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205-213
From:Earon Overson To:AOGCC Reporting (CED sponsored) Subject:Griner#1 permit to drill Date:Saturday, February 17, 2024 2:10:07 PM [You don't often get email from earon.overson@gmail.com. Learn why this is important at https://aka.ms/LearnAboutSenderIdentification ] CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Return receipt 7018 0680 00022049 1082 Permit to drill 205-213 Permit to drill 202-213 To whom it concern, the Griner property was satisfactory after the drilling process to my knowledge. The location site is free of debris, materials, supplies and structures. Thanks Earon Overson Sent from my iPhone Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov December 12, 2023 CERTIFIED MAIL – RETURN RECEIPT REQUESTED 7018 0680 00022049 1082 Earon Overson P.O. Box 1367 Anchor Point, AK 99556 RE: Well Site Clearance – Griner No. 1 (Permit to Drill 202-041) and Endeavour No. 1 (Permit to Drill 205-213) Dear Mr. Overson: The Alaska Oil and Gas Conservation Commission (AOGCC) is the state agency that regulates oil and gas well drilling in the state. Part of our duties are to make sure that wells are drilled safely and when there’s no more utility for the well that they are properly plugged and abandoned and that the drill site is properly restored. In March and April 2002, Union Oil Company of California (Unocal) drilled the Griner No. 1 exploratory well on land which Kenai Peninsula Borough records indicate you currently own along the Sterling Highway and Docs Rd (Kenai Peninsula Borough Parcel ID No. 16919033). Unocal plugged and abandoned the well in accordance with AOGCC regulations, and the plugging operations were verified by an AOGCC field inspector on April 21, 2003. In April and May 2006, Aurora Gas, LLC (Aurora) drilled the Endeavour No. 1 exploratory well on that same property. Aurora plugged and abandoned the well in accordance with AOGCC regulations, and the plugging operations were verified by an AOGCC field inspector on May 12, 2006. Although the wells are mechanically properly plugged and abandoned, AOGCC regulations also require operators to conduct site clearance work and successfully pass AOGCC site clearance inspections. Specifically, 20 AAC 25.170(a) states: At or after the time that a well drilled onshore is abandoned and before the earlier of one year after the well abandonment or the expiration of the owner’s1 rights to the property, (1) The operator shall remove the wellhead equipment and casing to a depth at least three feet below original ground level and install a well abandonment marker in accordance with 20 AAC 25.120; and 1 In this instance “owner” refers to the operators (Unocal and Aurora), not to the landowner. Page 2 of 2 (2) Unless the operator demonstrates to the commission that the surface owner has authorized a different disposition to facilitate a genuine beneficial use, the operator shall A. Remove all materials, supplies, structures, and installations from the location; B. Remove all loose debris from the location; C. Fill and grade all pits or close them in another manner approved by the commission as adequate to protect public health and safety; and D. Leave the location in a clean and graded condition. Unocal and Aurora completed the activities required under part (1) of this regulation by removing the wellhead, cutting the casing off below ground, and installing a marker plate, but Unocal and Aurora never arranged for the AOGCC to conduct site clearance inspections. AOGCC does not know if Unocal or Aurora complied with requirements (2)(A) to (2)(D), above, or if Unocal and Aurora otherwise left the well locations in a condition that is acceptable to you. If the sites were not cleared in compliance with 2(A)-(2)(D), the AOGCC may potentially have means at our disposal to remedy the situation. Please send a letter or an email to the AOGCC (at the letterhead address or to AOGCC.Reporting@alaska.gov) advising as to whether or not Unocal and Aurora left your property in a manner that is acceptable to you after plugging and abandoning the Griner No. 1 and Endeavour No. 1 wells. If you have any questions, please feel free to contact Dave Roby of our staff at 907-793-1232 or dave.roby@alaska.gov. Sincerely, Jessie L. Chmielowski Commissioner Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.12.12 15:09:04 -09'00' ~3~~ DATA SUBMITTAL COMPLIANCE REPORT 6/19/2008 Permit to Drill 2052130 Well Name/No. ENDEAVOR 1 MD 9225 TVD 9225 Completion Date 5/13/2006 REQUIRED INFORMATION Mud Log Yes Operator AURORA GAS LLC API No. 50-231-20030-00-00 Completion Status P&A Current Status P&A UIC N Samples No Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: Comp Neutron, GR, Litho-Density, Microlog, Array Induction, SP, CMR Well Log Information: Log/ Electr Data Digital Dataset Typ Med/Frmt Number Name D C Las 13926 duction/Resistivity k6g Formation Micro Ima I CI og Magnetic Resonance ~I,~g I Neutron ~ ~Log C "I I Neutron g Cement Evaluation og Formation Micro Ima Log Sonic Rpt Report: Final Well R C Pdf 13944~eport: Final Well R I/lag Mud Log ~etSg See Notes IL" --- ----_ --- ___ (data taken from Logs Portion of Master Well Data Maint Log Scale Log Media Run No Interval Start Stop OH / CH Received Comments 2457 9218 Open 5/30/2006 Comp Neutron GR Triple Lithodensity Microlog Array Induction SP /MDT / CMR /CBL plus PDF & PDS graphics Col 3 3705 6772 Case 6/5/2006 Modular Formation Dynamics Tester 7-May- 2006 5 Col 1 2457 9218 Case 6/5/2006 Combinable Magnetic Resonance Enhanced Pecision Mode ***High- Res*** 7-May-2006 25 Col 1 2457 9218 Case 6/5/2006 Compensated Neutron, GR, Triple-Litho Density, Microlog Array Induction - SP 7-May-2006 5 CoI 1 2457 9218 Case 6/5/2006 Compensated Neutron, GR, Triple-Litho Density, Microlog Array Induction - SP ***High-Res***7-May- 2006 5 Blu 4 84 2444 Case 6/5/2006 CBL, CCL, GR 8-May-2006 5 Col 3500 9210 Open 6/9/2006 5 Col 2343 9208 Open 6/9/2006 Dipole Sonic Imager 111 9225 Open 6/9/2006 111 9225 Open 6/9/2006 EOW in Digital form 2 Col 111 9225 Open 6/9/2006 2 Col 111 9225 Open 6/9/2006 DRILLING DYNAMICS ~~ DATA SUBMITTAL COMPLIANCE REPORT 6/19/2008 Permit to Drill 2052130 Well Name/No. ENDEAVOR 1 Operator AURORA GAS LLC API No. 50-231-20030-00-00 MD 9225 TVD 9225 Completion Date 5/13/2006 Completion Status P&A Current Status P&A UIC N ED C Pds 13951 See Notes 0 0 6/14/2006 Caliper, CBL, CMR, MDT, PEX-AIT, PEX-AIT, Mud Logs, DSI in LAS versions. Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number C~ments Cuttings 2280 9225 1/3/2007 1166 ADDITIONAL INFORMATION ~ ~ "' Well Cored? Y Daily History Received? ~ Chips Received? ~Y /10' Formation Tops Q/ N Analysis ~`fY'I~ Received? Comments: Compliance Reviewed By: Date: lr'~ u i t CHECKLIST-DNR REQUEST FOR CONFIDENTIAL INFORMATION REQUESTOR Laura Silliphant _ , ~ OPERATOR; Aurora .; ~, _ PROPERTY ID/ $; LEASE FIELD/POOL N/A PI/BH: WELL or Endeavor 1, API No. 50 ;?31-20030-0000. INFORMATION NAME ,n , , ~. .:_ , DEVELOPMENT (Describe) SERVICE .. .~ GAS ' ~ `" OIL St7Rl=~ ~ .OCATIl~11~1°°'`~"~ ' • 2~68'FSC~1834 FWL~~'-'~'I!~nge: ``F5 W -Sec. 3 BOTTOM HOLE Checklist for request: ~~ (1) .Has a formal, written request been received by the Commission from DNR? (2) is the requesting party a state employee listed on the cu~ent Memorandum of Agreement (3) Is the State of Alaska the landowner of the lease for which the data has been requested? (4) If the data is not from land owned by the State of Alaska,-;has an application been made for extended confidentiality pursuant to AS 31.05.035(c)? (5) If the data is not from land owned by the State of Alaska and an application-.for extended cohfidentiality has not been filed, have the owner(s) and landowner(s) provided written authorization to the Commission allowing DNR to view th~ information? .. - ~ - she request to: Con identia material ci~nriot be remove ~ rom the Commission's office) view the data? copy the data? (7) Is the --agent viewing or • copying the data state employee listed on .the .current Memorandum of Agreement? (8) If the request is to copy.the-data, have all copies of the data been stamped Confidential? o co yx~fhe~ data., :has a transmi letter been prepared by the eust is '~t requ (9)- If the ~ _ u nas•>copied and stating that the -nth ' a~missioner~listin ~~a~o si d i ais i~ e _ : g r gne y r~a~ s c e data. are confidential and must be handled accordingly, and that DNR-will not release the - data until it is made ublic b the o erator or the Commission? Place this checklist and DNR's_formal,,written request to view and/or copy the data in the Confidential Data Manifest binder located in the confidential r'oQrn.. ~- ~as art .~ ._ ~~. .._ . . _ _ ~_ ' .. ~ ,: O ~ ~ ~ SARAH PALIN, GOVERNOR DEPARTMENT OF NATURAL RESOURCES 55o WEST 7T" a,vENUE, suiTE soo '.ANCHORAGE, ALASKA 99501-3560 DIIJISI4N OF OIL & GAS PHONE: (so7~ 269-8800 FAX.• {907J 269-8938 October 10, 2007 ' John Norman AOGCC Chairman 330 W Th Avenue; Suite 100 Anchorage, AK 99501 ,M;, fi - Subject: Aurora, Endeavor,l, 50-231-20030-0000 Dear Mr. Norman: On behalf of the Division of Oil and Gas Resource Evaluation Group, I am requesting a completion report and any hard copy and/or digital well log data that you have fps the Aurora, Endeavor 1. The API number is 50-231-20030-0000, and he permit number is 20x2130. This well is confidential. The Division is conducting an evaluation of recently drilled exploration wells for a presentation to the RCA on October 15, 2007, The data will remain confidential, but the information will help in our evaluation. . ~'. -~.~ ~,_ ~ ~:~,~ ~.,, ~..,x.~,~:_~~ We would.p~rsciateRyaur°assistanee. ~ - ""'" V ~` Please call if there are questions or other information is required. Sincerely, ~~, ~~ Laura S~iphant Petroleum Geologist , _~. - r. ~ r . ce'Kevin Banks; Acting Director DO&G • • ti Aurrora Gas, LLC www.aurorapower.com G~~~ i9 ~® June 9, 2006 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 RE: Well Completion Report : Aurora Gas, LLC: Endeavour #1 (PTD 205-213) Dear Commissioner Norman: JUN Q 9 200b Alaska Oil $i Gas Cons. Corrrrbssion Anchorage Aurora Gas, LLC hereby submits its Well Completion Report for the work performed in drilling its Endeavour #1 exploration well in Anchor Point on the Kenai Peninsula. Please find enclosed the following information for your files: l) Form 10-407 Well Completion or Re-completion Report and Log 2) Wellbore Schematic 3) Well Operations Summary 4) CD containing the mud log and all wireline logs run If you have any questions or require additional information, please contact me at (713) 977-5799 or Bill Penrose at Fairweather at 258-3446. Sincerely, AURORA GAS, LLC J. dward Jones ice President, En Bring and Operations enclosures c: Mr. B1i11 P~nrpse - Fairwr 10333 Richmond Avenue, Suite 710 • Houston, Texas 77042 • (713) 977-5799 • Fax (713) 977-1347 1400 West Benson Blvd., Suite 410 • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 STATE OF ALASKA ALASI~IL AND GAS CONSERVATION COMMI~I WELL COMPLETION OR RECOMPLETION REPORT ~~~~~ V JuN ~ ~ 2006 Ai~talp 1a. Well Status: Oif^ Gas^ Plugged Q ~ Abandoned0 ' Suspended^ WAG^ 2onnczs.~os zonnczs.»o GINJ^ WINJ^ WDSPL^ No. of Completions Other 1b. Well Class: Development ^ E~~~ Service ^ Stratigraphic Test^ 2. Operator Name: Aurora Gas, LLC 5. Date Comp., Susp., or Aband.: 5J13/06 12. Permit to Drill Number: 205-213 3. Address: 1400 W. Benson Blvd., Suite 410, Anchorage, AK 99503 6. Date Spudded: April 7, 2008 13. API Number: 50-231-20030 -eac> /~ ~ ~ ~3 °~~ 4a. Location of Well (Governmental Section): Surface: 2288' FSL, 1834' FWL, Sec 3, TSS, R15W, SM ~ 7. Date TD Reached: May 6, 2006 14. Well Name and Number. Endeavour #1 Top of Productive Horizon: 2268' FSL, 1834' FWL, Sec 3, T5S, R15W, SM 8. KB Elevation (ft): 20' AGL 15. Fieki/Pool(s): Total Depth: 2268' FSL, 1834' FWL, Sec 3, T5S, R15W, SM 9. Plug Bads Depth(MD+TVD): SurFacs Exploratory 4b. Location of Well (State Base Plane Coordinates): Surface: x- 165362 y- 2113163 ' Zone- 4 ' 10. Total Depth (MD + TVD): 9225' MDlfVD 16. Property Designation: Dale Griner, et al. Lease TPI: x- 165362 y- 2113163 Zone- 4 Total Depth: x- 165362 y- 2113153 Zone- 4 11. Depth Where SSSV Set: N/A 17. Land Use Permit: NIA 18. Directional Survey: Yes ^ No ~ 19. Water Depth, if Offshore: WA feet MSL 20. Thickness of Permafrost: N/A 21. Logs Run: Comp. Neutron, GR, Litho-Density, Microlog, Array Induction, SP, CMR, CBL, Cal, FMI, DSI, MDT, Mud Log 22. CASING, LI NER AND CEMENTING RECORD CASING ~' PER GRADE SETTING DEPTH MD SETTING D EPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT• TOP BOTTOM TOP BOTTOM PULLED 13.3/8" 68# K-55 20' 101' 20' 101' Driven Grouted after driving 0' 9-518" 4Q# N-80 20' 2,45T 20' 2,45T 12-114" Cmt'd to surface 0' 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none': SIZE DEPTH SET (MD) PACKER SET (MD) None ~ No tubing set 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 26. PRODUCTION TEST Date First Production: Well was not tested or produced Method of Operation (Fknnring, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-0il Ratio: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate ~.- Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity -API (corr): 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". t_,,,,.,,,-,,,._,,,~,,,~y,,,,,, ' ~{~P41 f~=G E :4i'~ Converrtional Core #1:7705-35'. Irrterbedded conglomerate, sandtone, siltsone, clay and volcanic ash. ~,~~ Sr / .~ ~~[31NS ~F~. ,~uN ~ ~ Zoos ~t3' ILD ORIGINAL 'OQ'M111SSIOn ~.~~~ G 28. GEOLOGIC MARKE 29. FORMATION TESTS NAME TVD Inducts and briefly s ' e test results. List intervals tested, and attach detailed supporting d s necessary. If no tests were conducted, state "None". None TOP TYONEK FM 1985' 1985' STARICHKOF SAND 6745' 8745' TOP HEMLOCK FM 7448' 7448' TOP WEST FORELAND 7975' 7975 CRETACEOUS 8450' 8450' 30. List of Attachments: 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bill Penrose 258-3446 Printed Name: ~, E rd Jones T~~ Vice President, Engineering and Production Si nature: Phone: 713-977-5799 Date: INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is chanced. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water ARemating-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 Produdng Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in Rem 1, and in item 23 show the producing intervals for only the interval reported in item 26. (SubmR a separate form for each additional interval to be separately produt~d. showing the data pertinent to such intervan. Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 • • AURORA GAS, LLC. ENDEAVOUR #~ Surface cement plug Top 12' BGL Bottom 188' Bridge Plug @ 188' 12'/4" Hole to 2,465 f1 Cement plug across casing shoe: Top 2,268' Bottom 2,557' Open-hole cement plug: Top 4,400' Bottom 5,200' Open-hole cement plug: Top +5,300' Bottom 6,000' Open-hole cement plug: Top 6,470' Bottom 6,670' All casing cut off at 12' BGL 13-3/8", 68#, K-55, .480" wall, BFW ends Conductor driven to 101' 9 5/8", 40#, N-80, LTC Surface Casing set at 2,457 ft MD. Cemented to surface. i i i i i i i= i ~ ~---- 8-1/2" Open hole to 9,225' ~ ' i i Entire wellbore contains 9.3 ppg mud. l; I i i i i i i i i i i i `-•-•-•-•-•-' ~ TD at 9,225 ft. • • OPERATIONS SUMMARY Aurora Gas, LLC Endeavour #1 Apri17, 2006 MW 9.0 ppg Vis 52 sec Finish rigging up on location. Install and test diverter. Mix mud, M/U drilling BHA, tag bottom at 102'. Drill 12-1/4" hole 102' to 137'. April 8, 2006 MW 9.4 ppg Vis 65 sec Drill 12-1/4" hole from 137' to 940'. Inclination Surveys: 3.50° at 141' 2.00° at 170' 2.00° at 231' 1.75 ° at 322' 1.00° at 822' Apri19, 2006 MW 9.3 ppg Vis 45 sec Drill 12-1/4" hole from 940' to 1,919'. Inclination Surveys: 2.00° at 1,301' 4.25° at 1,800' 5.00° at 1,919' April 10, 2006 MW 9.3 ppg Vis 45 sec Drill 12-1/4" hole from 1,919' to 2,263'. POH, inspect bit. Inclination Surveys: 4.25° at 2,042' 4.75° at 2,166' April 11, 2006 MW 9.3 ppg Vis 45 sec RIH w/ same bit. Drill 12-1/4" hole from 2,263' to 2,465'. Circulate and condition hole for casing. POH. Inclination Surveys: 4.25° at 2,286' 3.50° at 2,442' April 12, 2006 MW 9.2 ppg Vis 44 sec Finish POH. L/D stabilizers, clear rig floor. R/U to run 9-5/8" casing. Run 9-5/8', 40#, N-80, LTC casing, tag fill at 2,449'. Wash down to 2,457' and C&C hole for cementing. Pump 5 bbl H2O, test surface lines to 2,000 psi. Pump 115 bbl 12.8 ppg lead cement followed by 82 bbl 15.8 ppg tail cement. Drop top plug, pump 5 bbl H2O and displace with 178 bbl mud. Bump plug w/ 1,400 psi. Check floats - OK. WOC. • • April 13, 2006 MW 9.1 ppg Vis 45 sec Finish WOC. N/D diverter, make rough cut on 13-3/8" conductor. Make final cuts on 9- 5/8" and 13-3/8" casing. Install wellhead and test to 2,400 psi. N/LJ and test BOPE. April 14, 2006 MW 9.3 ppg Vis 47 sec Finish testing BOPE. M/U 8-1/2" drilling assembly, RIH, tag cement at 2,352'. Test casing to 2,860 psi - OK. Drill shoe track plus 17' of new hole to 2,482'. C&C mud (MW = 9.3 ppg), conduct FIT to 18.0 ppg EMW. Drill from 2,482' to 2,682'. Attempt LOT - fm would not leak off at 18.0 ppg EMW. Drill from 2,682' to 2,833' Inclination Surveys: 3.00° at 2,653' April 15, 2006 MW 9.3 ppg Vis 44 sec Drill 8-1/2" hole from 2,833' to 2,882'. Attempt injectivity test to 1,050 psi - no good. Drill from 2,882' to 3,089'. Attempt injectivity test to 1,100 psi - no good. Drill from 3,089' to 3,299'. Attempt injectivity test to 1,100 psi - no good. Drill from 3,299 to 3,546'. Attempt injectivity test to 1,100 psi - no good. Drill from 3,546' to 4,010'. Inclination Surveys: 0.50° at 3,048' 1.50° at 3,516' April 16, 2006 MW 9.3 ppg Vis 44 sec Drill 8-1/2" hole from 4,010' to 4,037'. Attempt injectivity test to 1,100 psi - no good. Drill from 4,037' to 4,256'. Attempt injectivity test to 1,100 psi - no good. Drill from 4,256' to 4,530'. Short trip to 9-5/8" shoe. RIH and drill from 4,530' to 4,758'. Inclination Surveys: 1.00° at 4,007' 2.00° at 4,500' April 17, 2006 MW 9.3 ppg Vis 45 sec Dri118-1/2" hole from 4,758' to 5,512'. Inclination Surveys: 1.75° at 4,992' April 18, 2006 MW 9.3 ppg Vis 44 sec Dri118-1/2" hole from 5,512' to 6,355'. Inclination Surveys: 1.75° at 5,484' 1.75° at 5,976' April 19, 2006 MW 9.5 ppg Vis 44 sec Drill 8-1/2" hole from 6,355' to 6,559'. Short trip to 4,500'. RIH and drill from 6,559' to 6,807'. Inclination Surveys: 3.00° at 6,529' 3.75° at 6,776' • • Apri120, 2006 MW 9.3 ppg Vis 44 sec Drill from 6,807' to 7,021'. POH for new bit. Inclination Surveys: 3.75° at 6,985' April 21, 2006 MW 9.3 ppg Vis 44 sec Finish POH. Test BOPE. RIH w/ new bit, wash to bottom. Drill 8-1/2" hole from 7,021' to 7,107'. April 22, 2006 MW 9.3 ppg Vis 45 sec Drill 8-1/2" hole from 7,107' to 7,360'. Inclination Surveys: 4.00° at 7,206' April 23, 2006 MW 9.3 ppg Vis 47 sec Drill 8-1/2" hole from 7,360' to 7,449'. Apri124, 2006 MW 9.3 ppg Vis 48 sec Drill from 7,449' to 7,470'. Bit stopped drilling. POH. M/U new bit and modify BHA. RIH. Inclination Surveys: 2.50° at 7,450' Apri125, 2006 MW 9.3 ppg Vis 51 sec Continue RIH. Drill 8-1/2" hole from 7,470' to 7,705'. C&C hole for coring, POH. SB drilling BHA. Inclination Surveys: 3.50° at 7,705' April 26, 2006 MW 9.3 ppg Vis 51 sec P/U coring assembly and RIH. Take Core #1 from 7,705' to 7,735'. CBU & POH. Apri127, 2006 MW 9.3 ppg Vis 51 sec Finish POH. L/D core and load new inner barrel. L/D coring assembly. M!U drilling assembly and RIH. Ream core section and drill 8-1/2" hole from 7,735' to 8,006'. Apri128, 2006 Dri118-1/2" hole from 8,006' to 8,333'. MW 9.3 ppg Vis 48 sec Inclination Surveys: 4.50° at 8,182' 4.25° at 8,241' Apri129, 2006 MW 9.3 ppg Vis 52 sec Drill 8-1/2" hole from 8,333' to 8,373'. CBU, POH and SB BHA. Test BOPE. M/U new bit on mud motor and RIH. Apri130, 2006 MW 9.3 ppg Vis 52 sec Wash to bottom. Dri118-1/2" hole from 8,373' to 8,697'. • • May 1, 2006 MW 9.3 ppg Vis 51 sec Dril18-1/2" hole from 8,697' to 8,805'. CBU, POH Inclination Survey: 4.75° at 8,703' Mav 2, 2006 MW 9.3 ppg Vis 51 sec Finish POH, M/U new bit, RIH. Wash to bottom and drill 8-1/2" hole from 8,805' to 8,972'. Mav 3, 2006 MW 9.3 ppg Vis 52 sec Dri118-1/2" hole from 8,972' to 9,089'. Bit stopped drilling. CBU and POH. May 4, 2006 MW 9.3 ppg Vis 51 sec Finish POH. All cones missing from bit. M/U new bit and junk basket. RIH, wash slowly to bottom. Dri118-112" hole from 9,089' to 9,150'. May 5, 2006 MW 9.3 ppg Vis 53 sec Drill 8-1/2" hole from 9,150' to 9,153'. CBU, POH to check bit. Test BOPE. M/U new bit, RIH. Mav 6, 2006 MW 9.3 ppg Vis 53 sec Finish RIH. Drill 8-1/2" hole from 9,153' to 9,225' TD. C&C hole for logging. Drop survey and POH. Inclination Survey: 4.00° at 9,225' Mav 7, 2006 MW 9.3 ppg Vis 53 sec R/U to run wireline logs. P/LT tools, load sources. Log open hole with PEX/CMR. Change tools to FMUDSI and log with same. May 8, 2006 MW 9.3 ppg Vis 53 sec Change logging tools to MDT and record formation pressures at various depths. Change tools to GR/CBL and log 9-5/8" surface casing. L/D logging tools and R/D wireline unit. RIH w/ BHA and partial string of drill pipe. POH, laying down same. M/U mule shoe on drill pipe, RIH. Mav 9, 2006 MW 9.3 ppg Vis 54 sec Continue RIH to 7,200'. Wait on orders. POH, L/D drill pipe from 7,200' to 6,898'. Spot hi-vis pill at 6,870', POH to 6,670'. Pump 20.2 bbls 15.8 ppg cement and displace with mud. POH to 6,401', WOC. Mav 10, 2006 MW 9.3 ppg Vis 56 sec WOC. RIH, tag TOC at 6,470'. Pump 5.6 bbls cement on top of first cement plug. POH to 6,200' and place hi-vis pill. POH to 6,000'. Pump 62.5 bbls 15.8 ppg cement and displace with mud. POH to 5,108', WOO. RIH to 5,200'. Pump 64.5 bbls 15.8 ppg cement and displace with mud. POH to 4,200'. L/D 78 joints drill pipe. • • Mav 11, 2006 MW 9.4 ppg Vis 56 sec RIH, WOC. RIH, tag cement at 4,400'. Weight test w/ lOk lbs - OK. POH, L/D mule shoe, P/LJ cement retainer. RIH to 1,237'. Attempt infectivity test. Fm would not take fluid at 18.0 ppg EMW. POH, L/D retainer, M/U mule shoe. RIH to 2,757', spot hi-vis pill. POH to 2,557', pump 27.5 bbls of 15.8 ppg cement. POH to 1,971', clear drill pipe of cement. L/D 20 jts drill pipe. RIH to 1,914' and WOC. May 12, 2006 WOC. Wash from 1,914' to top of cement at 2,270' and tag with lOK lbs. Wait on AOGCC inspector. Pressure test plug to 1500 psi. Bleed off and tag plug at 2,268'. Verified by inspector. L/D 74 jts drill pipe. M/U bridge plug, RIH and set bridge plug at 188'. L/D all remaining drill pipe. N/D BOPE and clean mud pits. Mav 13, 2006 N/D BOPE, remove wellhead, cut off surface pipe and conductor at cellar floor level. Weld on marker plate. Finish cleaning pits, release rig. Final Report. • • DATA TRANSMITTAL Please reply to: AURORA GAS, LLC 10333 RICHMOND, STE. 710 HOUSTON, TX 77042 ATTN: ANDY CLIFFORD State of Alaska Oil & Gas Conservation Commission 333 W. 7~' Avenue, Suite 100 Anchorage, AK 99501 ATTENTION: Howard Okland Enclosed Paper Prints/Report including 1 CD From Aurora Gas LLC Area Endeavour-1 well, Cook Inlet, Alaska Date: 6 June, 2006 1. One set of paper prints from the Endeavour-1 well: Dipole Sonic Imager, Formation Micro Imager. 2. One Epoch report containing Mudlog (paper prints plus 1 CD) from the Endeavour-1 well. PLEASE ACKNOWLEDGE RECEIPT OF DATA BY SIGNING BELOW AND SENDING A COPY BACK TO AURORA GAS FOR OUR FILES. Received by: Date: °~ ~,. ~,~ AURORA GAS, LLC, 10333 RICHMOND, STE 710, HOUSTON, TX 77042 TEL: 713-977-5799, FAX: 713-977-1347 ~ o ,-- z ~ 3 • DATA TRANSMITTAL Please reply to: AURORA GAS, LLC - - 10333 RICHMOND, STE. 710 HOUSTON, TX 77042 ATTN: ANDY CLIFFORD , State of Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchors e AK 99501 ATTENTION: Howard Okland Enclosed Pa er Prints/1 CD From Aurora Gas LLC Area Endeavour-1 well, Cook Inlet, Alaska Date: 25 May, 2006 l~ r--9~e~et-emits-~e~r ~„ao ~~=ell: 2. One CD containing digital log data from the Endeavour-1 well: Platform Express, Platform Express "High Res", CMR, MDT and CBL.~ ~3 ~~, Gj Please note that other log data, including mudlog, to follow shorty PLEASE ACKNOWLEDGE RECEIPT OF DATA BY SIGNING BELOW AND SENDING A COPY BACK TO AURORA GAS FOR OUR FILES. Received by: Date: y /~ AURORA GAS, LLC, 10333 RICHMOND, STE 710, HOUSTON, TX 77042 TEL: 713-977-5799, FAX: 713-977-1347 ~ ~~ ~ ~~~ ~ ^`~4urrora Gas, LLC www.aurorapowercom May 19, 2006 Mr. Sohn Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Aurora Gas, LLC: Endeavour #1 Dear Mr. Norman: _ 1 This is a report of Aurora Gas, LLC's well operations on Endeavour #1 for the period May 12 through May 13, inclusive after which operations on this well were complete. May 12, 2006 WOC. Wash from 1,914' to top of cement at 2,270' and tag with lOK lbs. Wait on AOGCC inspector. Pressure test plug to 1500 psi. Bleed off and tag plug at 2,268'. Verified by inspector. L/D 74 jts drill pipe. M/U bridge plug, RIH and set bridge plug at 188'. L/D all remaining drill pipe. N/D BOPE and clean mud pits. May 13, 2006 N/D BOPE, remove wellhead, cut off surface pipe and conductor at cellar floor level. Weld on marker plate. Finish cleaning pits, release rig. Final Report. If you have any questions or require additional information, please contact me at (713) 977-5799 or Bill Penrose at Fairweather at 258-3446. Sincerely, AURORA GAS, LLC J. dward Jones ice President, E Bering and Operations cc: Bill Penrose -Fairweather 10333 Richmond Avenue, Suite 710 • Houston, Texas 77042 • (713) 977-5799 • Fax (713) 977-1347 1400 West Benson Blvd., Suite 410 • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 ao~ - ate ~~~4urora Gas, www.aurorapower.com May 12, 2006 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Aurora Gas, LLC: Endeavour #1 Dear Mr. Norman, LLC This is a report of Aurora Gas, LLC's well operations on Endeavour # 1 for the week of May 5 through May 11, inclusive. Mav 5, 2006 Dri118-1/2" hole from 9,150' to 9,153'. CBU, POH to check bit. Test BOPE. M/U new bit, RIH. Mav 6, 2006 Finish RIH. Drill 8-1/2" hole from 9,153' to 9,225' TD. C&C hole for logging. Drop survey and POH. Mav 7, 2006 R/U to run wireline logs. P/LT tools, load sources. Log. open hole with PEX/CMR. Change tools to FMUDSI and log with same. Mav 8, 2006 Change logging tools to MDT and record formation pressures at various depths. Change tools to GR/CBL and log 9-5/8" surface casing. L/D logging tools and R/D wireline unit. RIH w/ BHA and partial string of drill pipe. POH, laying down same. M/IJ mule shoe on drill pipe, RIH. May 9, 2006 Continue RIH to 7,200'. Wait on orders. POH, L/D drill pipe from 7,200' to 6,898'. Spot hi-vis pill at 6,870', POH to 6,670'. Pump 20.2 bbls 15.8 ppg cement and displace with mud. POH to 6,401', WOC. 10333 Richmond Avenue, Suite 710 • Houston, Texas 77042 • (713) 977-5799 • Fax (713) 977-1347 1400 West Benson Blvd., Suite 410 • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 acs-a ~3 ~aas -a r3 • Mr. John Norman Page 2 May 10, 2006 WOC. RIH, tag TOC at 6,470'. Pump 5.6 bbls cement on top of first cement plug. POH to 6,200' and place hi-vis pill. POH to 6,000'. Pump 62.5 bbls 15.8 ppg cement and displace with mud. POH to 5,108', WOO. RIH to 5,200'. Pump 64.5 bbls 15.8 ppg cement and displace with mud. POH to 4,200'. L/D 78 joints drill pipe. May 11, 2006 RIH, WOC. RIH, tag cement at 4,400'. Weight test w/ lOk lbs - OK, POH, L/D mule shoe, P/U cement retainer. RIH to 1,237'. Attempt infectivity test. Fm would not take fluid at 18.0 ppg EMW. POH, L/D retainer, M/U mule shoe. RIH to 2,757', spot hi-vis pill. POH to 2,557', pump 27.5 bbls of 15.8 ppg cement. POH to 1,971', clear drill pipe of cement. L/D 20 jts drill pipe. RIH to 1,914' and WOC. If you have any questions or require additional information, please contact me at (713) 977-5799 or Bill Penrose at Fairweather at 258-3446. Sincerely, AURORA GAS, LLC J Edward Jones ice President, Engineering and Operations cc: Bill Penrose -Fairweather .,, ._ ~, ~~ _, ~ e__ _ - ~-} FRANK H. MURKOWSKI, GOVERNOR ~~ OIL ~ ~ 333 W. 7"' AVENUE, SUITE 100 CO~SLRQAii'Va` ~OM~IISSIO~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 17, 2006 Bill Penrose Vice President/Drilling Manager ' Fairweather E&P Services, Inc. 2000 East 88th Avenue, Ste 200 Anchorage, Alaska 99507 Re: Endeavour #1 Well Application for Annular Disposal Approval Number 305-374 Dear Mr. Penrose: Per your request on May 17, 2006 the Alaska Oil and Gas Conservation Commission is returning your Application for Annular Disposal, since urora Gas will not be conducting annular disposal in the subject. well. ~ `ti ~S a (3 Endeavour #1 Subject: Endeavour #1 From: Bill Penrose <bill@fairweather.com> Date: Wed, 17 May 2006 09:43:39 -0800 To: Winton_aubert@adminatate.ak.us Winton, Since Aurora Gas will not be conducting annular disposal In the subject well, please consider the previously submitted Application for Annular Disposal for this well rescinded. Thanks and regards, Bill ['enros~ Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 E. 88th Avenue, Suite 200 Anchorage, Alaska 99507 907-258-3446 1 of 1 a0`J _ ~,~3 5/1712006 9:49 AM Endeavour #1 AD Information }, • Subject: Endeavour #`1 AD Information From: Bill Penrose <bill@fairweather_com> Date: Wed, IO May 2006 15:44:06 -0800 "To:.Iim Rc~~~~ jim_rc~~,i~rjadmin.stat~.ak.us= CC: jejonesrri?aurorapower.com Jim, i~~L ~ \ ~ ~ C( ~ Attached please find the proposed annular disposal rate test and injection procedure. More to come as I gather it up. Regards, Bill Penrose Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 E. 88th Avenue, Suite 200 Anchorage, Alaska 99507 907-258-3446 Content-Description: Procedure.doc Procedure.doc Content-Type: application/msword Content-Encoding: base64 1 of 1 c~~' al`3 5/11/2006 11:10 AM • Annular Disposal Procedure Aurora Gas Endeavour #1 Note: Notify the AOGCC of the intent to begin the following injectivity test to enable them to provide a representative to witness. 1. With the last open hole cement plug set with TOC at 4,400' and verified with a weight test, POH with drill pipe and make up a 9-5/8" cement retainer. 2. RIH and set the retainer in the 9-5/8" casing at 2,400', 57' above the casing shoe. 3. While stung into the retainer, slowly pressure up on the drillpipe using drilling mud until the formation below the shoe begins to take fluid. Monitor the 9-5/8" x drill pipe annulus for pressure, bleeding off as necessary as the drill pipe balloons and drives up the pressure. Do not allow the annulus pressure to exceed 4,025 psi (70% of the burst rating of the 9-518" casing) at any time. 4. Conduct a 4-point injectivity test as laid out in Steps 5 - 9. Record test on a chart and separately record the four rate-pressure pairs. 5. Establish an injection rate of 0.5 bbl/min and record the stabilized injection pressure at that rate. 6. Slowly increase the injection rate to 1.0 bbUmin and record the stabilized injection pressure at that rate. 7. Slowly increase the injection rate to 1.5 bbUmin and record the stabilized injection pressure at that rate. 8. Slowly increase the injection rate to 2.0 bbl/min and record the stabilized injection pressure at that rate. 9. Shut down pump and record pressure falloff on chart. 10. Bleed off drill pipe pressure and transmit the chart and rate-pressure pairs to Fairweather's Anchorage office for consultation with the AOGCC to determine the allowable injection rate. 11. Once the allowable injection rate is established and transmitted to the rig, slowly bring the mud pumps up to the allowable rate and inject all drilling mud on location through the retainer while continuously monitoring the annulus pressure and keeping it below 4,025 psi. • • 12. As pits and tanks are emptied, wash them out with water and send the rinse water down the well. 13. Record the time of the beginning of injection, end of injection and the total amount injected and submit to Fairweather's Anchorage office upon completion of mud disposal. 14. After the completion of mud disposal, resume the P&A of the well at Step 11 of the P&A Procedure (where the casing shoe cement plug is set through the retainer and 75' of cement is placed on top). Remaining Endeavour # 1 AD Data • • Subject: Remaining Endeavour #1 AD Data ~ ~ ~ tt~~ ~D From: Bill Penrose <bill~fairweather.com> ~~~~ Date: Wed, 10 May 2000 16:35:00-0fSl)(1 To: ,iim Re`~~ _jimre`~~~~~.iadiz~in.stale.ak.us= CC': jejone~s(ci.aurorapo«~er.com Jim, Attached please find the requested 9-5/8" cementing record and the attempted LOT at the casing shoe. The open hole was pressured up to an 18.0 ppg equivalent without breaking down so the test was accepted as a FIT. The calculated distance of the Griner wellbore from the Endeavour wellbore at the expected injection depth of 2,800' TVD is 890'. Please let me know if you need any additional information. Regards, Bill Penrose Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 E. 88th Avenue, Suite 200 Anchorage, Alaska 99507 907-258-3446 Content-Description: 9.625 Cmtg Record.PDF !. 9.625 Cmtg Record.PDF' Content-Type: application/octet-stream Content-Encoding: base64 __ __ __ __ _ _ _ _ _ _ Content-Description: 9.625 Casing Test & LOT 9.625 Casing Test & LOT Worksheet.xls Worksheet.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 aps'-al3 5/11/2006 9:17 AM Mai 10 06 03:54p William hutto Sch~emberger ~.. 90 - 5-0581 p.1 -~~rnenting ]ob Report~~ r __.__........._._ _.... _ ..._ __ _---- ~--- --- ___' ( tNeEl Endeavour A i ; Cllent FieEd 'NlldCat ( SIR No. Engineer Aibin Hale Ion type Country United states _ .. __ Job E)rtte .._. Pressure Rate-.-_---- -°,- -pensity Y eew~nva r..+. 16:2t:46 ! _ I '-~- I ~11 26:32:00 i I 16:42:00 •r 4 ~ ! 16:52:Op 1?:02:00 - ~_ • 3 ! t7:12:0p t'- 4 . ~~~~ 17:22:00 ! 13:32:OD ~ ! •...~ - r Sraz:oo i f 17:52:00 ~ ! 1_ i ! 18:02:00 I .~ 1 1 ResetTogl, Val = St5.D7 bbl Statt Mixlnp Tats Slurry Shutdown f Reset Total, V01 ~ 82.21 bbl Stare Uisplacernent Shutdown Rtg Pumps To DlsplacC MutlPUSH I[ to surface ~ ! 1s:t2:oa I Bumf 7pp Plug ! 18;20:58 ~ l Bleed Oft Preswre ' SLOpPed ACqul _ 5ttlon o m saw zc;y xw +ow soon ~ aar - --. .... ' • - ---- .-._ . ~ . __ _ hh:mrrss to ~.o :.a 6D soa xo sea sc,e '---"' ao.a as.o am ~ aas~ ama aaeo ,aoo sosr ~ w.answxras~ ------ PS[ ~- SAM .... ~/Ci .. _ ... `PSI . .. ~---------'--'-^-. ... _._ .._ 04Jt2/200618:25:OB CemCAT vl.4 AURORA GAS 2204941143 cj~l,w $UrF3C@ /~ 4u C 0412-2006 ------------ --- ._...~...._. _..______.~,_ ! WH Pressure Messages 4 Start Pumping \Va[er 1 [~L~M Sputt~wn f~-~' PrI;SSUrC T@S[UneS "t[T ~P Bo[mm Ptuq ttt Start Pumpng Spacer I RcsQt7otat, Vol = 3.21 bbl 'CJ-Ii Batch up tub t0 t2.8ppq 4 Stara Mixing itad Slurry :4 `t~ May 10 06 03:54p William hutto customer: Au..,,Ra ~n; ~1.kru~^~e~ District: K6NA1 tf1Y11Y1i RepreseMatrva: Jack ttfeDade DS Supervisor: Albin Hate Job pate: 0412-2006 WeIF. Endeavour # t TAne ~reating Pressure ~ WHP FtrrxRate mm:dd:yyyy:hh:mm:ss ...._..__._. _ psi pal bbUmin 04:12:2006:16:21:46 24 26 0.1 04:12:2005:16:22:16 17 10 D,1 04:t2:2D06:18:22:40 Stag Pumping Water 04:12:2006:16:22:4D 21 14 0.6 04:12:2006;16;22:46 33 18 1.9 04:12;2006;1623:76 98 79 3.1 04:12:2006:16:23:46 66 4? 2.8 04:12:2006;16:23;48 Shutdown 04:12:2006:18:23:46 46 8 0.6 04:12:2008;18:24:16 33 22 0.0 04:12:26:16'.24:46 46 41 0.1 D4:12:2006:76:25.16 600 599 4.D 04:12:2D06:18:25:46 SBO S81 0.0 04:12:2006:18x26:16 1967 1969 O.D D4:12:2006:16:26:45 Pressure Test Lines 04:1220D6:i6:26:45 1839 1943 0.0 04:122008:76:26:46 1939 1943 0.0 04:12~008:i6:27:1s 23 16 0.0 04x2~D06:18:27:48 i8 12 0.0 D4:72;2D66:16:2$:16 367 371 DA 04:12:2006:16:26:46 362 381 D.0 04:12:2006:16:29:17 356 358 0.0 04:72:2006:16:29:28 Orop Boticm Ptup 64:t2:2D66:18;29:28 355 356 0.0 04:12:2006;15:29:33 Start Pumping Spacer 04:12:2008:16:29:33 355 355 0.0 04:12:20D6as:29:47 354 357 a.D 04:12:2005:18:30:1? 350 350 D.0 04:12:2006:16:30;35 Reset Tool, Vol = 3.2,3 bbl 04;12;2006:16:3D:35 348 348 p,0 04:12:2006:16:36:47 348 347 0.0 04:12:2006:16:31:07 Bate up tub to i28Pp8 04:52:2005:16:31:D7 3x6 346 O.D 04:122006:16:31:17 344 346 0.0 04:12606:16:31:47 341 342 0.0 04:12'ZDg6:16:32x7 339 34D 0.0 04:12~D06:16:32:47 340 337 0.D 04:12:2DD6:16:33:17 338 336 p,p 04;12:2006:16:33:47 333 ~4 0.0 04:12:2006:16:3x:77 331 332 p,p 04:72;2606:18:34;47 333 329 0.0 D4:12:2006:16;35:1T 327 329 0.0 04:122006:16:35:47 329 327 p,p 04:122D08:16:35:17 328 326 0.D 04:122D06:18:36:47 323 323 D,p 04:12006:18:37:77 29 20 0.0 04:12:2D06x6:37:34 Start Mbdrlg Lead Slarry 04:]2:2066:1637:3a 80 72 0 5 Od:12:2006:76:37:xT 99 104 , 2,2 04:92:2006:18:38:17 135 134 2.7 04:12:2006:18:38:47 496 319 4 8 04:12:2pp8:1&39:17 304 282 . 4.6 04:12:2006:16:39:4'> 319 316 4.B 04:72;2006:16:40:77 292 215 4.8 D4:12:z6ps:16:ao:a6 255 276 4.6 04x2:2006;16:41:18 338 289 q.g 04:122006:16:41:48 252 278 4 8 04:12:2D06a6:A2:76 255 283 . 4 8 D4:122006:16:42:48 184 212 . 4.8 04:12:2006:16:x3x8 284 237 4.8 04:12:2006:16:43:48 280 210 4.8 04:12:2006:16:44:18 272 293 4.8 04;12:2006:16:4x:46 263 22T 4 8 04:12:2008:76:45:18 294 291 . 4 8 04:12:2006:76:45:46 280 265 . 4 8 04:122008:16:48:16 217 252 . A 8 04:722008:16:46:46 240 27d . 4 8 04:i2:2006:f6:47:1B 302 302 . $ p 04:f2:2006;16:47:48 292 302 , S 1 04:t2:20D6:iB:48:18 338 258 . 5 t 04:722006;16:46:46 293 284 . 5 1 04:72:2006:16:49:18 292 262 . 5 1 04:122006:16:49:48 331 289 . 5 1 04:122006:16:50:18 30fi 228 . A,8 04:72:2068:76:50:48 303 262 A.8 04x12:2006:75:51:18 221 261 q,3 04:12:2006:16:51:46 238 197 4.3 0412;2006:16:52:19 226 247 4,3 Page 1 of 4 90 - 35-05$1 p 2 ; CMT DENS ; CA1TSTG VOL Volume ~ YY~~ ._ ~Iblgal I kbt bbl _ i s.4a o-.o 6.43 0.1 6.43 0.2 8.43 0.3 6.43 i.6 6.43 3,1 8.43 3.2 8.43 3.2 B.4i 3.2 8.47 3.2 8.46 3.2 B.d7 3:2 6.47 3.2 6.47 3,2 8.46 3.2 6.47 3.2 8.43 3.2 8,44 3.2 6.45 3.2 8.45 3,2 s.a5 3.2 11,30 3.2 13.90 3.2 -3.13 3.2 13.98 0.0 13.91 0.0 13.77 0.0 13.52 0,0 13.16 0.0 1269 0.0 12.71 D.0 12.71 0.0 1272 O.o 1272 D.0 1269 0.0 1268 0.0 12.67 D.0 12.67 D,p 12.69 0.0 12.82 D.0 t 2.83 D.3 13.09 1.6 12.65 3.3 12.65 5.7 72.83 8,1 72.75 1D.5 1267 13.0 i2et 75.a 13.07 17.8 12 97 2p,2 12.83 22.6 12.97 25.0 12.96 27.4 12.42 29.8 12.88 32.2 12.86 54.5 12.85 36,9 12.66 39.3 12.87 41.7 12.$8 44.1 12.68 46.8 12.88 49.2 12.61 57.7 12.84 54.2 12.97 56.8 t 3.10 59.2 13.02 61.6 13.02 63.6 13.03 65.9 12.86 68.1 a,o O.t 0.2 0.3 7.6 3.t 3,2 3.2 3.2 3.2 3.2 3.2 3,2 32 32 3.2 3.2 3.2 3.2 3.2 3.2 3.2 3.2 3.2 3.2 3.2 3.2 32 32 9.2 32 32 3.2 3.2 3.2 3.Z 3.2 3.z 3.2 3.3 3.5 4.6 6.6 9.0 11.4 13.s 16,2 19.6 21.0 23.4 2s.e 26.2 30.6 33.0 35.4 37.8 40.2 42.6 45.0 97.3 49.9 52.4 54.9 57.3 60.0 62,4 64.8 st.o fi9.2 71.4 ,.