connections gases. (1560'-1680') SAND/CONGLOMERATES,PEBBLES AND SANDSTONE =Clear to colored trans- lucent green, golden amber to yellow amber to gray color to grayish white opaque quartz; poorly to fair sorted angular to sub angular loose unconsolidated sands of 60-70% quartz and 10-30% chert, biotite, calcite, shale, claystone, green stone, and siltstone; visible oil stains but no real fluorescence with same for conglomerates; pebbles are chert, shales, siltstone, and quartz of rounded sphericity; surface abrasions visible on pebbles and frosting on loose quartz along with etching; chert increasing at bottom of this sequence along with oil stains in chert and other sandstones; sandstones dominantly grain supported with angular well sorted grains; rarer matrix supported sandstone cuttings are of chert, and claystone; sandstones are indurated and very tight with poor visible porosity; no visible fluorescence and no cut from oil stains; back ground gases trace. (1680'-1800') SAND =Dominant quartz clear to grayish translucent to pale yellow to grayish white opaque color; well sorted, angular to subangular; low sphericity; visible surface abrasions; very little staining; increasing claystone with entrained loose unconsolidated sands; lower medium to upper medium grains size with some upper fine grain size; pebbles are 5 mm to 14 mm with coal and in sands increasing; gas background still trace with no fluorescence or cut; some mineral fluorescence from the pebbles and from contamination due to blue gasket materials and pipe dope in sample. (1800'-1860)SAND =Clear quartz to bluish milky white to opaque pale yellow white color; angular to sub- angular poorly sorted loose unconsolidated sands with larger conglomerates of chert, shale, carbonaceous material, coal, lithic fragments, green stone as glauconite, calcite, and some pyrite; oil stains visible in chert and a few rare sandstone cuttings; claystone within the sand giving it a cohesiveness that entrains larger cuttings of pebbles like shale, chert, and quartz; sand medium lower to coarse upper grain size; no fluorescence or gas. 8 EPOCH Chevron Panthera 28-6-9 (1860'-2020') SAND =Unconsolidated; frosted translucent to transparent milky white quartz with minor medium gray, translucent yellowish brown and occasional reddish orange upper fine to lower medium grain; subangular to sub- rounded in part with poor to fair sphericity in part; well sorted in upper part of interval, becoming more poorly sorted with random increase of coarse to very coarse angular grains; little or no evidence of clays/claystones in samples or at shakers. Samples from 1950-2010' resemble a pebble conglomerate with interbedded coarse angular sands. Interval exhibits (< 5%) bright yellow and dull orange fluorescence; no visible oil stain, extremely slow solvent reaction (brightening), no stream cut. 9 EPOCH Chevron Panthers 28-6-9 3.2 Connection Gas Summary 1 unit = 0.05% Methane Eauivalent Depth Gas over BGG Measured Strokes Bottoms U feet units) pum strokes (pum strokes No connection asses were observed, 3.3 Trip/Wiper Gas Summary 1 Unit = 0.05% Methane Eauivalent Depth Trip to Gas Downtime feet feet units hours No tri or wi er asses were observed. 3.4 Sampling Program/Sample Dispatch Set Processed As Frequency Interval Dispatched to Chevron, USA 909 West 9t" Avenue A B C Washed, dried, 30' 101' to 2019'MD P.O. Box 196247 ' ' envelopes Anchorage, Ak 99518-6247 Att: David Buthman/Trac Win er EPOCH Well Services, Inc. D Washed Wet 30' 8101' to 2019'MD 1615 Jefferson Island Rd. Whirlpak New Iberia, La 70560 For QFII Analysis Sample frequency may be altered according to drill rate constraints and zones of interest. • i 10 EP~CI~ Chevron Panthera 28-6-9 • 4 DRILLING DATA 4.1 Daily Activity Summary: March 24-27, 2008: Nabors Alaska Drilling Rig 106 completes obligations at Chevron Mastodon Pad and moves rig approximately 13 miles to Chevron Panthera Pad. Epoch representative Larry Resch arrives at Panthera, energizes mud logging unit ML014 and initiates unit rig up. March 28, 2008: Additional Epoch personnel arrive at Panthera and complete rig up of ML014. Nabors 106 continues rig up operations. Nipple up diverter system. Make up knife valve, diverter line, turnbuckles, Koomey lines, choke/kill valves. Work continues in the pits. Take on 525 bbls of 8.7 ppg spud mud. Rig up elevators. Pick up 1 joint of drill pipe and function test diverter system, Koomey, H2S et al gas alarms with AOGC inspector John Crisp. Rig up electrical cables in draw works; hang spinners and tongs. Tighten choke/kill line; change out valves/seats on #1 and #2 mud pumps. Load pipe shed with 62 joints drill pipe and 24 joints of HWDP: Strap and tally same. Adjust centrifuge and change out weights on #1 and #3 shakers from 90% to 100%. Hook up flow paddle for Epoch. Pick up 62 joints of drill pipe and stand back in derrick. Adjust Kelly