~. Malt 10 06 03;560 William hutfo 90 - 35-0581 p.3 WeO: E:ntleavou[ # 1 I ~ Job Date: 04-12-2006 Tirne Treating Pressure f _ YYHP Fbw Rate CMT DENS CMT STC, VOL ~ volume ~mm;dd:yyyy::rh:mm;ss psi f --- psi M. -,T~bbllmin Iblgal V bbi bbt 04:12:2006:16:53:19 --fL...__ 04:12:2006:16:53:49 04:12:2006:16:54:19 04:12:2006:16:54:49 04:12:2006:18:'55:19 04:12:20D6:18:55:49 04:12:2006:16:56:19 04:12:2006:1656:49 04:12:2006;16:57:19 04:12:2006;16:57:49 04:12:2006:16:56:19 04:12:2006:15:58:49 04:12:2006;16:59:19 04:12:2DD6:16:59:49 04:12;2006:17:00:19 04:12:2006:17:00:49 04:12:2006:19:01:19 04:12:2005:17:01;49 04:12:2008:17:02;19 04:12:2006:77:02:99 1M:122005:17:03:19 04:12:2008:17:03;32 04:12:2006:17:03:32 D4: t 2:2006:17:03:41 04:12:2006:77:03:41 04:122008:17:03: SD 04:12~D06:17:D4:20 04:12:2008:17:04:50 04: i 2:2006:17:05:20 Da:lz:zoD6:i7:os:so 04:12:2oD6:17:06;20 04:12:2006;17:06:50 04:122006:17:07;20 04:122006:17:07:50 04:12.2006:17:08:20 04:12:2006:17:08:50 04:12:2006:17:09:20 04:12:2006:17:04:50 D4:12:2006:17:1 D:20 04:12:2006:17:16:50 04:12:2D06;17:11:20 04:122006:17:11:50 04:12:2006:17;12:20 04:122D06:t7:12:50 04:12~006:t7:13:20 04:12:2006:17:1350 04t12~0p6:17:14~0 D4:12.•20p6;17:1450 04:12:2006:17:15:21 04:72:2006:17:15;51 D4:i2:2006:17:1b21 04:12:2006:17:16:51 04:122006;17:17:21 04:12:2006:17:17:51 oa:lzzoas:t7•.16:27 D4:1r3D06:17'.16:5' 04:12:2006;17:19:2' 04:12:2006;17:19:6' 04:12:2006:17;20:21 04:12:2006;17:20:51 04:12:2006:17:21:21 04:12.'1 D06:17:21: S i 04.12:2006:17:22;21 04:122006:17:22:51 04:122006;17;23:21 04;122006:17:23;51 04:122048:17:24:21 04;12:2006;17:24:51 04:12;2006:17:25:21 04:122006:17:25:51 04:12:2006:17:26:21 04:12:2006:17:26:52 04;12;2006:17;27:22 04:12:2006:17:Z7:5i 04:122006:17:28:2c" 04:122006;17:28:52 04:12;2006:17:29:22 04:172006:11:29:52 04:122006:17:30:2'e 04:12:2006:17:30:5c' 04;12:20D6:17:31;22 04:12:2006:17:31:52 D4:12:2DD6:17;32:22 04:122tl06:t7:32:52 m 258 224 193 23t 189 279 zzo 257 201 273 239 302 317 22II 260 281 157 iD3 12t 141 Reset Tatat, Vol =115.07 185 Start Mbdng Taii Sfuny 145 149 146 209 263 z5z 130 480 118 285 111 56 82 705 120 122 104 209 t86 227 222 98 4T 133 156 t7S 180 26D 250 227 23D 187 161 171 201 2t0 249 258 245 260 195 181 207 2D3 21D 221 177 163 zo6 ib3 158 215 211 255 244 787 186 192 205 203 209 4.3 13.04 724 75.6 193 4.3 12.96 74.5 77.8 248 4.3 12.91 76.7 7g,g 229 4.2 12.87 78.8 82.0 196 4.2 12.90 80.9 84.1 243 4.5 t2.92 83.1 86.3 218 4.5 12.93 85.4 88.fi 262 4.S 12.92 87.6 90.9 199 4.5 12.92 89,8 93.1 235 4.5 12.81 82.2 95.4 216 4.5 12.83 94.4 97.7 184 4.5 12.86 96, 7 99.9 239 4.5 1289 98.3 102,2 211 4.S 12.94 t07.2 104,4 253 4.5 1299 103.5 106.7 204 4.5 12.94 105,7 108.9 248 4.5 12.87 108.0 i t 1.2 221 4,5 72.88 110.2 113.5 94 27 13.29 111.8 115.t 101 2.7 14.35 113.2 116.5 127 2.5 3.12 114.5 117.8 bbl 85 2.6 15.05 115.1 118.3 153 2.6 15.16 0.4 118.7 133 2.6 15.18 O,B 719.1 105 2,6 15.41 2.1 120,4 282 3.8 15.63 3.7 122.0 276 3.6 -3.13 5.5 12;1,8 244 3.6 14.2 i 7.3 125.6 t02 2.4 14.89 6.9 121.2 310 4.0 15.87 10.8 129,1 106 0.9 -3.12 f 7.9 130.2 257 3.7 -3.13 13.0 431 3 96 1A 14,96 14,1 132.4 38 0.0 13.95 14.6 132.9 70 0,0 74.1D 14.6 132.9 93 0.0 14.83 14.6 132.9 112 0.0 15.63 14,6 132.9 t10 0.0 15.54 14.6 132.9 92 1.0 15.71 14.8 133.1 ~ 3.1 15.63 16.3 134.6 195 2.T -3,13 17.8 136,1 281 3.0 -3.13 19.3 137.6 231 3,1 -3.13 2D.8 739.t 88 0.0 t4.88 21.7 140.0 37 1.0 18.20 21.9 140.2 719 i.i 15.93 22.4 140.7 161 2.5 t5.64 23,6 141.9 t89 2.8 15.BD 24.9 143.2 198 2.7 15,97 28.3 144.6 253 3.2 15.80 27.8 146.1 244 3.2 15.73 29.4 747.7 217 3.2 15.71 31.0 149,3 219 3.2 -3.13 327 151.0 141 26 -3.13 34.1 152.4 193 26 -3.13 35.4 153.7 171 2.6 -3.13 36.7 155. D 173 2,b 3.13 38.0 156.3 188 28 .3.13 39.3 157.6 234 3.4 -3.13 4Q9 1592 233 3.4 -313 42.6 160.9 235 3.4 -3.13 44,3 182.6 275 3,4 -3.13 46.0 164.3 791 3.0 t5 fiD 47.6 i6fi 0 191 3,0 t5.49 49.1 . 187.4 175 2,9 15.54 50,5 168.9 192 2.9 1 b.66 521 170.4 147 2.9 -3,13 53.5 771.8 172 2.4 3.13 55.0 173.3 209 2.9 ~3.t3 56.4 174.7 197 2.9 -3.13 58.0 176.3 205 29 -3.13 59.4 177 7 202 2.9 -3,13 60.9 . 179 2 148 2.9 -3.12 62.3 . 180.6 183 2.9 -3.13 63.8 182.1 222 2.9 15.81 65.2 183.5 161 2.9 15.59 66.7 185.0 241 2.9 15.82 68.1 186.4 165 2.9 14.80 69.6 187.9 762 2.9 15.35 71.0 189.3 156 2.9 15.60 ?2.5 790.8 145 2,9 -3,13 73.9 192.2 150 2:9 -3,13 15.4 193,7 Page 2 4[ 4 Mai 10 06 03:55p William hufto • 90 - 5-0581 p,4 we71: Endeavour U 1 TEme mm`dd:yyyy: ht~:mm_ss 04:12:2006:17:33;22 04:12.2006:17:33:52 04:12:2006: 17:34:22 04:122006:17:34:52 04:12:2006:17:35:22 04:12:2006:17:35:34 04:12:2006:17:35:34 04:12:2006:17:35:37 04:12:2006:17:35;37 04:1 z:zoos:17:35s2 04:12:20D6:17:3fi:22 04:12:2006:17:36:52 04:122006:17:37:22 04:12:2006:17:37:24 04:12:2006:17:37:24 04:12:2006:17:37; 52 04:12:2006:17:38:22 04:12:2005:17:38:59 oa:1 2:2006:17:39 2s 04:12:2006:173924 04:1220D6: i 7:39:24 04:12:2006:17:39:53 04:12:2808:17:40:22 04:12:2006::7:40:22 09:12:2006:i7:4D;23 04:12:2008:77:40;53 04:12:2006:17:41:23 04:12:2006:17:41:53 04:12:2006:17:42;23 04:12:2006:17:42:53 04:12:2406:17:43:23 04:12:2006:17:43:53 04: i 2:20 0 6:'.7:44:23 D4;t2:2006:17:44'S3 04:1z2DDS:n:4s:23 04;122006: i 7:45;53 04:12:2006:17:46 23 p4:122006:17:46:53 04:12:2006:17:47 23 04:12200fi:17:47:53 04:122D06:1r:48~28 04:12:2006:17:48:53 04:122008:17:49;23 04:12:Zp86:17:49:53 04:12:2006:i7:5p:24 04;12:2006:17:50:54 04:12:2006:17:51:24 04:12:2006;17:51:54 oa:122pps:17:52:za 04;122006:17:52:54 04:122006:17:53:24 04:12:2006:17:53:54 04:12:2006:17:54:24 04:12:2006:17:54:54 04:12:2806:17:55:24 84:12:2006:17:55:54 04:122006:17:56:24 04:12:2006:17:56:54 04:12:2006:17:57:24 04:12:28~:17:5T:54 04:122D06:17:58:24 04:122D08;17:SB:54 04:12:2006:17:59:24 04:12:2(186:17:59:54 D4:12:2008:18:D824 44:12:2D06:i&D0:S4 04:12:2op6:7aro1aa 04:12:2008:181:55 a1:12:2aos:1a:o2:zs D4:122p06:18:D2:55 04;12:2006:16:D3:25 04:12:2006;18:(13:49 04:12:2006:18:03:49 04:12:2006:16:03:55 04:12:2006:18:04:25 04:12:2006:18:04:55 04:12:2006:18:8525 04:12:20:18:05:55 04:12:2006:18:06:25 04:12:2008:18:06:55 04:12:2006:18:87:25 04:12:2006:18:07:55 04:12:2008:78:0825 04:12:2006:18:88:SS TreatingPressufo 1PlHP Flow Rate ~I --- - .- ---Psl bCUmin . . 184 . ^ 181 _.. . --- 2.9 149 184 2.9 142 123 2.2 138 125 2,2 133 124 2.2 Shofdawn t3D Reset Total, Val = 6221 bbl 45 34 33 29 32 Start Displacement 29 239 Bt 78 36 Shutdown 26 2B Rig Pumps 70 l>isplxe 3t 30 27 27 29 28 29 51 31 27 45 30 30 27 49 50 48 47 30 24 25 26 37 ZO 2i 32 22 19 21 21 27 57 22 7fi 32 38 18 325 165 33 41 39 25 22 2D 24 41 2d MudPL15H II to surtaoe 24 26 25 47 x1 21 191 82 221 44 37 29 CMT DENS lblgal -3.13 x.13 15.72 16.18 16.15 ~~- CMT STG VOL 'Volume bbt ~ bbl ,-oh Hate: oa-l2-loos 76.8 195.1 78.2 196.5 79.6 197.9 $D,7 199.9 a1,8 aaD.1 120 0.7 76.15 82,2 200,5 26 0.1 16.16 82,2 200.5 76 0.0 78.16 0.0 200.5 19 D.0 16.15 0.0 2pQ5 17 0.0 16.15 0.0 200.5 15 0.0 18.14 0.0 200.5 20 0.0 16.14 D.0 200.5 224 5.8 16.13 1,1 201.6 68 1.9 16.11 2.7 209.2 72 2.5 16.12 4.0 204.5 17 0.7 15.11 S.2 205.7 10 0.4 18.11 5.2 205.7 17 0.0 16.11 5,2 205.7 15 0.0 16.1D 5.2 205.7 13 0.0 1fi.16 5.2 205.7 14 0.0 16.11 5.2 205,7 17 0.0 16.1D 5.2 205.7 13 0.0 16.10 5.2 205.7 15 8.0 16.09 5.2 205.7 15 0.0 16,09 5.2 205.7 36 O.D 16.09 5.2 205.r 14 0.0 16.09 5.2 205.7 15 0.0 16.09 5.2 205.7 ~ o.0 1s.oB s.2 2os.r 16 D.0 iS.OB S.2 205.7 i5 0.0 15,09 5.2 205,7 14 0.0 18.09 5.2 205,7 37 0.0 1fi.09 5.2 205.7 37 0.0 16,09 5.2 205.7 37 0.0 16.09 5.2 205.7 37 O.D 16.08 5.2 205.7 17 0.0 16.09 5.2 205.7 15 0.0 111.09 5.2 205.7 12 0,0 16.08 5.3 205.9 14 0.5 1x08 5.4 205.9 33 0,6 15.76 5.6 206.2 58 0.0 8,43 5.9 206.4 45 0.0 8.d2 5.9 208,4 69 0.0 8.43 S.9 206.4 44 0.0 8.43 5.9 206.-0 32 0.0 6.4a 5.5 206.4 56 0.2 8.44 8.3 206.8 42 0.1 6.43 7.1 207.6 49 D.3 6.27 7.2 207.7 11U 1.4 8.48 8.1 208.6 41 0.1 8.49 9.3 209,8 99 0,2 8,50 9.3 209.9 47 0.0 $,51 10.4 214.9 SO 1,3 8.51 11.7 212,? 27 0.1 8.52 12.7 213.2 362 5.8 8.52 14.4 274.9 164 4.0 8.51 16.6 217.1 37 0.3 8.39 17.2 217.7 47 0.7 8.20 18.1 219.6 37 1,0 8.25 21.5 222.0 25 0.1 825 21.6 222.1 15 0.1 8.37 25.6 222.1 21 0.1 8.41 21.7 222,2 19 0,1 6.42 21.7 222.2 AO 0.3 8.42 21.8 222.3 22 0.1 8.43 21.9 222,4 19 0.1 $.A3 21.9 222.4 18 0.1 8,q3 21.9 222.4 21 0,1 6,43 2Z.D 222.5 45 0.1 6.44 22.1 222.6 19 0.1 8.43 22.1 222,6 13 0.1 8.43 22.2 222.7 1 B9 5.7 6.34 23.7 224.2 62 0.1 8.42 25.2 225.7 256 5.8 8.43 26.9 227.4 50 2.4 8.43 28.2 226.7 36 2.6 6,44 29.5 230.0 24 Z7 B,q4 3fl.8 231,3 Page 3 Of 4 Ma { 10 06 03;56 Willi h ft • ~ l p am u o 9R 5-0 581 p 5 UYEB Endeavourif 1 j Job Data:04-12-2006 Time Treating Pressure WHP Flom Rate CMt DENS ChAT STG VOL Volume ~ _ ,.~.~ ~~-'_ _____. mm:dd:yyyy:hh:mm:ss - psi psi 1 -- bbUmin ~Igal bbl bd D4:122006:18:09:25 59 --_ 62 __....._ __ 2.7 8.44 32.1 232.7 04:1220;18:09:55 24 24 2.B 8.38 33.5 234.0 04:122006;18:10:25 30 28 2.7 0.42 34:8 235.3 04:12:2006:18:10:55 31 24 2.7 D.54 36.2 236,7 04:12:2006:18:11:25 49 33 2.T D.57 37.6 238.1 04:12:2006:18:11:55 1$ 15 2.7 0.58 98.4 239.5 04:12:2D06:18:t2:25 i6 5 2.7 0.28 40.3 240.8 04:122006:18:12:55 18 7 0.0 0.15 40.5 241.0 04:12:2006:18:13:26 13 4 0.0 0.16 40.5 241.0 04:12:2D06:1 8:13:56 I5 5 0.0 D.16 40.5 241.0 D4:122EY06:18:14:26 15 4 0.0 0.16 40.5 241.0 04:122006:18:14:56 15 1 O.D 0.17 40.5 241.0 D4:122008:18:15:28 ld 8 0.0 0.17 40.5 241.0 D4:122006:18:i5;56 3871 -3771 0.0 -8.25 04:12:2006:18:16:26 13 6 0.0 0.28 40,5 2410 04:12:2006:18:16;56 15 6 0.0 0.18 40.5 241.0 04a22006:18:17:26 1{ 6 0.0 0.18 40.5 241.0 04:12:2D06:18:17:49 Bump Top Plug 04:12:2006;18:17:49 12 3 0.0 D.17 {0.5 241.0 D4:12:2006:18:17:56 12 4 D.0 D,17 40.5 241.0 04:1220D6:18:16:26 10 5 0.0 0.17 40.5 241:0 D4:122D06:18:18:56 11 4 0.0 D_18 40.5 241,0 04:122006:18;19:13 Bleed Off Pressure 04:122006:18;19:13 23 18 D.0 D 17 40.5 241.0 04:12:2006:18:19;26 6 17 D,0 0.19 40.5 241.0 04:122006:18:19;56 87 108 0.0 0.18 40.5 241 0 04:122006:18:2D:26 1$ 8 D.0 D.18 40.5 . 241.0 04:12:2006:182D:56 i2 8 0.o D.18 40.5 241.0 Page 4 of 4 • • CASING AND LEAK-OFF FRACTURE TESTS Well Name: Endeavour #1 Date: 4/14/2006 Csg Size/V1/t/Grade: 9 5/8 40# N80 Supervisor: McDade Csg Setting Depth: 2457 TMD 2457 TVD Mud Weight: 9.1 ppg LOT= 18.02 ppg Fluid Pumped= Bbls Estimated Pump Output: LEAK-OFF DATA Enter Strokes Enter Pressure Here Here Leakoff pressure = 1140 psi Hole Depth = 2457 and Volume Back = bbls 0.058 Barrels/Stroke CASING TEST DATA Enter Strokes Enter Pressure Here Here 0 80 4 330 8 580 12 850 16 1150 20 1470 24 1790 28 2186 32 2609 34 2860 0 1140 1 1140 2 1135 3 1135 4 1135 5 1130 6 7 8 1130 1130 1130 9 1130 10 1130 Time Here Pressure Here tnter rtoiaing tnter Hoiaing Time Here Pressure Here ~ • -~-LEAK-OFF DATA -[3- CASING TEST DATA 4000 --------___.__._.. _____ _._______ _._.~._..~____,____.___ _.__._._.___._._____ ______________ 3900 3800 3700 3600 3500 3400 3300 3200 3100 3000 2900 2800 2700 2600 2500 2400 2300 2200 a 2100 v 2000 ~ N v 1900 a` 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 0 0 5 10 15 20 25 30 Time (Minutes) • • ~-LEAK-OFF DATA -~- CASING TEST DATA 4000 ..........................................•- ---.-...........-.-.................................................---•--••- 3900 3800 3700 3600 3500 3400 3300 3200 3100 3000 2900 2800 2700 2600 2500 2400 2300 2200 a 2100 w 2000 3 N v 1900 a` 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 , 0 0 10 20 30 40 Strokes (# o~ • ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~~ DATE: May 13, 2006 P.I. Supervisor 1 ~~~t~ ~ ~tV` ~~.'`` THRU: FROM: Lou Grimaldi Petroleum Inspector SUBJECT: Plug & Abandonement Endeavour#1 Aurora Gas Exploratory PTD 205-213 NON- CONFIDENTIAL Section: 3 Township: 5S Range: 15W Lease No.: Dale Griner, et : Drilling Rig: Kuukpik 5 Rig Elevation: Operator Rep.: Jack McDade Meridian: Seward Total Depth: CasinglTubin g Data: Casing Removal: Conductor: 13 3/8 O.D. Shoe@ Casing Cut@ Feet Surface: 9 518 O.D. Shoe@ 2457 Casing Cut@ Feet Intermediate: O.D. Shoe@ Casing Cut@ Feet Production: O.D. Shoe@ Casing Cut@ Feet Liner: O.D. Shoe@ Casing Cut@ Feet Tubing: O.D. Tail@ Casing Cut@ Feet Plugging Data: Type Plug Founded on Bottom Top of Cement Mud Weight Pressure (bottom up) of Cement Deoth Verified? above plug Test Applied Isolation Balanced Isolation Balanced Shoe Balanced 2560 est. 2268 DP to 9.3 1500 si Surface Retainer 200 Surf i Visual NA NA Type Plug Founded on: Verified? Open Hole Bottom Drillpipe tag Perforation Bridge plug Wireline tag Annulus Balanced C.T. Tag Casing Stub Retainer No Surface Surface cement down approx 10 feet. Dry-sacked to surface. ~ cc; Attachments: ~ ~~~~;~ i Distribution: orig -Well File c -Operator c - DNR/DOG c -Database c - Rpt File c -Inspector Rev.:S/28/00 by L.R.G. P&A Endeavour 1 05-13-06 LG.xls 5/15/2006 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Surface Abandonment /Location Clearance /Suspended Well ~~ ~~°1 5~ l`a ~~-' ( Title 20 AAC 25.170) , FILE INFORMATION: Operator: Aurora Gas, LLC Well Name: Endeavour #1 Address: 1400 W. Benson Blvd, suite 410, Anch. AK 99503 PTD No.: 205-213 API No. 50- 231-20030 Surtace Location (From Sec. Line): Unit or lease Name: Dale Griner, et al. Lease North/South 2268 FSL East/West 1834 FWL Field and Pool: Ex lorato Section: 3 Township: 5S Range: 15W Meridian: S Downhole P&A Date: 5/12/2006 20 AAC 25.120 -ABANDONMENT MARKER: Insp. Date: Surface Monument Approval Date: Post OD: (4" min) _" Length: _ ft. Set on (Wellhead, Csg , In Cmt) Height above final grade (4' min.): _ft. Casing stub_ft. below final grade Top of Marker Post Closed ? _ All openings closed ? Inspector: Insp. Date: 4/14/06 Subsurface Monument Approval Date: Marker Plate Diameter: 18 Distance below final grade Level: 6' Thickness: .5 Side Outlets removed or closed: Yes Marker Plate Attached To Conductor Y (Y/N) Cement to surtace (all strings)? Yes Ins ector: Lou Grimaldi Exact Information Beadwelded Directly to Marker Post or Blind Marker Plate: Insp. Date: 4/14/06 Approval Date: Aurora Gas LLC Endeavour#1 PTD-205-213 API 50-205-20030 Inspector: Lou Grimaldi Insp. Date: 20 AAC 25.170 -LOCATION CLEANUP: Approval Date: Pit's filled in? Liners Removed or Buried? Debris Removed: Notes: General condition of pad/location: (Rough, Smooth, Contoured, Flat, Natural ) Notes: Type of area surrounding location: (Wooded,Tundra,Grass,Brush,Dirt,Gravel,Sand) Debris on surrounding area: Notes: Access road present? Type road: (Dirt, Gravel, Ice, Other) Condition: Condition of road: Notes: Cellar filled in? Type of fill: Height above grade: Notes: Type work needed at this location: Ins ector: RECOMMENDED FOR APPROVAL OF ABANDONMEN Yes No (If "No" See Reason ) Distribution: orig -Well file c -Operator c -Database c -Inspector Sheet by L.G. 8/5/00 Reason: Final Inspection pertormed? Yes No Final Approval By: Title: Surface P&A Endeavour 1 05-1406 LG.xls DATE: 5/15/2006 • • ',~~~i Endeavor #1 (Aurora Gas LLC) Surface Abandonment Inspection Photos from Lou Grimaldi, AOGCC May 13, 2006 Run in OA w/ 1" pipe to tag TOC Dry sack cement OA for cement to surface Endeavor #1 Surface Aba~nment • May 13, 2006 Cement to surface in csg stub Marker Plate • ' ° ~ ~~~~3 {) iii' ~ ,3~ '"j~ ?~1~'~ r; yt~ ,'a ~~ ~~1i f~; ~ ,\ z AL~lSB-A oIL ~D G~5 Co~SEatvATaon coM1~IIS5ao1Q Edward Jones Vice President, Engineering and Operations Aurora Gas, LLC 1400 W. Benson Blvd, Suite 410 Anchorage, AK 99503 Re: Exploratory, Endeavour # 1 Sundry Number: 306-169 Dear Mr. Jones: i FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907} 276-7542 .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. DATED this ~~ day of May, 2006 Encl. ~~~- ~i3 Aurora Gas, LLC www.aurorapower.com May 10, 2006 Mr. John Norman, Chairman Alaska Oil and Gas Conservation Commission 333 West 7~` Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Application for Plug and Abandonment: Aurora Gas, LLC Endeavour # 1 Dear Mr. Norman: r;; Aurora Gas, LLC hereby applies for approval of its plans to plug and abandon its Endeavour # 1 exploratory well. The well did not find hydrocarbons in producible /~ quantities. Attached please find Form 10-403 Application for Sundry Approval and a plug and an abandonment procedure that conforms to the Commissions regulations pertaining to this ~ work. If you have any questions or require additional information, please contact me at (713) 977-5799 or Bill Penrose at 258-3446. Sincerely, AURORA GAS, LLC ward Jones President, l enclosures and Operations cc: Bill Penrose -Fairweather 10333 Richmond Avenue, Suite 710 • Houston, Texas 77042 • (713) 977-5799 • Fax (713) 977-1347 1400 West Benson Blvd., Suite 410 • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 ~yy ,Lid, STATE OF ALASKA G'Q ~'~~ J AL~ OIL AND GAS CONSERVATION COM ON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ~r~~ - F, 1. Type of Request: Abaraion ~ Suspend Operational shutdown Perforate Waiver Other Auer casirxt ^ Repair welt ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pult Tub~g ^ Perforate New Pool ^ Re-enter Suspended Wett ^ 2. Operator Name: 4. Current Wew Class: 5. Permit to Drill Number. Aurora Gas, LLC Devei©pment ^ Expkaratory Q 205-213 ~ 3. Address: Stratgraphic ^ Service ^ 6. AP! Number: 14dD W. Berrson Blvd, Suite 410, Anchorage, AK 99503 50-231-20030 ~ 7. KB Elevation (ft): 9. Wen Name and Number. 16' AGL Endeavour 9'1 ~ 8. Property Designation: 10. Field/Pools(s): Dale Griner, et at. Lease Exp~ratAry 11. PRESENT WELL CONDITION SUNBAARY Total Depth MID (ft): Total Depth TVD (ft): Effective. Depth MtD (ft}: Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9225` 9225' 9225 9225' None None Casing Length Size NtD TVD Burst Collapse Structural Corrductw 85' 13-3/8" 401' 101' t+UA NtA Surfak~ 2,44t' 9-518" 2,457' 2,45T 5,750 psi 3,094 psi Intermediate Production Liner Perforation Depth MD (ft}: Perfaation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MID (ft}: NtA / N!A N/A N/A N!A ~ Packers and SSSV Type: None Packers and SSSV MD (ft}: N/A 12 Attachments: Description Summary of Proposal ~ 13. Well Class aver proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory (] Development ^ Service ^ 14. Estimated Date for 15. Welt Status after Proposed work: Ctxnmencng Operations: Oil ^ Gas ^ Plugged ^ Abandoned ^~ 16. Verbal Approval: Date: 5f9/2006 WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Robert Crandall 17. I hereby t~rtify that the foregoing is true arxi correct to the best of my knowledge. Contact Bill' Penra~e 25&3446 .Printed Nam J. Jones Tile Vice President, En 'neerin and O Signature Phone 713-977-5799 Date ~ Q m V COABYNSSION USE. ONLY C s of approval: Notify Ctxnmissron so that a representative may witness Surxiry Number. Pkig lntegnty [~ BOP Test ^ Mleehanica! integrity Test ^ Location Clearance Lys Other. RBDMS BFI, ~~~ ~ ~ 2oos Subsequent Form Required: ~ O 7 , APPROVED t3Y Approved by: COMIMIISSlONER THE COMMISSION Date: ~ /~ i% V `~'/ ~-~-~' Form 10-403 Revised 07/2005 ~ ~ ~ 1 ttt Submit in Duplicate Endeavour # 1 Revised P&A Procedure Subject: Endeavour #1 Revised P&A Procedure /-, ~ ~ ~~i-~%~ From: Bill Penrose <bill@fairwEather.com> ` ~~~~~~ Date: ~V~d. 1O ~1av ?r)0613:51:28 -0800 "To: Jim Re~•~<jim ~c~;~~(cia~ii~iin.slale.ak.us== CC: jej~~nesra;aurorapotivcr.co~rz, Ri~~sife Atn~ora <~luror~l~wellsitc~d~~;yahoo.eoili= Jim, Per/our conversation earlier, attached is a revised P&A procedure in which: ~/ 1. I have provided cement volumes, and ;f2. I have removed the wait-on-cement time and verification tag on the middle of the three cement plugs. ~~,.-1~u.ll~i i Please let me know if you need anything else for approval of the plan. ~D~~v .- J' J~~~t s1 ~ a~~~: Thanks and regards, Bill Penrose Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 E. 88th Avenue,. Suite 200 Anchorage, Alaska 99507 907-258-3446 Content-Description: Procedure II.doc Procedure ILdoc Content-Type: application/msword Content-Encoding: base64 5/10/2006 4:04 PM 0 1 ;~ c~5 - a (~ • Plug and Abandonment Procedure Aurora Gas Endeavour #1 1. RIH with open-ended drill pipe and set a balanced Class G cement plug in the open hole from 6,670' to 6,460' in order to isolate the potentially gas-bearing zone from 6,565' to 6,567'. (21 bbls cement including 40% excess.) ,/~ 2. Pull OEDP up 3 stands above TOC and reverse out. WOC 12 hours. 3. RIH with OEDP, tag the cement plug and weight test with lOK lbs. ~ 4. POH to 6,000' and set a balanced Class G cement plug in the open hole from 6,000' to 5,300' in order to isolate the potentially gas-bearing zone from 5,400' to 5,893'. (69 bbls cement including 40% excess.) ,/ 5. Pull OEDP up 3 stands above TOC and reverse out. 6. POH to 4,910' and set a balanced Class G cement plug in the open hole from 4,910' to 4,400' in order to isolate the potentially gas-bearing zone from 4,500' to 4,810'. (50 bbls cement including 40% excess.) ~/' 7. Pull OEDP up 3 stands above TOC and reverse out. WOC 12 hours. ~' 8. RIH with OEDP, tag the cement plug and weight test with 1 OK lbs. :/ 9. POH and M/U a 9-5/8" cement retainer. 10. RIH and set the retainer in the 9-5/8" surface casing at 2,400', 57' above the shoe. ~ 11. Sting into the retainer and downsqueeze sufficient cement to fill the 57' of casing /,,,. below the retainer plus 100' of open hole. (14 bbls cement including 40% excess in the open hole.) 12. Unsting from the retainer and place 75' of cement (6 bbls cement) on top of it. J 13. Pull up 3 stands, reverse out and pressure test the cement/retainer to 1,500 psi for 10 /`lF minutes. POH, laying down all but 7 joints of drill pipe. 14. M/LJ a 9-5/8" bridge plug on drill pipe, RIH and set it at 200'. 15. Release from the bridge plug and displace cement into the wellbore from the bridge ~- plug to the surface. (14 bbls cement.) 16. Rig down and move out drilling rig. G S~"~~ ~C~S ~ai3 • 17. Cut off wellhead and all casing strings at least 5' below ground level. /'" 18. Weld a'/a" thick, 18" diameter round marker plate across the top of the 13-3/8" /y conductor. The marker plate should have the following information bead-welded onto it: Aurora Gas, LLC PTD No. 205-213 Endeavour #1 API # 50-231-20030 Note: Notify AOGCC so a rep can witness installation of marker plate. 19. Remove the cellar and bury the well marker with surrounding fill material up to the level of the surrounding pad. 20. Clean up the drilling location and finish the demobilization of all equipment and materials. Have AOGCC rep approve site close-out. a~S~2+.3 ~ ~ 1 Plug and Abandonment Procedure ~ Aurora Gas Endeavour #1 ~~~~ 1. R1H with open-en d drill pipe and set a balanced Class G cement plug in the open hole from 6,670' to 460' in order to isolate the potentially gas-bearing zone from 6,565' to 6,567'. 2. Pull OEDP up 3 stands a ve TOC and reverse out. WOC 12 hours. 3. RIH with OEDP, tag the cer~,ent plug and weight test with l OK lbs. 4. POH to 6,004' and set a balanc~l Class G cement plug in the open hole from 6,000' to 5,300' in order to isolate the entially gas-bearing zone from 5,400' to 5,893'. 5. Pull OEDP up 3 stands above TOC acid reverse out. WOC 12 hours. 6. Rll-1 with OEDF, tag the cement plug ar~l weight test with l OK lbs. 7. POH to 4,910' and set a balanced Class G ~ment plug in the open hole from 4,910' to 4,400' in order to isolate the potentially g -bearing zone from 4,500' to 4,810'. 8. Pull OEDP up 3 stands above TOC and reverse ut. WOC 12 hours. 9. RIH with OEDP, tag the cement plug and weight to with l OK lbs. 14. POH and M/U a 9-518" cement retainer. 11. RIH and set the retainer in the 9-5/8" surface casing at 2, 0', 57' above the shoe. 12. Sting into the retainer and downsqueeze sufficient cement to 11 the 57' of easing below the retainer plus 100' of open hole. 13. Unsting from the retainer and place 75' of cement on top of it. 14. Pull up 3 stands, reverse out and pressure test the cementlretaner to 1 00 psi for 10 minutes. POH, laying down all but 7 joints of drill pipe. 15. M/LT a 9-5/8" bridge plug on drill pipe, RIH and set it at 200'. 16. Release from the bridge plug and displace cement into the wellbore from the bl i plug to the surface. \ 17. Rig down and move out drilling rig. 205 -off l3 • • 18. Cut off wellhead a~l all casing strings at least 5' below ground level. 19. geld a'!a" thick, 18" 'ameter mend marker plate across the top of the 13-3f8" conductor. The marker late should have the following information bead-welded onto it: Aurora Gas, LLC PTD No. 205-213 Endeavour # 1 -~'I # 50-231-20030 Note: Notify AOGCC so a rep 20. Remove the cellar and bury the well level of the surrounding pad. witness installation of marker plate. with. surrounding fill material up to the 21. Clean up the drilling location and finish th~,demobilization of all equipment and materials. Have AOGCC rep approve site c se-out. ~t7S _~!~ Endeavor P&A Subject: Lt~d~~i~ or P&A ~,~~r, From: JallleS Rc~~~<jim_reggcradmin.state.~~l:.us> Date: Wed, lU ~tav ?UO6 16:58:12 -0800 ~ ~~- "['o: ~~'inton G Hubert<~~~~inton aubertiruadmin.state.ak.us% Received the P&A sundry from Bill Penrose and exchanged several calls with him this afternoon; here's the scoop - - Crandall approved plug locations verbally 5/9/06; noted on Sundry - checked cement calls; all ok ~ - we should witness test of plug at casing shoe (1500 psi; 10 min test) and casing cut/marker plate installation - I granted a waiver from 12hr WOC and tag for the middle open hole plug (5300-6000 ft) - gave them verbal approval to continue the P&A (they set 2nd plug this afternoon), so should be looking for AD approvals tomorrow. We have additional info for annular disposal; approach will be to pump drilling wastes through retainer instead of creating an annulus; this was the approach approved for Caribou 26-11 well drilled by Total. I have not reviewed CBL and ~ other info yet. Commissioner Foerster asked me to leave this with you to pretty up for signature. Call me on the cell (301-6470) if you have any questions. Jim 1 of 1 fps f~ 1.3 5/10/2006 5:00 PM Endeavor P&A • • Subject: Endea~.~or P~~~1 ~ r ~~~~~ From: James Regg jnn_regg~admin.stat~.ak.us> ~c~~~l Date: Wed, 10 May' ?046 16:8:1? -i)~00 To: ~~ inton G .Auberi ~~-Winton aubcrt(ciadnlin.state.ak.us> Received the P&A sundry from Bill Penrose and exchanged several calls with him this afternoon; here's the scoop - - Crandall approved plug locations verbally 5/9/06; noted on Sundry - checked cement calcs; all ok - we should witness test of plug at casing shoe (1500 psi; 10 min test) and casing cut/marker plate installation - I granted a waiver from 12hr WOC and tag for the middle open hole plug (5300-6000 ft) - gave them verbal approval to continue the P&A (they set 2nd plug this afternoon), so should be looking for AD approvals tomorrow. We have additional info for annular disposal; approach will be to pump drilling wastes through retainer instead of creating an annulus; this was the approach approved for Caribou 26-11 well drilled by Total. I have not reviewed CBL and other info yet. Commissioner Foerster asked me to leave this with you to pretty up for signature. Call me on the cell (301-6470) if you have any questions. Jim 1 of 1 5/11/2006 2:41 PM Re: Endeavor p&a 'y ~ • ~~ ~~~ ~ ~ Subject: Re: Endeavor p&a ~ ~ From: James Reg <jiin_regg@admin.stat~.ak.us> ~`~--'~~~~. Date: Tue, 09 May 200611:01:16 -0800 To: ~~'inton Hubert ~ =~~~~intotl auh~rl%~iadmin_stal~.ak.us~., CC: ~'atherinc P I~oers(et- ~~cath~~ t~~er~terr~'adiTiin.state.al:.us>. Dare Seam~,unt °~-~)an seamour~u~i`admin.statc.ak us:>, "~'randall, Soh" <bob crandalL~u;aclmin.stat~.ak.~as= I spoke with Jesse Mohrbacher (Fairweather) this morning about Endeavor #1 plugging and annular disposal: 1) reminded him that we need 10-403 for plugging ops; he said they are working on it (they have verbal approval to begin plugging well) 2) confirmed plug placement depths; Bob sent email to you summarizing revised plug placement 3) told him must have an annulus in the well for annular disposal - only option was to install pipe (drillpipe, tubing, casing) in well; requested following additional info to complete 10-403RD: infectivity test procedure, length of pipe that would be run in well and cemented; bond log and cementing records for 9-5/8"; shoe test and FIT (forgot to ask distance to Griner #1 at expected depth of receiving zone) Aurora is investigating alternatives to annular disposal. Ball is back in their court. Jim Winton Aubert wrote: ', Jim, ', (1) we need a 10-403 for plugging this well. We can work off verbal approvals ', (with E-mail) to avoid delays. (2) Please have Crandall verify the plug placement depths. See below. (3) The sundry for annular disposal is on my desk. (4) Leaving drill pipe in the well, thereby creating a 9-5/8" x DP annulus, may I allow annular injection. ', (5) If we allow annular injection, the length of drill pipe left must be determined based upon likely injection zone(s) depths. Crandall should have input. (6) I'll call you at the first break before I talk to Fairweather (unless someone else talks to them first). Thanks, and sorry to dump this on you, WGA -------- Original Message -------- Subject: Endeavor p&a Date: Mon, 08 May 2006 18:08:47 -0800 From: Jesse Mohrbacher <jesse~~fairweather.com> To: bob crandall~?admir:.state.ak.us CC: Bill Penrose <billcfairweather.ccm>, Ed Jones <je~one5~~aiz~°orauowe~-.c:;m>, Winton aubert~admin.state.ak.us Hi Bob, Attached are the mud log and a synthesis nulook log of the Endeavor well for your review. It is my understanding you already have the other logs on the well. i of 2 ~~ S _ 2 ~ 3 5/9/2006 11:01 AM Re: Endeavor p&a P ~ • ` j Aurora is ready to plug the Endeavor #1 well and requests verbal approval to plug the well. Proposed depths for setting cement plugs in the well are the following: Open Hole Plugs: ', 6670' to 6460' 6095' to 5890' 4910' to 4650' Plug across the surface casing shoe (2457'): !, by the displacement method, a continuous cement plug placed from 100 feet below to 100 feet above .the casing shoe; or by the downsqueeze method using a retainer set no less than 50 feet but no more ', than 100 feet above the casing shoe, a volume of cement sufficient to fill the wellbore from the retainer to 100 feet below the casing shoe to be pumped through the retainer, and cement must be pumped above the retainer to cap it with a 50 foot cement plug; Surface Plug: Surface to 155' BGL ', Aurora also proposes to dispose of approximately 1200 bbls of waste drilling ', fluids by annular injection approval from the Commission. This can be done immediately prior to setting the cement plug across the shoe by setting a retainer and pumping through the retainer followed by cementing through the j retainer as discussed above. Other options include pumping down the surface casing/drill pipe annulus or pumping down the drill pipe prior to setting a displacement type plug across the shoe. ', Please contact the undersigned at your earliest convenience to discuss the ', proposed abandonment program for the Endeavor #1 well. ', Regards, ', Jesse Mohrbacher Fairweather E&P Services, Inc. 12000 East 88th Ave., Suite 200 ', Anchorage, AK 99502 907-258-3446 907-343-0320 direct 907-244-4537 cell 1907-258-5557 fax 2 of 2 5/9/2006 11:01 AM C~~~ ~ 2A57- ~r2~ ~-~i _1 ~~ ~.--> ~`~`I ?,~' ~ Z~%~~~' .7 ~ ~ Cn~,,r,,.~' ~/ > ~ ~~-~ I S 7 ~ C~„~ -',"~~, ____ ,. _ ((~~ _ _ _ .. 6!~~ ~' yy~-~ tt W~~ _ ~~f'" ' ~ T2-~ IL~~ ___.____-- -_________.- [Fwd: ~ Endeavor p&a] .. Subject: [Fwd: Re: Endeavor p&a] From: Robert Crandall<bob_cra~dall~admin.state.~k.us> Date:. Tue, 09 May 2006 09: I ~: ~ ~ -OSOU To: "jiri~_r~e~~~'r'~r%ad«~in.statc.ak.us" ~ _jim_rc'~~~(~r?adri~in.state.akus=• -------- Original Message -------- Subject: Re: Endeavor p&a Date: Tue, 09 May 2006 08:52:58 -0800 From: Robert Crandall <bob crandallr~admin.state.ak.us> Organization: State of Alaska To: Jesse Mohrbacher <j_esse~fairweather.cor:3>, Winton G Aubert <W3..I1tOY1 aube.rt~~admin.sta.te.ak.us> CC: dan seamount <dan seamount:~admin.state,ak.us> References: <B05834F49940FE46A42L88668BD4D02,F9D69BBC~fwriail..fai.rweather_.lccal> Jesse: After reviewing the logs you've sent over, the following plugging program has been determined for the Endeavor No. 1 well 1) a continuous plug from 6670-6460' md. 2) isolation of the interval 6000-5300' and 3) isolation of the interval 4910-4400' and Let me know if you have any questions Regards BC Jesse Mohrbacher wrote: ', Jesse Mohrbacher ', Fairweather E&P Services, Inc. ', 2000 East 88th Ave., Suite 200 ', Anchorage, AK 99502 907-258-3446 907-343-0320 direct 907-258-5557 fax -----Original Message----- *From:* Jesse Mohrbacher *Sent:* Monday, May 08, 2006 6:09 PM *To:* 'bcb crandall:tiadmin.state.ak.us' *Cc:* Bill Penrose; Ed Jones; 'wir_ton aubert~~admir_.state.ak.us' *Subject:* Endeavor p&a Hi Bob, Attached are the mud log and a synthesis nulook log of the Endeavor well for your review. It is my understanding you already have the other logs on the well. Aurora is ready to plug the Endeavor #1 well and requests verbal approval to plug ', the well. Proposed depths for setting cement plugs in the well are the following: 1 of 2 5/9/2006 10:33 AM aG5"=r7 ~ [Fwd: Re: Endeavor p&a] E~ Open Hole Plugs: 6670' to 6460' 6095' to 5890' 4910' to 4650' Plug across the surface casing shoe (2457'): by the displacement method, a continuous cement plug placed from 100 feet below to 100 feet above the casing shoe; or by the downsqueeze method using a retainer set no less than 50 feet but no more than 100 feet above the casing shoe, a volume of cement sufficient to fill the wellbore from the retainer to 100 feet below the casing shoe to be pumped through the retainer, and cement must be pumped above the retainer to cap it with a 50 foot cement plug; Surface Plug: Surface to 155' BGL Aurora also proposes to dispose of approximately 1200 bbls of waste drilling fluids by annular injection approval from the Commission. This can be done immediately prior to setting the cement plug across the shoe by setting a retainer and pumping through the retainer followed by cementing through the retainer as discussed above. Other options include pumping down the surface casing/drill pipe annulus or pumping down the drill pipe prior to setting a displacement type plug across the shoe. Please contact the undersigned at your earliest convenience to discuss the proposed abandonment program for the Endeavor #1 well. Regards, Jesse Mohrbacher Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, AK 99502 907-258-3446 907-343-0320 direct 907-244-4537 cell 907-258-5557 fax 2 of 2 ~ (7J!°~~ (3 5/9/2006 10:33 AM Re: Endeavour #1 Logs • • Subject: Re: Endeavour #l Logs From: Robett Crandall <bob Grandall~t,~~irlin.statc.ak.us> Date: Mon. (18 Mav ~(1(1h 1?•(1(,•3i -n~j1n:) To: Winton ,lubcrt <~cinton ~iubcrn<<ailr»in.tatc.al:.us.> CC: ciail sc~unount'dan ;cane!uuiCrradmin.st.!tc.ak_u~-:~. Calh~ I' T~~,cr~[~r<c~dh~- foeCStet~aadmin ~talr,tkus-~ Winton; I reviewed the Aurora application for annular disposal in the Endeavor No. 1 well. As you know this is a twin for the UNOCAL Griner No. 1 well, these two vertical wells are 95 feet apart at the surface. We evaluated an annular disposal for that well also. The Griner well has unpotable salinities in the 1800-2500 TVD range, this was part of the evaluation that approved annular disposal for that well. Fairweather has sent over a copy of the open hole logs for the Endeavor well. The surface casing shoe in this well is ~ 2455 TVD and the first good sandstone below the shoe is present from 2692-2770 TVD. A clean section of the sand, with uniform log responses at the 2740-2750 TVD depth was used to calculate water salinity of 11,115 ppm. Fairweather supplied an analysis of an equivalent interval in the closely adjacent Griner No. 1 well that calculated a water salinity of 11,800 ppm. These two figures are in good agreement and demonstrate annular disposal in the Endeavor No. 1 well can be conducted in accord with AOGCC regulations. Let me know if you'd like to discuss. BC Winton Aubert wrote: Bob, Please review these. Penrose will call for annular disposal approval today or tomorrow. The sundry is on my desk. I am out all week. WGA -------- Original Message -------- Subject: Endeavour #1 Logs Date: Mon, 08 May 2006 08:14:51 -0700 (PDT) From: Rigsite Aurora aa:.,."~~.,..,,_;.:~-,•.~.te;<z-yahoo.;x;cn. To: Winton Aubert .wi...t:~.i a~_. a..rrla ,~tat.~..'ik.....~>, Bill Penrose obi. !~~:=az:~we.at:. .-~.c:onu Winton, Here's the log's from the Endeavour well for review. It look's like we will P&A the well. Jack McDade Drilling Supervisor Aurora Gas LLC 907-235-0581 Personal Cell-907-351-0865 a.roravreilsite'e=.: a^oo..^om ._..__._._..._..._._.__ ..................._......._.Y._...__..._._______-. -- ---- ------------------------------------ Yahoo! Messenger with Voice. t t~~ _(_~r' S 'Y.. ya 00. ~.~'ilima l_1_.__ i_Y 7C~.i l:: F`.:'+7p ~Gtmd. ?~ * t tp__j ~r S _rL ~d )O ._^.1m~ E?Vt: -.96r 6i ~r t1.p: ~~~'i1_ _.e:+?~~ _ ya :GO.CGm> PC-to-Phone calls for ridiculously low rates. 1 of 1 ~O5 ^~ ~ 5/8/2006 12:06 PM • ~Aur~ora Gas, LLC www.aurorapowercom May 5, 2006 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Aurora Gas, LLC: Endeavour #1 (PTD #205-213) Dear Mr. Norman: "! ^ '~ 9,. i skF~Si+.7 fib;. tom: .~ L ~, ;:. . ,~~'k This is a report of Aurora Gas, LLC's well operations on Endeavour #1 for the week of Apri128 through May 4, inclusive. Apri128, 2006 Dri118-1/2" hole from 8,006' to 8,333'. April 29, 2006 Drill 8-1/2" hole from 8,333' to 8,373'. CBU, POH and S/B BHA. Test BOPE. M/LJ new bit on mud motor and RIH. Apri130, 2006 Wash to bottom. Dri118-1/2" hole from 8,373' to 8,697'. Mav 1, 2006 Drill 8-1/2" hole from 8,697' to 8,805'. CBU, POH May 2, 2006 Finish POH, M/U new bit, RIH. Wash to bottom and drill 8-1/2" hole from 8,805' to 8,972'. May 3, 2006 Dri118-1/2" hole from 8,972' to 9,089'. Bit stopped drilling. CBU and POH. Mav 4, 2006 Finish POH. All cones missing from bit. M/U new bit and junk basket. RIH, wash slowly to bottom. Dri118-1/2" hole from 9,089' to 9,150'. 10333 Richmond Avenue, Suite 710 • Houston, Texas 77042 • (713) 977-5799 • Fax (713) 977-1347 1400 West Benson Blvd., Suite 410 • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 • • Mr. John Norman Page 2 If you have any questions or require additional information, please contact me at (907) 277-1003 or Bill Penrose at Fairweather at 258-3446. Sincerely, AURORA GA5, LLC dward Jones Vice President, Engineering and Operations cc: Bill Penrose -Fairweather r Aurora Gas, LLC www.aurorapower.com Apri128, 2006 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Aurora Gas, LLC: Endeavour #1 (PTD- 205-213) Dear Mr. Norman: ~~~~~~~a This is a report of Aurora Gas, LLC's well operations on Endeavour #1 for the week of Apri121 through Appil 27, inclusive. Apri121, 2006 Finish POH. Test BOPE. RIH w/ new bit, wash to bottom. Drill 8-1/2" hole from 7,021' to 7,107'. April 22, 2006 Drill 8-1/2" hole from 7,107' to 7,360'. Apri123, 2006 Dri118-1/2" hole from 7,360' to 7,449'. April 24, 2006 Drill from 7,449' to 7,470'. Bit stopped drilling. POH. M/LJ new bit and modify BHA. RIH. April 25, 2006 Continue RIH. Drill 8-1/2" hole from 7,470' to 7,705'. C&C hole for coring, POH. S/B drilling BHA. Apri126, 2006 P/U coring assembly and RIH. Take Core #1 from 7,705' to 7,735'. CBU & POH. Apri127, 2006 Finish POH. L/D core and load new inner barrel. L/D coring assembly. M/U drilling assembly and RIH. Ream core section and drill 8-1/2" hole from 7,735' to 8,006'. 