hose. March 29, 2008: Pickup and stand back 24 joints of HWDP. Set 12 5/16" wear ring. Rig up 4" tongs and change out elevators. Make up bit, mud motor and crossovers on HWDP. Break circulation through bleeder. Shut in and test to 1700 psi. Seal leaking on mud pump line: air up boot. Troubleshoot mud pump electrical issues. Fill hole through Kelly. Test circulation system. Test Kelly hose to 1700 psi: repair 4" valve on conductor. Continue to build volume. Spud well at 0920 hours at 88 ft. Drill ahead to 277'. Observe 800 psi increase in pump pressure. Back-pumps down to 460 GPM and drill ahead at 1500 psi on bottom. Pump pressure slowly decreases. Circulate and condition hole at 460 gpm and 1500 psi. Hole did not clean up. Pull out of hole from 276'. First stand pulled tight. Circulate and rotate out of hole to conductor. Tight spots at 245 ft and 215 ft. Blow down top drive. Lay down BHA, break bit and check float. Clean suction and discharge screens. Repair hydraulic line on top drive. Reprogram mud pumps (Academy). Rig test mud motor; pressure still high. Break bit to lay down motor. Found saver sub half closed. Change out saver sub and make up BHA. Trip in hole to 56 ft. March 30, 2008: Continue making up BHA while running in hole from 56 ft to 247 ft. Tag fill at 260 ft. Wash to bottom and drill ahead from 276 ft to 606 ft. Troubleshoot hydraulic failure on top drive. Repair communication cable to top drive. Resume drilling from 608 ft to 1045 ft checking for flow at each connection and directional survey every other connection. Circulate and condition while changing swab #2 on mud pump #1; change 4 shaker screens. Epoch continues to routinely check gas detection equipment. Tests at possum belly conducted while drilling at 0420, 0530, 0930, 2130, 2230, 2330 hours. ~ EPOCH ChCYrOT Panthera 28-6-9 • March 31, 2008: Complete repairs on mud pump. Resume drilling from 1045 ft to 1494 ft. Service rig top drive and continue drilling from 1494 ft to 1960 ft. Hole is taking a little fluid; adding water at 11 bph. Circulate bottoms up. Sample evaluation by Chevron geologist suggests drilling ahead from 1960 ft to 1980 ft. Circulate bottoms up. Sample evaluation by Chevron geologist suggests drilling ahead to 2020 ft. Reach casing point at 2020 ft. Circulate bottoms up. Drop carbide with expected round trip of 4320 strokes. Observe very flat/washed out response with initial carbide return at 6400 strokes and peak gas reading at 7250 strokes. Epoch continues to run routine gas equipment checks both in the logging unit and from the possum belly. April 01, 2008: Pull out of hole from 2019 ft. Pull out at 15 fpm from 1816 ft to 1752 ft for Schlumberger logs. Worked through tight spots with 15k maximum over-pull. Circulate and condition; make up top drive to pump for Schlumberger to downlink MWD tool. Work pipe while circulating with no hole problems. Continue out of hole running Schlumberger tools from 1752 ft to 1286 ft working through tight spots with no problems. Observe 15k maximum over pull. Pump and rotate out of hole from 1286 ft to 247 ft. with pump flow of 3.9 bpm and 250 psi at 1130 ft. Observing 10k drag; hole trying to pack off and torque up. Work through tight spot from 430 ft 410 ft. Back ream out at 65 rpm. Rack back 2 stands DC; lay down BHA, NM stabilizers and cross over. Check bit and mud motor. Make up new BHA to 164 ft and change over handling equipment. Run in hole from 164 ft to897 ft. Tag at 710 ft: Wash down from 710 ft to 836 ft at 420gpm and 1290 psi. Attempts to RIH without pumps fail. Continue washing down at 420gpm and 1100 psi. from 961 ft to 1411 ft at 50 rpm, 420gpm, 1300 psi. Run in hole from 1411 ft to 1926 ft at 50 rpm and 1300 psi. Wash last stand from 1926 ft to 1991 ft at 60 rpm, 600gpm and 2030 psi. Rotation weight is 62k. Pickup single and slow down pumps. Tag fill at 225gpm. Pickup off fill and bring pumps up to 600gpm at 2080 psi. Started loosing flow. Backed off pumps and tried unsuccessfully to get returns back. Back reamed out at 10-100gpm at 50-100 rpm from 1991 ft to 1926 ft with no returns. Pumped away 120 bbls of mud. April 02, 2008: Continue back reaming from 1926 ft to 1918 ft at 50-100 rpm, 8k-12k torque; 36gpm at 240 psi with no returns. Work stuck pipe: no rotation, no returns, maximum over pull 65k, maximum down weight 50k, maximum torque 12.5k. All attempts to free pipe fail. Losing mud above stuck point in static hole at .39 bph average with 33 bbl loss at 0150 hrs. Wait on Baker Tools until 1000 hrs. Rig up Baker wireline and build berm around unit. Lost 4.49 bbl above stuck point, 63.11 bbl down hole with a total loss of 67.6 bbl. Take on 128 bbl fluid. Rig. up wireline and tools. Run in hole to find free point. Stand back side entry tools in derrick. Pull 100k to cock jars with no success. Rig up wireline tools: Run in hole to cut HWDP. Pull 15k over and cut drill pipe. Stand