10333 Richmond Avenue, Suite 710 • Houston, Texas 77042 • (713) 977-5799 • Fax (713) 977-1347 1400 West Benson Blvd., Suite 410 • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 Mr. John Norman Page 2 If you have any questions or require additional information, please contact me at (907) 277-1003 or Bill Penrose at Fairweather at 258-3446. Sincerely, AURORA GAS, LLC dward J nes Vice President, Engineering and Operations cc: Bill Penrose -Fairweather Re: Kuukpik BOP Test ~~ ~-- Zc~.S - 213 Subject: Re: KuukpikBOPTest From: James Reba, <jim re~g cr,admin.state.ak.us> Date: Fri, 28 Apr 2tti ~(, 09:21:1 ~ -0800 --~ q, ~ Z~? ~~~, To: Ri~,sitc ;lurora ° aurora~tit:llslttru`yahoo.conl=> ~~~~ ~ l C'C: Winton <r ~~uhert <w~inton aubert'ri%adn~in.state.ak.u~~= _ %~dmin AUGCC Prticlhoe F~av < -ao~~ccprudhocba~ ~a~adrn i n.state.ak.us== Your request for a BOPE test extension is approved, enabling you reach TD (9200 ft) or until your next trip -whichever occurs first. You expect to reach TD within 2 days based on the current drilling rate. As I mentioned in our phone conversation this morning, the 7 day BOPE test requirement establishes a window for testing (not necessarily an interval) and it is expected the operator will take advantage of opportunities within that 7 day window to test BOPE. In this particular case, you could have tested BOPE when you tripped to pick up the drilling assembly after coring on day 5. Jim Regg AOGCC Rigsite Aurora wrote: Mr. Regg, I have a BOP test due today and am currently drilling @ 8,169' with intent to drill to 9,200' or until the bit wears out without tripping. I am requesting permission to due this with a BOP test planned when I come out of the hole. I appreciate any consideration in this matter. Thanks, Jack McDade Drilling Supervisor Aurora Gas LLC 907-235-0581 Personal Cell-907-351-0865 aurora~uellsite~ yahoo.com Love cheap thrills? Enjoy PC-to-Phone calls to 30-+- countries for just 2¢/min with Yahoo! Messenger with Voice. 1 of 1 4/28/2006.9:21 AM Re: Aurora Gas Endeavour #1: Directior~unrey ~5--2f3 Subject: Re: Aurora Gas Endeavour #1: Directional Survey From: Winton Hubert <Winton_aubert@admin.state.ak.us> Date: Thu, 20 Apr 2006 16:10:11 -0800 To: Bill Penrose <bill@fairweather.com> CC: Admin AOGCC Prudhoe Bay <aogcc_prudhoe_bay@admin.state.ak.us> Bill, In accordance with 20 AAC 25.050 (h), AOGCC hereby waives the continuous directional survey requirement for welt Endeavour #1 (PTD 205-213). Directional surveys must continue to be obtained at intervals not to exceed 500 feet measured depth. All other permit stipulations apply. Winton Hubert AOGCC 793-1231 Bill Penrose wrote: Winton, This is to request a waiver to the AOGCC requirement that a continuous directional survey be run in the subject well. The Endeavour #1 was planned as a straight hole and has been maintained as one while drilling. The well is currently being actively drilled at a depth of 7,000' MD/TVD. As required, directional surveys have been obtained at intervals of 500 drilled feet or less from the surface. With a few minor excursions, immediately corrected, the wellbore inclination has remained less than three degrees from vertical. The nearest well to the Endeavour #1 is the plugged and abandoned Unocal Griner #1. The Griner well, drilled, plugged and abandoned in 2002, is located 95' away from the Endeavour well at the surface and was intended as a straight hole. However, the operator experienced early directional problems and the wellbore deviated sharply to the west (as indicated on the attached well pad layout), reaching a lateral distance of more than 200' from Endeavour's location by the time the Griner reached 600' TVD and continued to diverge from there to TD. (The Griner post-drilling directional survey is also attached for your reference.) 20 AAC 25.050(a)(3) requires that a wellbore drilled within 200' of another wellbore, vertical or deviated, must have a directional survey run in it. Given that the Griner well is within 200' of Endeavour only very close to the surface and that the Griner well has been permanently plugged and abandoned, Aurora Gas requests that it be relieved of the requirement to run apost-drilling continuous directional survey in the Endeavour #1. Please contact me at 258-3446 (office) or 250-3446 (cell) if you wish to discuss this or need additional information. Regards, Bill 1 of 1 4/20/2006 4:10 PM c s. tiAur~ora Gas, LLC www.aurorapower.com April 14, 2006 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Aurora Gas, LLC: Endeavour #1 (PTD-205-213) Dear Mr. Norman: J~ '~ ~ 4 T~ ~-'~ ~ d ~~~~ This is a report of Aurora Gas, LLC's well operations on Endeavour #1 for the week of Apri17 through April 13, inclusive. A_pri17, 2006 Finish rigging up on location. Install and test diverter. Mix mud, M/iJ drilling BHA, tag bottom at 102'. Drill 12-1/4" hole 102' to 137'. A_nri18, 2006 Drill 12-1/4" hole from 137' to 940'. Apri19, 2006 Drill 12-1/4" hole from 940' to 1,919'. April 10, 2006 Drill 12-1/4" hole from 1,919' to 2,263'. POH, inspect bit. April 11, 2006 RIH w/same bit. Drill 12-1/4" hole from 2,263' to 2,465'. Circulate and condition hole for casing. POH. April 12, 2006 Finish POH. L/D stabilizers, clear rig floor. R/U to run 9-5/8" casing. Run 9-5/8', 40#, N-80, LTC casing, tag fill at 2,449'. Wash down to 2,457' and C&C hole for cementing. Pump 5 bbl H2O, test surface lines to 2,000 psi. Pump 115 bbl 12.8 ppg lead cement followed by 82 bbl 15.8 ppg tail cement. Drop top plug, pump 5 bbl H2O and displace with 178 bbl mud. Bump plug w/ 1,400 psi. Check floats - OK. WOC. April 13, 2006 Finish WOC. N/D diverter, make rough cut on 13-3/8" conductor. Make final cuts on 9- 5/8" and 13-3/8" casing. Install wellhead and test to 2,400 psi. N/LT and test BOPE. 10333 Richmond Avenue, Suite 710 • Houston, Texas 77042 • (713) 977-5799 • Fax (713) 977-1347 1400 West Benson Blvd., Suite 4i0 • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 ~. • Mr. John Norman Page 2 • If you have any questions or require additional information, please contact me at (713) 977-5799 or Bill Penrose at Fairweather at 258-3446. Sincerely, AURORA GAS, LLC J. E and Jones ' e President, Enginee g and Operations cc: Bill Penrose -Fairweather Zo5-2c3 2" To Shaker -~ ~ ~ J 2 1/16" 11 N ~ /~ J 3" 3" Panic To Gasbuster " 3 1/8 ~~ t ~ ~ ~ J ~ u 2 1/16" ~ ~_ I , _- L 2 1/16 (~ '~ 2 1/16" ~ ~ _ ~ \ T ~_ ~ ~ 3 1 /8" 1 ~ / T- ,~ ~ i,. '~ ~ 2 1/16" '. , 2 1/16" Manual Choke ~ ~~ ~ Automatic Choke 2 1/16" Inlet Pressure Sensor 3" 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED = 3 1/18" 5,000 PSI VALVES AND LINES BLUE = 2 1/16" 5,000 PSI VALVES Kuukpik Drilling Rig Choke Manifold Drawn By: L Ross Date: 8/1 /04 1~1 Grp 8171 z~o~o • • Choke And Kill Lines and Valve on Kuukpik Rig 5 3" Mud Line from Mud Pumps to Rig Floor 2" 5,000 psi threaded valve .. 2" 5,000 psi flanged hose Kiil Line Side 2 1/16" 5,000 psi rated manual valve 2 1/16" 5,000 psi rated manual valve 0 Drilling Spool ,~ 3 1/18" 5,000 psi Manual Valve 3 1/18" 5,000 psi Hydraulic Operated Valve Choke Line Side 3" Flanged Choke Hose To Choke Manifold inlet Kuukpik Drilling Rig 5 Choke and Kill Line Layout July, 2003 Drawn By L Ross Kuukpik Drilling Rig 5 • Rig Floor Revised 2/3/06 • • Kuukpik Drilling Rig 5 Rig Floor Revised 2/3/06 ~ ~ • • Zds - Z-l 3 March 14, 2006 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7t" Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Aurora Gas, LLC: Endeavour #1 Dear Mr. Norman, This is a report of Aurora Gas, LLC's well operations on Endeavour #1 for the week of March 7 through March 13, inclusive. March 7, 2006 Finish rigging up on location. Install and test diverter. Mix mud, M/LJ drilling BHA, tag bottom at 102' . Drill 12-1 /4" hole 102' to 13 7' . March 8, 2006 Drill 12-1/4" hole from 137' to 940'. March 9, 2006 Drill 12-1/4" hole from 940' to 1,919'. March 10, 2006 Drill 12-1/4" hole from 1,919' to 2,263'. POH, inspect bit. March 11, 2006 RIH w/ same bit. Drill. 12-1/4" hole from 2,263' to 2,465'. Circulate and condition hole for casing. POH. March 12, 2006 Finish POH. L/D stabilizers, clear rig floor. R/U to run 9-5/8" casing. Run 9-5/8', 40#, N-80, LTC casing, tag fill at 2,449'. Wash down to 2,457' and C&C hole for cementing. Pump 5 bbl H2O, test surface lines to 2,000 psi. Pump 115 bbl 12.8 ppg lead cement followed by 82 bbl 15.8 ppg tail cement. Drop top plug, pump 5 bbl H2O and displace with 178 bbl mud. Bump plug w/ 1,400 psi. Check floats - OK. WOC. March 13, 2006 Finish WOC. N/D diverter, make rough cut on 13-3/8" conductor. Make final cuts on 9- 5/8" and 13-3/8" casing. Install wellhead and test to 2,400 psi. N/U and test BOPE. 1 `.~ • • Mr. John Norman Page 2 - If you have any questions or require additional information;"ple~se contact me at (713) _.._ 977-5799 or Bill Penrose at Fairweather at 258-3446. ~ _ _ Sincerely, __ AURORA GAS, LLC J. Edward Jones Vice President, Engineering and Operations cc: Bill Penrose -Fairweather "~ ~ ~ . ) ' r ? ` ' ~ '®° ~ ~ ~ ~ a ~'~ FRANK H. MURKOWSKI, GOVERNOR ~ ~~ olalo-78A OIL A1~TI) Vr0-7 ~~ 333 W. 7"' AVENUE, SUITE 100 COI~TSERQA'1`IO1~T COMl~'IISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 J Edward Jones Vice President, Engineering and Operations Aurora Gas, LLC 1400 W. Benson Blvd., Suite 410 Anchorage, AK 99503 Re: Exploratory Field, Endeavour # 1 Aurora Gas, LLC Permit No: 205-213 Surface Location: 2268' FSL, 1834' FWL, Sec. 3, T5S, R15W, SM Bottomhole Location: 2268' FSL, 1834' FWL, Sec. 3, TSS, R 15W, SM Dear Mr. Jones: 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 in 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 pooling agreement conforming with 20 AAC 25.055(c) must be filed with the Commission before regular production from the Endeavor # 1 well can begin. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 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 Aurora Gas, LLC permit # 205-213 representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED thisQ~ day of March, 2006 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. t , , • Au-~ora Gas, www.aurorapower.com Alaska Oil and Gas Conse;-vation Commission 333 W 7th Avenue, Suite No. 100 .Anchorage, Alaska 99501-3539 Attn: Mr. Bob Crandell Pet~~oleum Engineer Gentlemen: LLC January 5, 2006 ~ ~4~.-L73 RECEIVEd FED 2 3 tuc.~ Alaska Oi{ & Gas Cons. Ca~xnissian Anchorage RE: Application to Brill Endeavour Lease Well Kenai Peninsula Borough Cook Inlet, Alaska Aurora Gas, LLC (AU.RORA), as Operator of the proposed. oa.ptioned well, Submits, as per your request, the enclosed two (2) land plats in suppart o` an initial Application to Dri11 for the captioned lease well recently submitted by Fairweather in our behalf. Additionally, please find. enclosed in duplicate originals AOGCC Foetus 10-4 i 1 and 10-417 being the DESIGNATION OF OPERATOR and the NOTICE OF CH~:NGE. OF OWNERSHIP, respectively. If you require additional information regarding this Application, please contact lair. Ed Jones, Vice President, Engineering, at the number below or theundersigned. Your prompt attention to this platter is sincerely appreciated. Very Truly Yours, (Randall D. Jon~'s~CPL Massager, Land & Negotiations rj ones(~;aurorapower.com cc: E. Jones w/Enclosures AK-173 Lease File w/Enclosures aogcc endeavour desg of opera _ chg caf ownership 10333 Richmond Avenue, Suite 710 • Houston, Texas 77042 • (713) 977-5799 • Fax (713) 977-1347 1400 West Benson Blvd., Suite 410 • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 ~~ ~ STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMI~N DESIGNATION OF OPERATOR 20 AAC 25.020 1. Name and Address of Owner: AURORA GAS, LLC 10333 RICHMOND AVENUE, SUITE 710 HOUSTON, TEXAS 77042-4176 2. Notice is hereby given of a designation of operatorship for the oil and gas property described below: Legal description of property: Township 5 South, Range 15 West, Seward Meridian, U.S. Section 3, SW1/4NE1/4, SE1/4NW1/4, NW1/4SE1/4, NE1/4SW1/4 SAVE AND EXCEPT the NE1/4SE1/4NW1/4 and the SE1/4NW1/4SE1/4 and also being known as TRACT 2B OF THE GRINER SUBDIVISION TOO, PLAT NO. 86-31, AS RECORDED ON APRIL 29, 1986, DISTRICT. Being 134.00 Gross and Net Acres, more or less. AK-000000273 GRINER, DALE, ET AL. Original Lessee-Anadarko Current Lessee-AURORA GAS, LLC Petroleum Corporation Lease Date- 2/23/1998 Recorded Book 273/Page 784 Homer AK Recording District Property Plat Attached: 3. Name and Address of Designated Operator: AURORA GAS, LLC 10333 RICHMOND AVENUE, SUITE 710 HOUSTON, TEXAS 77042-4176 4. Effective Date of Designation: 31-Dec-02 5. Acceptance of operatorship for the above described property within all attendant responsibilities and obligations is hereby acknowledged: Signature C~L Date 1/2/2006 Printed Name RANDALL D. JONES. CPL Title MANAGER. LAND & NEGOTIATIONS 6. The Owner hereby certifies that the foregoing is true and correct: ~ Signature (,. / L Date 1/2!2006 Printed Name RANDALL D. JONES. CPL Title MANAGER. LAND & NEGOTIATIONS - 7. Approved: Commissioner Date Approved: Commissioner Date Approved: Commissioner Date (Requires approval by two Commissioners) Form 10-411 Rev.10/2003 Submit in duplicate ~.--- , s ; _~ i -- -_-- -~- ----'- ~ _ ' .5.3._~ _ i j ~ ~ / ~ ---- - .~ i 2S8•PERRY `w~i ~ ~~ ,\ ~. \ ' ~. \\ \ '. 1~ u f 4 ,zV~ ~ t ~LHAAKEN ON ~ !} 2G5 . R NAAKE^350K \~ i ' i ~ ;~ ,- _...-__-_-~ __-- - -_ _ i f z<e? -vnLSON z5o - a.HAaxEN N t 1 ~ 1 ~~%7 - =AaAOt~r 1 ~ ,i ' o ' ~~ ~ `.091 ,off- e ., I ~ ~ L- ~ +~ k~,.. 'FCZN ,S' ~~ _ ( q 'r i ~ ~~i/ BAILEY 1 BAIL B!CKLE`! -G7 JELA y' ; -- - \~ -.--... ____._ 28W1d AODERICK ~ F 'c.NN RQ ;BOILFTi, ~~1.. _./ ,.:~ (J 282 -CNSTOTT __ _. .-_ LQ ~ ~ ~ ~ \~ INCCHESN>:E' 2RAlST , CN16HT(NJ~. U. I~ ~ U~~ `\\ iZ 260-06 SNOORe r F R. 1~ ZIoD_ D(p vau,ow~ ?b Z~ - ~ ~ C'~ ) 2 'D ERICK 2~7A3 TN i19P50N ~~ [',, ~, 782- ATLEY &GIL 7 ZC~(.~ O3 (p(? 1` y ~ ~ !'' ~` `%h. `- ~--. C/+APMiAN '183h - 5r'.il~Y _. _. - _ -_ _.~.-„T-_~ i -a,tz5 I ~ 27d •GRINER n I I .' ~C _ ~ A _ ~ n ~. ~ ~7 ..-f_~~\~ . ~- GRINER 1 ~. \ j ~_ ._. ~ ~~, ~ 758 - SUBDiV{DED . +..., r~ . 9AlLEY ` I \ I 1 '' 2lIJ-GR ~lER ~ I 1 ~ ~7~ Is~~ `' l , ~ j ' '0"'HI , U i ~ i 25' -____.. .. _..__.- _ .___ .. __.__ _L_. _. _.. ..._ ._....__. __-_ _...~~__ _i._~ L _.. ._..________..___-___-__.__._._.-._. 0 77C^~ $Zi{l:i f~ ~:i ~~~~ ~, ~uf1 ..IV nSOt: j (.. I •. `} r• ~_ STAFE ' ...,p rJ~ _. _ ..' . __ ur '' STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMI~ION NOTICE OF CHANGE OF OWNERSHIP 20 AAC 25.022 1. Operator Name: AURORA GAS, LLC 2. Address: 10333 RICHMOND AVENUE, SUITE 710 HOUSTON, TEXAS 77042-4176 3. Notice is hereby given that the owner ~ , of record for the oil and gas property described below has assigned or transferred interest in the property indicated below: Legal description of property: Township 5 South, Range 15 West, Seward Meridian, U.S. Section 3, SW1/4NE1/4, SE1/4NW1/4, NW1/4SE1/4, NE1/4SW1/4 SAVE AND EXCEPT the NE1/4SE1/4NW1/4 and the SE1/4NW1/4SE1/4 and also being known as TRACT 26 OF THE GRINER SUBDIVISION TOO, PLAT NO. 86-31, AS RECORDED ON APRIL 29, 1986, DISTRICT. Being 134.00 Gross and Net Acres, more or less. AK-000000273 GRINER, DALE, ET AL. Original Lessee-Anadarko Current Lessee-AURORA GAS, LLC Petroleum Corporation Lease Date- 2/23/1998 Recorded Book 273/Page 784 Homer AK Recording District LESSOR: GRINER, DALE, ET AL. LESSEE: AURORA GAS, LLC Property plat attached ^~ 4. Effective date of assignment or transfer: 5. Percentage interest assigned or transferred: 31-Dec-02 100% 6. Assignee or Transferee: AURORA GAS, LLC Address: 10333 RICHMOND AVENUE, SUITE 710 HOUSTON, TEXAS 77042-4176 7. Assignor or Transferor: ANADARKO PETROLEUM CORPORATION Address: 1201 LAKE ROBBINS DRIVE THE WOODLANDS, TEXAS 77380 8. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ^Y ~G. Date: 3-Jan-06 Printed Name: RANDALL D. JONES, CPL Title: MANAGER, LAND & NEGOTIATIONS Form 10-417 Rev.10/2003 '! ~~ ' ' ;Hlescv ~ ~ . A ~ __. t ---_-_ ~--~- ------ -7 f I ~ 1 __~„+~_ _ _ _.._ __ _..__.__ __ ~ k ~~ t 25G-PERRY .~i ',`~ / j ~~~ ~~ \~ ~ 1 , I 7 , ~. ; , i i 2f t uT.H ~_. ,r !. _ . _ .. .._.. I AAKSAi Os: 2G5 - R F+AAKENSCP: ~ n I ' i \~ ` . ~; ~ _t`~ i ; ~ '' 7 25 C? i! f I 2d7 -`MIt.aDH 2>6. 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I ~~ ~c ,. .-~ -,,.. ..._..._..__.. _.. _._f ___-__~.._~_..__.__._ __.- _..__ -_. _..__ I { wr ~ ~ r I _ ~- / tea` i ~~ ~ ~ ; ~ ~ i -~~ s r~. ~I ~ 1 ~• ~ .. - _ ' t - i _.. ~ ,-,, i ~ .- ._- ~ ,~ .. 1 A ' ` 2'A3 - C+Ri{lER ~ I ~ .~ 2.:8 •SUSWV4GED ` it ~ f ~~~.~ ~-'"~~ ~} '~~ ~ I~ t f ~--~--•ZSi aPfiTH } ~ I fi, ~ i -.-_._..~.~.._~ .. ._ .. ,~ Z..l~`~I ~~ 2~f,..f~,~,Qf: I ~ __ ,. ,~ .~ s.-~ --.~._z 57'ATE ~____ J - -- - -- i !~~ --_ . i n ... -.....iiY i i • • Aurrora Gas, LLC ECEIVED www.aurorapower.com ~aN a ~ 2aos Alaska Oil and Gas Conservation Commission January 5, 20 ~ ~ 6se Cam, Comrr~tsan 333 W 7th Avenue, Suite No. 100 ~~~,~ Anchorage, Alaska 99501-3539 Attn: Mr. Bob Crandell Petroleum Engineer RE: Application to Drill Endeavour Lease Well Kenai Peninsula Borough Cook Inlet, Alaska Gentlemen: Aurora Gas, LLC (AURORA), as Operator of the proposed captioned well, submits, as per your request, the enclosed two (?) 1~nd plats in support of an initial Api~li;,ation to Drill for the captio$~ed lease well recently submitted by Fairweather in our behalf. Additionally, please find enclosed in duplicate originals AOGCC Forms 10-411 and 10-417 being the DESIGNATION OF OPERATOR and the NOTICE OF CHANGE OF OWNERSHIP, respectively. If you require additional information regarding this Application, please contact Mr. Ed Jones, Vice President, Engineering, at the number below or the undersigned. Your prompt attention to this matter is sincerely appreciated. cc: E. Jones wiE~closures AK-173 Lease File w/Enclosures aogcc endeavour desg of opera _chg of ownership Very Truly Yours, Randall D. Jon s, CPL Manager, Land & Negotiations rj ones@aurorapower. com 10333 Richmond Avenue, Suite 710 • Houston, Texas 77042 • (713) 977-5799 • Fax (713) 977-1347 1400 West Benson Blvd., Suite 410 • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 :Fd45C4 ~ ~ ~ ~ ' ~ _. 1 ~ 2.56-PERRY ,-. ~~`~ i j ~ ~ 7 ' f i_ 7, , '~ ' `\ `j l \\~ ; ~ ~~ / / 1 --_~ ~ 2Q T.HAAKtgN ON 1 'l, J 2y5 . 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I ..,- _. _ _. i ~~~~~~ racCHESME•$6 -i2 RAL>T q ~_._. ~~ NIGNTOIJ ~,. ~, 1' ~/ ~~ ~'~ _ ~ ~ /~ 2iip-Eti 4AOORE '1 ''r ~ ~ I' ~~ / d~ wJlr~m ,vv Z 2 O ERICK 26:7!?; TN~W1PSON ' a ~~ 1 ~ ., v BEY s Z 1 ~:22- . 3 y _. . . .. ,. ~' ,. _... -- ..__ - - --- - ~ _ _.-- --s:ft _ 1 -=~•iiSl I '; Z? ~ '?I , i L5 I 27A - GRINER c. ~ ~ ~ 1 ~C 1 7 ~ Z71o ~~/ '3~Q • , r. - - -- .».-.~, .- \ - 1 I ; Z S8 ,, I ~ 4{ ~ - ~, I , I ~ , '• ,' ~ _ k~`~ ~~~`1 2'!~3-Gh^.1{-1ER ~ I I ~ I ~~~ ~I ~, ~ ~ ~ 'S i ~ TH ~ 1 {~ _ _ _ ,~ /; ~~ v (u,,~, ~ ~ 2,.(d~ _-_ i -- 1 i - ~i ~ti \ ~ ~'. 1 `~ ----- 3~00(~~ ST~,E ~.-~..~-s~_.-~~_~ __ - - _ -- _,._ - __ yL~ 1 . _ _. r... _.__.~ R "~ Y 1 I • ~ STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMI~N DESIGNATION OF OPERATOR 20 AAC 25.020 1. Name and Address of Owner: AURORA GAS, LLC 10333 RICHMOND AVENUE, SUITE 710 HOUSTON, TEXAS 77042-4176 2. Notice is hereby given of a designation of operatorship for the oil and gas property described below: legal description of property: Township 5 South, Range 15 West, Seward Meridian, U.S. Section 3, SW1/4NE1/4, SE1/4NW1/4, NW1/4SE1/4, NE1/4SW1/4 SAVE AND EXCEPT the NE1/4SE1/4NW1/4 and the SE1/4NW1/4SE1/4 and also being known as TRACT 26 OF THE GRINER SUBDIVISION TOO, PLAT NO. 86-31, AS RECORDED ON APRIL 29, 1986, DISTRICT. Being 134.00 Gross and Net Acres, more or less. AK-000000273 GRINER, DALE, ET AL. Original Lessee-Anadarko Current Lessee-AURORA GAS, LLC Petroleum Corporation Lease Date- 2/23/1998 Recorded Book 273/Page 784 Homer AK Recording District Property Plat Attached: 3. Name and Address of Designated Operator: AURORA GAS, LLC 10333 RICHMOND AVENUE, SUITE 710 HOUSTON, TEXAS 77042-4176 4. Effective Date of Designation: 31-Dec-02 5. Acceptance of operatorship for the above described property within all attendant responsibilities and obligations is hereby acknowledged: Signature ~ ~?/ /~ Date 1/2/2006 Printed Name RANDALL D. JONES. CPL Title MANAGER. LAND & NEGOTIATI ONS 6. The Owner hereby certifies that the foregoing is true and correct: Signature C/~ Date 1/2!2006 Printed Name RANDALL D. JONES. CPL Title MANAGER. LAND & NEGOTIATI ONS 7. Approved: Commissioner Date Approved: Commissioner Date Approved: Commissioner Date (Requires approval by two Commissioners) Form 10-411 Rev.10/2003 Submit in duplicate :HilSli~. ~ I ! i t \ \~, .Q ~, `~ t .__-__ _ 26a-T.HAAKF.T! ON I'' ~. }~ I i I . __..~ ~ 2G=i ~ R HAAKE!35OK ~ l i -.I . 7 25 ~ ~ % ~ II 2A7 • WII.^aO1•I 250 • R.HAAHEfJ `N t ~ I ~ ~ 1 _ :cam ..._~ e < '~'~~i' t 1 '- -- - ~ a r L! ~, ,~ -ti' p o f `,. •, ,.. -- ., ~ ;' ..- . _ ---- BAILEY ~ BAILEY -' O~ /' ~~' ~ 1 ~~~ ~ . ~-, _-t_-~_._ 260-Ra ROnERICK 6fGKLE4 -G7 `3ELA yi'' ~ 5 ` ENH R irIOLLF-TY'r """' ~----- --.- 1 ~5 281•CNS?O77 - ZQ.`~ ~~ cvtcCNESMi~ 2 RALS7 ~J•~Q~ I' _ -_~ 22_60,e-W NIOCRr t ~ !` ~ l~l~" O ~p WIMOOY'3 ~e z~ - ~ L '. 'f ~ ~ ~o ERICK `'~ 2~; =_ 260-03 RiP5ON ~ I~ / 2E2- AALEY BOIL 1 ~,~~ 03 /.o-~1 {w~ ~ L~c>~ f~ ~ ~~~ ) C/tAPlaAN~ 2R'd - 6,llLcf ----- ~°.: '-I.iZS E -~,tz.5 '~ ?7.1 - GRINER _ ~ I . ~ ~~ - ~ ~ 7 ~. `~Y- f ~'~, //GRINER '- --1~ - \ ., ~- -. c .I Y.>8 • SU6UNIDEU ~ L(.~ (U ::?f. - 9AILEY /J 77C n~ ~+~ u - ,~ ~'t // II`` r ~ ~lfiC~ r .~ -'1 2u<.1 - ,lJ ~ SOtd ~ i I - i i .., -, _ ~ ' i ) 37R-GRi~lER ~ T t i I i ~~ i, i ,~53 i ~._ . SR~i7H ' -::. S71;AS'E _~-.~t~..__~ _ --- -- i . f' ~ ..~ i STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMI~ION NOTICE OF CHANGE OF OWNERSHIP 20 AAC 25.022 1. Operator Name: AURORA GAS, LLC 2. Address: 10333 RICHMOND AVENUE, SUITE 710 HOUSTON, TEXAS 77042-4176 3. Notice is hereby given that the owner ~ , of record for the oil and gas property described below has assigned or transferred interest in the property indicated below: Legal description of property: Township 5 South, Range 15 West, Seward Meridian, U.S. Section 3, SW1/4NE1/4, SE1/4NW1/4, NW1/4SE1/4, NE1/4SW1/4 SAVE AND EXCEPT the NE1/4SE1/4NW1/4 and the SE1/4NW1/4SE1/4 and also being known as TRACT 2B OF THE GRINER SUBDIVISION TOO, PLAT NO. 86-31, AS RECORDED ON APRIL 29, 1986, DISTRICT. Being 134.00 Gross and Net Acres, more or less. AK-000000273 GRINER, DALE, ET AL. Original Lessee-Anadarko Current Lessee-AURORA GAS, LLC Petroleum Corporation Lease Date- 2/23/1998 Recorded Book 273/Page 784 Homer AK Recording District LESSOR: GRINER, DALE, ET AL. LESSEE: AURORA GAS, LLC Property plat attached Q 4. Effective date of assignment or transfer: 5. Percentage interest assigned or transferred: 31-Dec-02 100% 6. Assignee or Transferee: AURORA GAS, LLC Address: 10333 RICHMOND AVENUE, SUITE 710 HOUSTON, TEXAS 77042-4176 7. Assignor or Transferor: ANADARKO PETROLEUM CORPORATION Address: 1201 LAKE ROBBINS DRIVE THE WOODLANDS, TEXAS 77380 8. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: G(XX (/~~ (j Date: 3-Jan-06 Printed Name: RANDALL D. JONES, CPL Title: MANAGER, LAND & NEGOTIATIONS Form 10-417 Rev.10/2003 ~ruasc~J ~ ` ~ r I s . ~ __-_ - _~ . _ __ __ -~- I 1 { ^ --- _ - E _-~ - - :~. i ~-1' 1Ci \ I 256-PeRRY ~ I i ~~ ~) J / 1 r ~i __--_-__.__._.....i 2fi-5 - T.IdAAKI-~! O^: rG_i - R.HAhricft5ON f i ~ ~ ~ /~ ~ j %`~... i ~ r Z~ ~ 25 ~ j y .::~ \ a .~ j ~ . _~ _.___.........._..~ I 7.50 - R IJAAKEfI `N j _ _.. ~ - -- . _.. - .u_.._ ~ .h / ` ~ nLr r Q al • i c" { Z n - Z ~ /, F .. ~~, ~ Q' rpm .~ ~~ T t _...._..____._____..__'-_.._-___... ._.. _.__ ~:.? ` ` l .: Tt ~ /1 'W U'+ ~ ~ OFF. />>> j;: ROCTOR I l.!' i ~ 9 BAILEY BASLF.'r / a - 260-6) kODERICK BSGKlrY Gr ~Jf La ~ '', LNH RQ SIOLLf~{ _~- -~-_~_.__~._ U 281 - CNSTOT'i _ .~'_4_ - - __._-___ . z°-~ ~ ~ ~ \- ntcCHE54ee (36 2P.AL S7 (~ ..\ f 250-0G p5O0RE 3 2 - O ERICK ' ~~~ :_._ 2nG-G3 TN 1e7PSON ' 282 - AALEY T. GIL i '1 'i 1 2 ~-~ r ~;kAPQiNi~ ; e:lin - s:.iLcY _ . _. ._ . - __..~-~~,_.r,.r4_,~ i _ r tZ5 27,3 - GRINER o- ~ ; .' ~[ I 7 I n ~:-4/ A `4 / Y ~ ! ~ I j ;~ '~ j ???lll / ~i ~~ ~~_ ~ ._ ._.. J- ~~ ! 1~ `^ ~': l ! i 21r3-GR~iJER ~~ ~ ~ I I ?:~. -SUaLri41GED ~ ` 1 i 4 ~ ` I ,3 ~- ~. ; ~ ~• ~rnTE I _.T_ ~d.~~_-v..J ._ . _ _- T ~ ~ I ' °J (r,. %`?G . 9AILEY U'~~N STATE OF ALASKA ~ NOTICE TO PUBLISHER ~ ADVERTISING ORDER NO. ADVERTISING ORDER INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE A O_02614023 /'1 SEE BOTTOM FOR INVOICE ADDRESS F R AOGCC 333 W 7th Ave, Ste 100 AGENCY CONTACT Jod Colombie DATE OF A.O. December 22 2005 ° M Anchorage, AK 99501 _ PHONE PcN DATES ADVERTISEMENT REQUIRED: o Anchorage Daily News PO box 149001 Arichora e AK 99514 g ~ December 26, 2005 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Advertisement to be published was e-mailed Type of Advertisement X Legal ^ Display Classif ied ^Other (Specify) SEE ATTACHED SEND INVOICE IN TRIPLICATE TO AOGCC, 333 W. 7th Ave., Suite 100 Anch~raee_ AK 995Q1 PAGE 1 OF 2PAGES TOTAL OF ALLPAGES~ REF TYPE NUMBER AMOUNT DATE COMMENTS 1 VEN z Axle 02910 3 4 FIN eMrlI1NT CV rr. Pf:M 1 !': e~rT FV NM R DIST LIB 1 OS 02140100 73451 2 3 4 `, 9 REQUISITIONED BY: ~ R ,~ a DIVISION APPROVAL: • f Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Application for Annular Disposal of Drilling Waste in well Endeavor #1 Aurora Gas, LLC by application dated December 8, 2005 has requested authoriza- tion to dispose of drilling waste through the annular space of the Endeavor #1 well in ac- cordance with 20 AAC 25.080. Drilling waste may not be disposed in an interval that contains freshwater unless the commission finds that the freshwater has a total dissolved solids content of more than 3,000 mg/1, and is not reasonably expected to supply a public water system. The surface location of the Endeavor #1 well is 2268' from the south line and 1834' from the west line, Section 3, TSS, R15W, Seward Meridian. The proposed inter- val for disposal of drilling wastes is at approximately 2500' total vertical depth. Calcu- lated salinity values from log measurements taken while drilling nearby conservatively indicate a salinity in excess of 6500 parts per million at the surface casing shoe. A person may submit written comments regarding this request no later than 4:30 pm on January 27, 2006 to the Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. In addition, the Commission has tentatively set a public hearing on February 7, 2006 at 9:00 am at the Alaska Oil and Gas Conservation Commis- sion at 333 West 7t Avenue, Suite 100, Anchorage Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Com- mission prior to January 11, 2006. If a request for a hearing is not timely filed, the Commission will consider the is- suance of an order without a hearing. To learn if the Commission will hold the public hearing, please ca11793-1221. If you are a person with a disabili w o may need a special modification in order to comment or to attend the/~~blic he ing please contact Jody Colombie at 793-1221 before January 30, 2006.i~ ! 1. i Norman AO 02614023 Published 12/26/05 Anchorage Daily News. Affidavit of Publication 1001 Northway Drive, Anchorage, AK 99508 12/28/2005.:. PRICE OTHER OTHER OTHER OTHER THER GRAND AD # DATE 1~ ACCOUNT PER DAY C1lARGES CHARGES #2 C1iARGES #3 CHARGES #4 ~IARGES #5 TOTAL 688815 12/26/2005 STOF0330 $162.74 $162.74 $0.00 $0.00 $0.00 $0.00 $0.00 $162.74 Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission STATE OF ALASKA THIRD JUDICIAL DISTRICT Christine Clark, being first duly swonl on oath deposes and says that she is an advertising representative of the Anchorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all said time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on the above dates and that such newspaper was regularly distributed to its subscribers during all of said period. That the full amount of the fee charged far the foregoing publication is not in excess of the rate charged private individualsr~ -7 ~~ ~ ~ ~~ ~ ~ ~' Subscribed and sworn to me before this date: ~8 ~e-c~ ,~c~ 5 Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska MY COMMISSION EXPIRES: o~-~~ ~~~ ```lt~ (H((5~~~~i/i ~- . C v~ : N~AUf3L1 ~ r' ~ c or ALPS . ~~ iJ?lss • .. • ~'~ ~~ J/J/Yir; ~~:rlif2s~ ~~ l'/stilt))} Re:Application for Annular Disposal of Drilling Waste in well Endeavor Nl Aurora Gas, LLC by application dated De- cember 8, 2005 has re- quested authorization to dispose of drilling waste through the annular space of The Endeavor #1 well in accordance with 20 AAC 25.080. Drilling waste may not be disposed in an inter- valThaT contains fresh- water unless The commis- sion finds that the freshwater has a total dissolved solids content of more than 3,000 mg/I, and is not reasonabiv ex- pected To supply a public water system. The surface location of the Endeavor 1T1 well is 2260' from the south line and 1834' from the west line, Section 3, TSS, R15W, Seward Meridian. The proposed interval for disposal of drilling wastes is oT approximateiv 2500' Total vertical depth. Cal- culated salinity values from log measurements taken while drilling nearby conservatively In- dicate asalinity in ex- cess of 6500 parts per mil- lion at the surface casing shoe. A person may submit written comments re- garding this request no later than 4:30 pm on January 27, 2006 to the Conservation Commis- sion of 333 WesT 7Th Av- enue, Suite 100, Anchor- age, Alaska 99501. In addition, The Commission has tentatively set apub- IIc hearing on February 7, 2006 at 9;00 am at the Alaska Oil and Gas Con- servation Commission at 333 West 7th Avenue, Suite 100, Anchorage' Alaska 99501. A persoh may requesfihaT The ten- latively scheduled hear- ing be held by filing a written request with the commission prior To January 11, 2006. If a request for ahear- ng is not Timely filed, the commission will con- >ider the Issuance of an order without a hearing. fo learn if the Commis- oion will hold the public searing, please call '93-1221. If you ore a person with ~ disability who may seed a special modifica- ion in order to comment it To attend The public searing, please contact iodv Colombie aT 793-1221 Before January 30, 2006. John K. Norman Chairman AO 02614023 'ub: Dec. 26, 2005 Anchorage Daily News Affidavit of Publication 1001 Northway Drive, Anchorage, AK 99508 . i2/28/20Q5 PRICE OTHER OTHER OTHER OTHER OTHER GRAND AD # DATE I'O ACCOUNT PER DAY CHARGES CHARGES #2 CHAAGES~ CHARGES #4 CHARGES #5 TOTAL 688815 12/26/2005 STOF0330 $162.74 $162.74 $0.00 $0.00 $0.00 $0.00 $0.00 $162.74 Notice of Public Hearin! STATE OF ALASKA Alaska Oil and Gas Conservation Commissio Re:Application for Annular Disposal of Drilling Waste in well Endeavor #1 STATE OF ALASKA THIRD JUDICIAL DISTRICT Christine Clark, being first duly sworn on oath deposes and says that she is an advertising representative of the Anchorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all said time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on the above dates and that such newspaper was regularly distributed to its subscribers during all of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individuals.,.) '. '' l /~~ ' Subscribed and sworn to me before this date: Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska MY COMMISSION EXPIRES: ~D ~_ 02~ ~p ~. `~~~`y 1Hr SH/~~~'~ `~m.•~,oTARy?~ ~ ... • .`_. .--, . PuBLiG ~ 1 ~JlfJlron/~/1 I',~' i i~a~~~. Aurora Gas, LLC b application dated De cember 8, 2005 has re quested authorization t dispose of drilling wash Through The annuaa space of the Endeavor fl well in accordance will 20 AAC 25.080. Drilling waste may no be disposed in an inter val That contains fresh water unless the commis sion finds that Thi freshwater has a tofu dissolved solids content o more than 3,000 mg/I, ant is not reasonably ex petted to supply a public water system. The surface location of the Endeavor ftl well i! 2266' from the south line and 1034' from the wesl line, Section 3, TSS, R15W, Seward Meridian. The proposed inlervaifor disposal of drilling wastes is aT approximately 2500' total vertical depth. Cal- culated salinity values from log measurements taken while drilling nearby conservatively in- dicate a salinity in ex- cess of 6500 parts Per mil- lion at the surface casing shoe. A person may submit written comments re- garding this request no later than 4:30 pm on January 27, 2006 to the Conservation Commis- sion at 333 West 7th Av- enue, Suite 100, Anchor- age, Alaska 99501. In addition, the Commission has tentatively seta pub- lic hearing on February 7, 2006 at 9:00 am at the Alaska Oil and Gas Con- servation Commission at 333 WesT 7th: Avenue, Suite 100, Anchorage Alaska 9950E A person mavrequest that The ten-' tat{vely scheduled hear- ing be held by filing a written request with the Commission prior To January il, 2006. If a request for o hear- ing is not timely filed, the Commission wilt con- sider the issuance of an order without a hearing. To learn if the Commis- sion will hold the public hearing, please call 793-1221. If you are a person with a disability who may need a special modifica- tion in order to comment or to attend the Public hearing, please contact Jody Colombie at 793-1221 before January 30, 2006. John K. Norman Chairman AO 02614023 Pub: Dec. 26, 2005 Re: Public Notice • Subject: Re: Public Notice From: "Ads, Legal" <legalads@adn.com> Date:. Thu, 22 Dec 2005 15:30:12 -0900 To: Jody Colombie <Jody_colombe@admin.state.ak.us> Hello, Following is the confirmation information on your legal notice. Please review and let me know if you have any questions or need additional information. Account Number: STOF0330 Legal Ad Number: 688815 Publication Date(s): Your Reference or PO#: 02614023 Cost of Legal Notice: $162.74 Additional Charges: Web Link: E-Mail Link: Bolding: Total Cost To Place Legal Notice:$162.74 Your Legal Notice Will Appear On The Web: www.adn.com:xxx Your Legal Notice Will Not Appear On The Web www.adn.com:xxx Thank You and Happy Holidays, Christine Clark Anchorage Daily News Legal Classified Representative E-Mail: legalads@adn.com Phone: (907) 257-4296 Fax: (907) 279-8170 On 12/22/05 2:14 PM, "Jody Colombie" <jody colombie@admin.state.ak.us> wrote: 1 of 1 12/22/2005 3:45 PM 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM STATE OF ALASKA NOTICE TO PUBLISHER ADVERTISING ORDER NO. ADVERTISING INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED COPY OF /~ 0-02614023 /`1 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED ORDER ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE SEE BOTTOM FOR INVOICE ADDRESS F AOGCC AGENCY CONTACT DATE OF A.O. R 333 West 7th Avenue Suite 100 O . AnrhnrarrP AK A95(11 PHONE PCN M 907-793-1221 - DATES ADVERTISEMENT REQUIRED: o Anchorage Daily News December 26, 2005 PO box 149001 Arichora e AK 99514 g THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN ~ . SPECIAL INSTRUCTIONS: Account # STOF0330 AFFIDAVIT OF PUBLICATION United states of America RE M I N D E R State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. division. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. Before me, the undersigned, a notary public this day personally appeared ATTACH PROOF OF PUBLICATION HERE. who, being first duly sworn, according to law, says that he/she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2005, and thereafter for consecutive days, the last publication appearing on the day of , 2005, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This _ day of 2005, Notary public for state of My commission expires Citgo Petroleum Corporation Mary Jones David McCaleb PO Box 3758 XTO Energy, Inc. IHS Energy Group Tulsa, OK 74136 Cartography GEPS 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 Ft. Worth, TX 76102-6298 Houston, TX 77056 Mona Dickens Robert Gravely George Vaught, Jr. Tesoro Refining and Marketing Co. 7681 South Kit Carson Drive PO Box 13557 Supply & Distribution Littleton, CO 80122 Denver, CO 80201-3557 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Richard Neahring John Levorsen Hodgden Oil Company NRG Associates 200 North 3rd Street, #1202 408 18th Street President Boise, ID 83702 Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Kay Munger Samuel Van Vactor Michael Parks Munger Oil Information Service, Inc Economic Insight Inc. Marple's Business Newsletter PO Box 45738 3004 SW First Ave. 117 West Mercer St, Ste 200 Los Angeles, CA 90045-0738 Portland, OR 97201 Seattle, WA 98119-3960 Mark Wedman Schlumberger Baker Oil Tools Halliburton Drilling and Measurements 4730 Business Park Blvd., #44 6900 Arctic Blvd. 2525 Gambell Street #400 Anchorage, AK 99503 Anchorage, AK 99502 Anchorage, AK 99503 Ciri Ivan Gillian Jill Schneider Land Department 9649 Musket Bell Cr.#5 US Geological Survey PO Box 93330 Anchorage, AK 99507 4200 University Dr. Anchorage, AK 99503 Anchorage, AK 99508 Gordon Severson Jack Hakkila Darwin Waldsmith 3201 Westmar Cr. PO Box 190083 PO Box 39309 Anchorage, AK 99508-4336 Anchorage, AK 99519 Ninilchick, AK 99639 James Gibbs Kenai National Wildlife Refuge Penny Vadla PO Box 1597 Refuge Manager 399 West Riverview Avenue Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-7714 Soldotna, AK 99669-2139 Richard Wagner Cliff Burglin Bernie Karl PO Box 60868 PO Box 70131 K&K Recycling Inc. Fairbanks, AK 99706 Fairbanks, AK 99707 PO Box 58055 Fairbanks, AK 99711 Williams Thomas North Slope Borough Arctic Slope Regional Corporation PO Box 69 Land Department Barrow, AK 99723 PO Box 129 Barrow, AK 99723 Public Notice Subject: Public Notice From: Jody Colombie <jody_colombie@adminatate.ak.us> Date: Thu, 22 Dec 2005 14:15:27 -0900 To: Cynthia B Mciver <bren mciver@admin.state.ak.us> _._ Content-Type: application/msword Notice Endeavor.doc Content-Encoding: base64 1 of 1 12/22/2005 2:15 PM Public Notice Endeavor # 1 Subject:. Public Notice Endeavor.#1 From: Jody Colombie <Jody_colombie@admin.state.ak.us> Date: Thu, 22 Dec 2005 14:14:54 -0900 To: undisclosed-recipients:; BCC: Robert E Mintz <robert_mintz@law.state.ak.us>, Christine Hansen <c.hansen@iogcc.state.ok.us>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, Scott & Cammy Taylor <staylor@alaska.net>, stanekj <stanekj@unocaLcom>, ecolaw <ecolaw@trustees.org>, trmjrl <trmjrl@aol.com>, jbriddle <jbriddle@marathonoil.com>, shaneg <shaneg@evergreengas.com>, jdarlington <jdarlington@forestoil.com>, nelson <knelson@petroleumnews.com>, cboddy <cboddy@usibelli.com>, Mark Dalton <mark.dalton@drinc.com>, Shannon Donnelly <shamion.donnelly@conocophillips.com>, "Mark P. Worcester" <mark.p.worcester@conocophillips.com>, Bob <bob@inletkeeper.org>, wdv <wdv@dnr.state.ak.us>, tjr <tjr@dnr.state.ak.us>, bbritch <bbritch@alaska.net>, mjnelson <mjnelson@purvingertz.com>, Charles O'Donnell <charles.o'domlell@veco.com>, "Randy L. Skillern" <Ski11eRL@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Steven R. Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>, Dan Bross <kuacnews@kuac.org>, Gordon Pospisil <PospisG@BP.com>, "Francis S. Sommer" <SommerFS@BP.com>, Mikel Schultz <Mikel.Schultz@BP.com>, "Nick W. Glover" <GloverNW@BP.com>, "Daryl J. Kleppin" <KleppiDE@BP.com>, "Janet D. Platt" <PlattJD@BP.com>, "Rosanne M. Jacobsen" <JacobsRM@BP.com>, ddonkel <ddonkel@cfl.rr.com>, mckay <mckay@gci.net>, Barbara F Fullmer <barbara.£fullmer@conocophillips.com>, bocastwf <bocastwf@bp.com>, Charles Barker <barker@usgs.gov>, doug_schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank.alford@exxomnobil.com>, Mark Kovac <yesno 1 @gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady a shelLcom>, Fred Steece <fred.steec@state.sd.us>, rcrotty <rcrotty@ch2m.com>, jejones <jejones@aurorapower.com>, dapa <dapa@alaska.net>, jroderick <jroderick@gci.net>, eyancy <eyancy@seal-tite.net>, "James M. Ruud" <james.m.ruud@conocophillips.com>, Brit Lively <mapalaska@ak.net>, jah <jah@dnr.state.ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, loren_leman <loren_leman@gov.state.ak.us>, Julie Houle <julie_houle@dnr.state.ak.us>, John W Katz <jwkatz@sso.org>, Suzan J Hill <suzan_hill@dec.state.ak.us>, tablerk <tablerk@unocaLcom>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@borough.kenai.ak.us>, Jim White <jimwhite@satx.n•.com>, "John S. Haworth" <john.s.haworth@exxonmobiLcom>, marty <marty@rkindustrial.com>, ghammons <ghammons@ol.com>, unclean <rmclean@pobox.alaska.ne~,, rnkm7200 <mkm7200@aol.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens <db~elens@aurorapower.com>, Todd Durkee <TDURKEE@KMG.com>, Gary Schultz <gary_schultz@dnr.state.ak.us>, Wayne Rancier <RANCIER@petro-canada.ca>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoil.com>, Garry Catron <eatrongr@bp.com>, Sharmaine Copeland <copelasv@bp.com>, Kristin Dirks <kristin dirks@dnr.state.ak.us>, Kaynell Zeman <kjzeman@marathonoil.com>, John Tower <John.Tower@eia.doe.gov>, Bill Fowler <Bill_Fowler@anadarko.COM>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mekimbs@BP.com>, Steve Lambe <lambes@unocaLcom>, jack newell <jack.newell@acsalaska.net>, James Scherr <james.scherr@mms.gov>, david roby <David.Roby@mms.gov>, Tim Lawlor <Tim_Lawlor@ak.blm.gov>, Lynnda Kahn <Lynnda_Kahn@fws.gov>, Jerry Dethlefs <Jerry.C.Dethlefs@conocophillips.com>, Crockett@aoga.org, Tamera Sheffield <sheffield@aoga.org>, Jon Goltz <Jon.Goltz@conocophillips.com>, Roger Belman <roger.belman@conocophillips.com>, Mindy Lewis <mlewis@brenalaw.com>, Kari Moriarty <moriarty@aoga.org>, Patty Alfaro <palfaro@yahoo.com>, Jeff <smetankaj@unocaLcom>, Todd Kratz <ToddKratz@chevron.com?, Gary 1 of 2 12/22/2005 2:15 PM Public Notice Endeavor #1 Rogers <gary_rogers@revenue.state.ak.us>, Arthur Copoulos <Arthur_Copoulos@dnr.state.ak.us>, Ken <ken@secorp-inc.com>, Steve Lambert <salambert@unocal.com>, 7oe Nicks mews@adiokenai.com> Je McCutcheon <susitnah dronow ahoo.com> Paul Todd < aulto acsalaska.net>, Bill Walker p @ ~' Y @Y <bill-wwa@ak.net>, Iris Matthews <Iris_Matthews@legis.state.ak.us>, Paul Decker <paul_decker@dnr.state.ak.us> Content-Type: application/pdf Notice Endeavor.Pdf Content-Encoding: base64 2 of 2 12/22/2005 2:15 PM Public Notice . Subject: Public Notice From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Thu, 22 Dec 2005 14:14:07 -0900 To: Legal Ads Anchorage Daily News.<legalads@adn.com> __ Content-Type: application/msword Ad Order form.doc Content-Encoding: base64 Content-Type: application/msword Notice Endeavor.doc Content-Encoding: base64 1 of 1 12/22/2005 2:15 PM Aurora Gas. - Endeavour # 1 ~ • Subject: Aurora Geis - Endear uur #1 From: Bill P~rlrose <bill c~fair~~;eather.conl Date: Wed, l-~ l)cc ~Ol~~ 1 ~:-~>:19 -0900 ~'o: Robert C'ranciall "hobcrand~ill~ua~imin.statc.ah.u~> CC: jejones c~aurorapt~~~~~r.com Bob, You asked me last week via telephone to provide you with a discussion of the research that we conducted on offsetting wells when planning the Endeavour #1 well. We used three offsets: the Unocal Griner #1, the Pennzoil Starichkof State Unit #1 and the Pennzoil Starichkof State #1. We also took a brief look at the geology in the Standard Oil Anchor Point #1, but didn't place much weight on it as it lies across a major fault from the others. The Griner well provided the best information in that it is located in virtually the same place (95' away) as the Endeavour well and it was drilled just three years ago, so modern drilling techniques and equipment were used. Of course, the pore pressures in Endeavour will be identical to those in the Griner well as deep as the Griner well went. Griner .did not penetrate the Hemlock Fm as Endeavour will. This is why we used the Pennzoil Starichkof wells also. Those wells penetrated the Hemlock, so we constructed mud weight curves from top to bottom and matched them and the formation tops as best we could with the Griner well. The match wasn't bad at all. The good news is that there are no abnormally pressured intervals indicated. The bad news is that there were no leakoff tests run in any of these wells so we're left unsure of the local frac gradient(two shallow formation integrity tests conducted in the Griner well yielded formation strength values that were so anomalously high we discounted them). The casing program in Endeavour is therefore conservative compared to the other wells, with the surface casing set at 2,500' in order to handle any unexpected pressures encountered below the Griner well's TD. If you would like me to send copies of the casing design sheets to you, please advise. I won't attach the well files for the offset wells because we downloaded them from the Commission's own website. However, I've attached what we call geomechanical observation plots constructed for the three offsets and for the proposed Endeavour well. These types of plots usually contain more information than these do, with things like hole problems by interval and frac gradients, but these wells were poorly documented by the operators and such information is unavailable. Our research on the offsetting wells leaves us confident of the lithology and pore pressures we will be encountering. We have quite a bit of experience in drilling Cook Inlet geology from the surface through the Hemlock interval and are confident that we can.handle the local and regional hole problems typically encountered. Please let me know if you have any specific questions not addressed in the general discussion offered above. Regards, Bill Content-Description,: Endeavour #1 Geomech P1ots.PDF .:Endeavour #1 Geomech Plots.PDF Content-Type: application octet-stream Content-Encoding: base64 1 of 2 12/16/2005 8:54 AM ,~ ~ ~.: ~~~~ r~' ~ ~~~~, ~ ~~ ~ ~ r ~,.. ". 0 ~ ,aoo ~~2~ ~,y 2, 000 I 3,000 ,-. ..., s ~. 4,000 n ~a v > s,ooo 6,000 7,000 8,000 9.000 f O Starichkof State Unit #'! Geo-mechanical Observations I ~ _~" I I ~ .. ~ _ t F ~ 1...__ ._ ~_ ~ ~ ~__~~. 1 ~ _.. _... I~ ~---1- -~ ~ ~ ~ I __~ ~I ~ _ . h I ~.~..n, l~ ~ I ~ _, ~.._ ,~. .- . ' Griner#'l ~ ~o-me chanical Observa#ic~ra o ~~ 9.518" ..1,000 _~_fi. ~~ t ! ,~. ~ ;, i ~ ~a ~, ~~ f ~ 2 000 R; 7.. ~ - i ~- , ~ ~ ~~ ~~ ,~ ~ ~ i a,ooa ~; . x~ ~~ ~ ~ . ~ . L ~ I ~ D ~ ( ~ ~ 4,000 ~:,.~ _._~. .~ . _ . J ~ . i t ' ~ ____ '~ ~ ~ ~ i ~ ' Ai :~' j . ~ ~~ ~J,000 I ~ ~ - ,~, > 1 ' ~~.. ~~,.._._ ~.a. ~, .~ A~, __ ___ { - ~ ~ -- i ~ f ~ it , ~ ~ ~ I 6 000 ,..._ M__ .... ~ _. .. ~, ,., ., ,:. __ m: . ~ _ ~ ~ ~ 3 ` , , U I ,000 ': i f3- ~ i i 8,000.. 8 10 12 14 1 8 18 Mud Wt. pP9 ~' ~Aurrora Gas, LLC www.aurorapower.com December 8, 2005 Mr. John Norman, Chairman ~ .:~ . ~ Alaska. Oil and Gas Conservation Commission `~~ ~~~ ~~ ~"~ 333 West 7~' Ave., Suite 100 '<~ Anchorage, Alaska 99501 ~~ ~*. ~ ,'~ ~~;. RE: Application for Annular Disposal Permit: ~'ri o Aurora Gas, LLC Endeavour # 1 ~~ a®~ Dear Mr. Norman: Aurora Gas, LLC hereby applies for an Annular Disposal Permit to inject used drilling mud into a casing annulus in the Endeavour #1 exploratory well during testing and completion operations. Injection is expected to commence in mid-April 2006 and last less than 30 days. The Endeavour #1 will be drilled as an oil exploration well to test the production potential of the Lower Tyonek, Hemlock and West Forelands sands near Anchor Point on the Kenai Peninsula. An application for Permit to Drill has been submitted under separate cover. Aurora Gas proposes to dispose of used drilling fluid down the 7" X 9- 5/8" casing annulus. Since the 7" casing will serve as the production casing and will not be run until TD is reached, annular disposal will not occur down the annulus until after drilling operations are complete. Formation water salinities have been calculated using the logs run in the Unocal Griner # 1 drilled in 2002. The Griner # 1 is a vertical well located 95' away from the proposed Endeavour #1. Attached find a Form 10-403RD Annular Disposal Application, supporting documentation required in 20 AAC 25.080(b), a proposed wellbore schematic and a formation water salinity analysis for the receiving zone. As can be seen in the Application attachments, there is some information such as cement bond logs and leakoff tests that will not be available until drilling operations have commenced. We will transmit that information to the Commission as it becomes available. If you have any questions or require additional information, please contact me at (713) 977-5799 or Bill Penrose at 258-3446. Sincerely, AURO GAS, LLC J. E Jones Vie esident, Engineeri d Operations 10333 Richmond Avenue, Suite 710 • Houston, Texas 77042 • (713) 977-5799 • Fax (713) 977-1347 1400 West Benson Blvd., Suite 410 • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 • • Mr. John Norman Page 2 enclosures cc: Bill Penrose -Fairweather . ~ RE~EIVE[3 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ION DEG Q ~ ~~~~ ANNULAR DISPOSAL APPLICATION glsaka Oil & Gl~s Cons. Commissnra 1. Operator Name: Aurora Gas, LLC _ 3. Permit to Drill No: To be assigned 4. API Number: To be assigned 2. Address: 1400 West Benson Boulevard, Suite 410 5. Well Name: Enteavour #1 Anchorage, Alaska 99503 6. Field: it t 7. Publicly recorded wells 8. Stratigraphic s tion: a) Interval o d to Ty ek sands, shales and coals a) All wells within one- ope~an quarter mile: Unocal Griner #1 W e eceiving Tyon~k sands e b) water wells within one mile: See attached list O ` onfinement: Shales and coals within and overlying Tyonek .sands r 9. Depth to base of ~ 0. Hydrocarbon zones permafrost: No Permafrost Present ` above wa to receiving ~ zone: None 11. Previous volume disposed in annulus and date: 1 stim d d ity: 13. Maximum anticipated pressure at shoe: No previous disposal in well g 11.2 ppg) 2,500 psi 14. Estimated volume to be disposed with this reque ~ 1 Fluids to be disposed: Approximately 1,490 bbls Drilling mud and minor amounts of arctic grade diesel used for freeze protection of the annulus receiving the injection. 16. Estimated start date: Mid-April, Well Schematic (Include MD an TVD) ^~ SurF. Casing Cementing Data ^ 18. I hereby certify that the fore oing is ue and cor, nectto Cement Bond Log (if required) ^ Other ^ the best of my knowledge. Signature: ~."~ / ~~~~F/J~/J~~=/._~~~ Title: Vice President, Engineering and Operations \. Printed ~ Phone I ~~G O ~"" Name: ~' J. Edward Jones (..-~' Number: (713) 977-5799 Date: ( CJ J Commission Use Onl Conditions of approval: LOT review and approval: Subsequent form Approval ~ j~ ~ ~ ~- required: number: '~ Approved BY ORDER OF THE by: COMMISSIONER COMMISSION Date: ~c~-a (3 Form 10-403AD Rev.9/2003 INSTRUCTIONS ON REVERSE FIT Records w/ LOT Graph ^ Submit in Duplicate • • ENDEAVOUR #1 DISPOSAL OF DRILLING WASTE The following information is provided in support of Aurora Gas' request for authorization for disposal of waste drilling mud through injection down the 7" x 9-5/8" annulus in the Endeavour #1 well in accordance with AOGCC Regulations in Title 20, Chapter 25, 20 AAC 25.080. 1) The annulus to receive drilling waste will be the 7" x 9-5/8" annulus in the Endeavour #1. The 9-5/8" casing setting depth is planned to be at 2,500' RKB. 2) Depth to base of potable freshwater aquifers: Using the resistivity log from the adjoining Unocal Griner #1 well, it was attempted to locate the deepest occurrence of water that calculates to have 3,000 ppm salinity or less. The shallowest depth for which log quality is sufficient for calculating salinities is at 600' where the salinity is calculated to be 4,400 ppm. The base of the local freshwater aquifer is therefore at some depth shallower than 600' but cannot be exactly located from the logs. See the accompanying Formation Water Salinity Determination which also addresses the salinity at the interval to receive the injectant. Permafrost does not exist at this location. 3) The interval exposed below the shoe of the 9-5/8" casing will be in the top portion of the Tyonek Formation. The top of the 7" cement is also within the upper Tyonek. The receiving zone will be the upper Tyonek sands. Injection into this interval will be bounded at the top and bottom by shales and coals within and overlying the Tyonek sands. See the sonic and induction logs from the adjacent Unocal Griner #1 well on file at the AOGCC. 4) There is one publicly recorded well within one-quarter-mile of this location: the Unocal Griner #1 which was plugged and abandoned in 2002. The Griner #1 is located 95' away from the Endeavour #1 at the surface. The Griner#1 was drilled as a vertical well and the Endeavour #1 is also planned as a vertical well. There are many publicly recorded water wells within one mile of the Endeavour #1. A list of the wells, their locations and their depths is attached. 5) The waste to be injected will be used water-base drilling fluid. There may also be a small amount of diesel oil injected that is used as afreeze-protect fluid in the annulus receiving the injection. The estimated volume and maximum density are 1,490 barrels and 11.5 ppg. The volume is one and one half times the calculated hole volume at TD plus 500 bbls of active mud system in the surface mud system. The excess hole volume calculated reflects potential hole washout. The average slurry density is anticipated to be approximately 11.2 ppg, the expected mud weight needed when the well reaches TD. The maximum volume to be injected under any anticipated circumstances will not exceed 35,000 bbls. • • 6) Drilling wastes to be injected will be the drilling fluids used for drilling the well and associated rheologic modifiers, minor amounts of excess cementing materials, snow and wash water, and other as allowed under (h)(3) of AOGCC Chapter 25, Regulation 20 AAC 25.080.7). Also, minor amounts offreeze-protect diesel oil used specifically as part of this disposal process, may be injected. 7) The maximum anticipated pressure at the 9-5/8" casing shoe during disposal operations will be at or near the formation fracture pressure there as determined by leakoff tests conducted (a) upon drilling out the 9-5/8" casing shoe and (b) after drilling several hundred additional feet of open hole. The injection pressure during disposal operations may slightly exceed the original fracture pressure at times due to injected fines plugging off established fractures and having to re-fracture or otherwise overcome the tendency of the formation face to sand off. The maximum anticipated surface pressure during disposal operations is calculated as follows: = Fracture Pressure + Friction Pressure Losses -Hydrostatic Pressure _ (TVD of 9-5/8" shoe) (Avg injected MW) (.052 psi/ft-ppg) + 100 psi - (TVD of 9- 5!8" shoe) (8.6 ppg) (.052 psi/ft-ppg) This calculation is for the worst case (highest pressure): the injection interval depth to be 2,500', maximum friction pressure losses to be 100 psi, and fresh water is the least dense fluid to be injected. 8) After the 9-5/8" casing is set and cemented at +2,500'RKB, a cement bond log will be run across the casing and submitted to the Commission along with the cementing records while the 8-1/2" hole is being drilled. 9) Casing Safety Factors during Injection below 9-5/8" casing. Injection of fluids will be down the 7" x 9-58" annulus. This will expose the 9-5/8" casing to its maximum bursting stress at the casing shoe (surface injection pressure less friction loss plus the difference between the hydrostatic pressure of the injectant and the formation pore pressure behind the casing just above the shoe). The 7" casing will be exposed to its maximum collapse pressure at the surface (surface injection pressure with no hydrostatic or backup pressure inside). The 9-5/8" bursting stress and burst safety factor are calculated as follow: Burstin Sg tress = Surf. Injection pressure -friction pressure losses + (hydrostatic pressure of injectant at shoe -formation pore pressure at shoe) Safety Factor = Burst rating of 9-5/8" casing _ Bursting stress The 7" collapse stress and collapse safety factor are calculated as follow: Collapse Stress = Surface injection pressure Safet Fy actor = Collapse rating of 9-5/8" casing -Collapse stress Actual values for these formulae will be provided when apre-disposal injection test is conducted in the annulus. 10) The downhole pressure obtained during the leakoff test at the 9-5/8" casing shoe will be submitted to the AOGCC as soon as it is obtained as will a repeat leakoff test conducted after drilling several hundred additional feet of hole below the casing shoe. 11) Well logs run in the adjacent Unocal Griner #1 indicate there are no hydrocarbon-bearing zones above the anticipated top of the cement around the 7" casing. 12) The duration of disposal in this well is not anticipated to exceed 30 days. 13) No drilling waste has previously been disposed of in this well. 14) All drilling waste to be disposed of in this well will be generated during the drilling and evaluation of this well. 15) Aurora Gas intends to comply with all limitations established in 10 AAC 25.080(d). 16) Aurora Gas will, to the best of its ability, provide any additional data required by the Commission to confirm containment of the drilling waste. • LISTING OF ALL WATER WELLS LOCATED WITHIN ONE MILE OF THE PROPOSED ENDEAVOUR #1 LOCATION KEY LAS OWNER 1492 STOVAL, JAMES 19759 HESS, BRUCE P 20202 PENDREY, L.A. 21571 OLSON 22867 DINWIDDIE, CHARLES 23371 SEIGRIST, ROBIN 24052 HOMER REAL EST ASSOC 24807 LAS 22782 CARTER, G.T. 27803 LAS 22782 BROWN, T M DOC DEPTH MERID TWNSHP RANGE SEC 1/14/1985 76 SC 5 15 11/1/1980 88 SC 5 15 1 /1 /1957 30 SC 5 15 1 /1 /1965 90 SC 5 15 1 /1 /1992 94 SC 5 15 1/1/1995 0 SC 5 15 SC 5 15 1/1/1995 32 SC 5 15 6/1/1994 32 SC 5 15 SECPRTS MAPNUM STATUS 9 CBDC 2-Jan S 9 AADC 3-Jan S 9 ADCD 4-Jan S 9 DACA 1-Jan S 9 CADA U 9D U 9 DBAD U 9 DADC L 9 DADC U • • KEY LAS OWNER DOC DEPTH MERID TWNSHP RANGE SEC 14804 RODERRICK, PAUL 4/15/1987 105 SC 5 15 20359 11780 JACKSON, AARON 9/1/1983 65 SC 5 15 20431 THOMPSON, RICK 4/20/1977 120 SC 5 15 21430 KLEIN, 3/1/1983 37 SC 5 15 21432 NORTON, GORDON 2/1/1984 63 SC 5 15 21695 UNKNOWN 4/1/1989 49 SC 5 15 21844 OVERSON, GARY 7/2/1975 100 SC 5 15 21868 BALINTINE, JAMES 7/1/1978 85 SC 5 15 23972 BAILEY, D 17 SC 5 15 23976 BAILEY, D 18 SC 5 15 23992 LAS WINDOW, C 16 SC 5 15 24392 MOORE, ERIKA M. 14 SC 5 15 SECPRTS MAPNUM 3 3 CBDA 2-Jan 3 ABCC 1-Jan 3 DADB 3-Jan 3 DADA 4-Jan 3 DACB 3 3 DAC 3 AABA 3 ADDA 3 ABAA 3 ABBA • s KEY LAS OWNER DOC 173 206923 KUKUCHKA, GEORGE 9/7/1980 5598 AK DOT/PF ###### 5606 AK DNR-DLWM ###### 5769 KYLLONEN, H V ######## 7056 AK DOT/PF ######## 7469 CLUTTS, ROBERT ######## 7497 LAS 12765 AK DOT/PF ######## 7504 KYLLONEN, H V ######## 7569 CLUTTS, ROBERT ######## 7593 AK DOT/PF ######## 7594 AK DOT/PF ######## 7823 KLWONEN, H V ######## 7937 AK DOT/PF ######## 7970 ANCHOR RIVER INN ######## 10849 HUK CONST 9/10/1985 11040 3397 PATTERSON, DAVID 7/1/1985 13740 KENAI PENINSULA BOROUGH ######## 13743 BEDDINGFIELD 8/1/1981 13788 WALLIN, GORDY ######## 13791 ROSS, SCOTT R ######## 14803 VFW POST 10221 4/14/1987 16176 LIGHTHOUSE ASSEMBLY 9/29/1983 17760 CLUTTS, ROBERT ######## 18689 TRIMBLE, EMMITT 11/1/1979 20203 ENGLISHBEE, VIRGIL W 20204 HARRINGTON, STANLEY 20294 STROUP, K 3/1/1979 20356 12129 TRIMBLE, EMMITT ######## 20434 CLUTTS, JESSE 11/1/1983 20601 UNION 76 CRAIG 2/8/1977 20602 CRAIG'S UNION 76 2/10/1977 20603 NEFF, RICHARD 1/1/1965 20604 KENAI BOROUGH, ANCHOR POINTY 20605 HEDDELLS CABIN SHOP 1/1/1969 20606 HEDDLE, DUNCAN 9/1/1962 20607 KLEIN, LEO 1/1/1965 DEPTH MERID TWNSHP RANGE SEC. SECPRTS MAPNUM STATUS 76 SC 5 15 4 CADC 10-Jan S 21 SC 5 15 4 ACBB 17-Mar S 60 SC 5 15 4 BDCA 14-Jan S 20 SC 5 15 4 ABBD 12-Jan S 40 SC 5 15 4 ACBC 18-Jan S 18 SC 5 15 4 ACBB 17-Jun S 19 SC 5 15 4 ACBB 17-Feb S 41 SC 5 15 4 ACAC 16-Jan S 61 SC 5 15 4 ACAB 15-Jan S 61 SC 5 15 4 ACBB 17-May S 11 SC 5 15 4 ACBB 17-Apr S 11 SC 5 15 4 ABCD 13-Jan S 11 SC 5 15 4 ACBB 17-Jan S 10 SC 5 15 4 ACAB 15-Mar S 45 SC 5 15 4 CDDA 31-Jan S 51 SC 5 15 4 CDAC 11-Jan S 46 SC 5 15 4 ABDD 26-Jan S 62 SC 5 15 4 AADB 2-Mar S 40 SC 5 15 4 DCBB Jan-36 S 53 SC 5 15 4 AADD Jan-33 S 35 SC 5 15 4 ABBA 19-Jan S 380 SC 5 15 4 ABDC 27-Feb S 11 SC 5 15 4 ACAB 15-Feb S 33 SC 5 15 4 BDAB 28-Jan S 19 SC 5 15 4 DCBA U SC 5 15 4 DBDB Jan-34 S 42 SC 5 15 4A U 35 SC 5 15 4 BDAC Jan-32 S 50 SC 5 15 4 BDBB 29-Jan S 78 SC 5 15 4 AAAB 8-Jan S 57 SC 5 15 4 ARAB 8-Feb S 62 SC 5 15 4 AACB 1-Jan S 37 SC 5 15 4 AACB 1-May S 45 SC 5 15 4 AACA U 61 SC 5 15 4 AACA U 55 SC 5 15 4 AACA U • 20608 WILLIAMS 0 SC 5 15 4 AAAC 1-S S 20681 KENAI PENINSULA BOROUGH 3/26/1987 120 SC 5 15 4 ABDD 26-Feb S 20682 CLUTTS, BOB 3/1/1974 44 SC 5 15 4 ADBB 7-Apr S 20683 CLUTTS, BOB SC 5 15 4 ADBB 7-May S 20684 CLUTTS, BOB 0 SC 5 15 4 ADBC 1-S S 20685 SCHOLLENBERG, JIM 9/1/1979 86 SC 5 15 4 AADC 3-Feb S 20686 CARSON, R.W.,SR. 5/1/1980 48 SC 5 15 4 ABDC 27-Jan S 20687 KYLLONEN 4/1/1981 64 SC 5 15 4 ACDA 20-Jan S 20688 KACHEMAK BAY CHR CTR 12/1/1972 65 SC 5 15 4 ADBA 21-Jan S 20689 CARSON, DOUG 49 SC 5 15 4 ABAD 25-Jan S 20690 SYMENS, JOHN 1/1/1978 75 SC 5 15 4 AABA 23-Jan S 20691 SYMENS, JOHN 5/1/1984 54 SC 5 15 4 AABA 23-Feb S 20692 RENTMEESTER, BRUCE ######## 65 SC 5 15 4 AAAB 8-Apr S 20693 ANCHOR POINT COMMUNITY C 3/1/1974 55 SC 5 15 4 AACB 1-Feb S 20694 AK DEC ANCH PT PROJ 87 4/23/1987 54 SC 5 15 4 AAAB 8-Mar S 20695 AK DEC ANCH PT PROJ 87 4/25/1987 41 SC 5 15 4 AACC 6-Mar S 20696 STATE OF ALASKA, DEC, ANCH 4/26/1987 61 SC 5 15 4 AABD 24-Aug S 20697 AK DEC ANCH PT PROJ 87 4/28/1987 56 SC 5 15 4 AABA 23-Apr S 20698 AK DEC ANCH PT PR87 4/30/1987 56 SC 5 15 4 AABA 23-Jun S 20699 STATE OF ALASKA, DEC, ANCH 5/2/1987 55 SC 5 15 4 AABD 24-Mar S 20700 STATE OF ALASKA, DEC, ANCH ~## 52 SC 5 15 4 AABD 24-Jun S 20701 AK DEC, ANCHOR POINT PROJ ######## 36 SC 5 15 4 AACC 6-Feb S 20702 STATE OF ALASKA, DEC, ANCH ~ 55 SC 5 15 4 AABD 24-May S 20703 STATE OF ALASKA, DEC, ANCH ~ 56 SC 5 15 4 AABD 24-Jul S 20704 AK DEC, ANCHOR POINT PROJ ##~# 45 SC 5 15 4 AABD 24-Feb S 20705 AK DEC, ANCHOR POINT PROJ ~ 44 SC 5 15 4 AABD 24-Jan S 20706 AK DEC, ANCHOR POINT PR87 ##~ 50 SC 5 15 4 AABD 24-Apr S 20707 AK DEC, ANCHOR POINT PR87 ### 55 SC 5 15 4 AABA 23-May S 20711 NEFF, RICHARD 8/1/1974 57 SC 5 15 4 AABC 22-Jan S 21058 KYLLONEN, BUZZ 0 SC 5 15 4 CBDD 1-S S 21059 AK DIV PARKS SPRING 0 SC 5 15 4 CAAA 1-S S 21563 KENAI PENINSULA BOROUGH 9/16/1966 70 SC 5 15 4 AACC 6-May S 21573 MURTO, ARNE 1/1/1962 70 SC 5 15 4 DCAA 5-Feb S 21574 MURTO, ARNE 1/1/1952 60 SC 5 15 4 DCAA 5-Jan S 21575 ENGEBRETSEN, K (MUTCH, V) 6/1/1940 12 SC 5 15 4 BARB 9-Jan S 21576 KENAI PENINSULA BOROUGH 10/1/1959 40 SC 5 15 4 AACC 6-Apr S 21577 KENAI PENINSULA BOROUGH 1/1/1955 360 SC 5 15 4 AACC 6-Jan S 21578 COLLIE, JACK 1/1/1973 14 SC 5 15 4 ACDD 4-Jan S 21626 BARGE'S MULTI SERV ######## 51 SC 5 15 4 AABD 24-Sep S 21627 BARGE'S MULTI SERV ######## 51 SC 5 15 4 AABD 24-Oct S 21628 BARGE'S MULTI SERV ######## 51 SC 5 15 4 AABD 24-Nov S 21629 BARGE'S MULTI SERV ####+~### 56 SC 5 15 4 AABD 24-Dec S 21630 UNKNOWN ####~## 41 SC 5 15 4 AACD Jan-38 S 21631 BARGE'S MULTI SERV ######## 50 SC 5 15 4 AABD 13-24 S 21632 BARGE'S MULTI SERV ##### 51 SC 5 15 4 AABD 14-24 S 21633 SARGE'S MULTI SERV ######## 51 SC 5 15 4 AABD 15-24 S 21634 BARGE'S MULTI SERV ######## 51 SC 5 15 4 AABD 16-24 S 21635 BARGE'S MULTI SERV ######## 52 SC 5 15 4 AABD 17-24 S 21636 BARGE'S MULTI SERV ######## 51 SC 5 15 4 AABD 18-24 S 21637 BARGE'S MULTI SERV ######## 51 SC 5 15 4 AABD 19-24 S 21638 BAPTIST CHURCH ######## 51 SC 5 15 4 AABC 22-Feb S 21639 ROADHOUSE INN 6/3/1991 60 SC 5 15 4 AABC S 21640 ANCHOR POINT COMMUNITY C 6/3/1991 49 SC 5 15 4 AACB 1-Mar S 21641 UNKNOWN 6/1/1991 44 SC 5 15 4 ADBA 21-Feb S 21642 ANCHOR POINT USPS 6/1/1991 62 SC 5 15 4 AACA Jan-37 S 21643 UNKNOWN 5/31/1991 46 SC 5 15 4 AACD Feb-38 S 21644 ANCHOR POINT COMMUNITY C 5/31/1991 50 SC 5 15 4 AACB 1-Apr S 21645 CLUTTS 5/30/1991 37 SC 5 15 4 ADBB 7-Jan S 21646 CLUTTS 5/29/1991 37 SC 5 15 4 ADBB 7-Feb S 21951 AK DIV PARKS, SILVERKING 5/17/1974 140 SC 5 15 4 DBAC Jan-35 S 21967 KENAI PENINSULA BOROUGH 6/10/1983 72 SC 5 15 4 ABDD 26-Mar S 22126 BAPTIST CHURCH SC 5 15 4 AABC U 22127 KYLLONEN ENT. INC 0 SC 5 15 4 CBDC U 22128 THURMOND, WILLIAM 0 SC 5 15 4 AABA U 23168 BARGE'S MULTI SERV ######## 25 SC 5 15 4 AABD 20-24 S 23169 BARGE'S MULTI SERV 1/12/1988 25 SC 5 15 4 AABD 21-24 S 24055 UNKNOWN 0 SC 5 15 4 AADC U 24128 LAS 19883 AK DIV PARKS ANCHOR RIVER 9/12/1996 88 SC 5 15 4 CCAA U 25175 AK DIV PARKS ANCHOR RIVER 6/24/1999 55 SC 5 15 4 CCAA U 29703 LAS 24487 SHERIDAN, G ######## 36 SC 5 15 4 CCAD U 30454 LAS 23696 BRODERICK, M B 2/10/1993 18 SC 5 15 4 ABAC U KEY LAS 20432 21568 21569 21570 27760 LAS 23756 27761 LAS 23757 27842 LAS 22349 OWNER ADAMS, RALF RUGGEMAN,HENRY SOCAL STANDARD OIL CO WILLIAMS, SUSAN E WILLIAMS, SUSAN E KANE, W DOC DEPTH 5/1/1979 33 1/1/1975 23 12/9/1962 0 1 /1 /1962 100 6/1/1984 45 36 0 MERID TWNSHP RANGE SEC. SECPRTS MAPNUM STATUS SC 5 15 10 CDAB 3-Jan S SC 5 15 10 DCCB 2-Jan S SC 5 15 10 CCAC 1-Feb S SC 5 15 10 CCAC 1-Jan S SC 5 15 10 ACBB U SC 5 15 10 ACBB U SC 5 15 10 DCCD U • • AURORA GAS, LLC, ENDEAVOUR #~ 12'/<" Hole to 2,500 ft ~ TOC at 3,000' to enable mud disposal down 7" x 9-5/8" annulus Secondary target: Lower Tyonek just below 7,000' Contingency dual packers as needed to isolate potential secondary production zones Secondary target: West Forelands 8,145' - 8,780' • 13-3/8", 68# Conductor driven to -80 ft 9 5/8", 40#, L-80, LTC Surface Casing set at -2,500 ft MD. Cemented to surface. 3-1/2" Hole to 9,200 ft Primary target: Hemlock perforations between 7,525' and 8,125' (+100' total) T", 26#, L-80, BTC Production Casing. cemented at 9,200 ft. • • ~fll~l.,lJ~fll~--I~~ E & P SERVICES, INC. Formation Water Salinity Determination For Aurora Gas, LLC Logs provided are from March 2002 and were run for Unocal in the Griner #1 Company Field Well Location County Date Offset Well Logged Date Processed Log Analyst Aurora Gas, LLC Anchor Point Prospect Endeavour No.1 Sec. 3 Twp. 5S Rge.15W, SM Kenai Borough 18 March 2002 (1St Run Log) 25 March 2002 (2nd Run Log) 28 November 2005 Ron Doshier Fairweather E&P Services, Inc. 2000 East 88th Avenue Anchorage, Alaska 99507 (907) 258-3446 All interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any interpretations and we shall not, except in the case of gross negligence on out part, be liable or responsible for any loss, cost, damages or expenses incurred or sustained by anyone resulting from any interpretation made by any of our officers, agents or employees. • • Fairweather E&P Services, Inc. Log Data: 25 March 2002 Field: Anchor Point Prosuect Well: Griner No.l Introduction In support of an application for Annular Disposal permit for the proposed Aurora Gas, LLC Endeavour No. 1, Fairweather E&P Services, Inc has evaluated the formation water salinities in the Griner No.l, which was drilled by Unocal in March 2002. The Griner No. 1 is located 95 feet away from the proposed Endeavour #1 location and encountered the same formations as will Endeavour. The interval of interest is at 2,500 ft. at which depth it has been proposed to set casing. The data available for this evaluation was from Schlumberger's Platform Express which provides an Array Induction Log /Density /Neutron /Gamma Ray /Caliper. The reasons for this evaluation are to 1) attempt to locate the base of the fresh water aquifer, and 2) determine if the water salinity at this interval is sufficiently high for the interval to be used for injection. The spontaneous potential (SP) log The spontaneous potential tool measures natural electrical potentials that occur in boreholes and generally distinguishes porous, permeable sandstones from intervening shales. The "Natural Battery" is caused when the use of drilling mud with a different salinity from the formation waters, causes two solutions to be in contact that have different ion concentrations. Ions diffuse from the more concentrated solution (typically formation water) to the more dilute. The ion flow constitutes electrical current, which generates a small natural potential measured by the SP tool in millivolts. When the salinities of mud filtrate and formation water are the same, the potential is zero and the SP log should be a featureless line. With a fresher mud filtrate and so, more saline formation water, a sandstone will show a deflection in a negative potential direction (to the left) from a "shale base line" which is the zero potential measurement (to the right). The amount of deflection is controlled by the salinity contrast between the mud filtrate and the formation water. Clean (shale-free) sandstone units with the same water salinity should show a common value, the "sand line". In practice, there will be drift with depth because of the changing salinity of formation waters. The displacement on the log between the shale and sand lines is the "static self-potential" SSP. The conductivity of the drilling mud filtrate is measured by the logging engineers at the well-site and recorded on the "header" of the log. This information combined with the SSP "battery effect" shown on the log can be used to estimate the conductivity of the formation water. The calculation is made very commonly by petroleum log analysts as an important variable in the search for potential oil or gas zones. When used to evaluate the quality of aquifer waters, care must be taken to ensure realistic conclusions. Although formation water compositions at greater depths tend to be mostly sodium chloride, the ions of calcium, magnesium, bicarbonate and sulfate become more important in shallow, aquifer waters. As a result, the equations used by petroleum log analysts are only approximate and must be adjusted to honor the ionic mix of the local aquifer water. In general, the divalent ions of shallow waters tend to make them appear slightly more saline than they actually are when computed from the SP log. For this reason it is suggested that if water samples have been or will be collected that the resistivity of these samples be recorded for future corrections and transformed to estimates of total dissolved solids. ~ • Salinity Determination The salinity of the formation water (Rw) was determined by two techniques, SP interpretation and Rwa interpretation. The RWA interpretation method was used for the upper interval at 600 ft. due to poor SP response from the formation fluid continuing to decrease in salinity. The SP interpretation method was used at 1,500 ft. to 1,510 ft. to verify an approximate water salinity at that depth to show transition data. The lower interval from 2,500 ft. to 2,600 ft. was also calculated using the RWA interpretation method due to the mud system being changed out from fresh water base mud to oil base mud in which an SP is then not obtainable. Both techniques assume the fluid in the formation is water with no hydrocarbons. The charts used in this work are included in this report. Rwa Interpretation Zone Interva1600 ft. This interval was calculated with the RWA interpretive method due to little response from the SP due to decrease in formation water salinity. Rwa interpretation consists of the following steps. 1. Determine Rt from the Array Induction log 2. Determine Q) from Formation Density Log 4. Calculate Rwa (Rwa = X2'15 x Rt / 0.62) 5. Determine temperature at the zone of interest (Tzone = 40 + 0.013 X Depth) 6. Determine salinity (Chart Gen-9) Zone 600 ft. 1. Rt = 29m-m 2, ft~ = 20 3. Rwa = 1.64 ohm-m 4. Tzone = <50 5.. Salinity = 4,400 ppm SP Interpretation Zone 1,500 - 1,600 ft. SP interpretation consisted of the following steps. 1. Determine temperature at the zone of interest (Tzone = 40 + 0.013 X Depth) 2. Determine Rmf at temperature of zone (Chart Gen-9) 3. Determine Rmfeq (Chart SP-2) 4. Determine SP deflection from shale baseline 5. Determine constant K (K=61 + (0.133 x Temperature)) 6. Determine Rweq from formula SP deflection = -k x log (Rmf/Rweq) (Chart SP-1) 7. Determine Rw (Chart SP-2) 8. Determine salinity (Chart Gen-9) • Zone 1,500 ft. to 1,600 ft. 1. Temperature at zone = 60 F 2. Rmf at 60 F temperature = 3.4 ohm-m 3. Rmfeq = 1.4 ohm-m 4. SP deflection = -33 my 5. K = 68.98 6. Rweq = 0.75 ohm m 7. Rw=0.8ohmm 8. Salinity = 8,800 ppm at 60 F at 1,510 ft. • Rwa Interpretation Zone 2,500 ft to 2,600 ft. This interval was calculated using the RWA method as the drilling mud used to drill this section was Oil Base and therefore no SP could be run. Rwa interpretation consists of the following steps. 1. Determine Rt from the Array Induction log 2. Determine Q) from Formation Density Log 4. Calculate Rwa (Rwa = ~Z'15 x Rt / 0.62) 5. Determine temperature at the zone of interest (Tzone = 40 + 0.013 X Depth) 6. Determine salinity (Chart Gen-9) Zone 2,500 ft. to 2,600 ft. 1. Rt = 13 ohm-m 2. f~=18% 3. Rwa = 0.52 ohm-m 4. Tzone = 75 F 5.. Salinity = 11,800 ppm Conclusion: The salinity of the formation water just out of casing at 450 ft. is <4,400 ppm based on the calculation derived from the Rwa interpretation method at 600 ft. Potable water (salinity <3,000 ppm) appears to be covered by casing set at 430' behind which no logs were obtained. At the planned injection depth of 2,500 ft. the formation water salinity is approximately 11,800 ppm. , ~~ •~ ~~ • RWeq Determination from ESSP Clean formations ~fhis chart and nomograph calculate the equivalent forma- t_:r,~m/~!,•: SSP - 100 mV at 250°h' lion water resistivity, K„~.y, from the static spontaneous Rmr- 0.70 ohm-m at 100°}' potential, Essr. measurement in clean formations. or 0.33 ohm-m at 250°F Enter the nomograph with EssP in mV, turning through Therefore, Rm~~ 0.85 x 0.33 v the reservoir temperature in °F or °C to define the - 0.28 ohm-m at 250°F Kmi~y/R„~y ratio. From this value, pass through the R,,,i~y value to define K„~•,i. K„~y - 0.025 ohm-m at 250°F For predominantly NaCI muds, determine K,„r°y as EssP--K~log(R,,,i~.y/lt„~w) follows: Kc - 61 0.133 T r a. If Rmr at 75°F (24°C) is greater than 0.1 ohm-m, Kc - 65 • 0.24 T c correct R,,,, to formation temperature using Chart Gen-9, and use R,,,i«i - O.BS Rms. b. if K,,,, at 75°F (24°C- is less than 0.1 ohm-m, use Chart SP-2 to derive a value of Kmi~,i at formation temperature. 0.3 0.4 0.5 0.6 0.8 1 2 tr m 3 E 4 0 5 6 8 10 20 30 40 50 sch~,rMager Rmrev /R,,,,ey 0.3 0.4 0.6 0.8 1 2 4 6 8 10 20 40 +50 0 -50 -100 -150 -200 Esc, static spontaneous potential (mV) Rmteq (ohm-m) 0.01 0.02 0.04 0.06 0.1 0.2 0.4 0.6 1 2 4 6 10 20 40 60 100 SP-1 R~ (ohm-m) _ 0.001 0.005 0.01 0.02 0.05 0.1 0.2 . 0.5 1.0 . 2.0 2-5 SP 11 1 ~1 • Rw versus RWeq and Formation Temperature SP-2 (English) 0.001 0.002 0.005 0.01 0.02 E E r 0 m 0.05 E O Q! 0.1 0.2 0.5 1.0 Sthlumberger 2.0 0.005 5 0 0°F ~ 400°F 300°F ~ ~_ -200°F _ _' _ . \ -150°F -'f ° _100 F ~ ° - , 75 F _.. _+ Saturation ~ ~ ` ~ ~ ~ I - ~ ! \ ~~r7 F -- f ~ I -- _ 4~Q F_ ! `3~ F• I ~ 2~ F - ti ~ ~ • ~ ~s ~C . pl~~ ~ ~~ r~ `rte ~° 'I~ 0.01 0.02 0.03 0.05 0.1 0.2 0.3 0.5 1.0 2 3 4 5 RW or Rml (ohm-m) These charts convert equivalent water resistivity, RW~y, from Chart SP-1 to actual water resistivity, R,v. They may also be used to convert Rmf to Rmf°q in saline muds. Use the solid lines for predominantly NaCI waters. The dashed lines are approximate for "average" fresh formation waters (where effects of salts other than NaCI become signifi- cant). The dashed portions may also be used forgyp-base mud filtrates. L:runry~l~•: R„~y - 0.025 ohm-m at 120°C From chart, RW = 0.031 ohm-m at 120°C Special procedures for muds containing Ca or Mg in solution are discussed in Reference 3. Lime-base muds usually have a negligible amount of Ca in solution; they may be treated as regular mud types. z-s • Estimation of Formation Temperature men-6 T.i npar ~iHlt dSSIIIiIBd m Temperature gra~ern carwersions : i °F!i oo R = ~ ~3°G`Ji 00 m i°CJ1oom = o.s4s~'FlioOit Amtsl mean surface t~nperature ~ Temperature (''C~ it '~ is 2~ 5~~~~~~ L~.rumplc~: Bottomhole temperature (BI fl~) at 11,000 ft - 200°F (Point A) Temperature at 8000 ft = 167°F (Point B) 60° 100 i50 200 29D 300 39D manual mean Temperature ~' ~ surface t~nperature ~ • Resistivity of NaCI Solutions 8 6 5 4 3 2 1 0.8 ~ 0.6 E 0.5 0.4 0 -o' 0.3 0 T ~~ 0.2 .~ .~ 0.1 0.08 0.06 0.05 0.04 0.03 0.02 0.01 Conversion approximated by R2 = R1 [(T1 + 6.77)/(TZ + 6.77)]°F or RZ = R1 [(T1 + 21.5)/(T2+ 21.5)]°C 10 E n I 3Av ~` ~O, ~~ . ~b~ 1~ 1~ ~4~, ~~~ `rob "+47 ~` )~ ~b . ~O~ ~?~7 ~4 '~~ ~/y,_ ~~ ~~. SO'ab . ~~ T~ 7~-"(/ 7q~~0 Jry),~ /-y",f~J M ?~M'T/ 'F 50 75 100 125 150 200 250 300 350 400 ~K/ 'C 10 20 30 40 50 60 70 80 90 100 120 140 160 180 200 Temperature (°F or °C) Gen-9 r` io m m c .~ C7 10 15 20 25 30 40 50 N C .~ rn 100 `o E a 150 ~' c 0 200 ~ip 250 ~ 300 400 U m 500 Z 1000 lsoo 2000 2500 3000 4000 5000 10,000 15.000 20,000 Gen Schlurnbergg 7-5 • • ~Aurrora Gas, LLC www.aurorapower.com ~ E ~ ~ ~ ~~ Alaska Oil and Gas Conservation Commission December 19, 2005 ~~C ~ f ~~~~ 333 W 7th Avenue, Suite No. 100 Anchorage, Alaska 99501-3539 Alaska Oi! & G8s C~ ~.t: w.