back tools. Pull 1 stand from 1918 ft to 1862 ft. Pull at 45k over to free pipe. Rig down wireline sheave from derrick. • 12 EPOCH Chevron Panthera 28-6-9 April 03, 2008: Complete rig down of Baker Tools. Attempt to re-establish returns with no success at 20gpm, 250 psi and 48 rpm. Spot LCM pill: 31 bbls at MW 9.2, VIS 110, 5 #/bbl Walnut, 5 #/bbl Barafiber at 48gpm and 1050 psi. String parameters are 55k up, 45k slack off, 48 rpm, 2k-6k torque. Torque, pick up and slack off weights increase while circulating and rotating with no returns. Pull out of hole from 1762 ft to surface while pumping to minimize surge/swab. Trip out was smooth without rotating. Got returns back on last 2 stands. Lay down cut joint; clean/clear rig floor; cut mule shoe. Run in hole with mule shoe to 970 ft breaking circulation-every 5 stands (320 ft). Momentarily tag up at 865 ft but worked right past. Circulate bottoms up and condition mud. Monitored loss at 5 bbl. Continue trip in hole from 970 ft to 1291 ft. Stage pumps to 250gpm at 230 psi. Break circulation and circulate bottoms up. Attempts to make a connection failed as annulus is over balanced. Increase flow to 630gpm with large volume of cuttings (predominately pea sized gravel, very coarse sand and occasional minor chunks of woody coal) coming back. Pump 83 bbl 330 VIS sweep at 15 bpm while working pipe: 38k up, 40k down. Continue circulating well beyond calculated round trip time with no signs of sweep returning to surface. Attempts to make a connection fail as well continues to u-tube. Allowing well to u- tube results in string taking weight. Break circulation and work pipe. Drill string was plug off but clears at 1700 psi. Reduce pump output to 315gpm. Pump 5 bbl of 12 ppg slug to balance annular hydrostatic pressure. Trip out of hole from 1.291 ft to 970 ft. Work tight spot from 970 ft to 905 ft with pumps off. Pick up weight 37k, slack off 38k. April 04, 2008: Continue working pipe. Tag at 933 ft. Pull out of hole to 906 ft. Circulate • 16.5 bbl nut plug marker at 126gpm: Marker returns at 5000 strokes. Circulate a total of 6250 strokes. Pull out of hole from 906 ft. Strap and pick up 12 1/4" BHA. Run in hole to 101 ft and change out handling equipment. Run in hole to 468 ft with HWDP: 35k up/down weight. Continue trip in hole and tag at 854 ft. Wash and ream to 918 ft at 668gpm, 100 rpm, string weight 42k. Circulate and condition hole. Increase mud viscosity from 90 to 250 seconds. Continue to work pipe at 918 ft: 60 rpm, pick up weight 42k, slack off weight 43k. At 2000 hrs begin to pull out of hole from 905 ft to 100 ft, laying down drill pipe. Trip in hole from 100 ft to 700 ft. Lay down drill pipe from 700 ft to 100 ft. Trip in hole from 100 ft to 750 ft. Lay down drill pipe from 750 ft. Currently coming out of the hole from 750 ft to 500 ft at report time. April 05, 2008: Continue trip out of hole laying down drill pipe from 500 ft. to 100 ft. Trip in hole from 100 ft to 720 ft. Pull out of hole from 720 ft to surface laying down drill pipe, jars, drill collars and bit. Off load fluid in the pits. Pull wear ring and rig up to run 3 1/2" tubing. Run 29 joints of same to 906 ft. Circulate and condition hole in preparation to pump cement. Blow down top drive. Pump 5 bbl water and test cement lines to 2000 psi. Pump 15 bbl water followed by 353 bbl 10.7 ppg cement. Pump additional 43 bbl cement (396 bbl total) followed by 2 bbl water. Pull out of hole with tubing from 906 ft. to surface. Tubing was plugged. Trip back in hole to 217 ft and circulate out cement. Clean out flow line, drip pan, shakers, and drill floor. Pull out of hole from 217 ft. standing back tubing. Wait on cement. Rig up to flush stack. 13 ~ EPOCH [hevron Panthera 28-6-9 April 06, 2008: Lay down plugged stand of 3'/2"tubing. Clean out plugged joints. Wait on cement delivery from Deadhorse. General housekeeping chores continue. Run in hole to 405 ft. Break circulation and circulate out cement while working pipe. Start additional cement job by pumping 5 bbl water and testing lines to 2000 psi. Pump 5 bbls water followed by 221 bbl Type L 10.7 ppg cement at 4 bpm and 70 psi. Clear lines with 2 bbl water. Cement did not return to surface. Pull out of hole from 405 ft. Run in hole to 200 ft; circulate 120 bbl with no cement returns to surface. Rig down choke line and super choke. Trip in hole and tag cement at 298 ft. Pull out of hole and continue general housekeeping while waiting on cement delivery. Clean pits #7, 8, 2, 4. Flush #2 mud pump and pickle same. Drain degasser and u-tube. Make cellar ready for nipple down; clean pipe shed; load miscellaneous equipment on trucks. April 07, 2008: Run in hole with 3'/2" tubing. Tag cement at 240 ft; break circulation and blow down top drive. Lay down extra stands in derrick. Trip tubing/drill pipe to 215 ft. Rig up cementers and pressure test lines to 2000 psi with 10 