~cs i ,~~~hQra Attn: Mr. Bob Crandell Petroleum Engineer Gentlemen: RE: Application to Drill Endeavour Lease Well Kenai Peninsula Borough Cook Inlet, Alaska Aurora Gas, LLC (AURORA), as Operator of the proposed captioned well, submits, as per your request, the enclosed two (2) land plats in support of an initial Application to Drill for the captioned Lease well recently submitted by Fairweather in our behalf. If you require additional information regarding this Application, please contact Mr. Ed Jones, Vice President, Engineering, at the number below or the undersigned. Your prompt attention to this matter is sincerely appreciated. Enclosures aogcc endeavour apd plat Very Truly Yours, --. r~ ., ,, , r ' ~.., . ~- , J .:.~ ~, a ..~ . r~ a v~ ~ .. Randall D. Jones, CPL--°~' Manager, Land & Negotiations rj ones@aurorapower. com 10333 Richmond Avenue, Suite 710 • Houston, Texas 77042 • (713) 977-5799 • Fax (713) 977-1347 1400 West Benson Blvd., Suite 410 • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 _ ,-'F . I ~_ _ ___ ____ __. z_____ -- , , _ _ __ ,~ __: ,~ ~. ~ - / i _- 1 Zy ~ ~ ~ C-, I ~\ -- ---= ..:, - ~ ~ ~I ~ , 1 - ~~ i _ nl ^ (~ /( n ~' ' _. -, ~ I ._ .. _.. _._ _. ln~~ '' ,~- ',~ ~ z ~ ;, i L 4 /, V ... -~ >i_ci `~ i:.aL ~'~ j ~ 2fi0-0~: Rbf.E:dC'n ~I ~.. Y~_':. L ~- ~~ NEB ~ ~I ~31yfi . ~~. __ ~ t~. .r. . _,_ ' `~T l n-Z1~ Z-~Q ' ~#~ ': •Lt~i / t f ~.. i f ~ itsuPraar: . -------_-- _ --C _ ~ =- -- --- ~~ ~~~ ~- , _ ~:.t ' ' t Z5 ~\ `\ t \\ Z7 ~ : __, ;~- m 3 F~\ 27.3 __ __ _- ~= ~ ~ r - I ~---- j ----- - ; i i i ' i - __-,- - --t-- , _ ~ - i -- - - -- ~ I i - ~\ ~ 1 - ., ; i ~ ~ i :~ --- -- _ - - ~_ - - - - f -- - - -----~ ~~ ~ '.' ~ r ------- ._.. _. ~ i I =T- ' r-- ~. ,/. ~~, ~ G i ~~ j'~ Z~~ .~--T'~~-- " - ~ ~_.,: -- -- -; b ~ Y 1 • tiAurera Gas, LLC www.aurorapower.com December 8, 2005 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West '7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill: Endeavour #1 Dear Mr. Norman, ~, ~n,~h~r~~y~ '~~isaior~ Aurora Gas, LLC hereby applies for a Permit to Drill an onshore oil exploration well near Anchor Point on the Kenai Peninsula. The well is planned as straight-hole Hemlock test ~ for oil. It will be drilled from the same pad as the Unocal Griner #1 which was drilled to a shallower depth, tested and subsequently plugged and abandoned in 2002. Waste drilling fluids and ground cuttings will be disposed of via annular injection down the 7" x 9-5/8" annulus. An Annular Disposal Application will be submitted under separate cover. If for some reason injection down that annulus proves to be not possible, the drilling fluids and cuttings will be disposed of at a permitted facility. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information. attached to this application includes the following: 1) Form 10-401 Application for Permit fo Drill. 2) Fee of $100.00 payable to the State of Alaska. 3) A plat showing the surface location of the well. 4) A Time versus Depth plot. 5) Diagrams and descriptions of the BOP equipment to be used. 6) Proposed casing program. 7) Proposed cementing program. 8) Proposed drilling fluid program. 9) Proposed drilling program. 10) Summary of Drilling Hazards. 11) Schematic of the proposed wellbore and completion. 12) Aurora Gas does not anticipate the presence of H2S in the formation to be encountered in this well. However, H2S monitoring equipment will be functioning on the rig at all times during drilling and completion operations. 13) The following are Aurora Gas' designated contacts for reporting responsibilities to the Commission: 10333 Richmond Avenue, Suite 710 • Houston, Texas 77042 • (713) 977-5799 • Fax (713) 977-1347 1400 West Benson Blvd., Suite 410 • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 • Mr. John Norman Page 2 1) Completion Report (20 AAC 25.070) 2) Geologic Data and Logs (20 AAC 25.071) • Bill Penrose, Drilling Engineer (907) 258-3446 Andy Clifford, VP -Exploration (713) 977-5799 If you have any questions or require additional information, please contact me at (713) 977-5799 or Bill Penrose at (907) 258-3446. Sincerely, AURORA GAS, LLC enclosures cc: Randy Jones -Aurora Gas Bill Penrose -Fairweather Engineering and Operations STATE OF ALASKA ALAS'~"A OIL AND GAS CONSERVATION COMMI 510N PERMIT TO DRILL 20 AAC 25.005 W~ Pik- Z.( L7 2.0 0 4 ~~~~~ DEC ~ ~ "~uu ~i,..l,e nil R has Cons. Cotnt~ss~oh 1a. Type of Work: Drill Q Redrill ~ Re-entry ~ 1b. Current Well Class: Exploratory Q Development Oil n~~t~}Ip~one Q Stratigraphic Test ~ Service ~ Development Gas Single one 2. Operator Name: Aurora Gas, LLC 5. Bond: Blanket Q Single Well Bond No. 11. Well Name and Number: Endeavour #1 3. Address: 1400 W. Benson Blvd., Suite 410, Anchorage, AK 99503 6. Proposed Depth: MD: 9,200' TVD: 9,200' 12. Field/Pool(s): 4a. Location of Well (Governmental Section): Surface: 2268' FSL, 1834' FWL, Sec 3, T5S, R15W, SM 7. Property Designation: Dale Griner, et al. Lease Exploratory ~- Top of Productive Horizon: 2268' FSL, 1834' FWL, Sec 3, T5S, R15W, SM 8. Land Use Permit: N/A 13. Approxim,ai~t~ Spud Date: ;3171?A06 Total Depth: 2268' FSL, 1834' FWL, Sec 3, T5S, R15W, SM 9. Acres in Property: 134 14. Distance to Nearest Property: 500' 4b. Location of Well (State Base Plane Coordinates): Surface:x- 165362 y- 2113163 Zone- AK-04 10. KB Elevation GL = 145' AMSL (Height above GL): 16 feet 15. Distance to Nearest Well Within Pool: N/A 16. Deviated wells: Kickoff depth: N/A feet Maximum Hole Angle: N/A degrees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 5,358 psi Surface: 4,342 psi 18. Casing Program: Size Specifications Setting Depth Top Bottom Quantity of Cement c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 13-3/8" 68# L-80 BTC 80' 0' 0' 80' 80' Driven 12-1/4" 9-5/8" 40# L-80 LTC 2,500' 0' 0' 2,500' 2,500' 765 sx Class G 8-1/2" 7" 2f# L-80 BTC 9,200' 0' 0' 9,200' 9,200' 762 sx Class G 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry O perations) 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 Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch ~ Drilling Program ~ 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 to the best of my knowledge. Contact Bill Penrose 258-3446 Printed Name J. Edwa nes Title Vice President, Engineering and Operations Signature ~-- ~~-. ; Phone (713)977-5799 Date `~/~ ~ ~r %" Commission Use Only Permit to Drill ; Number: ~ _ Z API Nu beC:' 0- ,Z3/--..2 OQ ,30 Permit Approve! Date: . ~~ See cover letter for other requirements. Conditions of approval Samples required Yes No ~ Mud log required Yes ~ No Hydrogen sulfide measures Ye ~ ~ Directional survey required Yes ~ No `~ Other: ~~PiS 6 ~ O ~ ~- '~-O rj C7 D d ~ APPROVED BY Q Approved by: T E COMMISSION Date: ~ ~~~ Form 10-401 Revised 06/2004 v - v Submit inDuplicate ~- Aurora Gas, LLC Endeavour #1 Drilling Procedure 1. Prior to moving in drilling rig, excavate and install cellar then drill or drive 13-3/8" ~ conductor to as close to 80' below ground level as possible. 2. Move in, rig up drilling rig. Install diverter in 13-3/8" conductor and function test. / 3. Drill 12-1/4" hole to 2,500'. Run open-hole logs. 4. Run 9-5/8", 40#, L-80, LTC surface casing and cement to surface. ~ 5. Install wellhead, land casing and N/iJ 11", SK WP BOPE and test to 5,000 psi. ~ 6. M/tJ 8-1/2" drilling assembly, clean out to float collar and test 9-5/8" casing to 2,800 psi (70% of internal yield rating). Drill out float collar, cement, float shoe and 10' of new hole. Conduct leak-off test. 7. Dril18-1/2" vertical hole to 9,200'. Run open-hole logs. 8. Run 7", 26#, L-80, BTC casing and cement. (Cement not to reach the shoe of the j 13-3/8" surface casing to allow later annular injection down the 13-3/8" x 9-5/8" casing.) 9. Clean out 7" casing and pressure test both to 4,400 psi (70% of internal yield rating of 7" casing). 10. Conduct testing of the West Foreland sand. 11. Conduct testing of the shallower Hemlock sand. 12. Conduct testing of the shallowest Lower Tyonek sands 13. Complete well as an oil producer with 3-1/2" tubing and either one to three packers, depending on the number of intervals to be produced. 14. N/D BOPE, N/U tree. Test tree to 5,000 psi. Release rig. % • • AURORA GAS, LLC ENDEAVOUR #1 0 -1000 -2000 -3000 -4000 w LL Y -5000 t a m -6000 -7000 -8000 -9000 -10000 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 Day r Endeavour #1 Geo-mechanical Plot 0- 1,000 2, 000 3,000 ~ 4,000 ... t a m 5,000 as m ~ 6,000 7,000 8, 000 9,000 10,000 13-3/8"' ~ i 9 5/8" ~ -- ------ ------ --- -__ __ ____- Lowe He Tyon lock k r West Forela d -- - i, I ,. 7 ~~ ~ i i 8 10 12 14 16 18 Mud Wt. ppg • • AURORA GAS, LLC, ENDEAVOUR #~ ~ 12'/." Hole to 2,500 ft ~ TOC a ,000' to enable mud dispos -=flown 7" x 9-5/8" annulus Secondary target: Lower Tyonek just below 7,000' Contingency dual packers as needed to isolate potential secondary production zones Secondary target: West Forelands 8,145' - 8,780' 13-3/8", 68# Conductor driven to -80 ft 9 5/8", 40#, L-80, LTC Surface Casing set at 2,500 ft MD. Cemented to surface. 3-1 /2" Hole to 9,200 ft Primary target: Hemlock perforations between 7,525' and 8,125' (+100' total) T", 26#, L-80, BTC Production Casing cemented at 9,200 ft. • Aurora Gas, LLC • Pressure Calculations, Drilling Area Risks and Waste Disposal Endeavour #1 Maximum Anticipated Surface Pressure: 8-1/2" Hole Section The maximum anticipated surface pressure (MASP) for the 8-1/2" hole section in this sidetrack will be the lesser of the formation pore pressure (less a full gas column to the surface) at 9,200' TD or the formation fracture pressure at the 9-5/8" casing shoe (less a full gas column to the surface). Offsetting well information indicates that pore pressure at TD will be a maximum of 11.2 ppg EMW (or 0.582 psi/ft). The only formation strength data obtained in this area are two formation integrity tests conducted in the nearby Unocal Griner #1. In that well, leakoff was not achieved with a test of 35.2 ppg EMW at 462' and leakoff was again not achieved with 20.9 ppg EMW at 1,781'. Both of these tests are anomalously high, but, with no other data available, it is conservatively assumed that the shoe of the 9-5/8" casing will not break down when subjected to formation pressure at 9,200' TD less a gas column. 8-1/2" hole section MASP (pore pressure) _ (9,200 ft)(0.582 - 0.11) = 4,342 psi / With MASP in the 8-1/2" open hole section expected to be 4,342 psi, the 5,000 psi BOPE system to be used will be adequate. Well Proximity Risk: The closest wellbore to this one is the plugged and abandoned Unocal Griner #1 located approximately 95' away on the same pad. Drilling Area Risks: There are only two drilling risks anticipated in this area. The first to be encountered will be drilling the coal seams of the Lower Beluga Formation and the Tyonek Formation. These coals, if not handled correctly, can result in stuck drillpipe and sometimes loss of ability to circulate. The possibility of coal-stuck drillpipe will be mitigated by drilling this well vertically and via the use of PDC bits, which tend to slow down in coals and allow reaming them before they have a chance to plastically flow into the wellbore. The second risk is the relatively rapid rise in pore pressure as first the Hemlock, then the West Foreland Formations are penetrated. However, the pore pressures are not extreme • (the mud weight is not expected to exceed 11.2 ppg) and the drilling crews will be kept aware that mud weight increases will be needed below 7,000'. Disposal of Muds and Cuttings: An annular injection permit is being sought separately for disposal of waste fluids down l the 7" X 9-5/8" annulus. All solid waste, including drill cuttings, will be disposed of in a nearby permitted landfill.. If for some reason injection down that annulus proves to be not possible, the drilling fluids will be disposed of at a permitted facility. Aurora Gas, LLC Endeavour #1 Casing Performance Properties Size Weight in. 1( b/ft~ 9-5/8 40 7 26 Grade Cnxn L-80 LTC L-80 BTC Casing Properties and Design Verification Internal Collapse Tensile Strength Yield Resistance Joint Body TVD MD si si 1 000 lbs (ft RKB~ ~ft RKB) 5,750 3,090 737 916 2,500 2,500 7,240 5,410 667 604 9,200 9,200 Design Safety Factor* T B C 8.63 1.32 3.09 3.04 1.67 1.24 ~ U * Tensile design safety factors are calculated using pipe weight less buoyancy. Burst design safety factors are calculated at the surface using zero backup on the outside and MASP on the inside. Collapse design safety factors are calculated at the casing shoe using the maximum expected mud weight to be used at the shoe depth on the outside and the entire cased hole evacuated except for a gas gradient on the inside. Casing Setting Depth Rationale 9-5/8" 2,500'MD / 2,500'TVD Surface casing to stabilize shallow formations, provide an anchor for the BOP stack and provide shoe strength in the event of a kick. 7" 9,200'MD / 9,200'TVD Production liner to stabilize and isolate producing interval for production operations. • • ~ 1834'FWL Grid NORTH ENDEAVOUR N0. 1 AS-STAKED GRID N: 2113163.000 GRID E:165362.000 LATITUDE: 59°46'19.085"N LONGITUDE: 151 °48'56.523"W ELEVATION: 145.0' SECTION 3 T5S R15W SM AK 2268' FSL SCALE 1 inch = 300 ft. 0 300 450 600 ~__ FOUND OFFICIAL BRASS CAPPED GLO MONUMENT-- SW CORNER SECTION 3 NOTES 1) BASIS OF COORDINATES IS ALASKA STATE PLANE NAD 27 ZONE 4 ADOT GEOREF. PROJECT BM N86. 2) BASIS OF ELEVATION IS FROM NAVD88 NGS BM N86. ALL ELEVATIONS SHOWN HEREON WERE TAKEN ON GROUND. 3) SECTION LINES SHOWN HEREON ARE BASED ON BLM MONUMENTS RECOVERED. ~E QF A~q ~/~~ *.:•.49 ~ ••. * ~ ~ 'c •:M. SCOTT McLANE;'>ff . ~I~ s~F~'•. 4928-S .•'y~~ ,,I1' i~`ESSIONA`;` ~ ~\\\~ ENDEAVOUR NO. 1 WELL AS-STAKED SURFACE LOCATION DIAGRAM IV~cLane Consulting Inc APPLICANT: ENGINEERING/MAPPING/SURVEYING/TESTING •~;`~~~••`•'~•••••• P.O. BOX 468 SOLDOTNA, AK. 99669 .c :;: ~g VOICE: (907) 283-4218 FAX: (907) 283-3265 ~ .i EMAIL: msmclane®mclanecg.com PROJECT NO. DRAWN BY: DATE: SEC. LINE LOCATION: Nov. 1, 2005 OFFSETS: SECTION 3 053095 MSM 1834' FWL TOWNSHIP 5 SOUTH, RANGE 15 WEST 2268' FSL SEWARD MERIDIAN, ALASKA 11 " 5k PSI _ SCHAEFER ANNULAR BOP SCREWED HEAD FLANGED BOTTOM CONNECTION 3" #50~ HCR UAL 11 " 5k PSl DOUBLE GATE PREVENTOR 3-1/8" #5000 STUDDED CONNECTION GATE VALVE 3" C_ HOK_ E LINE _ _ _ _ _ _ _ 11 " 5000# API 3" KILL LINE ~ FLANGED MUD CROSS 3-1/8" //50( GATE VALVE NABOBS ALASKA RIG 129 11" BLOW-OUT PREVENTOR 3 RAM STACK CONFIGURATION 11 " 5k PSI HYDRAULIC RAM SINGLE GATE STUDDED CONNECTION 3-1/8" #5000 GATE VALVE ..y-- ..v,J ~~, ~.~ ~N~orsAlaslm P525 ~ Sb Y .w~0u..e~.,.nc~. ,Nd~«oyy., , YOl-T83-61 ~¢' NABOBS AUSKA RIC 129 i l' BLOW-OUT PREl¢NTOR 7 RATA STACK CONFIOURATpN • • ~ ~ > ca ~ ~ j ~ Y ~ v = ~ 0 U y ~ ~ p Q ~ TO •` '~' W C :.' _a ~i V ~ D O ~ CD ~ ~ r t ~ ~ ~ ~ ~ r e~ O c0 ~ ~ r M O c0 ~ ~ e N o ap a m ~ Q m • Endeavour #1 • Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE ~ The 8-1/2" hole section will be drilled through the Lower Beluga and Tyonek Formations which contain coal beds of varying thickness. Care must be exercised while drilling them as they tend to swell into the wellbore and may stick the drill pipe and possibly pack off, eliminating the ability to circulate. ~ There is an abandoned exploratory well (the Unocal Griner #1) located 95' from the Endeavour #1. Directional control will be important while drilling the Endeavour #1 to avoid the possibility of intersecting the other wellbore. ~ Below 7,000' increasing pore pressures will result in the need to gradually raise the mud weight from ±9.9 ppg to ±11.2 ppg. ~l There is no H2S risk anticipated for this well. CONSULT THE ENDEAVOUR #1 WELL PLAN FOR ADDITIONAL INFORMATION Halliburton BaROi~ Aurora Gas Mud Program BAuoIQ ~ Aurora Gas Endeavor #1 Kenai Peninsula, Alaska Baroid Mud Program Halliburton Baroid Name (Printed) Signature Date Originator Dave Higbie Reviewed by Dave Soquet Customer Approval Bill Penrose Version No: Date: 1.0 October 10,2005 Endeavor #1 v1.0 1 10/10//05 ~ Halliburton BaROiD Aurora Gas Mud Program ~ Endeavor #1 Introduction: The following mud program was prepared for a vertical well accessing the Tyonek and West Forelands sands on the Kenai Peninsula, Alaska. This well will be spudded with a 6% KCI drilling fluid and drilled vertically to the 2,500' MD range. It will be drilled with in a 12 '/4" hole size, 9 5/8" casing run and cemented. The surface casing will be drilled out with the existing mud system. The 8 %2" interval will then be drilled to section TD at 7,500' MD. Seven inch casing will be run and cemented at this depth. The 7" will be drilled out and a leak off performed with the water base system. The well will then be displaced to an INVERMUL system which will be used to drill the production hole. A 6 1/8" hole will be drilled to TD at 9,200' MD. A 5" production liner will then be run and cemented in place. Spud the well with a 6% KCI/PHPA mud ~ 8.6 ppg. The mud weight will then be held in the 8.6 - 8.9 ppg mud weight range to the surface hole TD unless hole conditions dictate otherwise. Our primary focus for surface hole drilling operations will be adequate mud weight for well control and sufficient mud viscosity for efficient hole cleaning. This spud mud is formulated with two mechanisms to provide waste minimization and effective wellbore stabilization, ionic inhibition (KCI),and polymer encapsulation (PHPA). This same 6% KCI/PHPA mud will be maintained through the intermediate interval. This mud offers good LCM responses if losses are encountered. Special emphasis should be placed on maintaining low ECD's and surge/swab pressures to minimize the potential for lost circulation. The production interval will begin with an 70/30 OWR oil base fluid. The ratio can then slowly be raised to reduce rheological parameters. CaCI levels will be maintained in the 270,000 - 290,000 ppm WPS range. The mud weight will be held in the 10.0-10.3 ppg range or as required for hole stability. Primary Drilling Objectives: • Zero fluid related HSE incidents • Achieve wellbore stability • Achieve good hole cleaning considering hole angle, geometry and anticipated ROP rates • Lost circulation mitigation/control • Achieve good Zonal Isolation as per plan • Achieve minimal formation damage in pay sands • Minimize fluids related NPT • Minimize drilling wastes Critical Fluid Issues: • Eliminating/controlling losses. • Maintaining a low ECD in the production zone to reduce risk of lost returns. • Maintaining a stable wellbore through coal seams.. • Reducing drilling wastes with the inhibited drilling fluid system. Well Specifics: Casing Program MD TVD Footage 12'/4" hole 9 5/8" cs 2500' 2500' 2500' 8 %2" hole 7 " casin 7500' 7500' 5000' 6 1/8 "Hole 3 %2" liner 9200' 9200' 1700' Endeavor #1 v1.0 2 10/10//05 I Halliburton BaROiD Aurora Gas Mud Program Surface Hole Recommendations Mud Type: 6%KCI, EZ Mud Properties: Density Vis PV Yield Point API FL pH 0 - 2500' 9.0 - 9.7 60 - 85 6 - 16 15-25 < 6 8.5-9.5 System Formulation: 6%KCI, EZ Mud Product Concentration Water 0.905 bbl KCI 21 ppb (30K chlorides) KOH 0.2 ppb (9 pH) Barazan D 1.25-1.5 ppb (as required 35 YP) EZ Mud DP 0.75 ppb (initial 0.15 ppb) PAC L 1 ppb at 1,000' Aldacide G 0.1 ppb Baracor 700 1 ppb Barascav D 0.5 ppb (add as the well spuds) Baroid to a 9.0 • Mix in order as listed • Add polymers slowly to minimize fisheyes. Concerns and Contingencies Surface Interval - (0 - 2500' MD Mud Type: 6 %KCI/EZ Mud 1. Mud weight: Spud with a 9.0 ppg density. Increase the weight to 9.7 ppg by 1,200' or as directed. 2. Rheology: Maintain a YP between 15 - 25 or as needed to achieve adequate hole cleaning. 3. Filtrate control: No filtrate control is required prior to reaching 1000' MD. Additions DriI-N-Slide may be required to control screen blinding/bit balling. Seepage losses in this interval can be controlled with additions of 3-5 ppb BAROFIBRE or by dedicated LCM pills. Operations Summary: This section will drill a 12'/" hole. Build the 6% KCI fluid in the proper order of addition. Be prepared for sloughing gravels in the upper interval; increasing the system rheology with BARAZAN-D will assist in bringing this material out of the well, as will pumping dedicated high-viscosity or Barolift sweeps. It is recommended that the pump rate be increased to the maximum practical rate while the hole is unloading gravel. Sweep Formulation: 30 barrels mud (500' annular coverage), add ca. 1.0 ppb BARAZAN D to achieve atau0>25. Additions of DriI-N-Slide and/or Condet are recommended when penetrating high-clay content sections. This to reduce the incidence of bit balling and shaker screen blinding. Endeavor #1 v1.0 3 10/10//05 Halliburton BaROi~ Aurora Gas Mud Program Be prepared to increase the YP if hole cleaning becomes an issue. Run DFG (Drilling Fluid Graphics) to confirm hole cleaning efficiency based on current rheology, flow rates and cuttings size. At TD, a Wallnut "flag" (20 bbl pill with 15 ppb of Wallnut F) should be pumped to gauge hole washout and to calculate the required cement volume. The cement will then be pumped and drilling mud will be used to bump-the plug. Pretreat this chase mud with 1 ppb Bicarb and 0.5 ppb citric acid. Hazards /Concerns -Surface Interval: • Preventing lost circulation through ECD management. • Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. • Maintain YP between 25 - 40 to optimize hole cleaning and to control ECD. • Pump high viscosity sweeps to enhance hole-cleaning efforts. Monitor sweep effectiveness. • Successfully cement casing. Maximum Acceptable ROP in fph at Specified GPM and RPM GPM 350 400 450 60r m 78 99 111 80r m 78 99 111 Baroid's recommended flowrate for this interval is 450 gpm minimum to maximize hole cleaning. RPM's have no effect on hole cleaning in this vertical section. Intermediate Hole Recommendations Mud Type: 6%KCI, EZ Mud Pro erties: Density Vis PV Yield Point API FL pH 2500-7500 9.3 - 9.8 40-53 6 - 15 13 - 20 <5 8.5-9.5 System Formulation: 6%KCI, EZ Mud Product Concentration Water 0.905 bbl KCI 19.8 ppb (30K chlorides) KOH 0.2 ppb (9 pH) Barazan D 1.25 ppb (as required 35 YP) Dextrid 1-2 ppb PAC L 1 ppb EZ Mud DP 0.75 ppb Aldacide G 0.1 ppb Baracor 700 1 ppb Barascav D 0.5 ppb Baroid As needed • Mix in order as listed • Add polymers slowly to minimize fisheyes. Endeavor #1 v1.0 4 10/10//05 ~ Halliburton BAROIO Aurora Gas Mud Program ~ Concerns and Contingencies Intermediate Interval - (2500 - 7500' MD Mud Type: 6 % KCI/PHPA 1. Mud weight: A 9.3 ppg density is required at drill out. Raise the weight to 9.8 ppg prior to 3,400'. Maintain the 9.8 ppg to interval TD or as directed. 2. Rheology: Maintain a YP between 13-20 or as needed to achieve adequate hole cleaning. 3. Filtrate control: Filtrate control is required in the <5 range. Add Dextrid and/or Pac L to reduce the filtrate. Additions of DriI-N-Slide and/or Condet may be required to control screen blinding/BHA balling. Losses in this interval can be controlled with additions of 1-2 ppb BAROFIBRE and 1-2 ppb of Baracarb or by dedicated LCM pills; see appendix for LCM decision tree. Operations Summary: Drill out the cement/casing with the existing mud system. Bicarb or soda ash and citric acid should be used to pretreat for any negative effects of the cement. BARAZAN-D should be used to maintain rheological parameters. Maintain the mud as clean as possible while drilling. Should sweeps be required a BAROLIFT sweep is recommended. This sweep will help clean the hole with no negative impacts on system mud weight or rheology. Daily additions of X-Cide 207 should be made to control bacterial action. Sweep Formulation: 25 bbl of mud with .25 ppb of Barolift added. Shear thoroughly prior to pumping. Dextrid and/or PAC L should be used for filtrate control. Baranex can be used if the solid loading deems it. Additions of DriI-N-Slide are recommended when penetrating high-clay sections. This to reduce the incidence of bit balling and shaker blinding. Maintain the pH in the 8.5 - 9.5 range with caustic soda. The system rheology may be relaxed as hole conditions allow. This will also lower the ECD to reduce chances of losses occurring. However, be prepared to increase the YP if hole cleaning becomes an issue Maximum Acceptable ROP in fph at Specified GPM and RPM GPM 300 400 500 60 r m 170 210 255 80r m 170 210 255 Baroid recommends a flowrate in the 400 gpm range to maximize hole cleaning efficiencies at these high penetration rates. This range allows high penetration while keeping the ECD in the 10.3 ppg range. Reduce system YP with Therma Thin as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what yp value they have targeted). The plug will again be bumped with mud on the well. If operations allow, the plug can be bumped with OBM. Hazards /Concerns -Intermediate Interval: • Preventing lost circulation. • Optimize solids control equipment to maintain density and sand content. • Maintain YP between 13-20 to optimize hole cleaning and to control ECD. Endeavor #1 v1.0 5 10/10//05 ~ Halliburton BaROiD Aurora Gas Mud Program • Pump high viscosity or Barolift sweeps to enhance hole-cleaning efforts. Monitor sweep effectiveness. • Successfully land and cement casing. Production Hole Recommendations System Formulation Product Concentration Base Oil 0.604 bbl EZ MUL NT 4 ppb INVERMUL 4 ppb GELTONE V 4 ppb Lime 5 ppb DURATONE 4 ppb RM 63 0.5 ppb Water 0.266 bbl CaCl2 24.6 ppb AK-70 4 ppb BARO I D to 9.8 Mud Type: Invermul System Mud Properties Density Vis PV YP ES HTHP WPS O/V~/ 7500-9200 9.8 then 55 - 80 18 - 29 9 -18 1000- <5 270 to 70/30 ~:0'~ 1100 290K Additional mud weight may be required for effective coal or shale stabilization. t(.4 ~G ~ Concerns and Contingencies Production Interval (7500' MD - TD): Mud Type: 9.8 ppg INVERMUL System 1. Mud weight: Drill out with a 9.8 ppg density. Adjust the weight to 10 ppg prior to 8,850' or as directed; use solids control and whole mud dilution. Increase density as required for hole stability/coal sloughing. Maximize solids control usage. 2. Rheology: Maintain a YP between 9 and 18. Pump high viscosity or Barolift sweeps throughout the interval as needed, particularly prior to POH for casing. Optimized mud rheology and flow rate will be the primary mechanisms for achieving hole cleaning in this wellbore. 3. Other issues: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to minimize the chances for losses and differential sticking. Please see the Coal Drilling recommendations attachment. Operations Summary: The water base mud system will be used to drill out the shoe and ca. 20 feet of new hole (unless operations can be worked out to bump the plug with the Invermul). Approximately 750 bbls of oil mud will be required for displacement. New mud will need built at the rig site. Prepare the pit system for the INVERMUL as follows: Endeavor #1 v1.0 6 10/10//05 Halliburton saROiD Aurora Gas Mud Program • Clean pits, solids control equipment, all lines and pumps. • Flush all lines with a small volume of oil and discard. • Disconnect all water lines to the pit area and rig floor. • Check all steam fittings in pit room for leaks and repair as needed. Once the shoe has been drilled, displace the well to the ENVIROMUL system designated for this interval of the well. Pump a 25 bbl spacer ahead of the oil mud as follows: Spacer Formulation: • 20 barrels of the OBM treated with GELTONE to a YP > 30 (app. 6-8 sx). Weight this pill to 2 ppg over the OBM weight. • Follow with INVERMUL mud system. Displacement procedure: • Monitor pump strokes to obtain correct displacement. • Maintain maximum pump rates. • Have the bit on bottom as the oil mud exits the bit. • Reciprocate the drill string by one joint every 15 minutes • Rotate the pipe as rapidly as allowed during the actual displacement. • Do not shut down during the displacement. • Use an E.S. meter at the flow line to determine when the fluid is water free enough to start taking the returns back into the system. An ES of 300-500 should be sufficient to indicate when displacement is complete. A retort should also be run at this time to confirm fluid quality. • Clean possum belly and any troughs which were used. Maintenance: 1. Additions of Geltone V and RM-63 will maintain/modify the system rheology to a YP between 9 and 18 to provide effective hole cleaning while controlling ECD and surge/swab pressures. Run the rheology checks at 120°F to TD. 2. OMC 42 will be available to condition (thin) the mud as required; however, caution should be used when using these oil mud thinners to avoid over-thinning the system. 3. Dri!! this interval with a tight DURATONE HT / AK-70 filtration mechanism (< 5 cc/30 min @ 200° F). Barablok and Barotrol will also be available to improve the filtration control mechanism. 4. For formation bridging/LCM, graded calcium carbonate (Baracarb(s)), cellulose fiber material (Barofibre) and SteelSeal are available. 5. The electrical stability of the mud should be run in the 1000-1100 volt range with INVERMUL and EZ MUL as the primary and secondary emulsifiers. DRILTREAT will be available as an effective wetting agent, if needed. 6. Maintain the water phase salinity between 270,000 - 290,000 mg/I range with sack calcium chloride. This level of salinity will .provide an effective mechanism for good well bore stabilization. 7. The excess lime content will be maintained in the 3 ppb range to provide an effective reserve alkalinity source and to improve the emulsion stability of the mud system. 8. The initial oil/water ratio will be 70:30. From there, the system will be maintained with base oil allowing the ratio to drift higher by TD. This will help reduce the cost of the original fluid and then help control rheology and ECD's with the higher ratio in the lower depths of the well. Endeavor #1 v1.0 7 10/10//05 Halliburton BaROiD Aurora Gas Mud Program ~ Suggested Drilling Parameters Pump rate should be optimized through the real-time use of the DFG software for the actual. ROP while drilling. The table below highlights the maximum ROP recommendations above which hole cleaning will become an issue. Maximum Acceptable ROP in fph at Specified GPM and RPM GPM 200 250 300 60 r m 146 189 247 80r m 146 189 247 Sweeps Two alternate types of hole cleaning sweeps can be used: • Increase the sweep density with SWEEPWATE to 2 ppg over system density. The SWEEPWATE will increase the sweep carrying capacity yet will be removed at the shakers; this will result in no density increase from running weighted sweeps. To reduce the density/viscosity build up in the system, sweeps can be built by adding 0.25 ppb BAROLIFT in place of the clay. The fibrous BAROLIFT will be removed at the shakers. Note: Properly size all sweeps for 300 - 400 ft of annular coverage Supplement the hole cleaning of the drilling fluid as dictated by hole cleaning indications. Monitor all sweeps pumped and report on their effectiveness. The objective of the sweep is to change the flow characteristics /carrying capacity that is inherent with the mud system. Select sweep type accordingly. Coal Drilling The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The hole stability risks when drilling coal seams are often high, and the fluid design and drilling operations have been optimized to combine reduced risk with reduced costs. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams. • Increase fluid density as required to control the running coal. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. In the -event that sloughing coal is encountered, consider spotting a 30 ppb BAROTROL pill across the coal seam. The pill can be safely "squeezed" into the coal by closing the bag and applying pressure not to exceed the total annular pressure loss (based on ECD values using the DFG software ). System density increases can also be employed in increments of 0.5 ppg. Solids Control Equipment Maximize the use of all solids control equipment to ensure that the solids content of the system is kept to a minimum during this interval Run the shale shakers with as fine a screen size as possible. • Size shakers screens with coarse mesh initially • Adjust screen size as solids loading, mud rheology and flowrates allow • Inspect the shakers frequently, taking time to repair /replace damaged screens 2. Maximize the use of the centrifuge, keeping the fluid as clean as possible. Endeavor #1 v1.0 8 10/10//05 ~ Halliburton BaROio Aurora Gas Mud Program ~ Running Casing /Cementing Preparation Monitor hole fill/returns closely while running the liner to insure losses haven't occurred. Refer to Baroid's DFG+ program if calculated surge/swab values are needed. Condition the mud prior to the cement job. Displace the cement with base diesel oil -ensure availability. Production Hole -Hazards /Concerns: • Optimize solids control equipment to minimize colloidal solids build up and dilution requirements. • Maintain flow profile based on PV, YP and tauo flow parameters. • Pump sweeps as required to enhance hole-cleaning efforts. Monitor the effectiveness of any sweeps pumped. • Follow the hole cleaning guidelines to assist in drilling parameter selection. Use connections for high RPM and pump rate support when these parameters are limited during drilling operations. • Follow the coal drilling guidelines. Estimated Fluid Costs P10 P50 P90 12'/4" Surface 18,000 35,000 62,000 8 %2" Intermediate 37,000 50,000 88,000 6 1/8" Production Oil 50,000* 105,000'~'~ 200,000 Total $105,000 $190,000 $350,000 * Assumes 600 bbls of used mud is available. *''`Assumes all new OBM is built. Endeavor #1 v1.0 9 10/10//05 Halliburton BaROi~ Aurora Gas Mud Program Surface Modeling X000 s3 hr f:l IT lime With pump rates of 400 gpm and 4"DP, penetration rates of 100'/hr will need augmented with sweeps and/or extra circulating time. Higher pump rates should be used, if possible. Endeavor #1 v1.0 10 10/10//05 Halliburton BaROro Intermediate Modeling Dpe~ator. Aurora Gas ell: Endeavor #1 Cuttings Transport Average Hole load, X Eff ava X V, ftlmin Anulr 2000 3000 400D 5000 6D00 ZOOD Mud Program KcLIEZ MUD Flog Rare = 400 gallmin POP =100 ftth~ ECD MudWeight = 9.8IhJgal Cutting Dia, =.15 in Ib! al P~1 s~ 100 ft1hr80 rpm ! HC~ fi0 rpm~3m t C=Sm 1 7 ut 8.835 in Cut 80,0 (8i i.Oj ft 10.006110.OOfi Ibtgal I I~I~ li,a~c in 250D,0 (25DO i1J ft 10.DOfi 110.1411btQal ~,e in .00 Z59D.0 7500.0 (i50D.OJ ft ~ fi.?5 K 2.813 N 5 1015 20 25 0 50 1000 173 345 30 fi0 90 9.80 10.30 10.8D 10.035110.1831btgal R hr f:l IT lime Excellent hole cleaning can be obtained with flow rates of 400 gpm in this vertical well. Aurora Gas Endeavor #1 v1.0 11 10/10//05 ~ Halliburton BaROi~ Aurora Gas Mud Program ~ Production Modeling 1000 • 2000 3000 • 4000 fi000 7000 8000 • operator: Aurora Ga ell: Endeavor #1 s :: Inve~mul Flov~ Rate = 300 gallmin RO P =125 ftlhr Cuttings Load, X Transport Eff av X Average V, ftlmin Hole An le EC Ib1 D al MudWeight =101blgal Cut R•1 sC~ 125 ftthr80rpm t HC• fi0 rpm•3 ting Dia m I C=S . =.15 in m t 1.24 .00 I w1o Cut fi?7fi in ~1 cr~t sD.D loo.o~ ft 0981bJ al 098111 11 j s . g . fi.276 in i f' f 5 0 0 ' ii 1.00 ~~ . ~) t 2 0 . (~ ` 11.0 t 11.238 Ibtgal 4 x 3.34 x 8780.0 ft ~~~~ ~ ~ fi,276 in 7500 ~ 50 j O f - 0 .85 t i . J t . 11.098111.2231b1gal .00 ~ fi 125 in 4. K 2.256 x 300.0 ft .00 9293 8 , 9200 0 0~~' i0 0 ft ` 4 75 25 120 0 f 2 5 1015 20 2 5 0 50 fi7 ~•0 24fi 492 30 fi0 9 01 0.00 11. 00 1 . 2.00 . ( 1 . ) 11.158111.2741h1gal . x x . t . 5 hr f:l IT lime Pump rates as low as 200 gpm can be used and good hole cleaning will be seen at ROP's of 125'/hr. Endeavor #1 v1.0 12 10/10//05 I Halliburton BaROi~ Aurora Gas Mud Program Losses Seepage 5-10 bbllhr Static Treat Active System with 5 sxlhr Barofibre Aurora Lost Circulation Decision Tree Partial Severe 15.60 bbllhr 60.200 bbllhrStatic Static Treat Active System 60-150 bbllhr Static 150-200 bbllhr Static with 10 sxlhr Barofibre Drill Across Fault I I Drill Across Fault Losses < 15 Yes bbllhr Drill Ahead No 5 sxlhr Barofibre ynamic Losses < 15 Yes bbllhr Drill Ahead No 40 ppb LCMIMud Pill: 10 ppb Baroseal F 10 ppb Baroseal M 10 ppb Barofibre 10 ppb Wallnut M Losses < 15 Yes bbllhr Drill Ahead No Proceed to'Partial Losses' Pill uynamlc 100 ppb LCM1Mud Pill: LOSSeS < 25 Yes 20 ppb Baroseal F bbllhr 20 ppb Baroseal M 30 ppb Barofibre Contact Drilling Engin Drill Ahead 20 ppb Wallnut M or En ineer on call 10 ppb Wallnut F No Contact Drilling Engineer or 70 ppb LCMIMud Pill: Engineer "On Call" 20 ppb Baroseal F Pump Gunk 20-ppb Baroseal M Squeeze pill 20 ppb Barofibre (Volume to be 10 ppb Wallnut M determined based upon losses) Losses < 15 Yes bbllhr Pump Gunk Drill Ahead Squeeze pill No Contact Drilling Engineer or Engineer on call to determine if additional LCM treatments are to be made or to proceed to Gunk Squeeze pill Total > 200 bbllhr Static I Drill Across Fault I Pump Gunk Squeeze pill to allow POH (Volume to be determined based upon losses Contact Drilling Engineer or Engineer on call POH, PU dumb iron BHA Consider cement ! plugback contingency Notes: 1) Drill across fault or loss zone 1.5 - 2.0 times the length of the throw before spotting Gunk Squeeze. 2) PBL sub should be run in BHA to spot pills if'Partial Loss' cases or above are anticipated prior to drilling to allow the spotting of LCM pills. 3) LCM pill volume = 300'-600' column based upon actual hole diameter. 4)PRIOR TO ANY LCM PILL, APPROPRIATE DISCUSSIONS AT THE RIG MUST BE MADE TO MINIMIZE THE POTENTIAL FOR PLUGGING THE DRILL STRING. Endeavor #1 v1.0 13 10/10//05 I Halliburton BaROi~ Aurora Gas Mud Program Losses Seepage 5-20 bbllhr Static Treat Active System with 5 sxlhr Baracarb 501150 Losses < 15 Yes bbllhr No Drill Ahead Increase Treatment to 10 sxlhr Baraarb 501 150 ynamic LOSSes < 15 Yes bbllhr Drill Ahead No 20 ppb LCM1Mud Pill: 20 bbls base mud 10 ppb Baracarb 50 10 ppb Baracarb 150 Losses < 15 Yes bbllhr Drill Ahead No Proceed to'Partial Losses' Pill Aurora Lost Circulation Decision Tree fl Payzone Mud Systems 200 bbllhr Static with 10 sxlhr Baracarb 150 Losses < 15 Yes bbllhr Drill Ahead No 50 ppb LCMIMud Pill: 20 bbls Base mud 10 ppb Baracarb 25 20 ppb Baracarb 50 20 ppb Baracarb 150 LOSSeS < 20 Yes bbllhr Drill Ahead No Contact the Engineer on call to determine if additional LCM treatments are to be made or to proceed to reverse gunk squeeze pill Severe 60.200 bbllhr Static 60-150 bbllhr Static ( 1150-200 bbllhr Static I Drill Across Fault I 100 ppb LCMIMud Pill: 20 ppb Baroseal f 20 ppb Baracarb 50 30 ppb Barofibre ZO ppb SteelSeal 10 ppb Baracarb 150 I Drill Across Fault I Pump reverse gunk squeeze pill to allow POH (Volume to be determined based upon losses) Contact Drilling Engineer or Engineer "On Call" Pump reverse gunk squeeze pill (Volume to be determined based upon losses or Engineer on call Total > 200 bbllhr Static I Drill Across Fault I Pump reverse gunk squeeze pill to allow POH (Volume to be determined based upon losses Contact Driiling Engineer or Engineer on call Plan to pump a second 50-80 bbl reverse gunk squeeze pill if massive losses continue. Consider cement I plugback contingency 1)Aurora must approve any steps past PARTIAL losses. 2) Drill across fault or loss zone 1.5 - 2.0 times the length of the throw before spotting reverse gunk squeeze pills. 3) PBL sub should be run in BHA to spot pills if'Partial Loss' cases or above are antiapated poor to drilling to allow the spotting of LCM pills. 4) LCM pill volume = 300'00' column based upon actual hole diameter 5)PRIOR TO ANY LCM PILL, APPROPRIATE DISCUSSIONS AT THE RIG MUST BE MADE TO MINIMIZE THE POTENTIAL FOR PLUGGING THE DRILL STRING. Endeavor #1 v1.O 14 10/10//05 r~ Aurora Gas, LLC Endeavour#1 Kenai County, Alaska November 4, 2005 Well Recommendation Prepared for: Bill Penrose Fairweather E&P Bus Phone: 907-258-3446 Mobile: 907-250-3113 i r~ I Proposal No: 179550883A Prepared by: Dave Susko Region Engineer Bakersfield, California Bus Phone: 661-396-4446 Mobile: 661-201-0873 POWERVISION~ POWERPRO • POW F.R~T~RAX • POW ERLt N K Service Point: Service Representatives: Kenai, AK Rod Edwards Bus Phone: (907) 776-4084 Account Manager (907) 659-2329 Anchorage, Alaska Fax: (907) 776-4087 Bus Phone: 907-349-6518 Mobile: 907-229-6536 Gr41 Q5 ~ s Operator Name: Aurora Gas, LLC Well Name: Endeavour #1 Job Description: 9-5/8" Surface Casing @ 2500 ft Date: November 4, 2005 Proposal No: 179550883A JOB AT A GLANCE Depth (TVD) 2,500 ft Depth (MD) 2,500 ft Hole Size 12.25 in Casing Size/V1leight : 9 5/bin, 40 Ibs/ft Pump Via 9 5/8" O.D. (8.835" .I.D) 40 Total Mix Water Required 6,086 gals Spacer Mud Clean II 30 bbls Density 8.4 ppg Lead Slurry Surface Lead Blend 327 sacks Density 12.5 ppg Yield 2.12 cf/sack Tail Slurry Surface Tail Blend 438 sacks Density 15.8 ppg Yield 1.15 cf/sack Displacement Drilling Mud 184 bbls Density 9.8 ppg Report Printed on: November 4, 2005 7:03 PM Gr4109 Operator Name: Aurora Gas, LL~ Well Name: Endeavour #1 ~ Job Description: 9-5/8" Surface Casing @ 2500 ft Date: November 4, 2005 Proposal No: 179550883A WELL DATA ANNULAR GEOMETRY ANNULAR I:0. DEPTH (in) MEASURED TRUE VERTICAL 12.415 CASING ~ 80 ~ 80 12.250 HOLE ~ 2,500 ~ 2,500 SUSPENDED PIPES Float Collar set @ 2,420 ft Mud Density 9.80 ppg Est. Static Temp. 77 ° F Est. Circ. Temp. 70 ° F VOLUME CALCULATIONS 80 ft x 0.3354 cf/ft 1,420 ft x 0.3132 cf/ft 1,000 ft x 0.3132 cf/ft 80 ft x 0.4257 cf/ft with 0 % excess = with 50 % excess = with 50 % excess = with 0 % excess = TOTAL SLURRY VOLUME _ 26.8 cf 667.5 cf 470.6 cf 34.1 cf (inside pipe) 1199.0 cf 214 bbls Report Printed on: November 4, 2005 7:03 PM Gr4115 Operator Name: Aurora Gas, LLC ~ Well Name: Endeavour #1 Job Description: 9-5/8" Surface Casing @ 2500 ft Date: November 4, 2005 Proposal No: 179550883A FLUID SPECIFICATIONS Spacer 30.0 bbls Mud Clean II @ 8.4 ppg VOLUME VOLUME FLUID CU-FT FACTOR AMOUNT AND TYPE OF CEMENT Lead Slurry 694 / 2.1 = 327 sacks Class G Cement + 2% bwoc Calcium Chloride + 0.4% bwoc CD-32 + 1 gals/100 sack FP-6L + 2% bwoc Sodium Metasilicate + 106.7% Fresh Water Tail Slurry 505 / 1.1 = 438 sacks Class G Cement + 0.4% bwoc CD-32 + 0.8% bwoc FL-62 + 1 gals/100 sack FP-6L + 43.6% Fresh Water Displacement 183.5 bbls Drilling Mud @ 9.8 ppg CEMENT PROPERTIES SLURRY SLURRY NO. 1 N0.2 Slurry Weight (ppg) 12.50 15.80 Slurry Yield (cf/sack) 2.12 1.15 Amount of Mix Water (gps) 12.03 4.91 Amount of Mix Fluid (gps) 12.04 4.92 Report Printed an: November 4, 2005 7:03 PM Gr0129 Operator Name: Well Name: Job Description: Date: Aurora Gas, LLC Endeavour#1 9-5/8" Surface Casing @ 2500 ft November 4, 2005 ~~ I•J Proposal No: 179550883A PRICE ESTIMATE Product Material QTY UNIT PRODUCT DESCRIPTION NET AMOUNT 765 941bs Class G Cement 23,078.52 615 Ibs Calcium Chloride 584.50 615 Ibs Sodium Metasilicate 1,492.24 1 ea Cement Plug, Rubber, Bottom 9-5/8 in 450.00 1 ea Cement Plug, Rubber, Top 9-5/8 in 240.48 1260 gals Mud Clean I I 1,251.94 288 1bs CD-32 2,260.22 8 gals FP-6L 495.36 330 1bs FL-62 4,217.40 Product Material Subtotal: $34,070.66 Service Charges QTY` UNIT I PRODUCT DESCRIPTION NET AMOUNT 12 hrs Service Supervisor -hourly charge 1,062.72 24 hrs Equipment Operator -hourly charge 1,740.96 1 ea Personnel Surcharge -Cement Svc 148.00 804 cu ft Bulk Materials Service Charge 1,904.52 Service Charges Subtotal: $4,856.20 Customer will be charged for all 'SPECIAL PROPPANTS' delivered to location, whether they are pumped or not. All proppants other than standard grade frac sand are considered 'SPECIAL PROPPANTS'. The technical data contained in this proposal is based on the best information available at the time of writing and is subject to further analysis and testing. The pricing data contained in this proposal are estimates only and may vary depending on the work actually performed. Pricing does not include federal, state and local taxes or royalties. This quotation is based on BJ Services Company being awarded the work on a first call basis and within thirty (30) days of the proposal date. These prices will be subject to review if the work is done after thirty (30) days from the proposal date, or on a second or third call basis. Report Printed on: November 4, 2005 7:03 PM Gr4161 • Operator Name: Well Name: Job Description: Date: Aurora Gas, LLC Endeavour#1 9-5/8" Surface Casing @ 2500 ft November 4, 2005 Proposal No: 179550883A PRICE ESTIMATE Equipment QTY UNIT PRODUCT QESCRIPTION NET AMOUNT 1 4hrs Cement Pump Casing, 2001 - 3000 ft 3,096.00 3 ea Radio Communications 440.64 1 job Cement Head 374.40 1 job Data Acquisition, Cement, Standard 975.60 70 miles Mileage, Heavy Vehicle 360.36 140 miles Mileage, Auto, Pick-Up or Treating Van 409.25 Equipment Subtotal: $5,656.25 Freight/Delivery Charges QTY UNtT PRODUCT DESCRIPTION NET AMOUNT 2581 tonmi Bulk Delivery, Dry Products 4,459.97 Freight/Delivery Charges Subtotal: $4,459.97 TOTAL: $49,043.08 Customer will be charged for all 'SPECIAL PROPPANTS' delivered to location, whether they are pumped or not. All proppants other than standard grade frac sand are considered 'SPECIAL PROPPANTS'. The technical data contained in this proposal is based on the best information available at the time of writing and is subject to further analysis and testing. The pricing data contained in this proposal are estimates only and may vary depending on the work actually performed. Pricing does not include federal, state and local taxes or royalties. This quotation is based on BJ Services Company being awarded the work on a first call basis and within thirty (30) days of the proposal date. These prices will be subject to review if the work is done after thirty (30) days from the proposal date, or on a second or third call basis. Report Printed on: November 4, 2005 7:03 PM Gr4161 Operator Name: Aurora Gas, LLC ~ Well Name: Endeavour #1 Job Description: 7" Production Casing @ 9200 ft Date: November 4, 2005 Proposal No: 179550883A JOB AT A GLANCE Depth (TVD) 9,200 ft Depth (MD) 9,200 ft Hole Size 8.5 in Casing Size/V1/eight : Tin, 23 Ibs/ft Pump Via 7" O.D. (6.366" .I.D) 23 Total Mix Water Required 5,536 gals Weighted Spacer MCS-4 Spacer 30 bbls Density 11.5 ppg Lead Slurry Production Lead Blend 254 sacks Density 12.5 ppg Yield 2.10 cf/sack Tail Slurry Production Tail Blend 508 sacks Density 15.8 ppg Yield 1.15 cf/sack Displacement Drilling Mud 359 bbls Density 11.2 ppg Report Printed on: November 4, 2005 7:03 PM Gr4109 Operator Name: Aurora Gas, LLC r Well Name: Endeavour #1 Job Description: 7" Production Casing @ 9200 ft Date: November 4, 2005 Proposal No: 179550883A WELL DATA ANNULAR GEOMETRY ANNULAR LD. TH (in) MEASURED TRUE VERTICAL 8.835 CASING ~ 2,500 ~ 2,500 8.500 HOLE ~ 9,200 ~ 9,200 SUSPENDED PIPES Float Collar set @ 9,120 ft Mud Density 11.20 ppg Est. Static Temp. 151 ° F Est. Circ. T VOLUME CALCULATIONS 3,000 ft x 0.1268 cf/ft 3,200 ft x 0.1268 cf/ft 80 ft x 0.2210 cf/ft emp. with with with TOTA 130°F 40 % excess = 533.2 cf 40 % excess 568.4 cf 0 % excess = 17.7 cf (inside pipe) ,L SLURRY VOLUME = 1119.2 cf = 200 bbls Report Printed on: November 4, 2005 7:03 PM Gr4115 Operator Name: Aurora Gas, LLC ~ Well Name: Endeavour #1 Job Description: 7" Production Casing @ 9200 ft Date: November 4, 2005 Proposal No: 179550883A FLUID SPECIFICATIONS Weighted Spacer 30.0 bbls MCS-4 Spacer + 6 Ibs/bbl MCS-D + 8.62 Ibs/bbl Potassium Chloride + 28.85 Ibs/bbl Bentonite + 146 Ibs/bbl Barite -Sacked @ 11.5 ppg VOLUME VOLUME FLUID CU-FT FACTOR AMOUNT AND TYPE OF CEMENT Lead Slurry 533 / 2. = 254 sacks Class G Cement + 2.2% bwoc Sodium Metasilicate + 0.5% bwoc FL-62 + 0.2% bwoc CD- 32 + 1 gals/100 sack FP-6L + 105.8% Fresh Water Tail Slurry 586 / 1.1 = 508 sacks Class G Cement + 1 gals/100 sack FP- 6L + 0.2% bwoc Sodium Metasilicate + 0.7% bwoc FL-62 + 0.3% bwoc R-3 + 43.8% Fresh Water Displacement 359.0 bbls Drilling Mud @ 11.2 ppg CEMENT PROPERTIES SLURRY SLURRY NO. 1 NO.2 Slurry Weight (ppg) 12.50 15.80 Slurry Yield (cf/sack) 2.10 1.15 Amount of Mix Water (gps) 11.93 4.93 Amount of Mix Fluid (gps) 11.94 4.94 Report Printed an: November 4, 2005 7:03 PM Gr4129 • • ;, ~~~ r~IO~~ ' ~O.A~A~ " FIRSANCHORAGE~AK 9 52DS~ 2 ~ 0 10333 RICHMOND AVE, SUITE^71d6\' 89-s/i252 HOUSTON TX, 77tl42 12/8/20b5 .713-977-5799' ~ ~„ s.'~g&~'s'~ 10~ 9~' w PAY t0 THE _ :,~.,...=a^a'~"~+"TM° ~~~'~~.hy~xs ~~~'" ~ k ~' t ~R i ~ ,_, I ~ 100,00 ORDER OF CiatP~nLAlaska .,,. ~,~ ~g frGS,~'~3u"' i,Re ~~ ~~ ~,~~s~r ^"•~ ***k#k#kk#k##kkkkkkklk**++*+#+k++*+i4$1IF##~{ k+# ~"~#~~`~91~I<`k~#i~#kkkkkkkkkk#kkkkkkk#kk#kkkkkk#*kk b -9na Flundred and Op/100 ~ ~ _ ~ ~ _ ,a,~t° DOLLARS 8 ' z~ ~.. , rar , ' .~ ~r~a xa ~ u~~.4 ;,; State of Alaska ~ .~~.,f ~ ~ , v.,+a« d ~= I i~ w MEMO-Endeavour # 1 APU tt'00 2904tt' ~; L 2 5 200060: 30 20 389 711' • • TRANSNIITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO SE INCLUDED IN TR.ANSvIITTAL LETTER WELL NAME ~i~(~/r i/ ! ~ /- PTD# ` /ice CHECK WHAT APPLIES ADD-ONS "CLUE" (OPTIONS) ~ MULTI The permit is for a new wellbore segment of LATERAL ~ existing well , Permit No, API No. (If API number ~ Production should continue to be reported as last two (2) digits ~ a function of the original API number stated are between 60-69) above. G, C~/~ ~11G f G 7~~ ~'~ ~ t !~3 '~~ ' ~C 1 ~ ~fbLt, - PILOT HOLE ; In accordance with 20 AAC 25.005(f), al! (P~ j records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - I 70/80) from records, data and logs acquired i for well (name on permit). SPACING j The permit is approved subject to full EXCEPTION I compliance with 20 AAC 25.055. Approval to perforate and groduce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH SAMPLE All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\j ody\transm ittal_ch ec klist • 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. ~o~ - ~~ 3 ~ ~ Aurora Power ENDEAVOUR 9 a~S-~c3 SEC 3 - T5S - R15W - SM • April 7, 2006 -May 6, 2006 Craig Silva: Senior Logging Geologist Lees Browne: Senior Logging Geologist Ralph Winkelman: Senior Logging Geologist ~ [~ EPOCH AURORA GAS, LLC ENDEAVOUR 1 • TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT AND CREW ............ .....................................................................................2 1.1. EQU/PMENT SUMMARY ........................ .....................................................................2 1.2. PERSONNEL .......................................... ........................................•----........................2 2. GENERAL WELL DETAILS ........................................................................................:...............................3 2.1. OBJECTIVES .......................................... ..................................................................... 3 2.2. WELL RESUME ...................................... ..................................................................... 3 2.3. HOLE DATA ............................................ ........•---......................................................... 3 3. GEOLOGICAL DATA ........................................... ......................................................................................4 3.1. LITHOLOGY REVIEW ............................. ..................................................................... 4 4. DRILLING DATA ...............................•---------•---..........................................................------.........................18 4.1. DAILYACT/VITY SUMMARY .................. ...................................................................18 4.2. MUD RECORD ....................................... ................................................................... 24 4.3. B/T RECORD .......................................... ................................................................... 26 4.4. DRILLING PROGRESS CHART ............. ...................................................................27 4.5. SAMPLE /NVENTORY ............................ ................................................................... 28 • 4.6. CORE REPORT ...................................... ................................................................... 29 DAILY REPORTS APPENDIX I FORMATION LOGS APPENDIX II DRILLING DYNAMICS LOGS APPENDIX III • ~~ EPOCH 1 • ~h1/7Qt"~# @l AURORA GAS, LLC ENDEAVOUR 1 1 MUDLOGGING EQUIPMENT AND CREW 1.1. EQUIPMENT SUMMARY C] • Parameter Equipment Type And Position Total Downtime Comments Ditch Gas QGM Electric Trap Mounted In Possum Belly; FID Total Hydrocarbon Analyzer And Chromatograph 0 Rate of Penetration (ROP} Primary Drawworks Shaft Encoder On Drum Shaft N/A WITS feed from PASON rig s stem Pump stroke counter Externally Mounted Magnetic Proximity Sensor N/A " Hookload /Weight on bit (WOB) Hydraulic Pressure Cell N/A " Drill string torque Digital Signal From Top Drive N/A " Top drive rotary (RPM} Non-Functional on Glacier #1 N/A " Standpipe Pressure Hydraulic Pressure Cell N/A " Mud flow in /out (MFI / MFO) MFI Derived From SPM / MFO From Flow Paddle N/A " Pit volumes Ball Float Pit Sensors In All Pits And Trip Tank N/A " Driller's work station Explosion Proof Touch Screen N/A " Casing Pressure Hydraulic Pressure Cell N/A " Company man's work station HP COMPAQ N/A None Tootpusher's work station HP COMPAQ NIA None Geologist's work station HP COMPAQ NIA None Pit's work station Explosion Proof Touch Screen N/A None 1.2. PERSONNEL Unit Number: ML004 Endeavour 1 Mudloggers Years Experience Days at well Sample Catchers Days at well Technician Days at well Craig Silva 27 16 Patrick Walker 10 Steve Forrest 3 Lees Browne 25 31 Edward Revollo 19 Howard Lamp 2 Ralph Winkelman 15 15 Dan Lee 9 ~~ EPOCH 2 2.1. OBJECTIVES AURORA GAS, LLC ENDEAVOUR 1 2. GENERAL WELL DETAILS The objective of AURORA ENDEAVOUR 1 is to successfully drill and log an exploration well through Lower Tyonek, Hemlock and West Foreland formations, with a minimum of hole or other problems, set 7" casing and proceed with testing procedures to fully assess the gas and oil potential available on the lease holding. Determinations on well follow-up and future drilling activities to be determined after all evaluations are completed. 2.2. WELL RESUME Operator: AURORA GAS, LLC Well Name: ENDEAVOUR 1 Field: Exploration County: Kenai Peninsula Borough State: Alaska Company Representatives: Jack McDade Jon West Location: -~"~ ~"^~-oe~.~ ~4N 1~11W SIB Y-~7~~8.7~ Y-2~~~~~.~1 Classification: Exploratory API #: Permit #: ''.~-~'n- Activity Code: (WBS #s) DD.06.13353.CAP.DRL, DD.06.13353.CAP.CMP Rig Name /Type: Kuukpik Drillers 5 /Land /Double levation: Ground, RKB 145' GL, 166' RKB rimary Target: /Target Depth: Hemlock Secondary Targets: /Target Depths: Lower Tyonek (Starichkof Sands), West Foreland Spud Date: April 7, 2006 Total Depth 9225' Total Depth Formation: West Foreland or Cretaceous Total Depth Date: May 6, 2006 MWD Company: /Tools Run: None Directional Drilling: None Drilling Fluids Company: BAROID Drilling Fluids Lagging Companies: Schlumberger Wireline Services: Quad-Combo logging suite on shuttle C. Hole Maximum Depth T D Mud Deviation Shoe Depth F.I.T. Section MD SSTVD Formation Weight (PP9) (°inc) Casing.. MD SSTVD EMW 12 '/" 2465' 9.3 3.9 9 5/8" 2457' 17.9 $ '/2" 9225' 9.3 4.0 2.3. HOLE DATA Endeavour 1 ~~ EPOCH 3 ~ ~11-'Of i8 @I' AURORA GAS, LLC ENDEAVOUR 1 • 3. GEOLOGICAL DATA 3.1. LITHOLOGY REVIEW TUFFACEOUS SILTSTONE (2280'-2320') =LIGHT GRAYISH BROWN WITH FAINT OLIVE GRAY SEC HUE TO OLIVE GRAY; MANY SUBTLE INTERMEDIATE COLOR AND HUE VARIATIONS; EST 50% SOFT-SCI FRM, 50% MOD FRM-BRIT; SILTY TO CLAYEY TO ASHY TO VARIOUS MATTE TEXTS; EARTHY LUSTRE; MOST APPS MASSIVE. TUFFACEOUS SILTSTONE {2330'-2390') =VERY LIGHT GRAY TO LIGHT GRAY SOME LIGHT BROWNISH GRAY AT 2390'; GENERAL VERY POOR TO POOR INDURATION; SLIGHT TO MODERATE 5ECTILE IN CLAYEY SECTIONS; LUMPY TO CLUMPY; CLUSTERED TO CLOTTED; MUSHY TO PASTY; TACKY TO SLIMY; VARIOUS CONSISTENCIES; NpN TO VERY POOR COHESIVE MODERATE ADHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT; EARTHY TO SUBGREASY LUSTER; SILTY TO CLAYEY TEXTURE; MASSIVE GRADATIONAL SILTS AND CLAY; MINOR INTBD SANDS; MODERATELY HYDROPHILIC. COAL (2400'-2420 =BLACK; FIRM TO HARD RESINOUS LUSTER; MATTE TEXTURE; CONCH TO HACKLY FRACTURE; VISIBLE BLEEDING GASFROM FRESH BROKEN CUTTINGS. TUFFACEOUS SILTSTONE {2390'-2465') =MAJOR CHARACTERISTICS CONSISTENT WITH ABOVE; LT BRNISH GRY TO MED LT GRY TO LT OLIVE GRAY; NOTE "ASHIE$T" SLTST OFTEN HAS V FNT GRYSH ORNG PNK SEC HUE; NOTE COM ASSOCIATED ASHY SLTY SS, LOCALIZED HARD CALCAREOUS TUFF AND BRIT-HARD MED DK GRY OLIVE GRY CALCAREOUS TUFF SLTST. SAND {2465'-2525 =VERY LIGHT GRAY; CLAST SIZE RANGE: MEDIUM UPPER TO FINEUPPER; • SURROUND TO SUBANGULAR; MODERATE DEVELOPED SPHERICITY; MODERATE TO POOR SORTING; IMPACTED TEXTURE; IMMATURE NATURE; NON TO SLIGHT SILIC CEMENT; HEAVLY INTERBEDDED WITH ABUNDANT CLAY STRUCTURED MATRIX; LOOSELY ATTACHED; DOMINANT MATRIX SUPPORT; COMPOSED OF 90% QTZ, 10% CRT, TUFF AND VARIOUS MINOR CITRIC FRAGMENTS; POOR POROSITY AND PERMEABILITY; NO SHOW OF OIL. COAUCARBONACEOUS CLAY AND SHALE (2525'- 2610') BLACK IN COAL TO BROWNISH GRAY TO DARK YELLOWISH BROWN MOTTLED BROWNISH BLACK; THIN BEDDED FIRM COALS WITH VERY SOFT CARB CLAY AND SHALE; VERY SOFT TO SOFT; EARTHY FRACTURE; MICRO CARE SHALE LAMINAE GRADING TO COAL IN PARTS; VERY GRADATIONAL; BECOMING MODERATELY CARBONACEOUS c~ 2600 ;CLAYEY TO COLLOIDAL TEXTURES; VERY DETRITALISH AND OVERALL DIRTY APPEARANCE. SAND (2600'-2655') =VERY LIGHT GRAY; CLAST SIZE FINE LOWER TO VERY FINE LOWER GRADING TO SILT; SURROUND; MODERATE DEVELOPED SPHERICITY; POOR SORTING; IMPACTED TEXTURE; IMMATURE NATURE; NON TO SLIGHT SILIC CEMENT; DOMINANT CLAY STRUCTURED MATRIX; LOOSELY ATTACHED w/ VARIOUS CARBON DETRITAL MATERIAL FINES; COMPOSED OF >90% QTZ; POOR POROSITY AND PERMEABILITY; NO SHOW OF OIL. TUFFACEOUS CLAYSTONE (2280-2730') =MEDIUM LIGHT GRAY TO MEDIUM DARK GRAY; LIGHT GRAY WHEN MORE CLOSELY GRADATIONAL LESS REWORKED VOLCANIC ASH; FAINT TO VERY STRONG LIGHT BROWNISH GRAY SECONDARY HUES; MANY CLOSE VARIATIONS OF GRAY AND BROWN COLORS AND SECONDARY HUES IN VERY MINOR AMOUNTS; VERY SOFT TO VERY SLIGHTLY FIRM; 95% IS SOFT, MUSHY, HYDROPHILIC, EXPANSIVE WHEN HYDRATED AND ENTIRELY OR PARTIALLY SOLUBLE; CLAYEY TO ASHY TO SILTY TEXTURES; EARTHY LUSTRE; LOCALLY MICROSPARKLY WHEN ASHY CONTENT INCREASES. SAND/SANDSTONE (2730'-2800') =GREENISH GRAY TO OLIVE GRAY WITH MEDIUM GRAY SECONDARY HUES; CLOSELY RANGES TO MEDIUM GRAY WITH VERY STRONG GREENISH ~~ EPaCH 4 ~4urora I ~bwer AURORA GAS, LLC ENDEAVOUR 1 • GRAY OR OLIVE GRAY SECONDARY; ALSO VERY FAINT LIGHT GRAYISH BROWN SECONDARY HUE OVERALL;VERY FINE UPPER TO COARSE LOWER; MOST IS MODERATE TO MOD WELL SORTED AT FINE UPPER TO MEDIUM UPPER CUTOFF; ANGULAR Tp SUBANGULAR, AND DISCOIDAL TO SUBDISCOIDAL; PERVASIVELY DISAGGREGATED WITH SPOTTY CONSOLIDATED PIECES THAT ARE MIXED GRAIN AND MATRIX SUPPORTED BY VARIOUS COMBINATIONS OF CALCITE (AND TRACE SILICA) CEMENTATION AND MATRIX MATERIAL OF VOLCANIC ASH DERIVED SEDIMENT; SUBLITHIC ARENITE TO LITHIC ARENITE; SLIGHTLY "DIRTY" SALT AND PEPPER APPEARANCE; DARK GRAINS ARE DOM ARGILLITE-PHYLLITE METALITHIC ROCK FRAGS WITH AMOUNT OF OTHER DIVERSE LITHICS. TUFFACEOUS SANDSTONE (2800'-3100'} =LIGHT GRAY TO MEDIUM LIGHT GRAY; COMMON FAINT TO VERY FAINT SECONDARY HUES INCLUDE LIGHT BROWNISH GRAY, LIGHT OLIVE GRAY, YELLOWISH GRAY, AND OCCASIONAL PINKISH GRAY TO GRAYISH ORANGE PINK; VERY FINE LOWER TO FINE UPPER; NOTE THAT VERY FINE FRACTION HAS GLASS SHARDS PREVIOUSLY WINNOWED FROM VOLCANIC ASH AND REDISTRIBUTED WHICH SHOULD NOT BE CONFUSED WITH "FRESHER" SHARDS AND MICROSHARDS WHICH ARE AN INCLUSIVE PART OF THE SUPPORTING ASH MATRIX; ANGULAR TO SURROUNDED; OCC SLIGHTLY CALCAREOUS; COMPOSITION IS LITHIC G2UARTZ ARENITE TO SUBLITHIC ARENITE; DISPLAYS MOST OF THE SAME SAND CHARACTERISTICS AS OTHER SANDS DESCRIBED PREVIOUSLY WHEN THE MATRIX IS WASHED AWAY, BUT ALSO HAS MANY OF THE SAME CHARACTERISTICS AS THE TUFFACEOUS CLAYS WHEN THE MATRIX VOLUME INCREASES; OFTEN CLOSELY GRADATIONAL TO VERY SAND TUFFACEOUS CLAYSTONE AND VOLCANIC ASH; SOME OF THE TUFFACEOUS SANDSTONE HAS THIN MICROBEDS OF NON-TUFFACEOUS ANDUSUALLY CALCAREOUS GRAIN SUPPORTED SS. CALCAREOUS TUFF (2800'-3100 =FAIRLY CONSISTENT IN AT LEAST TRACE AMOUNTS, AND ALMOST INCREASES IN ABUNDANCE AT VERY SLOW DRILLING ZONES; NOTE ZONE AT 2905' TO • 2910' WAS 80-100°lo CALC TUFF; MOST COMMON COLOR VARIATION IS PALE YELLOWISH BROWN TO GRAYISH ORANGE, WITH LESS ABUNDANT BUT STILL COMMON MEDIUM GRAY WITH THE FORMER COLORS AS SECONDARY HUES; ALSO LOCALLY COLOR VARIATION WITH DECREASED LIGHTNESS VALUES TO DARK YELLOWISH ORANGE; BRITTLE TO MARGINALLY HARD TO OCCASIONALLY MODERATELY HARD; MODERATE TO VERY CALCAREOUS, AND OFTEN LATER REPLACED BY SILICA; IRREGULAR TO THIN BLADED PLATY HABIT; ROUGH SHALINESS TUFFACEOUS SILTSTONE (3100'-3210') = LT BROWNISH GRAY TO PALE YELLOWISH BROWN; VERY POOR TO MODERATE INDURATION; MUSHY TO PASTY; SOME CLUSTERED TO CLOTTED; SL COHESIVENESS SLIGHT TO MODERATE ADHESIVE EARTHY FRACTURE; SUBBLOCKY TO SUBPLATY HABIT; DULL EARTHY LUSTER; SILTY TO ASHY TEXTURE; MASSIVE GRADATIONAL BEDS OFTUFFACEOUS SILT, MINOR SANDS (SOME BEING TUFFACEOUS) AND CARBONACEOUS MATERIAL. TUFFACEOUS SILTSTONE (3210'-3240') =YELLOWISH GRAY; VERY SOFT; LUMPY TO CLUMPY; CLUSTERED TO CLOTTED; MUSHY TO PASTY; NON TO SLIGHT COHESIVENESS; SL ADHESIVE; SUBNODULAR TO AMORPHOUS HABIT; HYDROPHILIC; MODERATE EARTHY LUSTER; INTERBEDDED AND GRADING TO TUFFACEOUS SANDSTONE IN PARTS; CLAYEY TO SILTY SOME GRITTY TEXTURE; MASSIVEGRADATIONAL BEDS; VERY DETRITALISH. TUFFACEOUS SANDSTONE (3230'-3270'} = LT GRAY TO VERY LIGHT GRAY; CLAST SIZE RANGES FROM FINE LOWER TO VERY FINE LOWER GRADING TO SILT; SURROUND; MODERATE SOME WELL DEVELOPED SPHERICITY; POOR SORTING; PITTED TEXTURE; IMMATURE NATURE; NON TO VERY SLIGHT SILK CEMENT; DOMINANT TUFF AND ASH SUPPORTED MATRIX MATERIAL; LOOSELY ATTACHED AND GRADING TO TUFFACEOUS SILTSTONE; COMPOSED OF PREDOMINANTLY QUARTZ; POOR POROSITY AND PERMEABILITY; NO OIL SHOWS. I~ EPOCH 5 Aurora Power AURORA GAS, LLC ENDEAVOUR 1 • TUFFACEOUS SILTSTONE (3270'-3360') =LIGHT BROWNISH GRAY TO PALE YELLOWISH BROWN BECOMING MEDIUM LIGHT GRAY AT\ 3360 ;POOR INDURATION SOME BECOMING FIRM TO STIFF IN LOCAL PARTS; SLIGHTLY SECTILE; MUSHY; SLIGHT TO MODERATE COHESIVE; NON TO MODOERATE ADHESIVENESS; EARTHY FRACTURE; SUBNODULAR TO SUBWEDGE HABIT; MODERATE EARTHY LUSTER; SILTY TO CLAYEY TEXTURE; MASSIVE HOMOGENEOUS BED OF TUFFACEOUS SILT AND INTERBEDDED WITH TUFFACEOUS SAND IN PART UNIFORM STRUCTURE WITH MICRO LAMINAE OF CARBONACEOUS MATERIAL WITH NO PLANAR ORIENTATION TUFFACEOUS SANDSTONE (3360'-3420') =PALE YELLOWISH BROWN; CLAST SIZE RANGES FROM VERY FINE UPPER TO VERY FINE LOWER GRADING TO SILT; SURROUND SOME ROUNDED; MODERATE SOME WELL DEVELOPED SPHERICITY; POOR SORTING; POLISHED TO PITTED TEXTURE IMMATURE NATURE; NON TO VERY SLIGHT SILK CEMENT; DOMINANT TUFF/ASH SUPPORT OF MATRIX; LOOSELY ATTACHED AND GRADING TO TUFFACEOUS SILTSTONE; COMPOSED OF >90% QUARTZ; POOR POROSITY AND PERMEABILITY; NO SHOW OF OIL. TUFFACEOUS SILTSTONE (3420'-3480') =PALE YELLOWISH BROWN; VERY POOR TO POOR INDURATION; LUMPY TO CLUMPY; CLUSTERED TO CLOTTED; MUSHY TO PASTY; NON TO SLIGHT COHESIVENESS; SLIGHT TO MODERATE ADHESIVE; EARTHY FRACTURE; SUBNODULAR HABIT; MODERATE EARTHY LUSTER; SILTY TO ASHY TEXTURE; MASSIVE GRADATIONAL BED OF SILT AND VERY FINE GRAIN SANDS. TUFFACEOUS SANDSTONE (3490'-3585') =LIGHT BROWNISH GRAY TO PALE YELLOWISH BROWN; CLAST SIZE RANGES FROM VERY FINE UPPER TO VERY FINE LOWER AND GRADING TO SILT; MODERATE TO SOME WELL DEVELOPED SPHERICITY; POpR SORTING; POLISHED AND PITTED TEXTURE; IMMATURE NATURE; NON TO VERY SLIGHT SILK CEMENT; DOMINANT • TUFF AND ASH MATRIX SUPPORT AND GRADING TO TUFFACEOUS SILTSTONE; LOOSELY ATTACHED MATRIX; SOME GOING INTO SOLUTION; COMPOSED OF >90% QUARTZ WITH MINOR CITRIC FRAGMENTS; POOR POROSITY AND PERMEABILITY; NO SHGOW OF OIL. DEVIT ASH (3585'-3610') =WHITE MOTTLED VERY LIGHT GRAY; VERY POOR INDURATION; HYDROPHILIC; MODERATE TO BRIGHT EARTHY LUSTER; ASHY TO SILTY TEXTURE; INTER BEDDED WITH TUFFACEOUS SANDSTONE AND TUFFACEOUS SiLTSTONE; APPEARS REWORKED AND REDEPOSITED; DETRITALISH; VISIBLE PYROCLASTIC RELIC SHARDS; OCCURS AS THIN TO THICK BEDS OF SUBTUFFITE. TUFFACEOUS CLAYSTONE (3610'-3640') LIGHT BROWNISH GRAY; VARY SOFT TO SOFT SOME BECOMING FIRM LOCALLY; SECTILE IN PARTS; MUSHY TO PASTY OVERALL; TACKY TO SLIMY; SLIGHT TO MODERATE COHESIVENESS; MODERATE ADHESIVE; MODERATE HYDROPHILIC; EARTHY FRACTURE; SUBNODULAR TO SUBBLOCKY HABIT; DULL EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; MASSIVE BED OF VERY TUFFACEOUS SILTSTONE (3640'-3680') =LIGHT BROWNISH GRAY BECOMING LIGHT GRAY AT 3690'; POOR INDURATION; MUSHY TO PASTY; TACKY TO SLIMY; SLIGHT COHESIVE; MODERATE ADHESIVE; EARTHY FRACTURE; SUBNODULAR TO SUBBLOCKY HABIT; DULL EARTHY LUSTER; SILTY TO CLAY/ASHY TEXTURE; MASSIVE HOMOGENEOUS BED OF TUFFACEOUS SILT; TRACE ASH; MINOR MICRO LAMINAE OF CARBONACEOUS SHALE AND CLAY. TUFFACEOUS SANDSTONE (3670'-3750') =LIGHT BROWNISH GRAY SECONDARY LIGHT GRAY; CLAST SIZE RANGES FROM VERY FINE UPPER TO VERY FINE LOWER GRADING TO SILT SURROUND TO ROUNDED; MODERATE TO WELL DEVELOPED SPHERICITY; VERY POOR SORTING; ABUNDANT TRANSPARENT GAS; IMMATURE NATURE; DOMINANT TO ABUNDANT SILT/ASH MATRIX SUPPORT GRADING TO SILTSTONE WITH DEPTH AND BECOMING • HYDROPHILIC; COMPOSED OF PREDOMINANTLY QUARTZ w/ MINOR CITRIC DETRITAL MATERIAL; VISIBLE PYROCLASTIC RELIC SHARDS; POOR POROSITY ~~ EPOCH 6 :- AIZ/17~1~ ~Wle/' AURORA GAS, LLC ENDEAVOUR 1 COAL (3765'-3775') = BLACK TO GRAYISH BLACK MOTTLED REDDISH BLACK; BRITTLE TO FIRM; EARTHY SOME RESINOUS LUSTERS; MATTE TEXTURE; HACKLY FRACTURE; LIGNITE; CARBON SHALE; VISIBLE BLEEDING GAS. TUFFACEOUS SILTSTONE (3780'-3840') =LIGHT BROWNISH GRAY IV~OTTLED VERY LIGHT GRAY IN ASHY SECTIONS; VERY POOR TO POOR INDURATION; CRUMBLY TO MUSHY; PASTY IN ASH; NON TO COHESIVE; SLIGHT TO MODERATE ADHESIVE; EARTHY FRACTURE; SUBNODULAR HABIT; DULL TO MODERATE EARTHY LUSTER; SILTY TO ASHY TEXTURE; THICK TO MASSIVE GRADATIONAL BEDS OF SILT, ASH AND VERY FINE GRAIN SANDS; ~tEWORKED; DIRTY. TUFFACEOUS SANDSTONE (3750'-4050') =GRADES TO BOTH VERY SANDY TUFFACEOUS CLAYSTONE AND LESS TUFFACEOUS NON DIFFERENTIATED SANDSTONES; CLASTIC COMPOSTION INCLUDES ABUNDANT GRAINS OF REWORKED GLASS SHARDS THAT HAVE BEEN WINNOWED FROM THE ORIGINAL AIRFALL ASH; THE SUPPORTING MATRIX ALSO HAS PERVASIVE SHARDS AND MICROSHARDS THAT HAVE NOT YET BEEN SIGNIFICANTLY SEPARATED FROM THE ASH AND MIXED WITH QUARTZ AND LITHICS; LIGHT GRAY TO MEDIUM LIGHT GRAY; PATCHY FAINT TO VERY FAINT SECONDARY HUES OF LIGHT BROWNISH GRAY, LIGHT OLIVE GRAY; YELLOWISH GRAY, GRAYISH ORANGE PINK; VARY FINE LOWER TO FINE UPPER; VERY FINE OCCASIONALLY GRADES TO SILITY SANDSTONE; MODERATELY WELL SORTED OVERALL; ANGULAR TO ROUNDED; NOTE MANY ROUNDED GRAINS ARE SHARDS THAT HAVE NOT BEEN SIGNIFICANTLY TRANSPORTED; OCC SLIGHTLY CALCAREOUS; COMPOSITION IS CITRIC QUARTZ ARENITE TO SUBLITHIC ARENITE; DISPLAYS MOST OF THE SAME SAND CHARACTERISTICS AS TUFF SANDS DESCRIBED ABO~{E; ALSO HAS MANY OF THE CHARACTERISTICS AS THE TUFFACEOUS CLAYS DESCRIBED ABO~/E AND IS EXPANSIVE WHEN HYDRATED; MANY PIECES DISPLAY THIN MICROBEDS OF NON-TUFFACEOUS AND OFTEN CALCAREOUS GRAIN SUPPORTED SANDSTONE. • TUFFACEOUS SILTSTONE (4050'-4400') =COMPLEX SILTSTONE GROUP THAT IS BOTH TUFFACEOUS AND CARBONACEOUS; APPEARS GENERAL HIGH ORGANIC CONTENT; ALSO ABUNDANT FRACTION IS GRADATIONAL TO CALCAREOUS TUFF AND DISCERNIBLY VERY THINLY BEDDED WITH CALL TUFF; DOMINANT COLOR IS LIGHT BROWNISH GRAY TO BROWNISH GRAY, BUT OFTEN RANGES TO BROWNISH BLACK WHEN CARBONACEOUS CONTENT; MANY SUBTLE GRAY AND BROWN VARIATIONS IN SECONDARY HUES; WHEN IN CLOSE ASSOCIATION WITH CALC TUFF, OFTEN HAS STRONG GRAYISH ORANGE TO MODERATE YELLOWISH BROWN SECONDARY HUES; RANGES FROM SOFT TO MODERATELY HARD; MOST IS SLIGHT TO MODERATELY FIRM OR BRITTLE; BRITT~.E SILTSTONE OFTEN HAS OME INDICATIONS OF MINOR CALCITE AND/OR SILICA REPLACEMENT; SILTY TO ASHY TO CLAYEY TO VARIOUS MATTE TEXTURES; MORE HIGHLY CARBONACEOUS VARIATION OFTEN HAS A DENSE MATTE TEXTURE SIMILAR TO THE CARBONACEOUS SHALE, BUT WITH A MORE DISTINCTIVE "'GRAININESS"; WHEN BRITTLE TO HARD SOME OF THE SILTSTONE HAS TEXTURE THAT APPEARS MICROSUCROSIC TO SMOOTH; EARTHY TO DULL TO MICROSPARKLY LUSTER; SOME OF THE MOST CARBONACEOUS HAS SOFT "COALY" LUSTER. CALCAREOUS TUFF (4000'-4400 =FAIRLY CONSISTENT IN AT LEAST TRACE AMOUNTS, AND ALMOST INCREASES IN ABUNDANCE AT VERY SLOW DRILLING ZONES; NOTE SEVERAL THIN ZONES WITH HIGH PERCENTAGE IN SAMPLES; HAS VERY CLOSE ASSOCIATION WITH TUFFACEOUS CARB SILTST ABOVE; MOST COMMON COLOR VARIATION IS PALE YELLOWISH BROWN TO GRAYISH ORANGE, WITH LESS ABUNDANT BUT STILL COMMON MEDIUM GRAY WITH THE FORMER COLORS AS SECONDARY HUES; ALSO LOCALLY COLOR VARIATION WITH DECREASED LIGHTNESS VALUES TO DARK YELLOWISH ORANGE; BRITTLE TO MARGINALLY HARD TO OCCASIONALLY MODERATELY HARD; MODERATE TO VERY CALCAREOUS, AND OFTEN LATER REPLACED BY SILICA; IRREGULAR TO THIN BLADED PLATY HABIT; ROUGH SHALINESS TO MASSIVE BLOCKINESS. • EPOCH Auras Power AURORA GAS, LLC ENDEAVOUR 1 SANDSTONE/SAND (4100'-4400'} =MINOR NON TUFFACEOUS SANDSTONE THAT IS VERY THINLY INTERBEDDED IN TUFF SILTST; GRAY TO OLIVE GRAY WITH MEDIUM GRAY SECONDARY HUES; CLOSELY RANGES TO MEDIUM GRAY WITH FAINT GREENISH GRAY OR OLIVE GRAY OR LIGHT GRAYISH BROWN SECONDARY HUES; VERY FINE LOWER TO MEDIUM LOWER; MODERATELY SORTED; ANGULAR TO SUBANGULAR, AND DISCOIDAL TO SUBDISCOIDAL; DOMINANTLY CONSOLIDATEDPIECES THAT ARE A MIX OF GRAIN AND MATRIX SUPPORTED BY COMBINATIONS OF CALCITE (AND TRACE SILICA CEMENTATION AND MINOR SILTY TUFFACEOUS SEDIMENT; SUBLITHIC ARENITE TO COMPOSITIONAL GRAYWACKE; COMMON "DIRTY" SALT AND PEPPER APPEARANCE; DARK GRAINS ARE DOM ARGILLITE- PHYLLITE METALITHIC ROCK FRAGS WITH AMOUNT OF OTHER DIVERSE LITHICS. ARGILLITE- PHYLLITE METALITHIC ROCK FRAGS WITH AMOUNT OF OTHER DIVERSE LITHICS. TUFFACEOUS SILTSTONE (4410'-4440') =MEDIUM LIGHT GRAY MOTTLED LIGHT GRAY; MODERATE INDURATION; CRUMBLY TO CRUNCHY; STIFF IN PARTS; MODERATE COHESIVE; SLIGHT ADHESIVE; EARTHY FRACTURE; SUB PLATY TO SUBNODULAR HABIT; DULL TO MODERATE EARTHY LUSTER; SILTY TO GRITTY TEXTURE; MASSIVE GRADATIONAL BEDS OF TUFFACEOUS SILT AND SANDSTONE; NON CALCAREOUS WITH A DIRTY APPEARANCE. SAND (4440'-4570') =VERY LIGHT GRAY TO LIGHT BROWNISH GRAY IN LOCAL SILT; CLAST SIZE RANGES FROM MEDIUM LOWER TO VERY FINE UPPER; SUBROUNQ; MODERATE SOME WELL DEVELOPED SPHERICITY; POOR SORTING; POLISHED TO PITTED TEXTURE; IMMATURE NATURE; NON TO VERY SLIGHT SILK CEMENT; LOCALLY GRAIN SUPPORTED WITH OVERALL SILT AND ASH MATRIX STRUCTURED SUPPORT; COMPOSED OF 90% QUARTZ, 10% CHERT, META AND VARIOUS CITRIC FRAGMENTS; POOR TO THIN FAIR POROSITY; NO SHOW OF OIL. DEVIT ASH (4530-4560 =LIGHT BROWNISH GRAY MOTTLED VERY LIGHT GRAY GRADING FROM VERY TUFFACEOUS SANDSTONE; GREASY TO EARTHY LUSTER; ASHY TO VERY SILTY TEXTURE; VERY POOR TO POOR INDURATION; APPEARS REWORKED AND REDEPOSITED; VISIBLE PYROCLASTIC RELIC SHARDS; VERY FINE SAND, SILT ANDS MICRO CARBON LAMINAE TUFFACEOUS SILTSTONE (4560-4620') =LIGHT BROWNISH GRAY MOOTTLED LIGHT GRAY; VERY POOR TO POOR INDURATION; MUSHY TO PASTY; TACKY TO SLIMY; VERY SLIGHT TO SLIGHT COHESIVENESS; SLIGHT TO MODERATE ADHESIVE; EARTHY FRACTURE; SUBNODULAR HABIT; MODERATE TO GREASY LUSTER IN ASHY SECTIONS; SILTY TO ASHY TEXTURE; GRADING TO DEVIT ASH; REWORKED; HYDROPHILIC AND VERY DETRITALISH. SAND (4600'-4680) =VERY LIGHT GRAY TO VERY PALE ORANGE HUES IN ASHY MATRIX; CLAST SIZE RANGES FROM FINE UPPER TO VERY FINE UPPER; SURROUND; MODERATE DEVELOPED SPHERICITY; MODERATE SORTING; IMMATURE TO SUBMATURE, POORLY INDURATED; MATRIX HAS VERY MOTTLED APPEARANCE; SUSPECT MIXING AND REMIXING OF ASH, SILT AND SAND IN CONFINED AREA. COAL (4700'-4820') =BLACK; BRITTLE; FRAGILE; HIGHER GRADE LIGNITE TO SUBBIT; GENERALLY FINE FRAGMENTS, CLOSE TO A "COFFEE GROUND" COAL; SMOOTH TO DENSE MATTE TEXTURE; SHINY SUBVITREOUS TO RESINOUS LUSTRE; FINE IRREGULAR TO PLATY FRACTURE; SOME LARGER FRAGMENTS HAVE BROWN STREAKING OR STAINING. SAND/SANDSTONE (4720'-4840') =MEDIUM LIGHT GRAY TO LIGHT GRAY; VERY FAINT LIGHT OLIVE GRAY SECONDARY HUE; HAS SLIGHTLY "DIRTY" SALT AND PEPPER; NOTE THAT THIS SAND IS SIGNIFICANTLY "CLEANER LOOKING" THAN PREVIOUS; VERY FINE LOWER TO MEDIUM LOWER; MODERATELY WELL SORTED IN FINE LOWER TO MEDIUM LOWER RANGE, AND DOMINANT FRACTION IS FINE UPPER; ANGULAR TO SUBANGULAR, DISCOIDAL TO SUBSPHER; MOSTLY DISAGGREGATED GRAINS, BUT ALSO LOCALLY ABUNDANT SMALL CONSOLIDATED PIECES; NOTE THAT MAJORITY OF SANDSTONE IS GRAIN SUPPORTED WITH WEAK CALCITE AND SILICA) CEMENTATION AND PARTIAL SUPPORT BY APPARENT DEVITRIFIED ASH; CITRIC QUARTZ ARENITE TO SUBLITHIC ARENITE; $0-90% QUARTZ AND VOLC GLASS, TR FELDSPAR, EPOCH 8 .Aurora Power AURORA GAS, LLC ENDEAVOUR 1 TR-10% VARIOUS CRYPTOSILIC, 5-20% LITHICS AND MAFIC MINERALS, DOM BY GREENST AND ARGLLTE-PHYLLTE METALITHS. TUFFACEOUS SILTSTONE (4850'-4950') =INCLUDES ABUNDANT SILTSTONE THAT IS BOTH TUFFACEOUS AND CARBONACEOUS; GENERAL HIGH ORGANIC CONTENT; VERY COM FRACTION GRADATIONAL TO CALCAREOUS TUFF; DOMINANT COLQR IS LIGHT BROWNISH GRAY TO BROWNISH GRAY, BUT OFTEN RANGES TO BROWNISH BLACK WHEN HIGH CARBONCEOUS CONTENT; MANY SUBTLE GRAY AND BROWN VARIATIONS IN SECONDARY HUES; GRAYISH ORANGE TO YELLOWISH BROWN WHEN GRADING TO CALC TUFF; SOFT TO MODERATELY HARD; MOST IS SLIGHTLY TO MODERATELY FIRM OR BRITTLE; SILTY TO ASHY TO CLAYEY TO VARIOUS SOFT MATTE TEXTURES; OCCASIONAL BRIT PCS APP MICROSUCROSIC; VERY CARBONACEOUS PCS HAVE DENSE MATTE TEXT OF COALS; EARTHY TO MICROSPARKLY LUSTRE (FROM MICMICA); OVERALL VERY COMPLEX ROCK WITH MANY SANDY, ASHY, COALY VARIATIONS; ABNT MIC THIN INTERBEDS OF DIFFERENT LITHS; COM MED BROWN TUFF SILTST WITH PROM CLASTIC CALC TUFF FRAGS. TUFFACEOUS SANDSTONE/SAND (4960'-5080') =VERY LIGHT GRAY MOTTLED IN WHITE DEVIT ASH; CLAST SIZE RANGES FROM MEDIUM LOWER TO FINE LOWER; SUBANGULAR; MODERATE DEVELOPED SPHERICITY; MODERATE SORTING; SUBMATURE NATURE; SLIGHT SOME MODERATE SILK CEMENT; LOCAL GRAIN SUPPORT WITH OVERALL ABUNDANT WHITE LOOSLEY ATTACHED ASH MATRIX SUPPORT; CONSOLIDATED IN LQOSELY LITHIFYING THICK ASH DEPOSITS; TRACE CALCAREOUS TUFFS; COMPOSED OF 90°1o QUARTZ, 10% CRT, META AND VARIOUS MINOR CITRIC FRAGMENTS; POOR LOCALLY FAIR PQROSITY AND PERMEABILITY; NO OIL SHOWS. DEVIT ASH (5020'-5080') =WHITE MOTTLED VERY PALE ORANGE TQ VERY LIGHT GRAY; GREASY TO EARTHY LUSTER; ASHY TO SILTY TEXTURE; VERY POQR INDURATION; REWORKED . AND REDEPOSITED; VISIBLE PYROCLASTIC RELIC SHARDS; INTERBEDDED WITH MEDIUM GRAIN SAND GRAINS AND VARIOUS MICRO LAMINAE OF CARBON CLAY. TUFFACEOUS SILTSTONE (5080'-5130') =DARK YELLOWISH BROWN TO PALE YELLOWISH BROWN; POOR SOME MODERATE INDURATION IN SANDY SECTIONS; MUSHY TO PASTY; SLIMY SLIGHT TO MODERATE COHESIVE; SLIGHT TO MODERATE ADHESIVE; PDC TO EARTHY FRACTURE AND HABIT; DULL EARTHY LUSTER; SILTY TEXTURE; CQMPOSED OF >90% FRIABLE SILT; MASSIVE BED OF GRADING SILTS BECOMING INTERBEDDED ~IVITH VERY FINE SAND COAL (5130'-5180') = BLACK TO GRAYISH LACK; FIRM; HACKLY FRACTURE; EARTHY TO RESINOUS LUSTER; MATTE TEXTURE; THIN TO THICK BEDS OF LIG,NITIC COAL. SAND/TUFFACEOUS SANDSTONE (5190'-5220 =VERY LIGHT GRAY WITH WHITE HUES IN ASH; CLAST SIZE RANGES FROM FINE UPPER TO FINE LOWER; SUBANGULAR; LOW TO MODERATE DEVELOPED SPHERICITY; MODERATE SORTING; IMPACTED TEXTURE; SUBMATURE NATURE; NON TO VERY SLIGHT SILK CEMENT; ABUNDANT WHITE ASH STRUCTURED MATRIX; DOMINANT MATRIX SUPPORT; POSSIBLE LOCAL GRAIN SUPPORT; LOOSELY ATTACHED; COMPOSED OF >90% QUARTZ; POOR POROSITY; NO OIL SHOWS TUFFRCEOUS SILTSTONE (5220'-5280') =PALE YELLOWISH BROWN TO DARK YELLOWISH BROWN SOME YELLOWISH GRAY AND VARIOUS HUES OF ALL; VERY POOR INDURATION; BRITTLE; NON TO VERY SLIGHT COHESIVENESS SLIGHT ADHESIVE; EARTHY FRACTURE; SUB PLANAR HABIT; DULL EARTHY LUSTER; ASHY TEXTURE; MASSIVE GRADATIONAL. BEDS OF ASH SILT AND MICRO LAMINAE OF CARBONACEOUS MATERIAL; ORGANIC APPEARANCE BECOMING CLEANER ~ 5280'; TRACE CALCAREOUS TUFF. COAUCARBONACEOUS SHALE AND CLAY (5290'- 5340') =BLACK AT MASS TO BROWNISH . BLACK AT CONTACTS; BRITTLE TO FIRM; EARTHY TO RARE RESINOUS LUSTERS;. MATTE TO SUBCLAY TEXTURE; HACKLY TO EARTHY FRACTURES; COMPOSED OF LIGNITIC COAL TO VERY ~~ EPOCH 9 ..