bbl water. Pump 206 bbl 10.7 ppg Type L cement. Chase lines with 2 bbl water. Lay down 1 joint to 183 ft. Rig up cement lines and circulate 27 bbls Type C Permafrost cement. Cement truck fails. Circulate mud at 4 bpm; mud came back at 22 bbl mixed with cement. Pull out of hole. Clean all surface equipment and flush lines. Run in hole to 60 ft; wash down to 120 ft. Shut down; blow down top drive; rig up cementers. Circulate 20 bbl cement. Pump 60 bbls Type C cement. Lay down drill pipe and tubing. Flush stack; pump out cellar; clean flow line. Rig down floor and diverter; pickle stack; flush #1 mud pump and pickle same; continue cleaning pits. Epoch Well Services released from obligations at 1300 hours and began rigging down logging unit. 14 ~ EPOCH Chevron Panthera 28-6-9 4.2 Surveys Measured Depth ft Incl. (deg) Azim. (deg) True Vertical Depth (ft) Northings (ft){+N/-S} Eastings (ft){+E/-W} Vertical Section (ft Dogleg Rate /100ft 0 0 0 0 0 0 0 0 295.26 0.21 49.39 295.26 0.35 0.41 0.41 0.07 416.85 0.09 325.34 416.85 0.58 0.53 0.53 0.18 540.53 0.06 140.19 540.53 0.61 0.51 0.51 0.12 661.60 0.14 205.37 661.60 0.42 0.49 0.49 0.10 783.72 0.10 146.89 783.72 0.20 0.48 0.48 0.10 905.92 0.45 189.82 905.92 -0.36 0.46 0.46 0.31 1034.42 0.72 208.02 1034.41 -1.57 -0.01 -0.01 0.25 1164.27 0.79 212.60 1164.25 -3.05 -0.87 -0.87 0.07 1292.17 0.80 216.70 1292.14 -4.51 -1.88 -1.88 0.05 1420.67 0.98 224.67 1420.62 -6.01 -3.19 -3.19 0.17 1550.27 1.02 223.87 1550.20 -7.63 -4.77 -4.77 0.03 1678.87 0.89 223.26 1678.48 -9.18 -6.24 -6.24 0.10 1806.67 0.80 218.31 1086.57 -10.6 -7.48 -7.48 0.09 1936.71 0.91 221.29 1936.59 -12.09 -8.72 -8.72 0.09 p. 2019.91 0.91 221.29 p.2019.79 -12.09 -8.72 -8.72 0.09 4.3 Bit Record • Bit Size Type Ser. No. Jets In Out Ftg. Hrs. Wear Reason 1 12.25 HUGHES MX-L1 X 5140713 4x15, 1x13 88' 2019' 1932' 34.1 Unknown Left In Hole C 15 EPQCH Chevron Panthers 28-6-9 4.4 Mud Record Contractor: BAROID -Spud Mud in 12 %4' hole Date Depth MW (ppg) Fo T (F) VIS (s/qt) PV YP Gels FL (cc) FC Sols (/o) NAP/VII Ratio Sd (/o) MBT pH CI- (ml/I) Ca+ (ml/I) 03/28/08 Surf. 8.80 -- 193 38 47 22/40/49 6.4 2 3.5 1.0/95.2 -- 25.0 7.2 900 120 03/29/08 276 8.80 67 127 34 40 12/22/30 8.0 2 3.5 0.8/95.4 0.25 25.0 7.5 800 240 03/30/08 951 9.00 63 93 30 40 13/30/38 8.0 2 5.1 0.2/94.5 0.75 20.0 7.5 500 80 03/31/08 1960 9.30 85 64 24 26 09/12/15 5.0 2 7.3 0.1/92.4 0.75 22.0 7.2 350 80 04/01/08 2019 9.30 -- 126 35 40 12/44/63 5.0 2 7.3 0.1/92.4 0.75 30.0 7.1 500 60 04/02/08 2019 9.20 -- 78 28 31 11 /24/32 5.2 2 6.5 0.1 /93.2 0.75 20.0 7.2 400 80 04/03/08 2019 9.35 -- 92 32 34 11/33/50 5.2 2 7.7 0.1/92.0 0.75 27.5 7.1 500 80 04/04/08 2019 8.80 -- 193 38 47 22/40/49 6.4 2 3.5 1.0/95.2 -- 25.0 7.2 900 120 04/05/08 2019 9.25 -- 72 25 20 08/21 /30 6.6 2 6.8 0.1 /92.8 0.50 30.0 7.2 700 40 Abbreviations MW =Mud Weight WL =Water or Filtrate Loss Ca =Hardness Calcium YP =Yield Point Gels =Gel Strength CI =Chlorides PV =Plastic Viscosity FLT =Flow Line Temp Sand =Sand content ECD =Effective Circulating Density VIS =Funnel Viscosity FC =Filter Cake Sols =Solids NAP/W =Oil to Water ratio ~ EPOCH • • • MORNING REPORTS thEVf4fl Panthera 28-6-9 EPQCH • Daily Report Page 1 of 1 Chevron, USA White Hills Project DAILY WELLSITE REPORT ~~~~,~~ Panthera 28-6-9 EPORT FOR Floyd Hurt, Jason Bradford DATE March 31, 2008 DEPTH 2019' PRESENT OPERATION Circulate bottoms up at casing point. TIME 2359 hrs YESTERDAY 1045' 24 HOUR FOOTAGE 974' CASING INFORMATION 16" @ 88' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 416.85' 0.09 325.34 416.85' SURVEY DATA 783.72' 0.10 146.89 783.72' 1164.27' 0.79 212.60 1164.25' 1550.27' 1.02 223.87 1550.20' 1936.71' 0.91 221.29 1936.59' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 1 12 1/4" HUGHES MXL-1X 5140713 4X15, 1X13 88' 1932' 34.1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 138.7 @ 1864 7.3 @ 1517 71.1 28.6 FT/HR SURFACE TORQUE 4623 @ 1196 245 @ 1720 1572.9 1986 AMPS WEIGHT ON BIT 19 @ 1334 1 @ 1430 12.9 11.0 KLBS ROTARY RPM 116 @ 1980 51 @ 1068 91.3 87 RPM PUMP PRESSURE 2134 @ 2015 1658 @ 1105 1926.9 2093 PSI DRILLING MUD REPORT DEPTH 1960' MW 9.3 VIS 64 PV 24 YP 26 FL 5.0 Gels 9/12/15 CL- 350 FC 2 SOL 7.3 SD .75 OIL MBL 22.0 pH 7.2 Ca+ 80 CCI MWD SUMMARY INTERVAL 276' TO 2020' TOOLS Tri-cone bit with mud motor and LWD: Gamma, Resistivity, Porosity, D & I GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 490 (Carbide) @ 1415 0 @ 0.9 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 0 @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ @ AVG PROPANE (C-3) 0 @ @ CURRENT BUTANE (C-4) 0 @ @ CURRENT BACKGROUND/AVG TRACE PENTANE (C-5) 0 @ @ HYDROCARBON SHOWS No gas shows observed during todays drilled interval. Oil shows as indicated on mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Permafrost and beyond. PRESENT LITHOLOGY ----------sand, some small pebble conglomerate---------- Complete repairs on mud pump. Resume drilling from 1045 ft to 1494 ft. Service rig top drive and continue drilling from 1494 ft to DAILY 1960 ft. Hole is taking a little fluid; adding water at 11 bph. Circulate bottoms up. Sample evaluation by Chevron geologist ACTIVITY suggests drilling ahead from 1960 ft to 1980 ft. Circulate bottoms up. Sample evaluation by Chevron geologist suggests drilling SUMMARY ahead to 2020 ft. Reach casing point at 2020 ft. Circulate bottoms up. Drop carbide with expected round trip of 4320 strokes. Observe very flat/washed out response with initial carbide return at 6400 strokes and peak gas reading at 7250 strokes. Epoch continues to run routine gas equipment checks both in the logging unit and from the possum belly. ~OCH PERSONNEL ON BOARD Reach, Bleys + 2 SC_ DAILY COST : DML $4550, RW $825 REPORT BY Larry Resch file://C:\Documents%20and%20Settings\Administrator\My%20Documents\My%20Wells\CHEV... 6/ 18/2008 Daily Report Page 1 of 1 Chevron, USA White Hills Project DAILY WELLSITE REPORT F,~~~,~ Panthera 28-6-9 EPORT FOR Floyd Hurt, Jason Bradford DATE March 31, 2008 DEPTH 2019' PRESENT OPERATION Circulate bottoms up at casing point. TIME 2359 hrs YESTERDAY 1045' 24 HOUR FOOTAGE 974' CASING INFORMATION 16" @ 88' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 416.85' 0.09 325.34 416.85' SURVEY DATA 783.72' 0.10 146.89 783.72' 1164.27' 0.79 212.60 1164.25' 1550.27' 1.02 223.87 1550.20' 1936.71' 0.91 221.29 1936.59' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 1 12 1/4" HUGHES MXL-1X 5140713 4X15, 1X13 88' 1932' 34.1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 138.7 @ 1864 7.3 @ 1517 71.1 28.6 FT/HR SURFACE TORQUE 4623 @ 1196 245 @ 1720 1572.9 1986 AMPS WEIGHT ON BIT 19 @ 1334 1 @ 1430 12.9 11.0 KLBS ROTARY RPM 116 @ 1980 51 @ 1068 91.3 87 RPM PUMP PRESSURE 2134 @ 2015 1658 @ 1105 1926.9 2093 PSI DRILLING MUD REPORT DEPTH 1960' MW 9.3 VIS 64 PV 24 YP 26 FL 5.0 Gels 9/12/15 CL- 350 FC 2 SOL 7.3 SD .75 OIL MBL 22.0 pH 7.2 Ca+ 80 CCI MWD SUMMARY INTERVAL 276' TO 2020' TOOLS Tri-cone bit with mud motor and LWD: Gamma, Resistivity, Porosity, D & I GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 490 (Carbide) @ 1415 0 @ 0.9 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 0 @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ @ AVG PROPANE (C-3) 0 @ @ CURRENT BUTANE (C-4) 0 @ @ CURRENT BACKGROUND/AVG TRACE PENTANE (C-5) 0 @ @ HYDROCARBON SHOWS No gas shows observed during todays drilled interval. Oil shows as indicated on mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Permafrost and beyond. PRESENT LITHOLOGY ---------sand, some small pebble conglomerate---------- Complete repairs on mud pump. Resume drilling from 1045 ft to 1494 ft. Service rig top drive and continue drilling from 1494 ft to DAILY 1960 ft. Hole is taking a little fluid; adding water at 11 bph. Circulate bottoms up. Sample evaluation by Chevron geologist ACTIVITY suggests drilling ahead from 1960 ft to 1980 ft. Circulate bottoms up. Sample evaluation by Chevron geologist suggests drilling SUMMARY ahead to 2020 ft. Reach casing point at 2020 ft. Circulate bottoms up. Drop carbide with expected round trip of 4320 strokes. Observe very flaUwashed out response with initial carbide return at 6400 strokes and peak gas reading at 7250 strokes. Epoch continues to run routine gas equipment checks both in the logging unit and from the possum belly. POCH PERSONNEL ON BOARD Resch, Bleys + 2 SC_ DAILY COST : DML $4550, RW $825 REPORT BY Larry Reach file://C:\Documents%20and%20Settings\Administrator\My%20Documents\My%20Wells\CHEV ... 6/18/2008 Daily Report Page 1 of 1 Chevron, USA White Hills Project DAILY WELLSITE REPORT El'~~I-~ Panthera 28-6-9 EPORT FOR Floyd Hurt, Jason Bradford DATE March 31, 2008 DEPTH 2019' PRESENT OPERATION Circulate bottoms up at casing point. TIME 2359 hrs YESTERDAY 1045' 24 HOUR FOOTAGE 974' CASING INFORMATION 16" @ 88' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 416.85' 0.09 325.34 416.85' SURVEY DATA 783.72' 0.10 146.89 783.72' 1164.27' 0.79 212:60 1164.25' 1550.27' 1.02 223.87 1550.20' 1936.71' 0.91 221.29 1936.59' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 1 12 1/4" HUGHES MXL-1X 5140713 4X15, 1X13 88' 1932' 34.1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 138.7 @ 1864 7.3 @ 1517. 