~ Aurvra power AURORA GAS, LLC ENDEAVOUR 1 . CARBONACEOUS SHALE AND CLAY; VISIBLE BLEEDING GAS AT PURE COALS; CONTINUED VERY ORGANIC SILTSTONES TO 5340'. TUFFACEOUS SILTSTONE (5340'-5480') = A COMPLEX ROCK IN THIS INTERVAL; BETTER DESCRIBED AS TUFFACEOUS CARBONACEOUS SANDY SILTSTONE; WIDE RANGE OF BROWNISH GRAY AND BROWN COLORS AND SECONDARY HUES; HIGHER LIGHTNESS VALUES WHEN ASH CONTENT INCREASES, LOW LIGHTNESS VALUE CARBONACEOUS CONTENT INCREASES; NEARLY PERVASIVE MIXED, MOTTLED APPEARANCE; ASSUMES MANY OF THE CHARACTERISTICS ON THE OTHER CONST{TUENT LITHOLOGIES AS LOCAL PERCENTAGES VARY; NON TO VERY CALCAREOUS; WHEN VERY CALCAREOUS IS IT OFTEN GRADATIONAL TO CALCAREOUS TUFF, AND THE DOMINANT COLORS THEN FALL INTO THE YELLOWISH BROWN TO GRAYISH ORANGE GROUP; SLIGHTLY FIRM TO MODERATELY HARD; DOMINANT SLIGHT TO MODERATELY FIRM OR BRITTLE; SILTY TO ASHY TO VARIOUS SOFT MATTE TEXTURES; OCCASIONAL ALSO SANDY, CLAYEY, MICROSUCROSIC TEXTS AND V DENSE MATTE TEXT OF COALS; EARTHY TO MICSPRKLY (MICMICA) LUSTRE; COM TUFF SLTST WITH PROMINENT CLASTIC CALC TUFF FRGS; SANDSTONEiSAND (5410'-5800') =ANOTHER COMPLEX ROCK, MOST IS NOT "CLEAN" LT GRAY COLORED SS, BUT A SILTY TUFFACEOUS CARBONACEOUS SANDSTONE; SOME ZONES WITH VERY HIGH AMOUNT OF CLASTIC CARBONACEOUS MATERIAL; V FINE LOWER TO COARSE LOWER; MOD SORTD tN FINE LOWER TO MEDIUM LOWER; ANGULAR TO SUBANGULAR, DISCOIDAL TO SUBDISCOIDAL; INCREASED ROUNDED GRAINS IN VERY FINE RANGE WHEN ASH CONTENT INCREASES; DOMINANT COLOR IS MEDIUM LIGHT GRAY WITH MANY STRONG TO SUBTLE VARIATIONS OF GRAY AND BROWN SECONDARY COLORS AND HUES; AS SANDSTONE BECOMES SILTIER IT ASSUMES MANY OF 7HE CHARACTERISTICS OF THE COMPLEX SILTSTONE DESCRIBED ABOVE; ABUNDANT DISAGGREC~ATED GRAINS, BUT GREATER FRACTION OF CONSOLIDATED SANDSTONE; SANDSTONE IS BOTH GRAIN AND MATRIX SUPPORTED BY MANY COMBINATIONS OF ASH, SILT, CLAY SUPPORT AND CALCITE AND SILICA CEMENTATION; THE SILTIEST SANDSTONE HAS A DISTINCTIVE TEXTURE THAT INCLUDES A PATCHY MIXED OR MOTTLED APPEARANCE, AND ALSp A VERY ROUGH MATTE APPEARANCE; THIN LAYERING OR ZONING IS VERY COMMON; ANR OFTEN THIS GROUP OF SANDSTONE HAS ALTERNATING LIGHTER AND DARKER MICROBEQS. SANDSTONE/SAND (5410'-5480') =CONTINUED SILTY TUFFACEOUS CARBONACEOUS SANDSTONE S ABOVE; NOTE THAT THE MOST HIGHLY CARBONCEOUS VARIATION IS PALE BROWN TO LIGHT MEDIUM GRAY TO MEDIUM GRAY WITH VERY STRONG BROWNISH GRAY AND OCCASIONALLY BROWNISH BLACK SECONDARY HUES; INCLUDED IN THE COMPOSTION OF THIS SANDSTONE ARE MICROFRAGMENTS OF COAL AND CARBONACEOUS MATERIAL; SOME LAMINAE OR MICROZONES APPEAR TO BE TINY COAL FRAGMENTS CEMENTED WITH CALCITE; LOCALLY COMMON SANDSTONE FRAGMENTS HAVE ALTERNATING MICROZONES OF CONCENTRATED COALY MATERIAL, SILTY SANDSTONE, "CLEAN" SANDSTONE, MICROMICA, SILT-CLAY, AND VARIEGATED VOLCANIC ASH; ADDITIONALLY WITHIN THE SAME CUTTWGS PIECE CAN BE DIFFERNT TYPES OF GRAIN AND MATRIX SUPPORT AND CEMENTATION. TUFFACEOUS SANDSTONE (5410'-5800') =GRADES SANDY TUFFACEOUS CLAYSTONE AND LESS TUFFACEOUS NON-DIFFERENTIATED SANDSTONE; COMPOSITION INCLUDES ABUNDANT REWORKED GLASS SHARDS NOT WINNOWED FROM ORIGINAL AIRFALL ASH; SUPPORTING MATRIX ALSO HAS PERVASIVE SHARDS AND MICROSHARDS NOT SEPARATED FROM THE ASH AND MIXED WITH QUARTZ AND LITHICS; LIGHT GRAY TO MEDIUM LIGHT GRAY; FAINT LIGHT BROWNISH GRAY, YELLOWISH GRAY, SECONDARY HUES; VERY FINE LOWER TO FINE UPPER; VERY FINE GRADES TO ASHY SILTSTONE; MODERATE TO MODERATELY WELL SORTED OVERALL; ANGULAR TO ROUNDED; OCC SLIGHTLY CALCAREOUS; COMPOSITION IS CITRIC QUARTZ ARENITE TO SUBLITHIC ARENITE; WHEN SOFT HAS MANY OF THE CHARACTERISTICS • OF ASH AND TUFF CLAY.. EPQGH 10 .. ~IJ/'t1-71 ~N/@/' AURORA GAS, LLC ENDEAVOUR 1 • CONGLOMERATIC SAND/CONGLOMERATE (5800'-5820'} =FIRST SIGNIFICANT SAND WITH COARSE OR LARGER GRAINS SIZE; COARSE LOWER TO GRANULE; GENERALLY SAME CHARACTERISTICS AS FINER SANDS, BUT GRANULES ARE DOMINANTLY TRANSLUCENT QUARTZ AND CHALCEDONY; CLASTS DOM W ROUNDED; INCREASINGLY DIVERSE LITHICS. TUFFACEOUS SILTSTONE (5870'-5940') =LIGHT BROWNISH GRAY TO MEDIUM LIGHT GRAY VERY POOR TO POORLY INDURATED; SECTILE IN CLAYEY SECTIONS; MUSHY TO PASTY; SLIMY; NON TO SLIGHT COHESIVE; SLIGHT TO MODERATE ADHESIVE; SUBPLANAR TO PDC FRACTURES; SUBBLOCKY TO PDC HABIT; DULL EARTHY LUSTER; CLAYEY TO SILTY TEXTURES; MASSIVE GRADATIONAL BEDS OF TUFFACEOUS SILTSTONE AND CLAYSTONE; SCATTERED MICRO LAMINAE OF CARBONACEOUS CLAY TO VERY THIN COALS; ORGANIC APPEARANCE. SAND (5945'-5977'} =VERY LIGHT GRAY; CLAYT SIZE MEDIUM UPPER TO VERY FINE TO 5970', INCRASE TO MEDIUM UPPER TO FINE UPPER AT 5977 ;SORTING FROM POOR TO MODERATE; IMMATURE INCREASED TO SUB MATURE; ABUNDANT ASH MATRIX ~ 5950' TO GENERAL MATRIX SUPPORT AT 5975' w/ SECONDARY ASH MATRIX LOCALLY; POOR POROSITY INCREASING TO FAIR TO GOOD; TRACE DEAD OIL TAR AT 5975'; NQ SHOW OF FLOURESCENCE OR OIL CUTS; COAL AND VERY CARBON SHALE ~ 5981'-5986'. COAUCARBONACEOUS SHALE AND CLAY (5980'- 6080 = BLACK TO BROWNISH BLACK GRADING TO DUSKY BROWN IN CARBON CLAYS; BRITTLE TO FIRM; VARIOUS CONSISTENCY AND TENACITY; GRADING FROM VERY SOFT CARBON CLAY TO LIGNITIC COALS; VISIBLE BLEEDING GAS FROM COAL; OVERALL VERY CARBONACEOUS AND ORGANIC APPEARANCE; THIN TO THICK BEDDING. SAND (6090'-6105') =VERY LIGHT GRAY; CLAST SIZE MEDIUM LOWER TO VERY FINE; • SURROUND; MODERATE TO WELL DEVELOPED SPHERICITY; VERY POOR SORTING; PITTED TEXTURE; IMMATURE NATURE; NON TO VERY SLIGHT SILK CEMENT; ABUNDANT ASH MATRIX LOOSELY ATTACHED MATRIX SUPPORT; 90% QTZ, 10% CRT, META; POOR -FAIR POROSITY AND PERMEABILITY; NO OIL SHOWS. TUFFACEOUS SANDSTONE {6110'-6295 =MASSIVE AND HOMOGENEOUS; NO SIGNIFICANT INTERBEDDING, AND A ONLY VERY MINOR FRACTIONS THAT GRADE TO EITHER SANDY VOLCANIC ASH OR "CLEAN" NON-TUFFACEOUS SANDSTONE; NOTE THAT THOUGH REWORKED VOLCANIC GLASS SHARDS ARE STILL VERY ABUNDANT, THERE IS HIGHER PERCENTAGE OF QUARTZ THAN IN SHALLOWER TUFF SS; WHEN THE SUPPORTING MATRIX IS WASHED ENTIRELY AWAY, THE COMPOSITION OF THE DISAGGREGATED SAND IS GENERALLY THE SAME AS OTHER NON-DIFFERENTIATED SANDSTONE. TUFFACEOUS SANDSTONE (6110'-6295') =WHITE TO VERY LIGHT GRAY TO LIGHT GRAY; FAINT TO VERY FAINT SECONDARY HUES OF YELLOWISH GRAY, LIGHT BROWNISH GRAY, VERY PALE GRAYISH ORANGE PWK; VERY FINE LOWER TO MEDIUM LOWER; RARE MEDIUM UPPER TO COARSE GRAINS; MODERATELY WELL SORTED IN FINE LOWER TO FINE UPPER RANGE; VERY FINE FRACTION IS LARGELY COMPOSED OF REWORKED GLASS SHARDS; ANGULAR TO ROUNDED OVERALL, BUT VERY DOMINANT ANGULAR TO SUBANGULAR, DISCOIDAL TO SUBDISCOIDAL; MANY ROUNDED GRAINS ARE GLASS SHARDS; MATRIX SUPPORTED BY VERY ABUNDANT VOLCANIC ASH; RARE VERY THIN LOCALIZED ZONES OF "CLEAN LOOKING" GRAIN SUPPORTED CALCITE CEMENTED SS; CITRIC QUARTZ ARENITE TO SUBLITHIC ARENITE; 80-90°r6 QUARTZ AND VOLCANIC GLASS, TR FELDSPAR, TR-10% VARIOUS CRYPTOSILICA (CHALCEDONY, CHERT), 10-20% LITHICS AND MAFIC MINERALS; LITHICS ARE DOMINATED BY DARK GRAY TO GRAYISH BLACK PHYLLITE-ARGILLITE MEDIUM GRADE META ROCK FRAGMENTS, AND MINOR GREEN TO GRAYISH GREEN TO VARIEGATED GREEN LOW GRADE META GREENSTONE ROCK FRAGMENTS. ~~ EPOCH 11 AURORA GAS, LLC ENDEAVOUR 1 TUFFACEOUS SILTSTONE (6295'-6480') =NOTE PERVASIVE SILTSTONE THAT IS BOTH TUFFACEOUS AND CARBONACEOUS; GENERAL HIGH ORGANIC CONTENT; VERY COMMONLY IS GRADATIONAL TO CALCAREOUS TUFF; DOMINANT COLOR IS BROWNISH GRAY, BUT CONSISTENTLY RANGES TO BROWNISH BLACK IF CARBONACEOUS CONTENT INCREASES; MANY NEAR GRAY AND BROWN VARIATIONS OF PRIMARY COLORS AND SECONDARY HUES; NOTE COMMON YELLOWISH BROWN TO GRAYISH ORANGE COLOF~ATION WHEN IN CLOSE ASSOCIATION TO CALCAREOUS TUFF; SLIGHTLY FIRM OR BRITTLE AND FRAGILE, TO MARGINALLY HARD AND TOUGH; DOMINANT MODERATELY FIRM OR BRITTLE; SILTY TO ASHY TO CLAYEY TO COMMON SOFT MATTE TEXTURES; ALSO SOME MICMICA, VERY DENSE MATTE, MICROSUCROSIC, GRAINY, AND MIXED OR MOTTLED TEXTURES, INCLUDING UNUSUAL "COALY" SILT ROCK WITH COAL MICROCLASTS; EARTHY TO VARIOUS MICROSPARKLY LUSTRES; ABUNANT MICROTHIN INTERBEDS OF DIFFERENT LITHOLOGIES; NOTE LOCALLY VERY PROMINENT PIECES WITH CALC TUFF CITRIC FRAGMENTS; OVERALL VERY COMPLEX ROCK WITH MANY SANDY, ASHY, COALY VARIATIONS. SAND/SANDSTONE/TUFFACEOUS SANDSTONE (6480'-6560') =BOTH NON-DIFFERENTIATED AND TUFFACEOUS TYPES; APPARENT THIN BEDDING RATHER THAN MASSIVE; ONE GROUP OF SS IS DOM MEDIUM GRAY WITH LIGHT GRAYISH BROWN SECONDARY HUE; V FINE TO MED, MOD SORTED, COM APPEARS IN DISCERNIBLE TIGHT MICROBEDS; TUFF SS IS DOM VERY LIGHT GRAY, V FN TO MED, SLI MORE MASSIVE, NO THIN BEDDING IS APPARENT, OVERALL SORTING IS BETTER BUT SLI INCREASED RANGE OF GRAIN SIZE TO SUGGEST POSSIBLE FINING UPWARD; NOTE NO OIL INDICATORS GAS SAND ~ 6550-6555' CARBONACEOUS CLAY AND SILT (6560'-6610 =PALE YELLOWISH BROWN TO DARK YELLOWISH BROWN TO MODERATE BROWN MOTTLED BLACK; VEF~Y SOFT TO SOFT; BRITTLE COALS; LUMPY TO CLUMPY; MUSHY TO PASTY; HYDROPHILIC; NON TO VERY SLIGHT COHESIVE; MODERATE ADHESIVE; AMORPHOUS FRACTURE AND HABIT DULL EARTHY • LUSTER; ASHY TO COLLOIDAL TEXTURES; THIN GRADATIONAL BEDS OF VERY CARBONACEOUS CLAY, SILT AND SHALES. TUFFACEOUS SILTSTONE (6610'-6660') =DARK YELLOWISH BROWN TO DUSKY YELLOW BROWN SOME PALE YELLOWISH GRAY AND VARIOUS HUES OF ALL; POOR TO MODERATE INDURATION; MUSHY; SLIGHT COHESIVENESS; SLIGHT TO MODERATE ADHESIVE; EARTHY TO SUBPLANAR FRACTURE; SUBPLATY HABIT; DULL EARTHY LUSTER; SILTY TO CLAYEY/ASHY TEXT COMPOSED OF VERY ORGANIC CARBON SILT AND CARBON CLAY WITH VARIOUS DETRITAL FINES. SAND (6660-6705') =VERY LIGHT GRAY; CLAST SIZE MEDIUM LOWER TO VERY FINE UPPER; SUBROUND; MODERATE SPHERICITY; POOR SORTING; IMPACT TEXTURE; GRADES TO SILT; ABUNDANT ASH MATRIX AND SUPPORT AND VERY HYDROPHILIC; COMPOSED OF 90% QTZ, 10% CRT, META, TR GREENSTONE; POOR TO FAIR POROSITY AND PERMEABILITY; NSFOC VERY COARSE SAND/CONGLOMERATE (6735'- 6760 =FIRST INTERVAL ON WELL THAT HAS A SIGNIFICANT AMOUNT OF VERY COARSE, CONGLOMERATIC SAND; MEDIUM LIGHT GRAY WITH VERY FAINT LIGHT BROWNISH GRAY SECONDARY HUES; DISTINCTIVE OVERALL COARSE SALT AND PEPPER APPEARANCE, SLIGHTLY SPECKLED WITH PALE ORANGE (FROM GRAINS OF LOW GRADE JASPER); FINE LOWER TO GRANULE TOTAL RANGE, BUT 90% OR MORE IS COARSE UPPER TO GRANULE, AND LOCALLY NEARLY ALL IS VERY COARSE TO GRANULE; GENERALLY ALL DISAGGREGATED, BUT TRACE PIECES OF CONSOLIDATED CONGLOMERATE THAT ARE WEAKLY CEMENTED BY A COMBINATION OF CALCITE AND SILICA, WITH SOME ADDITIONAL SUPPORT BY APPARENT DENITRIFIED ASH; OVERALL CONGLOMERATE COMPOSITION SIMILAR TO SAND FRACTION: CLASTS ARE 75% QUARTZ AND VOLCANIC GLASS, TR FELDSPAR, 10-15% CRYPTOSILICA (CHALCEDONY, CHERT), 15-25% DIVERSE LITHICS DOM BY GREENSTONES; NOTE LARGEST CLASTS (GRANULES) ARE 50%/50% FRACTIONS OF WELL ROUNDED AND . ANGULAR. EPOCH 12 Aurora mower AURORA GAS, LLC ENDEAVOUR 1 • TUFFACEOUS SANDSTONE (6790'-6905') =VERY LIGHT GRAY TO LIGHT GRAY; VERY MASSIVE HOMOGENEOUS OVERALL APPEARANCE; VERY FINE TO GRANULE RANGE; ASH MATRIX VOLUME IS PERVASIVE AND GENERALLY HI %; CLOSELY GRADATIpNAL TO VERY SANDY VOLC ASH; DESPITE MASKING OF MATRIX ASH, REPEAT SECTIONS OF Ft-VtNG UPWARD !S DISCERNIBLE; MANY LRG CLSTS ARE W RDD; SUBLITHIC ARENITE; LITHICS DOM GREENSTS. TUFFACEOUS SILTST/CLAYSTONE (6910'-6960) =PALE BROWN TO PALE YELLOWISH BROWN TO LIGHT BROWNISH GRAY SOME MEDIUM GRAY; VERY POOR TO POORLY INDURATED; MUSHY TO PASTY; THINLY BEDDED STRATIFIED LAYERS -VARIOUS DEGREES OF CARBONACEOUS; GRADES FROM CARBON CLAY AND SILT TO COAL: SUB LIGINTIC; ASHY- SILTYTEXTURE HYDROPHILIC OVERALL ORGANIC APPEARANCE. SAND/CONGLOMERATIC SAND (6970'-7010') =VERY LIGHT GRAY; CIr.AST MEDIUM UPPER TO FINE LOWER; SOME ANGULAR TO SURROUNDED; MOD SPHERICITY; PR SORTING; HYDROPHILIC ASH MATRIX; LOOSELY GR SUPPORTED TO MTRX SUPPORTED; 75-$5% QTZNOLC GLASS, 5-10% CRYPTOSILIC,10-20°I° METALITHICS/MAFIpS; FAIR VIS POR AND PERM; NO FLUOR OR STAIN FROM 6735' TO 7015', BUT FAINT TO PALE TO MARGINALLY BRI YELLOW CUT FLUOR, FNT TO PALE DULL YEL-BRNSH YEL RESD FLUOR. TUFFACEOUS SANDSTONE (7070'-7100 =VERY LIGHT GRAY TO Lt~HT GRAY; MASSIVE HOMOGENEOUS APPEARANCE; V FN TO GRANULE MOD SORTED ©VERALL; PERVASIVE ASH MATRIX; ANGULAR TO SURROUNDED; GRADES TO V SANDY VOLC ASH; SUBLITHIC ARENITE; LITHICS DOM BY GREENSTONES; ASH MTRX IS HYDROPHILIC, EXPANSIVE, SOLUBLE IN PART. TUFFACEOUS SILTSTONE/NON-DIFFENTIATED SANDSTONE/COAL (7100'-7135') =GROUP OF LITHS IN CLOSE ASSOCIATION; SS IS NOT TUFFACEOUS, AND RANGES FROM "CLEAN" TO SILTY; TUFFACEOUS SILTST IS STRONGLY CARBONACEOUS IN PART; BOTH SS AND SILTT HAVE COM TO ABNT CARE LAMS AND PARTICLES TUFFACEOUS SANDSTONE (7100'-7230') =VERY LIGHT GRAY TO LIGHT GRAY; FAINT YELLOWISH GRAY TO VERY FAINT GRAYISH ORANGE PINK SECONDARY HUES; V FN LOWER TO GRANULE; APPARENT REPEAT FINING UPWARD SEQUENCES; MOD SORTING THRU EACH CHANGING MODE; DOM FN LOWER TO MED LOWER; ANGULAR TO SURROUNDED; VERY COARSE AND GRANULES OFTEN RDD; PERVASIVE VOLCANIC ASH MATRIX SUPPORT; GRAD TO V SANDY VOLC ASH; SOME OF THE ASH APPS V EXPANSIVE; LITHIC QTZ ARENITE TO SUBLITH ARENITE;EST 75-85% QTZ-VOLC GLASS, 5-10%° CYRPTOSILIC, 10-20% LITHICS (DOM GRNST). CONGLOMERATE SAND/SAND (7240'-7280') =VERY LIGHT GRAY; CLAST SIZE COARSE GRAIN TO FINE GRAINS; SURROUND TO SUBANGULAR BIT IMPACTED GRAINS; MODERATE SPHERICITY POOR SORTING; NO ABUNDANT FACTION; POLISH COARSE TO IMPACTED TEXTURE IN THE MEDIUM GRAINS; SUBMATURE; MODERATE TO SLIGHT ASH MATRIX; HYDROPHILIC; LOOSELY ATTACHED; GRAIN SUPPORTED WITH SECONDARY MATRIX SUPPORT IN PARTS; COMPOSED OF 90% QTZ, 10% META, GRNSTN; TRACE LIMONITE; FAIR POROSITY AND PERMEABILITY; GRADING TO ASHY TUFFACEOUS SILT ~ 7280'. VOLCANIC ASH/ TUFF (7300' - 7380 =VERY LIGHT GRAY WITH LIGHT BROWN AND MED TO DARK GRAY SECONDARY HUES; VERY SOFT; FRAGILE AND PULVERULENT;IRREGULAR SHAPED CUTTINGS; ASHY TO SILTY TO SLIGHTLY GRIT TEXTURE FROM FINE GRAIN SUSPENDED SANDS; EARTHY TO SLIGHTLY GLASSY LUSTRE; SCATTERED VISIBLE SHARDS;NON TO SLIGHTLY CALC COMMONLY GRADING TO A TUFFACEOUS SILTSTONE. SAND/ SANDSTONE (7360' - 7420 =LIGHT TO MEDIUM GRAY WITH LIGHT GREENISH GRAY UNCONSOLIDATED DOMINANT; ANGULAR PEBBLE TO SURROUND MEDIUM TO FINE GRAINS; NO ABUNDANT FACTION; POOR SORTING; CHIP TO IMPACT TEXTURE; GRAIN SUPPORT • INCREASED WITH DEPTH; POOR TO FAIR POROSITY AND PERMEABILITY;NON Tt3 SLIGHTLY CALCAREOUS; NO OIL INDICATORS PRESENT. EPC~CI-~ 13 Aurora Pla-wer AURORA GAS, LLC ENDEAVOUR 1 • TUFFACEOUS SAND) VOLCANIC ASH (7470' - 7530= VERY LIGHT GRAY TO GRAYISH WHITE WITH VERY LIGHT BROWN AND GRAY SECONDARY HUES, MOTTLED; FRAGILE TO PULVERULENT; IRREGULAR CUTTINGS; SILTY TO GRITTY TEXT FROM SUSPENDED SAND; SAND DOMINANTLY CL TO TRANS QUARTZ AND VOLCANIC GLASS; OCC VARICOLORED LITHS OF RED, ORANGE, BLUISH GREEN; FINE TO PEBBLE FRAGS, DOMINANTLY FINE UPPER TO MEDIUM UPPER; ANGULAR TO SUBANGULAR; POORLY SORTED;UNCONSOLIDATED EST POOR POROSITY AND PERMEABILITY; NON TO SLIGHTLY CALC; NO CUT OR CUT FLUOR. DEVIT ASH (7530'-7580') =MOTTLED PALE YELLOWISH BROWN TO VERY LIGHT GRAY TO WHITE; BRITTLE; VERY POOR INDURATION; MODERATE EARTHY LUSTER; ASHY TEXTURE; HEAVY REWORKING; INTERBEDDED WITH SILT, PYROCLASTIC RELIC SHARDS, LOOSE SAND AND MICRO CARBONACEOUS MATERIAL; OVERALL SALT AND PEPPER APPEARANCE. TUFFACEOUS SILTSTONE AND ASH (7580-7620) = MOTTLED SALT AND PEPPER, LIGHT GRAY TO WHITE; POOR INDURATION; MODERATE EARTHY LUSTER; ASHY TO SILTY TEXTURE; HEAVY REWORKED SILT, ASH AND SAND; VISIBLE PYROCLASTIC RELIC SHARDS; GRADING TO TUFFACEOUS SANDSTONE; THIN BEDS OF ORGANIC SILT AND CLAY. TUFFACEOUS SILTSTONE AND ASH (7630-7670} =LIGHT GRAY MOTTLED WHITE; VERY POOR INDURATION; BRITTLE TO CRUMBLY; NON TO SLIGHT COHESIVE; SLIGHT ADHESIVE; EARTHY FRACTURE; SUBNODULAR HABIT; MODERATE EARTHY LUSTER; ASHY TO SILTY TEXTURE; MASSIVE GRADATIONAL BEDS OF REWORKED SILT, ASH AND TUFFACEOUS SANDSTONE; SOME INTERBEDDED CARBON MATERIAL; SALT/PEPPER DEVIT ASH (7670-7705') =VERY LIGHT GRAY MOTTLED WHITE; POOR INDURATION; CRUMBLY; EARTHY FRACTURE; SUBNODULAR HABIT; BEDS OF REWORKED SILT/ASH INTERBEDDED • SAND. CORE #1 7705' - 7735', FULL RECOVERY; TUFFACEOUS CONGLOMERATIC SANDSTONE =LIGHT TO MEDIUM GRAY TO GREENISH GRAY WITH SALT AND PEPPER APPEARANCE, QUARTZ AND VOLCANIC GLASS DOMINANT WITH GREENSTONE AND DARK GRAY TO BLACK PEBBLES; FINE GR TO 15mm PEBBLES; SUBANG TO RDD; MODERATE DEVELOPED SPHERICITY; POOR SORTING; IMPACTED TEXTURE; SUBMATURE NATURE; NON TO VERY SLIGHT SILIC CEMENT; VERY SLIGHT CALC CEMENT; GRAIN SUPPORT WITH SECONDARY ASH MATRIX SUPPORT = LOOSELY ATTACHED; COMPOSED OF 90°lo QTZ, 10% CHT, META, GRNSTN; FAIR TO POOR POROSITY AND PERMEABILITY; NSFOC. COAUCARBONACEOUS SHALE AND CLAY (7790'- 7820') =BLACK MOTTLED GRAYISH BROWN AND VARIOUS HUES OF BROWN; GROUND UP CUTTING BRITTLE; EARTHY TO RESINOUS LUSTER; HRCKLY COAL FRACTURE TO PLANAR IN SHALE; VISIBLE BLEEDING GAS FROM COALS; THIN BEDS OF GRADATIONAL COAL, CARB SHALE AND ORGANIC CARBON CLAYS. TUFFACEOUS SILTSTONE AND ASH (7830-7860) =SALT/PEPPER LIGHT GRAY WITH CARBON SPECS POOR INDURATION; SECTILE IN PARTS; MUSHY SLIGHT COHESIVE AND ADHESIVE; EARTHY FRACTURE; SUBNODULAR HABIT; GREASY TO EARTHY LUSTER; ASHY TO 51LTY TEXTURE; MASSIVE REWORKED/REDEPOSITED 51LTY ASH BEDS INTBD w/ RELIC SHARDS, ASH, CARBON FINES AND VARIOUS DETRITAL MATERIAL. CONGLOMERATE SAND/SAND {7860'-7900') =VERY LIGHT GRY -LIGHT GRAY; CLAYT SIZE COARSE UPPER TO 7980' TO FINE LOWER 7900 SUBANGULAR GRADING TO SUBROUND wl DEPTH MODERATE SPHERICITY; POOR SORTING 7980' TO MODERATE (cD 7990'; CHIP TO IMPACT TEXT SLIGHT TO MODERATE SILT/ASH MATRIX; BOTH GRAIN AND MATRIX SUPPORT; HYDROPHILIC; COMPOSED OF 85-90% QTZ, 15-10% META, CHT FAIR TO GOOD POROSITY AND • PERMEABILITY ~ 7870' BECOMING FAIR ~ 7890' NO OIL SHOW ~~ EPCJCH 14 AGt'Ol'~ ~IA/~~' AURORA GAS, LLC ENDEAVOUR 1 TUFFACEOUS CLAYSTONE/ SILTSTONE (7930'- 8000 =LIGHT TO MEDIUM GRAY WITH LIGHT BROWN SECONDARY HUES; VERY SOFT, FRAGILE IRREGULAR SHAPED WITH "SCOOPED" APPEARANCE FROM PDC BIT ACTION; SILTY TO CLAYEY TO ASHEY TEXTURE; DULL TO EARTHY LUSTRE; TRACE MICROTHiN, BLACK CARBONACEOUS LAMINATIONS; NON CALCAREOUS; MODERATELY SOLUBLE; EXPANSIVE WHEN HYDRATED; POOR TO FAIR COHESIVENESS AND ADHESIVENESS; OCCASIONALLY GRADING TO LIGHT GRAYISH WHITE AND MOTTLED FRAGILE ASHY TUFF. SAND (7980' - 8100') =VERY LIGHT GRAY FROM ASHY COMPONENT, INDIVIDUAL GRAINS DOMINANTLY CLEAR TO TRANSLUCENT QUARTZ AND VOLCANIC GLASS, TRACE DUSKY RED, GRAY AND BLACK LITHS; VERY FINE LOWER TO RARE VERY COARSE LOWER, DOMINANTLY VERY FINE UPPER TO MEDIUM LOWER; SUBANGUALR TO SUB ROUNDED; POORLY SORTED; UNCONSOLIDATED; COMMON LIGHT GRAYISH WHITE ASHY/ CLAY~1( SUPPORTING MATRIX COMMON; NON CALCAREOUS; TRACE VERY DARK BROWN TO BLACK CARBONACEOUS MATERIAU COAL BEDS; NO SHOW. VOLCANIC ASH/TUFFACEOUS SAND (8090' - 8160'}= VERY LIGHT GRAY TO GRAYISH WHITE WITH VERY LIGHT BROWN AND GRAY SECONDARY HUES, MOTTLED; FRAGILE TO PULVERULENT; IRREGULAR CUTTINGS; SILTY TO GRITTY TEXT FRAM SUSPENDED SAND; SAND DOMINANTLY CL TO TRANS QUARTZ AND VOLCANIC GLASS; OCC VARICOLORED LITHS OF RED, ORANGE,GRAYISH GREEN; FINE TO PEBBLE FRAGS, DOMINANTLY FINE UPPER TO MEDIUM UPPER; ANGULAR TO SUBANGULAR; POORLY SORTED; COMMON ASH SUPPORT; TRACE HARD, SILK CEMENTED SAND STONE; MEDIUM TO COARSE GRAIN; NO SHOW. TUFFACEOUS SILTSTONE (8160'-8210') =PALE YELLOWISH BROWN TO PALE BROWN; DARK YELLOWISH BROWN; LIGHT GRAY MOTTLE WHITE VARIOUS GRADATION HUES; POOR INDURATION; MUSHY; NON TO SLIGHT COHESIVE; SLIGHT TO MODERATE ADHESIVE; EARTHY • FRACTURE; SUB NODULAR HABIT; DULL TO MODERATE EARTHY LUSTER; ASHY TEXTURE; INCREASED ASH MIX WITH DEPTH; COMPOSED OF VARIOUS ASH VERY FINE SAND, CARBON FINES AND VARIOUS DETRITAL MATERIAL. TUFFACEOUS SILTSTONE (8210'-8260') =PALE YELLOWISH BROWN BECOMING MOTTLED WITH WHITE ASH @> 8260"; POOR INDURATION; BRITTLE; ASHY CRUMBLY; MUSHY; NON TO VERY SLIGHT COHESIVENESS; MODERATEADHESIVE; EARTHY PDC FRACTURE; PDC HABIT DULL EARTHY LUSTER BECOMING MODERATE ~ 8260'; ASHT TEXTURE; MICRO LAMINAE OF CARBON FINES; SCATTERED THIN COALS. VOLCANIC ASH/TUFFACEOUS CLAY (8280' - 8320') =VERY LIGHT GRAY TO GRAYISH WHITE WITH VERY LIGHT BROWN AND GRAY SECONDARY HUES, MOTTLED; FRAGILE TO PULVERULENT; IRREGULAR CUTTINGS; SILTY TO GRITTY TEXT FROM SUSPENDED SAND; COM VISIBLE SHARDS; GRADING TO SOFT/ STICKY CLAY; NON CALCAREOUS; ACST AS SUPPORTING MATRIX FOR LOOSE FINE TO MEDIUM SAND; TRACE DARK BROWN TO BLACK CARBONACEOUS MATERIAL; NO SHOW. TUFFACEOUS SAND (8330' - 8370') =LIGHT GRAYISH WHITE OVERALL FROM ASHY COMPONENT, INDIVIDUAL GRAINS DOMINANTLY CLEAR TO TRANSLUCENT QUARTZ AND VOLCANIC GLASS FINE LOWER TO COARSE LOWER; ANGULAR TO SUBANGULAR; POOR TO FAIR SORTING; COMMON ASHY SUPPORTING MATRIX; NON CALC;NO SHOW COAUCARBONACEOUS MATERIAL (8370'-8400)= VERY DARK BROWN TO BLACK WITH DARK GRAY SECONDARY HUES; FRAGILE TO MODERATELY HARD; PLATY TO FLAKY; PLANAR FRACTURE DOMINANT; FINELY GROUND UP FROM PDC BIT ACTION; GRITTY TO EARTHY TEXTURE; SMOOTH TO RESINOUS LUSTRE; COMMONLY GRADING TO A CARBONACEOUS SILTSTONE; NO OUTGASSING. AURORA GAS, LLC ENDEAVOUR 1 . VOLCANIC ASH(fUFFACEOUS CLAY (8420' - 8480')= VERY LIGHT GRAY TO GRAYISH WHITE WITH VERY LIGHT BROWN AND GRAY SECONDARY HUES, MOTTLED; FRAGILE TO PULVERULENT; IRREGULAR CUTTINGS; SILTY TO GRITTY TEXT DULL TO GLASSY LUSTRE; NON TO SLIGHTLY CALCAREOUS; ACTS AS SUPPOORTING MATRIX FOR SAND;000ASIONALLY GRADING TO STICKY LIGHT GRAYISH BROWN CLAY; NO SHOW. TUFFACEOUS CLAYSTONE/ASH (8490'-8540') =YELLOWISH GRAY TO LIGHT GRAY BECOMING LIGHT GREENISH GRAY ~ 8510 ;VERY POORLY INDURATED; ASHY TEXTURE; DEVIT ASH; VISIBLE PYROCLASTIC RELIC SHARDS; APPEAR REWORKED; INTERBEDDED FINE TO MEDIUM LOOSE SAND; NO ORIENTATION; GRADATIONAL; TRACE VITRIG TUFF FRAGMENTS; GRADING TO SMALL COALS AND CARBONACEOUS MATERIAL. CONGLOMERATE SAND (8535'-8550') =LIGHT GRAY; CLAST COARSE UPPER TO FINE LOWER; SUBANGULAR TO SURROUND; MODERATE SPHERICITY; VERY POQR SORTING; NO ABNT FACTION; CHIP -PITTED TEXTURE; MODERATE ASH STRUCTURED MATRIX; GRAIN AND MATRIX SUPPORT; LOOSELY ATTACHED; POOR TO FAIR POROSITY AND PERMEABILITY; NO SHOW OF Oll FLUORESCENCE OR OIL CUTS. TUFFACEOUS ASHY SILTSTONE (8550-8620') =YELLOWISH GRAY BECOMING VERY PALE LIGHT GREENISH GRAY ~ 8590 ;POOR INDURATION; SLIGHTLY SECTILE; MUSHY; NON TO SLIGHT COHESIVE; MODERATE ADHESIVE; EARTHY FRACTURE; SUBNODULAR HABIT; GREASY TO MODERATE EARTHY LUSTER; ASHY TEXTURE; REWORKED; VISIBLE PYROCLASTIC RELIC SHARDS; SCATTERED LOSE INTERBEDDED SAND. CONGLOMERATIC SAND (8640' - 8680') =DOMINANTLY CLEAR TO TRANSLUCENT TO FROST QUARTZ AND VOLCANIC GLASS, TRACE BLACK, DK GRAY AND GREENISH GRAY TO PALE GREEN LITHS; ANGULAR TO SUBANGULAR; FINE TO VERY COARSE, SHATTERED SHARDS, . DOMINANT MEDIUM UPPER TO COARSE LOWER; POORLY SORTED; DOMINANTLY ASHY MATRIX SUPPORT; FRAGILE TO PULVERULENT;LOOSELY ATTACHED; PRESENT AS INCLUSIONS IN A DOMINANTLY ASHY TUFF/ CLAYSTONE/ SILTSTONE; TRACE DARK BROWN TO BLACK CARBONACEOUS MATTER IN 8680' SAMPLE; OVERALL NON CALCAREOUS; NO OIL INDICATORS PRESENT. VOLCANIC ASHlTUFFACEOUS CLAY (8730' - 8760= VERY LIGHT GRAY TO GRAYISH WHITE WITH LIGHT YELLOWISH BROWN SECONDARY HUES, MOTTLED; FRAGILE TO PULVERULENT; TIGHLY INTERBEDDED CONGLOMERATE SAND AND LOCAL CARBONACEOUS ZONES. TUFFACEOUS SILTSTONEJASH (8760'-8790'} =YELLOWISH GRAY MOTTLED OFFWHITE SOME LIGHT GREENISH GRAY HUES; VERY POOR INDURATION; MUSHY; EARTHY FRACTURE; SUB NODULAR HABIT; MODERATE EARTHY LUSTER; ASHY TEXTURE; REWORKED SILT AND ASH; w/ THIN CARBONS AND INTERBEDDED SANDS. CONGLOMERATE SAND (8820'-8890') =VERY LIGHT GRAY, PALE GREEN, YELLOWISH GRAY AND VARIOUS HUES OF ALL; CLAST SIZE IS VERY COARSE UPPER TO FINE LOWER MATRIX SANDS; ANGULAR BIT IMPACTED PEBBLES TO SURROUND FINE GRAINS; NO ABUNDANT SIZE; POOR COARSE TO WELL DEVELOPED SPHERICITY IN FINE GRAINS; VERY POOR SORTING; CHIP TO POLISHED -PITTED TEXTURES; SUBMATURE NATURE; NON TO VERY SLIGHT SILIC CEMENT; MODERATE ASH STRUCTURED MATRIX; LOOSELY ATTACHED WITH BOTH GRAIN AND MATRIX SUPPORT;. COMPOSED OF 85% QTZ, 15% CHT, GREENSTONE, META; FAIR POROSITY AND PERMEABILITY; BECOMING INTERBEDDED WITH HEAVY ASH AND SILT MATRIX AT $860' AND GIVING POOR POROSITY; NO SHOW OF OIL. TUFFACEOUS CLAYSTONE/ SILTSTONE (8880'- 8950') =LIGHT TO MEDIUM GRAY WITH LIGHT GREENISH GRAY AND LIGHT TO MEDIUM BROWN SECONDARY HUES; SOFT; FRAGILE TO PULVERULENT; IRREGULAR TO FLAKY CUTTINGS; SILTY TO CLAYEY TEXTURE; DULL TO OCCASIONALLY SPARKLY LUSTRE FROM ASHY SHARDS; NON TO SLIGHTLY SOLUBLE; POOR ~~ EPOCH 16 =Aurora l ~ic-wer AURORA GAS, LLC ENDEAVOUR 1 • ADHESIVENESS; FAIR TO GOOD COHESIVENESS; NON EXPANSIVE; NON CALCAREOUS; GRADING TO VERY ASHY TUFF; TRACE BLACK CARBONACEOUS MATERIAL; NO OIL INDICATORS PRESENT. CONGLOMERATIC SAND (8960' - 9160') =LIGHT GREENISH GRAY OVERALL FROM FRAGILE SILTY/ ASHY SUPPORTING MATRIX,INDIVIDUAL LITHS DOMINANTLY CLEAR TO TRANSLUCENT QUARTZ AND VOLCANIC GLASS,MEDIUM TO DARK GRAY, LIGHT TO DARK GREEN TO GREENISH GRAY, TRACE DARK REDDISH BROWN TO RUST; VERY FINE UPPER TO VERY COARSE UPPER; WELL SORTED IN FINE TO MEDIUM, POORLY SORTED IN COARSE; ANGULAR TO SURROUNDED, DOMINANTLY SUBANGULAR;FINE LOOSE SAND TO MEDIUM TO COARSE SILICOUS CEMENTED SAND; CHIP-PITTED-IMPACTED TEXTURES; MODERATE CLAY/ASH MATRIX LOOSELY ATTACHED; MATRIX SUPPORT wi SECONDARY GRAIN SUPPORT; COMPOSED OF 85% QTZ, 15% CHT, META AND GREENSTONE; FAIR POROSITY PERMEABILITY; NO SHOW OF FLUORESCENCE OR OIL CUTS. TUFFACEOUS CLAY/ SILT (9200' - 9125 =LIGHT GRAYISH GREEN; SOFT; MUSHY; SLIGHTLY COHESIVE AND ADHESIVE; SUBPLANAR FRACTURE; SUBPLATY HABIT; MODERATE EARTHY LUSTER; CLAYEY TO SILTY TE3XTURE; INTERBEDDED WITH PYROGLASTIC RELIC SHARDS; SILTY IN PART. TUFFACEOUS SILTSTONE AND CLAYSTONE { 9160' - 9225 =VERY PALE GREEN TO LIGHT GREEN GRAYS 9175' BECOMING LIGHT BROWN ~ 9180' BECOMING LIGHT GRAY TO MEDIUM LIGHT GRAY ~ 9190'; POOR TO MODERATE INDURATION; SECTILE; MUSHY; SLIGHT TO MODERATELY COHESIVE AND ADHESIVE; EARTHY FRACTURE; SU~3NODULAR HABIT; MODERATE EARTHY LUSTER; CLAYEY TEXTURE; MASSIVE HOMOGENEOUS BED OF 60% SILT, 40% CLAY. • ~~ EPOGH 17 AURORA GAS, LLC ENDEAVOUR 1 • 4. DRILLING DATA 4.1. DAILYACT/V/TYSUMMARY 4/6/06: Rigging Up 4/7/06: Rig up procedures. Nipple up BOPs. Set and tighten down diverter spool and diverter. Install knife valve and hook up to diverter line. Install bell nipple. Change liners in pump #2 to 6". Mix spud mud. Nipple up BOPE. Rig down pick-up slings. Install rotary table. Rig up hydraulic elevators. Set mouse hole. Mix spud mud. Install shaker screens. Pressure up and check accumulator. Function check diverter. Install 4" cellar valves. Work on berms around rig. Clean rig floor and cellar. Pick 1 joint of HWDP for testing. Load sub rack and lifting subs to rig floor. Bolt down diverter line. Build, circulate, condition and shear mud. Pump air into boots on flow tee. Pin rotary. Perform tests (on diverter, accumulator, gas alarms, flow-show, pit monitors) for State certifier. Continue building berms. Test run both pumps. Shell test mud line to 2000psi. Continue to build, circulate and condition mud. Change shaker screens. Pick up and make up bottom hole assembly. Run in and drill out and clean out conductor. Drill from 102' to 137'. Initiate and calibrate PASON system during drilling. 4/8/06: Drill from 137' to 940'. (Break during drilling and run single shot surveys at 141', 170', 231', 322', and 822. 4/9/06: Drill from 940' to 1950'. (Break during drilling and run single shot surveys at 1301', 1800' and 1919'). 4/10/06: Drill from 1950' to 2073'. Circulate bottoms up. Survey (at 2042'). Drill from 2073' to 2200'. Circulate. Survey (at 2166. Drill from 2200' to 2263'. Circulate. Survey (at 2196'). Circulate bottoms up. Pull out of hole to inspect bit. Pump out to drill collars. Continue pulling out of hole. Note top stabilizer is • 1/4" out of gauge, bottom stabilizer is in gauge and bit is in gauge and in excellent condition. Begin running back in hole with Bit #1. 4/11/06: Continue running in hole. (Fill pipe at 1000'). Run in hole to 2200'. Ream from 2200' to 2263'. (Note 10' of fill). Record 78 units of trip gas. Drill from 2263' to 2319'. Circulate (15 minutes). Survey (at 2286. Drill from 2319' to 2420'. Survey (at 2413. Circulate bottoms up and circulate and condition mud. Pump around Hi-VislNut Plug sweep. Pump around another full circulation after sweep. Drill from 2420' to 2465' (Surface Casing TD). Circulate bottoms up and circulate and condition mud. Survey (at 2442. Pull out of hole {from 2465' to 1823'). 4/12/06: Pull out of hole (from 1823' to 424'). Lay down jars. Pull out of hole with remaining bottom hole assembly. Secure pipe spinner. Lay down stabilizers and break, grade and load off bit. Clear and clean rig floor. Prepare to run casing. Puii wear bushing. Change from drill pipe tongs to casing tongs. Change bails and elevators. Rig up GBR casing running tools. Rig up fill-up line. Hold pre-job meeting on safety and procedures for running casing. Pick up and make up 9 5/8" casing shpe track. Baleriok all float equipment and the bottom 4 joints of casing. Check floats. Run in hole with 53 joints of 9 5/8" casing (N- 80 40 Ibs/ft) filling every 5 joints. Tag fill at 2449'. Rig down and off load GBR casing running tools. Rig up circulating head and line. Pump down to 2457'. Circulate and condition mud while reciprocating pipe. Record 42 units of trip gas. Circulate around 2 casing volumes. Rig down circulating head and line. Rig up floor section of cementing lines. Install cementing head with plugs pre-loaded. Hold pre-job meeting with Schlumberger on safety and procedures during cementing. Switch to Schlumberger pumping unit. Pump 3 bbls of water and shut down. Pressure test lines to 2000psi. Bleed off pressure. Drop bottom plug. Pump 25 bbls of 10.2ppg Mud Push II weighted spacer. Batch up tub to 12.8ppg. Mix and pump 115.3 bbls of 12.8ppg lead slurry (329 sacks Class G cement plus 86.6 bbls mix water with accelerator chemicals), followed by 82 bbls of 15.8ppg (393 sacks Class G cement plus 47.7 bbls mix water with accelerator chemicals) while reciprocating casing. Shut down. Drop top plug and kick out with 5 bbls of water. Switch to rig pumps. Pump and displace cement with 178 bbls mud while continuing to reciprocate. • (Total displacement is 183 bbls). Slow pump rate down 10 bbls short of the top plug landing in the float collar. Bump plug with 500psi over circulating pressure (1400psi total pressure) and hold far 2 minutes. ~~ EPQCH 18 AURORA GAS, LLC ENDEAVOUR 1 • Stop reciprocating with the casing positioned at the bottom of the last down-stroke. Casing shoe set at 2457'. Bleed pressure off and verify floats are holding. Cement in place. Vyait on cement. Flush through stack and mud manifold. Rinse and blow down cementing head and Schlumberger lines. Rig down, lay down and load off cementing equipment. Load off Weatherford subs. Clear and Gean rig floor. Begin conditioning mud in pits. Suck out possum bellies. Disconnect and lay down 4" hoses. Nipple down and rig down diverter line and knife valve. Rig down shock hoses. Start pulling all but 4 joining bolts at each stack connection. 4/13/06: Wait on cement. Continue to condition mud. Prepare cellar for nipple down. Change oil in HPUs. Install flare line. Level pipe rack. Change out liner wash pump for Mud Pump #1. Pick up diverter. Rough cut and lay down 9 5/8" casing. Nipple down and set out mud manifold and annular. Remove and lay out starting head. Make final cuts on 13 3/8 and 9 5/8 casings. Start nipple up of BOPs. Finish dressing stub.. Final cut is 34 1/4" below ground level. Set wellhead 6" above ground level. lest wellhead to 2400psi for 10 minutes. Pull rotary. Pick up Hydril. Pick up and make up double gate. Open doors and install variable in-top rams and verify and make up blinds in lower double gate. Pick up and make single gate and mud manifold. Pick up and make up riser and DSA spool. Set stack on riser and make up. Install and make up choke and kill lines, bell nipple and flowline. Set rotary. Center stack on hole. Make up accumulator lines. Begin testing BOPs. Pick up and prepare testing equipment. Make up test joint. Make up floor valve and test cap to Topdrive. Fill stack for shell test. Observe leak during door seal Low test. Open door and clean, grease and reamake seals. Shell test Hydril to 250psi Low/ 3500psi High. Shell test to 5000psi on Top Rams and observe leak on lower door seal. Tighten seal and successfully retest to 5000psi. Final test Hydril to 250psi Low/ 3500psi High 4/14/06: Continue testing BOPs (pipe and blind rams, Topdrive, choke manifold, floorvalves, choke and kill line valves to 250psi Low / 3500psi High and hold for 5 minutes). Do performance test of the accumulator. Set wear ring. Lay down test joint. Make up bit and bit sub. Run in hole to 1025' making up bottom hole assembly. Continue running in hole. Tag at 2352'. Circulate and condition mud. Test casing • to 2850psi for 15 minutes. Tag float collar at 2360'. Drill shoe tract (float cellar, cement, casing shoe, old open hole) to 2465'. Drill 17' of new hole to 2482'. Circulate bottoms up and circulate and condition mud. (Mud weight is 9.3ppg in and out). Perform Formation Integrity Test (to 17,9 EMW). Drill from 2482' to 2682'. Circulate and condition mud and pump sweep from surface to surface. Survey (at 2650', 3.0 degrees). Perform injectivity leak off test (which failed, result same as shot; integrity test). Drill from 2682' to 2833'. 4/15/04: Drill from 2833' to 2882'. Perform injectivity test to 1050psi. Test failed. Drill from 2882' to 3089'. Survey (at 3048', 0.5 degrees). Perform injectivity test to 1100psi. Test failed. Drill from 3089' to 3299'.. Perform injectivity test. Test failed. Drill from 3299" to 3546'. Circulate bottoms up and circulate and condition mud. Pump sweep around. Perform injectivky test. Test failed. Survey (at 3516', 1.25 degrees). Drill from 3546' to 4010'. 4/16/06: Drill from 4010' to 4037'. Circulate and condition. Survey (at 4007', 1.0 degree). Peform injectivity test. Test failed. Drill from 4037 to 4256'. Circulate and condition mud. Perform injectivity test. Test failed. Drill from 4256' to 4530'. Circulate and condition. Pump around Hi-Vis sweep. Survey (at 4500', 2.0 degrees). Pump dry job. Pull out of hole on wiper trip to 2520' (inside shoe). Lubricate rig. Run in hole from 2420' to 4440'. Wash down last 90` to 4530'. Drill from 4530` to 4758`. 4/17/06: Drill from 4758' to 5022'. Circulate and condition mud. Survey (at 4992', 1.75 degrees). Drill from 5022' to 5512'.. 4/18/06: Circulate and condition mud. Survey (at 5484', 1.75 degrees}. Drill from 5512' to 6007'. Circulate and condition mud. Survey (at 5976', 1.75 degrees). Drill from 6007' to 6335'. 4/19106: Drill from 6335' to 6559'. Circulate bottoms up and circulate and condition mud. Survey (at 6529', • 3.0 degrees). Pull out of hole from 6559' to 4500' on wiper trip. Lubricate r1g. Run in hole from 4500' to 6559'. (Work through tight spots at 5303', 5335', 5453', 5529', and 5629'). Drill from 6559'to 6807'. Circulate bottoms up and circulate and condition mud. Survey (at 6776', 3.75 degrees). EPOCH 19 Aurora Pbwer AURORA GAS, LLC ENDEAVOUR 1 4/20106: Finish survey at 6776'. Drill from 6807' to 7021'. Circulate bottoms up. Pump sweep around. Survey (at 6985', 3.75 degrees). Monitor well for 10 minutes. Pull out of hgle (from 7021' to 1800') on bit trip. 4/21/06: Continue pulling out of hole on bit trip (from 1800' to 419'}. Pull bgttom hole assembly out of hole. Break bit. Pull wear ring. Make up test joint. Fill stack. Test Hydril to 250psi Low/3500psi High. Test top rams, kill line valves, choke line valves, floor valves, Topdrive valves, lower pipe rams to 250psi Low/5000psi High. Do accumulator perFormance test. Test blind rams to 250psi Low/5000psi High. Set wear ring. Lay down test joint. Make up bit. Run in hole with drill collars to 414'. Continue running in hole to 2256'. Fill pipe. Slip and cut 65' of drill line. Lubricate rig. Continue running in hole from 2256' to tight spot at 6979'. Kelly up and wash down to 7021'. Drill from 7021' to 7107'. Change shaker screens. 4/22/06: Drill from 7107' to 7236'. Survey ~ 7206', 4 deg. TVD 7199.1' Drill from 7236' to 7351'. Circ while change swab in pump #1. Drill from 7351' - 7360'. 4/23/06: Drill 7360' - 7449'. 4/24/06: Drill 7449' - 7470'. Condition mud. CBU. Pump dry job. Drop survey cLD 7450'. POOH to 2100'. Level derrick. POOH to 1025'. Monitor well for 10 minutes at BHA. Stand back BHA. Break off bit. Clean rig floor. Make up new bit. RIH w! BHA. 4/25J06: Cont trip in hole to 7294'. Ream 7294' - 7470. Drill 7470' - 7705'. CBU. Drop survey. POOH 7705' - 2400'. Mild swabbing 7300' - 7200'. Lubricate rig at shoe. Cont POOH. Stand back HWDP, UD jars. 4/26/06: Cont POOH. LD stabs. Break off bit. Remove survey tool. Clean floor. PU core barrel and jars. • RIH to 1018'. Fill pipe. RIH 1018' - 7662'. Ream 7662' - 7705'. Tag bottom. PU single, drop ball. Circ and condition mud. Core 7705' - 7735'. CBU at 6 bpm. LD single. POOH 7735' - 2400'. Work thru tight hole at 7570' - 7050'. Monitor well at shoe and service rig. POOH 2400 - 1020'. Monitor well at BHA and stand back HWDP. 4/27/06: POOH w/ BHA. LD core barrel and swivel assembly. Make up new core barrel and swivel assembly and LD. PU BHA and Trip in hole from 1020' to 2450'. Fill pipe at shoe. RIH, fill pipe at 5250'. Cont RIH to 7662'. Condition mud and Circ. Wash core section and CBU. Change shaker screens. Drill 7735' - 8006'. 4/28/06: Drill 8006' - 8216'. CBU. Survey ~ 8182', 4-5 deg inc. Drill 8216' - 8276'. CBU. Resurvey ~ 8241', 4.25 inc. Drill 8276' - 8333'. 4/29!06: Dril( 8333' - 8373'. CBU, pump dry job. POOH. Stand back BHA, clean rig floor. Test BOP, gas alarms and Koomey. Break out bit. Pick up motor, make up bit. RIH. Wash 8302' - 8373', and tag bottom @ 8373. CBU 4/30/06: Drill 8373' - 8550'. CBU and look at samples. Drill 8550' - 8697'. 5/01/06: Drill 8697' - 8734'. Survey ~ 8703', with 4.75 deg inc. Drill 8734' - 8805'. CBU. Monitor well for 10 min. POOH 5/02/06: Cont POOH. Break off bit, in gauge. Make up mill tooth bit, RIH. Top stab 1/2"out, Bottom stab 1/4" out of gauge. RIH to shoe. Cut 108' drill line. Fill pipe. Lubricate rig. RIH to 5000', fill pipe. RIH to 7000', Fill pipe. RIH to 8740'. Fill pipe and wash to bottom. CBU, bell nipple and shakers over flowing on bottoms up. Drill 8805' - 8972' 5/03/06: Drill 8972' - 9089'. CBU, monitor well for 10 minutes. Pump out of hole 9089' - 8700. POOH 8700' - 1046'. Monitor well for 10 minutes. Stand back HWDP, lay down jars. ~~ EPOCH 20 . ~~/17Cl1~ ~IA/@/' AURORA GAS, LLC ENDEAVOUR 1 . 5/04/06: Cont POOH with drill collars. No cones on bit. Lay down mud motor and bit sub, break off bit. Make up bit, bit sub and junk basket. RIH to 1080'. Lubricate rig and fill pipe. RIH and fill pipe ~ 4000', 5300', 6500', 8950'. Ream 8950' - 9089'. Dri119089' - 9150'. 