71.1 28.6 FT/HR SURFACE TORQUE 4623 @ 1196 245 @ 1720 1572.9 1986 AMPS WEIGHT ON BIT 19 @ 1334 1 @ 1430 12.9 11.0 KLBS ROTARY RPM 116 @ 1980 51 @ 1068 91.3 87 RPM PUMP PRESSURE 2134 @ 2015 1658 @ 1105 1926.9 2093 PSI DRILLING MUD REPORT DEPTH 1960' MW 9.3 VIS 64 PV 24 YP 26 FL 5.0 Gels 9/12/15 CL- 350 FC 2 SOL 7.3 SD .75 OIL MBL 22.0 pH 7.2 Ca+ 80 CCI MWD SUMMARY INTERVAL 276' TO 2020' TOOLS Tri-cone bit with mud motor and LWD: Gamma, Resistivity, Porosity, D & I GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 490 (Carbide) @ 1415 0 @ 0.9 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 0 @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ @ AVG PROPANE (C-3) 0 @ @ CURRENT BUTANE (C-4) 0 @ @ CURRENT BACKGROUND/AVG TRACE PENTANE (C-5) 0 @ @ HYDROCARBON SHOWS No gas shows observed during todays drilled interval. Oil shows as indicated on mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Permafrosk and beyond. PRESENT LITHOLOGY ----------sand, some small pebble conglomerate---------- Complete repairs on mud pump. Resume drilling from 1045 ft to 1494 ft. Service rig top drive and continue drilling from 1494 ft to DAILY 1960 ft. Hole is taking a little fluid; adding water at 11 bph. Circulate bottoms up. Sample evaluation by Chevron geologist ACTIVITY suggests drilling ahead from 1960 ft to 1980 ft. Circulate bottoms up. Sample evaluation by Chevron geologist suggests drilling SUMMARY ahead to 2020 ft. Reach casing point at 2020 ft. Circulate bottoms up. Drop carbide with expected round trip of 4320 strokes. Observe very flat/washed out response with initial carbide return at 6400 strokes and peak gas reading at 7250 strokes. Epoch continues to run routine gas equipment checks both in the logging unit and from the possum belly. ~QCH PERSONNEL ON BOARD Reach, Bleys + 2 SC_ DAILY COST : DML $4550, RW $825 REPORT BY Larry Resch file://C:\Documents%20and%20Settings\Administrator\My%20Documents\My%20 Wells\CHEV ... 6/18/2008 Daily Report Page 1 of 1 Chevron, USA White Hills Project DAILY WELLSITE REPORT ~,P~~~ Panthera 28-6-9 EPORT FOR Floyd Hurt, Jason Bradford DATE March 31, 2008 DEPTH 2019' PRESENT OPERATION Circulate bottoms up at casing point. TIME 2359 hrs YESTERDAY 1045' 24 HOUR FOOTAGE 974' CASING INFORMATION 16" @ 88' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 416:85' 0.09 325.34 416.85' SURVEY DATA 783.72' 0.10 146.89 783.72' 1164.27' 0.79 212.60 1164.25' 1550.27' 1.02 223.87 1550.20' 1936.71' 0.91 221.29 1936.59' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 1 12 1/4" HUGHES MXL-1X 5140713 4X15, 1X13 88' 1932' 34.1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 138.7 @ 1864 7.3 @ 1517 71.1 28.6 FT/HR SURFACE TORQUE 4623 @ 1196 245 @ 1720 1572.9 1986 AMPS WEIGHT ON BIT 19 @ 1334 1 @ 1430 12.9 11.0 KLBS ROTARY RPM 116 @ 1980 51 @ 1068 91.3 87 RPM PUMP PRESSURE 2134 @ 2015 1658 @ 1105 1926.9 2093 PSI DRILLING MUD REPORT DEPTH 1960' MW 9.3 VIS 64 PV 24 YP 26 FL 5.0 Gels 9/12/15 CL- 350 FC 2 SOL 7.3 SD .75 OIL MBL 22.0 pH 7.2 Ca+ 80 CCI MWD SUMMARY INTERVAL 276' TO 2020' TOOLS Tri-cone bit with mud motor and LWD: Gamma, Resistivity, Porosity, D & I GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 490 (Carbide) @ 1415 0 @ 0.9 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 0 @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ @ AVG PROPANE (C-3) 0 @ @ CURRENT BUTANE (C-4) 0 @ @ CURRENT BACKGROUND/AVG TRACE PENTANE (C-5) 0 @ @ HYDROCARBON SHOWS No gas shows observed during todays drilled interval. Oil shows as indicated on mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Permafrost and beyond. PRESENT LITHOLOGY ----------sand, some small pebble conglomerate--------- Complete repairs on mud pump. Resume drilling from 1045 ft to 1494 ft. Service rig top drive and continue drilling from 1494 ft to DAILY 1960 ft. Hole is taking a little fluid; adding water at 11 bph. Circulate bottoms up. Sample evaluation by Chevron geologist ACTIVITY suggests drilling ahead from 1960 ft to 1980 ft. Circulate bottoms up. Sample evaluation by Chevron geologist suggests drilling SUMMARY ahead to 2020 ft. Reach casing point at 2020 ft. Circulate bottoms up. Drop carbide with expected round trip of 4320 strokes. Observe very flat/washed out response with initial carbide return at 6400 strokes and peak gas reading at 7250 strokes. Epoch continues to run routine gas equipment checks both in the logging unit and from the possum belly. c OCH PERSONNEL ON BOARD Resch, Bleys + 2 SC_ DAILY COST : DML $4550, RW $825 REPORT BY Larry Resch file://C:\Documents%20and%20Settings\Administrator\My%20Documents\My%20 Wells\CHEV ... 6/18/2008 Daily Report Page 1 of 1 Chevron, USA White Hills Project DAILY WELLSITE REPORT ~,~{~~,~ Panthera 28-6-9 EPORT FOR Floyd Hurt, Jason Bradford DATE March 31, 2008 DEPTH 2019' PRESENT OPERATION Circulate bottoms up at casing point. TIME 2359 hrs YESTERDAY 1045' 24 HOUR FOOTAGE 974' CASING INFORMATION 16" @ 88' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 416.85' 0.09 325.34 416.85' SURVEY DATA 783.72' 0.10 146.89 783.72' 1164.27' 0.79 212.60 1164.25' 1550.27' 1.02 223.87 1550.20' 1936.71' 0.91 221.29 1936.59' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 1 12 1/4" HUGHES MXL-1X 5140713 4X15, 1X13 88' 1932' 34.1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 138.7 @ 1864 7.3 @ 1517 71.1 28.6 FT/HR SURFACE TORQUE 4623 @ 1196 245 @ 1720 1572.9 1986 AMPS WEIGHT ON BIT 19 @ 1334 1 @ 1430 12.9 11.0 KLBS ROTARY RPM 116 @ 1980 51 @ 1068 91.3 87 RPM PUMP PRESSURE 2134 @ 2015 1658 @ 1105 1926.9 2093 PSI DRILLING MUD REPORT DEPTH 1960' MW 9.3 VIS 64 PV 24 YP 26 FL 5.0 Gels 9/12/15 CL- 350 FC 2 SOL 7.3 SD .75 OIL MBL 22.0 pH 7.2 Ca+ 80 CCI MWD SUMMARY INTERVAL 276' TO 2020' TOOLS Tri-cone bit with mud motor and LWD: Gamma, Resistivity, Porosity, D & I GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 490 (Carbide) @ 1415 0 @ 0.9 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 0 @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ @ AVG PROPANE (C-3) 0 @ @ CURRENT BUTANE (C-4) 0 @ @ CURRENT BACKGROUND/AVG TRACE PENTANE (C-5) 0 @ @ HYDROCARBON SHOWS No gas shows observed during todays drilled interval. Oil shows as indicated on mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Permafrost and beyond. PRESENT LITHOLOGY ----------sand, some small pebble conglomerate--------- Complete repairs on mud pump. Resume drilling from 1045 ft to 1494 ft. Service rig top drive and continue drilling from 1494 ft to DAILY 1960 ft. Hole is taking a little fluid; adding water at 11 bph. Circulate bottoms up. Sample evaluation by Chevron geologist ACTIVITY suggests drilling ahead from 1960 ft to 1980 ft. Circulate bottoms up. Sample evaluation by Chevron geologist suggests drilling SUMMARY ahead to 2020 ft. Reach casing point at 2020 ft. Circulate bottoms up. Drop carbide with expected round trip of 4320 strokes. Observe very flat/washed out response with initial carbide return at 6400 strokes and peak gas reading at 7250 strokes. Epoch continues to run routine gas equipment checks both in the logging unit and from the possum belly. ~OCH PERSONNEL ON BOARD Resch, Bleys + 2 SC DAILY COST : DML $4550, RW $825 REPORT BY Larry Resch file://C:\Documents%20and%20Settings\Administrator\My%20Documents\My%20Wells\CHEV ... 6/18/2008 Daily Report Page 1 of 1 Chevron, USA White Hills Project DAILY WELLSITE REPORT EI'~~I-~ Panthera 28-6-9 EPORT FOR Floyd Hurt, Jason Bradford DATE March 31, 2008 DEPTH 2019' PRESENT OPERATION Circulate bottoms up at casing point. TIME 2359 hrs YESTERDAY 1045' 24 HOUR FOOTAGE 974' CASING INFORMATION 16" @ 88' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 416.85' 0.09 325.34 416.85' SURVEY DATA 783.72' 0.10 146.89 783.72' 1164.27' 0.79 212.60 1164.25' 1550.27' 1.02 223.87 1550.20' 1936.71' 0.91 221.29 1936.59' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 1 12 1/4" HUGHES MXL-1X 5140713 4X15, 1X13 88' 1932' 34.1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 138.7 @ 1864 7.3 @ 1517 71.1 28.6 FT/HR SURFACE TORQUE 4623 @ 1196 245 @ 1720 1572.9 1986 AMPS WEIGHT ON BIT 19 @ 1334 1 @ 1430 12.9 11.0 KLBS ROTARY RPM 116 @ 1980 51 @ 1068 91.3 87 RPM PUMP PRESSURE 2134 @ 2015 1658 @ 1105 1926.9 2093 PSI DRILLING MUD REPORT DEPTH 1960' MW 9.3 VIS 64 PV 24 YP 26 FL 5.0 Gels 9!12/15 CL- 350 FC 2 SOL 7.3 SD .75 OIL MBL 22.0 pH 7.2 Ca+ 80 CCI MWD SUMMARY INTERVAL 276' TO 2020' TOOLS Tri-cone bit with mud motor and LWD: Gamma, Resistivity, Porosity, D & I GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 490 (Carbide) @ 1415 0 @ 0.9 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 0 @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ @ AVG PROPANE (C-3) 0 @ @ CURRENT BUTANE (C-4) 0 @ @ CURRENT BACKGROUND/AVG TRACE PENTANE (C-5) 0 @ @ HYDROCARBON SHOWS No gas shows observed during todays drilled interval. Oil shows as indicated on mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Permafrost and beyond. PRESENT LITHOLOGY ----------sand, some small pebble conglomerate---------- Complete repairs on mud pump. Resume drilling from 1045 ft to 1494 ft. Service rig top drive and continue drilling from 1494 ft to DAILY 1960 ft. Hole is taking a little fluid; adding water at 11 bph. Circulate bottoms up. Sample evaluation by Chevron geologist ACTIVITY suggests drilling ahead from 1960 ft to 1980 ft. Circulate bottoms up. Sample evaluation by Chevron geologist suggests drilling SUMMARY ahead to 2020 ft. Reach casing point at 2020 ft. Circulate bottoms up. Drop carbide with expected round trip of 4320 strokes. Observe very flaUwashed out response with initial carbide return at 6400 strokes and peak gas reading at 7250 strokes. Epoch continues to run routine gas equipment checks both in the logging unit and from the possum belly. EPOCH PERSONNEL ON BOARD Resch, Bleys + 2 SC DAILY COST : DML $4550, RW $825 REPORT BY Larry Resch file://C:\Documents%20and%20Settings\Administrator\My%20Documents\My%20Wells\CHEV... 6/ 18/2008 Daily Report Page 1 of 1 Chevron, USA White Hills Project DAILY WELLSITE REPORT F,~~~,~~ Panthera 28-6-9 EPORT FOR Floyd Hurt, Jason Bradford DATE March 31, 2008 DEPTH 2019' PRESENT OPERATION Circulate bottoms up at casing point. TIME 2359 hrs YESTERDAY 1045' 24 HOUR FOOTAGE 974' CASING INFORMATION 16" @ 88' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 416.85' 0.09 325.34 416.85' SURVEY DATA 783.72' 0.10 146.89 783.72' 1164.27 0.79 .212.60 1164.25' 1550.27 1.02 223.87 1550.20' 1936.71' 0.91 221.29 1936.59' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 1 12 1/4" HUGHES MXL-1X 5140713 4X15, 1X13 88' 1932' 34.1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 138.7 @ 1864 7.3 @ 1517 71.1 28.6 FTlHR SURFACE TORQUE 4623 @ 1196 245 @ 1720 1572.9 1986 AMPS WEIGHT ON BIT 19 @ 1334 1 @ 1430 12.9 11.0 KLBS ROTARY RPM 116 @ 1980 51 @ 1068 91.3 87 RPM PUMP PRESSURE 2134 @ 2015 1658 @ 1105 1926.9 2093 PSI DRILLING MUD REPORT DEPTH 1960' MW 9.3 VIS 64 PV 24 YP 26 FL 5.0 Gels 9/12/15 CL- 350 FC 2 SOL 7.3 SD .75 OIL MBL 22.0 pH 7.2 Ca+ 80 CCI MWD SUMMARY INTERVAL 276' TO 2020' TOOLS Tri-cone bit with mud motor and LWD: Gamma, Resistivity, Porosity, D & I GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 490 (Carbide) @ 1415 0 @ 0.9 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 0 @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ @ AVG PROPANE (C-3) 0 @ @ CURRENT BUTANE (C-4) 0 @ @ CURRENT BACKGROUND/AVG TRACE PENTANE (C-5) 0 @ @ HYDROCARBON SHOWS No gas shows observed during todays drilled interval. Oil shows as indicated on mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Permafrost and beyond. PRESENT LITHOLOGY ----------sand, some small pebble conglomerate---------- Complete repairs on mud pump. Resume drilling from 1045 ft to 1494 ft. Service rig top drive and continue drilling from 1494 ft to DAILY 1960 ft. Hole is taking a little fluid; adding water at 11 bph. Circulate bottoms up. Sample evaluation by Chevron geologist ACTIVITY suggests drilling ahead from 1960 ft to 1980 ft. Circulate bottoms up. Sample evaluation by Chevron geologist suggests drilling SUMMARY ahead to 2020 ft. Reach casing point at 2020 ft. Circulate bottoms up. Drop carbide with expected round trip of 4320 strokes. Observe very flat/washed out response with initial carbide return at 6400 strokes and peak gas reading at 7250 strokes. Epoch continues to run routine gas equipment checks both in the logging unit and from the possum belly. ~QCH PERSONNEL ON BOARD Resch, Bleys + 2 SC DAILY COST : DML $4550, RW $825 REPORT BY Larry Resch file://C:\Documents%20and%20Settings\Administrator\My%20Documents\My%20Wells\CHEV ... 6/18/2008 Daily Report Page 1 of 1 Chevron, USA White Hills Project DAILY WELLSITE REPORT ~,~~~~ Panthera 28-6-9 EPORT FOR Floyd Hurt, Jason Bradford DATE March 31, 2008 DEPTH 2019' PRESENT OPERATION Circulate bottoms up at casing point. TIME 2359 hrs YESTERDAY 1045' 24 HOUR FOOTAGE 974' CASING INFORMATION 16" @ 88' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 416.85' 0.09 325.34 416.85' SURVEY DATA 783'72 0.10 146.89 783.72' 1164.27' 0.79 212.60 1164.25' 1550.27' 1.02 223.87 1550.20' 1936.71' 0.91 221.29 1936.59' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 1 12 1/4" HUGHES MXL-1X 5140713 4X15, 1X13 88' 1932' 34.1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 138.7 @ 1864 7.3 @ 1517 71.1 28.6 FT/HR SURFACE TORQUE 4623 @ 1196 245 @ 1720 1572.9 1986 AMPS WEIGHT ON BIT 19 @ 1334 1 @ 1430 12.9 11.0 KLBS ROTARY RPM 116 @ 1980 51 @ 1068 91.3 87 RPM PUMP PRESSURE 2134 @ 2015 1658 @ 1105 1926.9 2093 PSI DRILLING MUD REPORT DEPTH 1960' MW 9.3 VIS 64 PV 24 YP 26 FL 5.0 Gels 9/12/15 CL- 350 FC 2 SOL 7.3 SD .75 OIL MBL 22.0 pH 7.2 Ca+ 80 CCI MWD SUMMARY INTERVAL 276' TO 2020' TOOLS Tri-cone bit with mud motor and LWD: Gamma, Resistivity, Porosity, D & I GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 490 (Carbide) @ 1415 0 @ 0.9 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 0 @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ @ AVG PROPANE (C-3) 0 @ @ CURRENT BUTANE (C-4) 0 @ @ CURRENT BACKGROUND/AVG TRACE PENTANE (C-5) 0 @ @ HYDROCARBON SHOWS No gas shows observed during todays drilled interval. Oil shows as indicated on mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Permafrost and beyond. PRESENT LITHOLOGY ---------sand, some small pebble conglomerate---------- Complete repairs on mud pump. Resume drilling from 1045 ft to 1494 ft. Service rig top drive and continue drilling from 1494 ft to DAILY 1960 ft. Hole is taking a little fluid; adding water at 11 bph. Circulate bottoms up. Sample evaluation by Chevron geologist ACTIVITY suggests drilling ahead from 1960 ft to 1980 ft. Circulate bottoms up. Sample evaluation by Chevron geologist suggests drilling SUMMARY ahead to 2020 ft. Reach casing point at 2020 ft. Circulate bottoms up. Drop carbide with expected round trip of 4320 strokes. Observe very flat/washed out response with initial carbide return at 6400 strokes and peak gas reading at 7250 strokes. Epoch continues to run routine gas equipment checks both in the logging unit and from the possum belly. EPOCH PERSONNEL ON BOARD Resch, Bleys + 2 SC_ DAILY COST : DML $4550, RW $825 REPORT BY Larry Resch file://C:\Documents%20and%20Settings\Administrator\My%20Documents\My%20Wells\CHEV ... 6/18/2008