5/05/06: Drill to 9153'. CBU. POOH to 8530', pump dry job. POOH. Break off bit, stabs wore out. Test BOP. Perforrn Koomey test. Change out lower pipe rams, replace rubbers. Cont BOP test. Make up bit and trip in hole. 5/06/06: Trip in hole fill pipe every 2000'. Drill 9153' - 9225'. CBU. Pump FII VIS sweep. Drop survey tool. Pump dry job. POOH. 5/07/06: Finish POOH. Break off bit, pull survey tool, make up bit. Pre job safety meeting with Schlumberger for wireline logging. Rig up Schlumberger. Make up tool, load sources. RIH and log Platform express with CMR. Lay down Platform express and pick up FMI/QSI tools. RIH and log. 5/08/06: Wireline log. Rig down Schlumberger. RIH to 2051'. POOH and Icy down pipe. Move Schlumberger unit from end of catwalk. Mix and pump dry job. Cont POOH and UD drill pipe, HWDP, collars and bit. Make up mule shoe and RIH. U • EPOCH 21 • • i Aunora P1'lawer AURORA GAS, LLC ENDEAVOUR 1 SURVEY RECORD (single shot survey) Measured Depth /nclinatfon Azimuth ND Vertical Section Rectangular Coordinate Rectangular Coordinate Closure Closure Azimuth DLS ft (de (de ft) ft ft) (ft ft) de de /100ft) 141 3.5 140.9 170 2.0 169.9 231 2.0 230.8 322 1.75 321.8 597 1.75 596.7 822 1.0 821.6 1301 2.0 1300.4 1800 4.25 1798.7 1919 5.0 1917.3 2042 4.5 2039.8 2166 4.75 2163.4 2196 3.9 2193.27 2286 4.25 2283.04 2413 3.5 2409.75 2442 3.5 2438.69 2653 3.0 2649.35 2881 3.0 2877.04 3048 0.5 3044.07 3516 1.25 3512.01 4007 1.0 4002.91 4500 2.0 4495.72 4992 1.75 4987.46 5484 1.75 5479.23 5976 1.75 5971.00 6529 3.0 6523.49 6776 3.75 6770.06 6985 3.75 6978.61 7206 4.0 7199.10 €~ EPOCH 22 • Aurora mower AURORA GAS, LLC ENDEAVOUR 1 Measured Depth inclination Azimuth ND Vertical Section Rectangular Coordinate (+) N/S (-) Rectangular Coordinate (+) EJW (-) Closure Closure Azimuth DLS ft de ) (de ) ft ft (ft ft) (ft de (de /100 ft 7450 2.5 7442.7 7705 3,5 7697.4 8241 4.25 8232.1 8703 4.75 8692.7 9225 4.0 9213.2 ~~ EP(JGI~ 23 • • Aurora /~CI-wer AURORA GAS, LLC ENDEAVOUR 1 4.2. MUD RECORD Contractor: Baroid Mud Type: KCI/Polymer: 102' - 9225' DATE MD MW VIS PV YP GELS FL FC SOL OIL/H20 SD MBT pH Alk CI- Ca+ 4/7/06 175' 9.0 52 7 16 6/9/0 11.0 1 /0 1.6 0/96 0.10 0 9.8 0.10 29000 28 4/8/06 946' 9.3+ 65 13 41 17/26/0 6.0 1 /0 3.6 0/94 0.30 5.5 9.0 0.10 29000 104 4/9/06 1955' 9.3 45 9 24 9/15/0 6.5 1 /0 2.7 0/95 0.70 12.5 9.2 0.10 28000 128 4/10/06 2263' 9.3 49 11 20 9/22/0 7.0 1/0 2.6 0/95 0.50 7.5 9.0 0.10 29000 188 4/11 /06 2465' 9.3 44 11 16 5/1510 6.0 1 /0 2.6 0/95 0.50 10.0 9.0 0.10 29000 160 4/12/06 2465' 9.2 44 12 14 5/17/0 6.5 1 /0 2.7 0/95 0.50 7.5 9.0 0.10 28000 320 4/13/06 2465' 9.1 45 11 16 5/12/0 7.0 1 /0 2.6 0/95 0.50 7.5 8.7 0.10 29000 720 4/14/06 2864' 9.3 47 12 19 5!16/0 6.5 1 /0 2.8 0/95 0.50 10.0 9.5 0.10 26000 320 4/15/06 4017' 9.3 47 17 20 5/20/0 6.5 1 /0 2.6 0/95 0.50 10.0 9.5 0.10 29000 450 4/16/06 4754' 9.3 44 10 14 4/14/0 6.5 1 /0 2.8 0/95 0.50 10.0 8.5 0 26000 400 4/17/06 5513' 9.3 45 11 17 7/18/0 7.0 1/0 2.6 0/95 0.50 10.0 9.0 0 29000 320 4/18/06 6340' 9.3 44 11 13 4/0/0 7.0 1 /0 2.6 0/95 0.30 10.0 9.3 0 29000 160 4/19/06 6807' 9.5 44 11 10 2/8/0 6.5 1/0 3.6 0/94 0.30 10.0 9.5 0.10 29000 80 4/20/06 7021' 9.3 44 12 12 2/5/0 0 0/1 2.5 0/95 0.30 7.5 9.2 0 30000 160 4/21!06 7107' 9.3 44 11 11 2/7/0 0 0/1 2.4 0/95 0.30 10.0 9.3 0 31000 120 4/22/06 7361' 9.3 45 13 13 2/6/0 0 O/2 2.4 0/95 0.30 10.0 9.1 0 31000 200 4/23/06 7450' 9.3 47 12 16 3/8/0 0 0/2 2.4 0/95 0.30 10.0 9.1 0 31000 160 4/24/06 7470' 9.3 48 14 12 3/6/0 4.9 1 /0 3.5 0/94 0.25 9.0 9.0 0.10 30000 60 4/25/06 7705' 9.3 51 18 14 4/6/8 4.1 0/1 3.5 0/94 0.25 8.0 $.9 0.10 31000 120 4/26/06 7735' 9.3 49 15 14 3/5/7 4.3 1 /0 3.5 0/94 0.0 $.8 8.9 0.10 31000 120 4/27/06 8000' 9.3 52 21 15 4/6/8 3.8 1 /3 3.5 0/94 0.25 7.0 $.9 0.10 30000 120 4/28/06 8320' 9.3 48 16 13 315/7 3.7 1 /0 4.1 0/93.5 0.25 7.0 8.9 0.10 29000 120 4!29/06 8373' 9.3 52 18 14 4/6/8 3.7 1 /3 4.1 O/93.5 0.0 7.0 8.8 0.05 30000 120 4/30/06 8690' 9.3 52 16 15 4/6/0 3.7 1 /3 4.1 0/93.5 0.25 7.0 8.8 0.10 29000 120 EP(JCH 24 • ~ • 14urora Power AURORA GAS, LLC ENDEAVOUR 1 DATE MD MW VIS PV YP GELS FL FC SOL OIL/H20 SD MBT pH Alk CI- Ca+ 5/01 /06 8805 9.3 51 16 13 4/7/0 3.6 1 /3 4.1 0/93.5 0 7.0 8.8 0.10 29000 100 5/02/06 8960 9.3 51 19 14 4/6/7 3.8 1 /3 4.2 0/93.5 .25 7.5 9.0 0.10 28000 120 5/03/06 9089 9.3 52 18 14 4/6/7 3.6 1/3 4.1 0/93.5 0 7.5 8.$ 0.10 29000 100 5/04/06 9140 9.3 51 20 14 3/5/7 3.4 1 /3 4.2 0/93.5 .25 7.5 9.0 0.10 28000 120 5/05/06 9153 9.3 53 20 13 4/6/0 3.8 1 /3 4.2 0/93.5 0 7.5 8.8 0.05 28000 120 5/06/06 9225 9.3 53 20 14 4/6/9 3.8 1 /3 4.2 0/93.5 0 7.5 9.0 0.10 28000 120 5/07/06 9225 9.3 53 20 15 4/5/0 4.2 1 /3 4.2 0/93.5 0 7.5 $.7 0.10 28000 100 5/08/06 9225 9.3 53 19 15 5/7/0 4.3 1/0 4.2 0!93.5 0 7.5 8.8 0.10 2$000 100 ~~ EPCaCH 25 • ~ • -Aurora Pbwer AURORA GAS, LLC ENDEAVOUR 1 4.3. BIT RECORD R PP BIT SIZE TYPE SJN JETS/ IN OUT FT HRS AVE WOB P Lo -Avg CONDITION NO. °° TFA ROP Lo -Avg - Hi - Hi 1 1 12 25 STC XR+ - 2X14, 101 2465 2364 65.5 58.8 0-11-32 2 594-1270-1961 1-1N0-A-E-1-NO-TD . 1X8 0 1 2 8.5 SEC FS2653 10684401 6X13 2465 7021 4556 103.7 84.6 0-7-26 1 412-1187-1760 4-8-WT-S-X-1-BT-PR 0 3 8 5 SEC FM2643 _ 3X13, 7021 7470 449 53.3 -33.1 2-14-34 9 66-1055-1703 5-8-WT-N-X-1-CT-PR . 3X15 5 4 8 5 SEC FM 3649 10749119 5X13, 7470 7705 235 9 $ 24.0 0-6-27 9 1054-1369- 1-1-NO-A-X-I-NO-CP . 15 . 4 1622 5 8 5 CORE BIT 4980966 9x13 7705 7735 30 2 7 11.1 6-10-15 6 556-628- NO GRADE . REED CD93 . 1 1417 Rr4 8 5 SEC FM 3649 10749119 3x13, 7735 8373 638 36 0 17.7 2-$-15 9 624-1655- NO GRADE . 15 . 5 1976 RR4 3x13 9 1913-2183- 7-2-RO/PNMIT-N-N/A- BHA 8.5 SEC FM3649 10749119 , 15 8373 8805 432 36.6 11.8 4-10-20 7 2484 IN-BU-PR 7 7 8.5 SEC XSC1 S 10700513 3x20 8805 90$9 284 25.8 11.0 1-14-21 5 8 1995-2243- 2619 NO CONES 8 8 5 SEC 10725472 3X20 9089 9153 64 15 0 4 3 3-15-21 8 1099-1869- 6-1-BTMIT-M/G-E-IN- - . XSC1 S . . 7 2619 PR/TQ 9 8 5 HUGHES 6046677 3x20 9153 9225 72 3 10 7 0 1-14-19 7 982-1823- 0-0-NO- -E-IN- -TD MXL18DX . . 7 2301 ~~ EPOCH 26 r~ 4/8 4/9 4/10 4/11 4/12 4/13 4/14 4/16 4/16 4/17 4/18 4/19 4/20 4/21 4/22 4/23 4/24 4/26 4/26 4/27 4/28 4/29 4/30 6/1 6/2 6/3 6/4 6/6 6/6 6/7 6/8 Aurora Power 4.4. DRILLING PROGRESS CHART • AURORA GAS, LLC ENDEAVOUR 1 ~~ EPOCH • -0 -1000 -2000 -3000 -4000 -5000 ---~-DEPTH -6000 -7000 -8000 -9000 -10000 27 Endeavour-1 Days vs Depth Day 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 ~~ - AUPD/~ ~We~" AURORA GAS, LLC ENDEAVOUR 1 • ~~ EPOCH WELL SERVICIES INC. Samples taken by: Company: AURORA Edward Revollo, Patrick Walker and Well: Endeavour # 1 Dan Lee Field: Anchor Point Depth: 9225 feet May 6 of 2006 Samples each30 feet, from 2280' to 6510' Samples each 10 feet, from 6520' to 9225' TD Wet samples, set A: BOX # DEPTH Box # 1 2280' to 3720' Box # 2 3750' to 5160' Box # 3 5190' to 6590' Box # 4 6600' to 7180' Box # 5 7190' to 7730' Box # 6 7740' to 8280' Box # 7 8290' to 8890' Box # 8 8900' to 9225' Dry samples, set A, B, and C: BOX # DEPTH Box # 1 2280' to 3600' Box # 2 3630' to 4890' Box # 3 4920' to 5120' Box # 4 6150' to 6760' Box # 5 6770' to 7170' Box # 6 7180' to 7580' Box # 7 7590' to 7890' Box # 8 7900' to 8210' Box # 9 8220' to 8600' Box # 10 8610' to 8490 Box # 11 9000' to 9225' Total boxes for wet samples 8, from 2280' to 9225' Total boxes for dry samples 10, from 2280' to 9225' €~ EPCJCH 28 {{''~~ CORE REPO ~~V ~~ OPERATOR Aurora Gas, LLC WELL NAME Endeavour #1 LOCATION Sec 3, T5N, R15W SW BOROUGH /STATE Kenai Borough, Alaska DATE: 4/27/2006 DESCRIPTIONS CORE No.: CORE INTERVAL: FOOTAGE DRILLED: FOOTAGE RECOVERED: PERCENT RECOVERY: • 7705' - 7735' 30' 30' 100% DEPTH LITHOLOGY SECONDARY STRUCTURE GRAIN SORT POR- ODOR VISIBLE SAMPLE CUT VISIBLE OIL REMARKS COMPOSITION SIZE OSITY STAIN FLUORESCENCE FLUORESCENCE CUT RATING (CEMENT, INDUR, BED LAM FISS FOSSILS, ETC.) ~ W ~ a ~ 3 ~ Z °w o O~ '~ C °W a~ U~ a ~ r W F F F z~ ~'~ ~ 5 y ''~ ~,w3 ~' "rr'. ~ a u ~ x° ~ F h ~ O e W ~ ~ ~ ~ a ~ ~ z ~ ~ ~ y ~ a z ~ x i ~ 3 ~ ~ F z z ~ O O a w ~ zQ y, ~ ~ . O ~ a z ~ Wz a pa w z ~ O 8 F a ~ ~ ~ a ~" w~~ ~ pO O 0 6 a a O O O ~ O H % C ~ ee 0~ ~ a `~ ~ ~ ' a F e e „ G O PO , a ¢ d . 6 . o . a > COLOR a COLOR % a a COLOR ce a a F y ']'JQS"- 1 sandstone it-med and well compacted ss ']']~$ gmy sl x x X x x x R X x abnt volt ash ']']Q$- 1 sandstone It-med and well compacted ss ']~] ] ~' gray sl x x X X X x x x x X x bnt volt ash, incr pebble size T] 1 j- sandstone It gry 'creased cobble size some ']'Jr4' 1 s&p sl x x x x x x x x x x 'sh gry colors 7714- conglomerate gmish olcanic cobble very hrad ']'] ], 7' j sandstone gmy a x x x x x X X &w crystal inclusions 2-3" 7717- conglomerate dk gtnish ~ gry tong sand 772` 1 sandstone gray x x x x x x x x ery coarse 772- conp~omerate It gry caic It gmy s&p tong ss 7723` 1 sandstone s&p X x X x x x X x g to rdd easily breaks 7723- med gry bnt ashlday supported 772(' ], sandstone s&p x X x 8 x x x x X x easily breaks apart ']726- conglomerate med gry fine ko v ooarse se poor 7729' ]. sandstone s&p x x X x x x x X x x sorting well cemented 7729- conglomerate mad gry fine to v coarse as poor 7732 1 sandstone s @p X X x x X X x X x X sorting well cemented ']732_ conglomerate med gry x x x x x x x x x x x x 'tional fir to crs, fri. ']']~ $ ~ 1 sandstone gry-gm it cem to hd very talc e scattered mineral fluorescence overall o show of oil fluorescence roil cuts in core ~p = salt ~ pepper EXCEL / CORE.XLS Daily Report Aurora Gas, LLC Ecploratory Endeavour1 REPORT FOR Jack McDade DATE Apr 07, 2006 TIME 24:00 • C ~ 52 PV 1.6 SD CASING INFORMATION 13 3/8" @ 101' SURVEY DATA DEPTH INCLINATION BIT INFORMATION INTERVAL NO. SIZE TYPE S/N JETS IN OUT 1 12.25 STC XR+ PC5307 2x14, 12, 8 101 DRILLING PARAMETERS RATE OF PENETRATION SURFACETOROUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.0 VIS FC 1 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) DITCH GAS CUTTING GAS DAILY WELLSITE REPORT DEPTH 137 YESTERDAY 101 24 HOUR FOOTAGE 36 HIGH 98.2 @ 115 6 @ 115 115 @ 112 1349 @ 112 DEPTH 175 7 YP 0.1 OIL AZIMUTH [~ EPOCH PRESENT OPERATION Drilling VERTICAL DEPTH CONDITION REASON FOOTAGE HOURS T/B/C PULLED 36 1.7 In Hole LOW AVERAGE CURRENT AVG 44.3 @ 134 73.7 62.3 FT/HR @ AMPS 5 @ 134 6.7 6.3 KLBS 115 @ 137 120.3 115.7 RPM 1349 @ 137 1403.3 1349.3 PSI 16 FL 11.0 Gels 6/9/10 CL- 29000 0/96 MBL 0.0 pH 9.8 Ca+ 28 CCI HIGH LOW AVERAGE 2 @ 137 1 @ 125 1.5 @ @ CHROMATOGRAPHY (ppm) Page 1 of 2 TRIP GAS WIPER GAS SURVEY METHANE (C-1) 395 @ 137 207 @ 125 297.0 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 1 / 1.5 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Rig up procedures. Nipple up BOPs. Set and tighten down diverter spool and diverter. Install knife valve and hook up to diverter line. Install bell nipple. Change liners in pump #2 to 6". Mix spud mud. Nipple up BOPE. Rig down pick-up slings. Install rotary table. Rig up hydraulic elevators. Set mouse hole. Mix spud mud. Install shaker screens. Pressure DAILY up and check accumulator. Function check diverter. Install 4" cellar valves. Work on berms around rig. Clean rig floor ACTIVITY and cellar. Pick 1 joint of HWDP for testing. Load sub rack and lifting subs to rig floor. Bolt down diverter line. Build, SUMMARY circulate, condition and shear mud. Pump air into boots on flow tee. Pin rotary. Perform tests (on diverter, accumulator, gas alarms, flow-show, pit monitors) for State certifier. Continue building berms. Test run both pumps. Shell test mud line to 2000psi. Continue to build, circulate and condition mud. Change shaker screens. Pick up and make up bottom hole assembly. Run in and drill out and clean out conductor. Drill from 102' to 137'. Initiate and calibrate PASON system during drilling. EPOCH PERSONNEL ON BOARD 2 DAILY COST ML: 1400 RW: 275 file://D:\Aurora\Morning%20Reports\20060407.htm ~ /~ s i~ nnti Daily Report Page 2 of 2 • • REPORT BY Craig Silva file://D:\Aurora\Morning%20Reports\20060407.htm 5/25/2006 • • • Daily Report Page 1 of 1 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT r,P~~,H Endeavour1 REPORT FOR Jack McDade DATE Apr 08, 2006 DEPTH 940 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 137 24 HOUR FOOTAGE 803 CASING INFORMATION 13 3/8" @ 101' DEPTH INCLINATION ,AZIMUTH VERTICAL DEPTH 141 3.5 140.87 170 2 169.83 SURVEY DATA 231 2 230.80 322 1.75 321.75 822 1.0 821.59 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE H OURS T/B/C PULLED 1 12.25 STC XR+ PC5307 2x14, 12, 8 101 839 16.2 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 161.3 @ 914 3.6 @ 410 66.5 61.7 FT/HR SURFACETOROUE @ @ AMPS WEIGHT ON BIT 32 @ 914 0 @ 438 9.3 16.5 KLBS ROTARY RPM 115 @ 138 100 @ 940 115.5 100.6 RPM PUMP PRESSURE 1395 @ 940 1347 @ 929 1351.3 1395.6 PSI DRILLING MUD REPORT DEPTH 946 MW 9.35 VIS 65 PV 13 YP 41 FL 6.0 Gels 17/26/30 CL- 29000 FC 1 SOL 3.6 SD 0.30 OIL 0/94 MBL 5.5 pH 9.0 Ca+ 104 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 74 @ 763 1 @ 680 14.1 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 14674 .@ 763 197 @ 680 2794.9 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 2 / 24 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Drill from 137' to 940'. (Break during drilling and run single shot surveys at 141', 170', 231', 322', and SUMMARY 822'). EPOCH PERSONNEL ON BOARD 2 DAILY COST ML: 1400 RW: 275 REPORT BY Craig Silva file: //D:\Aurora\Morning%20Reports\20060408.htm 5/25/2006 Daily Report Page 1 of 1 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT ~,~~~,H Endeavour1 REPORT FOR Jack McD ade DATE Apr 09, 2006 DEPTH 1950 PRESENT OPERATION Drilling (and stopping to run surveys) TIME 24:00 YESTERDAY 940 24 HOUR FOOTAGE 1010 CASING INFORMATION 13 3/8" @ 101' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1301 2.0 1300.41 SURVEY DATA 1800 4.75 1798.57 1919 5.0 1917.18 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25 STC XR+ PC5307 2x14, 12, 8 101 1849 35.3 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 152.6 @ 1080 5.6 @ 1813 68.6 69.5 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 22 @ 1337 6 @ 1860 15.0 10.9 KLBS ROTARY RPM 159 @ 1947 72 @ 1653 106.6 157.5 RPM PUMP PRESSURE 1560 @ 1715 951 @ 1179 1269.2 1338.3 PSI DRILLING MUD REPORT DEPTH 1955 MW 9.3 VIS 45 PV 9 YP 24 FL 6.5 Gels 9/15/20 CL- 28000 FC 1 SOL 2.7 SD 0.7 OIL 0/95 MBL 12.5 pH 9.2 Ca+ 128 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 196 @ 1882 3 @ 1764 33.9 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 39372 @ 1882 631 @ 1764 6572.8 CON NECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 12 / 36 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drill from 940' to 1950'. (Break during drilling and run single shot surveys at 1301', 1800' and 1919'). EPOCH PERSONNEL ON BOARD 2 DAILY COST ML: 1400 RW: 275 • REPORT BY Craig Silva file: //D :\Aurora\Morning%20Reports\20060409.htm 5/25/2006 Daily Report • • Page 1 of 1 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT F,+~~~,H Endeavour1 REPORT FOR Jack McDade DATE Apr 10, 2006 DEPTH 2263 PRESENT OPERATION P ulling out of hole to inspect bit TIME 24:00 YESTERDAY 1950 24 HOUR FOOTAGE 313 CASING INFORMATION 13 3/8" @ 101' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2042 4.5 2039.76 SURVEY DATA 2166 4.75 2163.35 2196 3.9 2193.27 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25 STC XR+ PC5307 2x14, 12, 8 101 2263 2162. 51.3 NG (Excellent) Inspect bit DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 109.6 @ 2230 2.5 @ 2261 31.7 2.5 FT/HR SURFACETOROUE @ @ AMPS WEIGHT ON BIT 19 @ 2263 1 @ 2159 8.3 19.8 KLBS ROTARY RPM 176 @ 2068 108 @ 2138 148.1 131.1 RPM PUMP PRESSURE 1961 @ 2213 732 @ 2199 1107.4 1327.6 PSI DRILLING MUD REPORT DEPTH 2263 MW 9.3 VIS 49 PV 11 YP 20 FL 7.0 Gels 9/22/- CL- 29000 FC 1 SOL 2.6 SD 0.50 OIL 0/95 MBL 7.5 pH 9.0 Ca+ 188 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 101 @ 1989. 5 @ 2219 23.8 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 20344 @ 1989 1137 @ 2219 4761.5 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY Drill from 1950' to 2073'. Circulate bottoms up. Survey (at 2042'). Drill from 2073' to 2200'. Circulate. Survey (at ACTIVITY 2166'). Drill from 2200' to 2263'. Circulate. Survey (at 2196'). Circulate bottoms up. Pull out of hole to inspect bit. SUMMARY Pump out to drill collars. Continue pulling out of hole. Note top stabilizer is 1/4" out of gauge, bottom stabilizer is in gauge and bit is in gauge and in excellent condition. Begin running back in hole with Bit #1. • EPOCH PERSONNEL ON BOARD 2 DAILY COST MW: 1400 RW: 275 REPORT BY Craig Silva file://D:\Aurora\Morning%20Reports\2006041 O.htm 5/25/2006 r~ L.J • • Daily Report Page 1 of 2 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT EI'Q~,H Endeavour1 REPORT FOR Jack McDade DATE Apr 11, 2006 DEPTH 2465 PRESENT OPERATION Pulling out of hole to run 9 5/8" casing TIME 24:00 YESTERDAY 2263 24 HOUR FOOTAGE 202 CASING INFORMATION 13 3/8" @ 101' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2286 4.25 2283.04 SURVEY DATA 2413 3.5 2409.75 2442 3.5 2438.69 2465 (Projection) 3.5 2461.65 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN -0UT FOOTAGE HOURS 7/B/C PULLED 1 12.25 STC XR+ PC5307 2x14, 12, 8 101 2465 2364 65.5 In Hole Casing point DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 64.6 @ 2265 2.5 @ 2263 20.3 44.5 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 19 @ 2263 2 @ 2356 7.9 10.2 KLBS ROTARY RPM 167 @ 2301 131 @ 2263 162.7 154.1 RPM PUMP PRESSURE 1356 @ 2417 594 @ 2264 1207.5 1294.3 PSI DRILLING MUD REPORT DEPTH 2465 / 2462 TVD MW 9.3 VIS 44 PV 11 YP 16 FL 6.0 Gels 5/15/ CL- 29000 FC 1 SOL 2.6 SD 0.50 OIL 0/95 MBL 10.0 pH 9.0 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 315 @ 2419 7 @ 2275 26.6 TRIP GAS 78 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 62957 @ 2419 1540 @ 2275 5323.8 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Major Tuffaceous Siltstone, Tuffaceous Claystone, Sandstone/Sand, Coal/Carboncaeous Shale. Minor Tuffaceous Sandstone, Calcareous Tuff, Volcanic Ash, Tuffaceous Shale. PRESENT .......TUFFACEOUS SILTSTONE..........TUFFACEOUS SANDSTONE..........TUFFACEOUS CLAYSTONE.......... LITHOLOGY Continue running in hole. (Fill pipe at 1000'). Run in hole to 2200'. Ream from 2200' to 2263'. (Note 10' of fill). Record DAILY 78 units of trip gas. Drill from 2263' to 2319'. Circulate (15 minutes). Survey (at 2286'). Drill from 2319' to 2420'. ACTIVITY Survey (at 2413'). Circulate bottoms up and circulate and condition mud. Pump around Hi-Vis/Nut Plug sweep. Pump SUMMARY around another full circulation after sweep. Drill from 2420' to 2465' (Surface Casing TD). Circulate bottoms up and circulate and condition mud. Survey (at 2442'). Pull out of hole (from 2465' to 1823'). file:J/D :\Aurora\Morning%20Reports\20060411.htm 5/25/2006 Daily Report EPOCH PERSONNEL ON BOARD 2 DAILY COST MW: 1400 RW: 275 • REPORT BY Craig Silva • • file : //D : \Aurora\Morning%20Reports\20060411. htm Page 2 of 2 5/25/2006 r C Daily Report Page 1 of 2 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT El'O~~H Endeavour1 REPORT FOR Jack McDade DATE Apr 12, DEPTH 2465 PRESENT Waiting on cement and making preparations for BOP nipple 2006 OPERATION down TIME 24:00 YESTERDAY 2465 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 2457 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25 STC XR+ PC5307 2x14, 12, 8 101 2465 2364 65.5 1-1-NO-A-E-1-NO-TD Casing point DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 2465 / 2462 TVD MW 9.2 VIS 44 PV 12 YP 14 FL 6.5 Gels 5/17/ CL- 28000 FC 1.0 SOL 2.7 SD 0.50. OIL 0/95 MBL 7.5 pH 9.0 Ca+ 320 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 42 @ TG during cmtng 6 @ at pump shut down N/A TRIP GAS 42 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Pull out of hole (from 1823' to 424'). Lay down jars. Pull out of hole with remaining bottom hole assembly. Secure pipe spinner. Lay down stabilizers and break, grade and load off bit. Clear and clean rig floor. Prepare to run casing. Pull wear bushing. Change from drill pipe tongs to casing tongs. Change bails and elevators. Rig up GBR casing running tools. Rig up fill-up line. Hold pre-job meeting on safety and procedures for running casing. Pick up and make up 9 5/8" casing shoe track. 8alerlok all float equipment and the bottom 4 joints of casing. Check floats. Run in hole with 53 joints of 9 5/8" casing (N-80 40 Ibs/ft) filling every 5 joints. Tag fill at 2449'. Rig down and off load GBR casing running tools. Rig up circulating head and line. Pump down to 2457'. Circulate and condition mud while reciprocating pipe. Record 42 units of trip gas. Circuiate around 2 casing volumes. Rig down circulating head and line. Rig up floor section of cementing lines. Install cementing head with plugs pre-loaded. Hold pre-job meeting with Schlumberger on safety and procedures during DAILY cementing. Switch to Schlumberger pumping unit. Pump 3 bbls of water and shut down. Pressure test lines to 2000psi. ACTIVITY Bleed off pressure. Drop bottom plug. Pump 25 bbls of 10.2ppg Mud Push II weighted spacer. Batch up tub to 12.8ppg. file : //D :\Aurora\Morning%20Reports\20060412. htm 5/25/2006 Daily Report Page 2 of 2 SUMMARY Mix and pump 115.3 bbls of 12.8ppg lead slurry (329 sacks Class G cement plus 86.6 bbls mix water with accelerator chemicals), followed by 82 bbls of 15.8ppg (393 sacks Class G cement plus 47.7 bbls mix water with accelerator chemicals) while reciprocating casing. Shut down. Drop top plug and kick out with 5 bbls of water. Switch to rig pumps. Pump and displace cement with 178 bbls mud while continuing to reciprocate. (Total displacement is 183 bbls). Slow pump rate down 10 bbls short of the top plug landing in the float collar. Bump plug with 500psi over circulating pressure (1400psi total pressure) and hold for 2 minutes. Stop reciprocating with the casing positioned at the bottom of the fast down-stroke. Casing shoe set at 2457'. Bleed pressure off and verify floats are holding. Cement in place. Wait on cement. Flush through stack and mud manifold. Rinse and blow down cementing head and Schlumberger lines. Rig down, lay down and load off cementing equipment. Load off Weatherford subs. Clear and clean rig floor. Begin conditioning mud in pits. Suck out possum bellies. Disconnect and lay down 4" hoses. Nipple down and rig down diverter line and knife valve. Rig down shock hoses. Start pulling all but 4 joining bolts at each stack connection. EPOCH PERSONNEL ON BOARD 2 DAILY COST ML: 1400 RW: 275 REPORT BY Craig Silva • file://D:\Aurora\Morning%20Reports\20060412.htm 5/25/2006 • • Daily Report Page 1 of 2 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT ~,P~~,H Endeavour1 REPORT FOR Jack McDade DATE Apr 13, 2006 DEPTH 2465 PRESENT OPERATION Testing BOPs TIME 24:00 YESTERDAY 2465 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 2457' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 2465 / 2462 TVD MW 9.1 VIS 45 PV 11 YP 16 FL 7.0 Gels 5/12/ CL- 29000 FC 1 SOL 2.6 SD 0.50 OIL 0/95 MBL 7.5 pH 8.7 Ca+ 720 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Wait on cement. Continue to condition mud. Prepare cellar for nipple down. Change oil in HPUs. Install flare line. Level pipe rack. Change out liner wash pump for Mud Pump #1. Pick up diverter. Rough cut and lay down 9 5/8" casing. Nipple down and set out mud manifold and annular. Remove and lay out starting head. Make final cuts on 13 3/8 and 9 5/8 casings. Start nipple up of BOPS. Finish dressing stub. Final cut is 34 1/4" below ground level. Set wellhead 6" DAILY above ground level. Test wellhead to 2400psi for 10 minutes. Pull rotary. Pick up Hydril. Pick up and make up double ACTIVITY gate. Open doors and install variable in top rams and verify and make up blinds in lower double gate. Pick up and make SUMMARY single gate and mud manifold. Pick up and make up riser and DSA spool. Set stack on riser and make up. Install and make up choke and kill lines, bell nipple and flowline. Set rotary. Center stack on hole. Make up accumulator lines. Begin testing BOPs. Pick up and prepare testing equipment. Make up test joint. Make up floor valve and test cap to Topdrive. Fill stack for shell test. Observe leak during door seal Low test. Open door and clean, grease and reamake seals. Shell test Hydril to 250psi Low/ 3500psi High. Shell test to 5000psi on Top Rams and observe leak on lower door seal. Tighten seal and successfully retest to 5000psi. Final test Hydril to 250psi Low/ 3500psi High. file://D:\Aurora\Morning%20Reports\20060413 .htm 5/25/2006 Daily Report EPOCH PERSONNEL ON BOARD 2 DAILY COST ML: 1400 RW: 275 REPORT BY Craig Silva • r ~~ file://D :\Aurora\Morning%20Reports\20060413 .htm Page 2 of 2 5/25/2006 U • ., Daily Report Page 1 of 2 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT T,~~~,H Endeavour) REPORT FOR Jack McDade DATE Apr 14, 2006 DEPTH 2833 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 2465 24 HOUR FOOTAGE 368 CASING INFORMATION 9 5/8" @ 2457' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2653 3.0 2649.35 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5 SEC FS 2653 10684401 6x13 2465 368 9.0 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 151.0 @ 2562 7.1 @ 2482 60.5 84.2 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 10 @ 2809 0 @ 2491 4.2 9.9 KLBS ROTARY RPM 143 @ 2762 90 @ 2561 121.5 124.0 RPM PUMP PRESSURE 1247 @ 2615 962 @ 2486 1116.6 1138.0 PSI DRILLING MUD REPORT DEPTH 2864 / 2860 TVD MW 9.3 VIS 47 PV 12 YP 19 FL 6.5 Gels 5/16/ CL- 26000 FC 1 SOL 2.8 SD 0.50 OIL 0/95 MBL 10.0 pH 9.5 Ca+ 320 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 250 @ 2670 2 @ 2500 39.0 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 49991 @ 2670 445 @ 2500 7699.9 CONNECTION GAS HIGH ETHANE (C-2) 55 @ 2677 0 @ 4.0 AVG PROPANE (C-3) 20 @ 2677 0 @ 1.0 CURRENT BUTANE (C-4) 6 @ 2763 0 @ 0.0 CURRENT BACKGROUND/AVG 25 / 40 PENTANE (C-5) @ @ HYDROCARBON SHOWS No oil indicators in any of the sands. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION Many thin sands with gas over Increased gas from zones that Maximum gas from Sand/SS =fairly "clean", salt and 100 units, but no sustained generate disaggregated grains and relatively massive pepper, light med gry, fn-med, mod w increase in background after zones of consol ss. clean sandstone is srtd; disaggregated; sublithic to lithic drilling through. 104units arenite; no oil indicators. LITHOLOGY Major Sand/Sandstone, Tuffaceous Claystone, Tuffaceous Siltstone, Coal/Carbonaceous Shale. Minor Tuffaceous Sandstone, Volcanic Ash, Calcareous Tuff. PRESENT ..........TUFFACEOUS SANDSTONE..........COAL.......... LITHOLOGY DAILY Continue testing BOPS (pipe and blind rams, Topdrive, choke manifold, floor valves, choke and kill line valves to 250psi ACTIVITY Low / 3500psi High and hold for 5 minutes}. Do performance test of the accumulator. Set wear ring. Lay down test joint. i SUMMARY Make up bit and bit sub. Run in hole to 1025' making up bottom hole assembly. Continue running in hole. Tag at 2352'. Circulate and condition mud. Test casing to 2850psi for 15 minutes. Tag float collar at 2360'. Drill shoe tract (float collar, cement, casing shoe, old open hole) to 2465'. Drill 17' of new hole to 2482'. Circulate bottoms up and circulate and file://D :\Aurora\Morning%20Reports\20060414.htm 5/25/2006 • Daily Report Page 2 of 2 condition mud. (Mud weight is 9.3ppg in and out). Perform Formation Integrity Test (to 17.9 EMW). Drill from 2482' to 2682'. Circulate and condition mud and pump sweep from surface to surface. Survey (at 2650', 3.0 degrees). Perform infectivity leak off test (which failed, result same as shoe integrity test). Drill from 2682' to 2833'. EPOCH PERSONNEL ON BOARD 2 DAILY COST ML: 1400 RW: 275 REPORT BY Craig Silva • file://D:\Aurora\Morning%20Reports\20060414.htm 5/25/2006 Daily Report ~~ L J Page 1 of 2 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT E~~~~ Endeavour) REPORT FOR Jack McDade DATE Apr 15, 2006 DEPTH 4010 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 2833 24 HOUR FOOTAGE 1177 CASING INFORMATION 9 5!8" @ 2457' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3048 0.5 3044.07 SURVEY DATA 3516 1.25 3512.01 4007 1.0 4002.91 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5 SEC FS 2653 10684401 6x13 2465 1545 24.6 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 672.0 @ 3365 6.9 @ 3300 109.1 70.8 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 11 @ 3908 1 @ 3378 5.6 2.1 KLBS ROTARY RPM 163 @ 3711 49 @ 2882 118.1 137.0 RPM PUMP PRESSURE 1306 @ 3784 619 @ 3237 1103.7 1158.62000 PSI DRILLING MUD REPORT DEPTH 4017 / 4013 TVD MW 9.3 VIS 47 PV 17 YP 20 FL 6.5 Gels 5/20/ CL- 29000 FC 1 SOL 2.6 SD 0.50 OIL 0/95 MBL 10.0 pH 9.5 Ca+ 450 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 907 @ 3235 7 @ 3647 100.6 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 178166 @ 3235 1298 @ 3647 19190.2 CONNECTION GAS HIGH ETHANE (C-2) 113 @ 3999 0 @ 14.9 AVG PROPANE (C-3) 35 @ 3841 0 @ 4.4 CURRENT BUTANE (C-4) 14 @ 3999 0 @ 0.2 CURRENT BACKGROUND/AVG 22 / 88 PENTANE (C-5) @ @ HYDROCARBON SHOWS No oil indicators in any of the sands. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION Many thin sands with gas over All sandstones are dominantly Maximum gas Sandstone =dominantly tuffaceous, It 100 units, but gas levels drop tuffaceous clay matrix supported, and from tuffaceous med gry, of-fn, mod w srtd, ang-rdd, vis rapidly after drilling through. visually appear to have poor porosity. sandstone is 718 Por appears poor due to matrix units. volume, no oil indicators. LITHOLOGY Major Sand/Sandstone, Tuffaceous Sandstone, Tuffaceous Siltstone, Tuffaceous Siltstone, Coal. Minor Volcanic Ash, Calcareous Tuff. PRESENT ........„TUFFACEOUS SANDSTONE..........SAND/SANDSTONE..........TUFFACEOUS CLAYSTONE.......... LITHOLOGY DAILY Drill from 2833' to 2882'. Perform injectivity test to 1050psi. Test failed. Drill from 2882' to 3089'. Surve ACTIVITY y (at 3048', 0.5 SUMMARY degrees). Perform injectivity test to 1100psi. Test failed. Drill from 3089' to 3299'. Perform injectivity test. Test failed. Drill from 3299' to 3546'. Circulate bottoms up and circulate and condition mud. Pump sweep around. Perform file://D:\Aurora\Morning%20Reports\20060415.htm 5/25/2006 Daily Report Page 2 of 2 infectivity test. Test failed. Survey (at 3516', 1.25 degrees). Drill from 3546' to 4010'. EPOCH PERSONNEL ON BOARD 2 DAILY COST ML: 1400 RW: 275 REPORT BY Craig Silva ~ J file://D:\Aurora\Morning%20Reports\2006041 S.htm 5/25/2006 Daily Report Page 1 of 2 r~ Hurora vas, LLC Exploratory Endeavourl REPORT FOR Jack McDade DATE Apr 16, 2006 TIME 24:00 DAILY WELLSITE REPORT DEPTH 4758 YESTERDAY 4010 24 HOUR FOOTAGE 748 CASING INFORMATION 9 5/8" @ 2457' DEPTH INCLINATION SURVEY DATA 4500 2.0 BIT INFORMATION INTERVAL N0. SIZE TYPE S/N JETS IN OUT FOB 2 8.5 SEC FS 2653 10684401 6x13 2465 DRILLING PARAMETERS HIGH LOW RATE OF PENETRATION 258.3 @ 4284 5.0 @ 4725 SURFACE TORQUE @ @ WEIGHT ON BIT 17 @ 4668 1 @ 4687 ROTARY RPM 160 @ 4558 70 @ 4554 PUMP PRESSURE 1513 @ 4678 962 @ 4701 DRILLING MUD REPORT DEPTH 4754 / 4750 TVD MW 9.3 VIS 44 PV 10 YP 14 FL • FC 1 SOL 2.8 SD 0.5 OIL 0/95 MBL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1655 @ 4387 9 @ 4698 112 6 . CUTTING GAS @ @ CHROMATOGRAPHY(ppm) METHANE (C-1) 348542 @ 4387 18$0 @ 4698 22711 6 . ETHANE (C-2) 336 @ 4387 2 @ 4698 25 6 . PROPANE (C-3) 116 @ 4387 0 @ g 1 BUTANE (C-4) 26 @ 4387 0 @ p g PENTANE (C-5) @ @ HYDROCARBON SHOWS No oil indicators in any of the sands. I NTERVAL LITHOLOGY/REMARKS Roughiy 20 thin sands with All sands up to 4700' are tuff clay matrix supported g as over 100 units, no and appear poor vis Por after 4700' sand s t . appears ustained gas after drilling significantly "cleaner" and consol pcs more often gr hru each one . spprtd, so gas sand potential has probably improved. • DAILY ACTIVITY SUMMARY LITHOLOGY PRESENT LITHOLOGY Major Tuffaceous Siltstone, Carbonaceous Tuffaceous Siltston Volcanic Ash, Coal. Minor Tuffaceous Sandstone, Calcareous ........SAND/SANDSTONE.......... Drill from 4010' to 4037'. Circulate and condition. Survey (at 4007' Drill from 4037' to 4256'. Circulate and condition mud. Perform inje Circulate and condition. Pump around Hi-Vis sweep. Survey (at 4E wiper trip to 2520' (inside shoe). Lubricate rig. Run in hole from 24 [~ EPOCH PRESENT OPERATION Drilling AZIMUTH VERTICAL DEPTH 4495.72 CONDITION REASON )TALE HOURS T/8/C PULLED 293 38.1 In Hole AVERAGE CURRENTAVG 110.5 73.1 FT/H R AMPS 6.5 7.1 KLBS 117.1 91.2 RPM 1224.2 1145.5 PSI 6.5 Gels 4/14/ CL- 26000 10.0 pH 8.5 Ca+ 400 CCI TRIP GAS WIPER GAS 583 SURVEY CONNECTION GAS HIGH AVG CURRENT CURRENT BACKGROUND/AVG 13 / 125 GAS DESCRIPTION Maximum gas Sd/SS (after 4700') = It gry, of-fn, from tuffaceous mod w srtd, ang-rd, gr spprted by sandstone is mineralization and poss devit 750 units ash; Sme apps tight, sme apps fair Por a, Tuffaceous Claystone, Sand/Sandstone, Puff, Carbonceous Shale. 1.0 degree). Peform infectivity test. Test failed. ctivity test. Test failed. Drill from 4256' to 4530'. 00', 2.0 degrees). Pump dry job. Pull out of hole on ?0' to 4440'. Wash down last 90' to 4530'. Drill from file://D:\Aurora\Morning%20Reports\20060416.hhn C /~,c /~,nn~ Daily Report 4530' to 4758' • EPOCH PERSONNEL ON BOARD 2 DAILY COST ML: 1400 RW: 275 REPORT BY Craig Silva • • Page 2 of 2 file://D:\Aurora\Morning%20Reports\20060416.htm 5/25/2006 Daily Report Aurora Gas, LLC Exploratory Endeavourl REPORT FOR Jack McDade DATE Apr 17, 2006 TIME 24:00 DAILY WELLSITE REPORT DEPTH 5512 YESTERDAY 4758 24 HOUR FOOTAGE 754 CASING INFORMATION 9 5/8" @ 2457' DEPTH SURVEY DATA 4992 5484 BIT INFORMATION NO. SIZE TYPE 2 8.5 SEC FS 2653 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 VIS FC 1 SOL MWD SUMMARY INTERVAL TO TOOLS INCLINATION 1.75 1.75 INTERVAL S/N JETS IN OUT 10684401 6x13 2465 Page 1 of 2 AZIMUTH ~~ocH PRESENT OPERATION Drilling FOOTAGE HOURS 3047 56.9 HIGH LOW 219.8 @ 5332 2.5 @ 4845 @ @ 24 @ 4846 1 @ 5464 152 @ 5007 70 @ 5096 1352 @ 4841 412 @ 4954 DEPT H 5513 / 5508 TVD 45 PV 11 YP 17 FL 2.6 SD 0.5 OIL 0/95 MBL AVERAGE 70.3 7.9 113.2 1116.8 VERTICAL DEPTH 4987.46 5479.23 CONDITION T/B/C In Hole CURRENT AVG 17.2 7.5 103.0 1153.4 REASON PULLED FT/HR AMPS KLBS RPM PS I 7.0 Gels 7/18 CL- 29000 10.0 pH 9.0 Ca+ 320 CCI GAS SUMMARY (units) HIGH LOW .AVERAGE DITCH GAS 631 @ 5406 6 @ 5181 94.4 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY .,METHANE (C-1) 126004 @ 5406 1039 @ 5181 18368.9 CONNECTION GAS HIGH ETHANE (C-2) 131 @ 5300 1 @ 5181 27 7 PROPANE (C-3) 69 @ 5499 0 @ . 10 7 AVG BUTANE (C-4) 23 @ 5499 0 @ . 1.1 CU CURRENT RRENT BACKGROUND/AVG 25 / 115 PENTANE (C-5) @ @ HYDROCARBON SHOWS No oil indicators in any of the sands. INTERVAL LITHOLOGYlREMARKS GAS DESCRIPTION Several gas sands with gas over 100 units. Gas falls and Sands supported by matrix clay look tight. The non-tuffaceous sand t i Maximum 490 units f SS/SD =med It gry-grysh brn, fn-med, does not add to background s one n this interval looks tight rom a tuff ss; 440 't f mod w srtd, ang-rd, gr spprtd by • uni s rom tight minralztn, mtrx spprtd by tuff cly; often looking talc ss. v silty; most apps tight. LITHOLOGY Major Tuffaceous Siltstone, Sandstone/Sand, Carbonaceous Tuffaceous Siltstone, Tuffaceous Claystone, Coal/Carbonaceous Shale, Tuffaceous Sandstone. Minor Calcareous Tuff, Carbonaceous Material. PRESENT LITHOLOGY ••~••••~••SANDSTONE..........TUFFACEOUS SANDSTONE..........TUFFACEOUS SILTSTONE.......... DAILY ACTIVITY Drill from 4758' to 5022'. Circulate and condition mud. Survey (at 4992', 1.75 degrees). Drill from 5022' to SUMMARY 5512'. file://D:\Aurora\Morning%20Reports\20060417.hhn S /~ c i~nn~ • • • Daily Report EPOCH PERSONNEL ON BOARD 2 REPORT BY Craig Silva DAILY COST ML; 1400 RW: 275 file://D:\Aurora\Morning%20Reports\20060417.htm Page 2 of 2 5/25/2006 • • Daily Report Page 1 of 2 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT ~+,~~~,H Endeavour1 REPORT FOR Jon West DATE Apr 18, 2006 DEPTH 6335 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 5512 24 HOUR FOOTAGE 823 CASING INFORMATION 9 5/8" @ 2457' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5976 1.75 5971.00 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5 SEC FS 2653 10684401 6x13 2465 3870 74.4 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 255.1 @ 6114 4.3 @ 5799 79.1 74.2 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 26 @ 5649.00000 0 @ 6049 8.1 8.2 KLBS ROTARY RPM 117 @ 6189 1 @ 5952 95.9 97.8 RPM PUMP PRESSURE 1455 @ 5852 1004 @ 6068 1259.1 1297.2 PSI DRILLING MUD REPORT DEPTH 6340 / 6335 TVD MW 9.3 VIS 44 PV 11 YP 13 FL 7.0 Gels 4/10/ CL- 29000 FC 1 SOL 2.6 SD 0.3 OIL 0195 MBL 10.0 pH 29000 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 951 @ 5984 i (Chnge shkr screen) @ 5917 147.6 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 978062 @ 5978 376 @ 5917 31980.0 CONNECTION GAS HIGH ETHANE (C-2) 1394 @ 5978 0 @ 49.0 AVG PROPANE (C-3) 491 @ 5978 0 @ 18.8 CURRENT BUTANE (C-4) 119 @ 5978 0 @ 2.8 CURRENT BACKGROUND/AVG 35 / 167 PENTANE (C-5) 11 @ 6160 0 @ 0.3 HYDROCARBON SHOWS No oil indicators in any sands. Note tiny amount of C5 in massive tuffaceous sandstone section from 6110' to 6295', but no fluorescence or cut. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION Nearly pervasive sand sectlions Most sand/sandstone sections are Maximum 951 units SS/SD= 2 major variations, v It gry- with gas over 100 units but either tuffaceous or silty, and visually from near the top of med gry-It grysh brn, mod w srtd, continued fall off of gas without do not look like good porosity the massive tuff sand fn-med, ang-rd, mtrx spprtd by ash, adding significantly to background candidates. indicated above, and gr spprted with silt assist, gen apps trace C5. tight. LITHOLOGY Major Sand/Sandstone, Tuffaceous Sandtone, Tuffaceous Siltstone, Coal/Carbonaceous Shale, Volcanic Ash. Minor Tuffaceous Claystone, Carbonaceous Material, Calcareous Tuff, Tuffaceous Shale. PRESENT ,,,,TUFFACEOUS SILTSTONE..........COAL... LITHOLOGY .......SANDSTONE.......... DAILY ACTIVITY Circulate and condition mud. Survey (at 5484', 1.75 degrees). Drill from 5512' to 6007'. Circulate and condition SUMMARY mud. Survey (at 5976', 1.75 degrees). Drill from 6007' to 6335'. file: //D :\Aurora\Morning%20Reports\20060418.htm 5/25/2006 • • Daily Report Page 1 of 2 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT E~~~,,,H Endeavour1 REPORT FOR Jon West DATE Apr 19, 2006 DEPTH 6807 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 6335 24 HOUR FOOTAGE 472 CASING INFORMATION 9 5/8" @ 2457' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6529 3.0 6523.49 6776 3.75 6770.06 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5 SEC FS 2653 10684401 6x13 2465 4342 88.9 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 230.9 @ 6631 2.3 @ 6746 62.4 86.6 FTIHR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 22 @ 6703 1 @ 6622 9.0 6.1 KLBS ROTARY RPM 113 @ 6703 21 @ 6426 96.1 97.5 RPM PUMP PRESSURE 1451 @ 6570 1114 @ 6579 1287.3 1207.9 PSI DRILLING MUD REPORT DEPTH 6807 / 6801 TVD MW 9.5 VIS 44 PV 11 YP 10 FL 6.5 Gels 2/8l CL- 29000 FC 1 SOL 3.6 SD 0.3 OIL 0/94 MBL 10.0 pH 9.5 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 787 @ 6753 20 @ 6705 123.3 TRIP GAS CUTTING GAS @ @ WIPER GAS 331 CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 160562 @ 6753 3860 @ 6712 25832.2 CONNECTION GAS HIGH ETHANE (C-2) 346 @ 6753 7 @ 6603 55.8 AVG PROPANE (C-3) 108 @ 6753 2 @ 6602 20.3 CURRENT BUTANE (C-4) 39 @ 6748 0 @ 4.3 CURRENT BACKGROUND/AVG 28 / 114 PENTANE (C-5) 9 @ 6753 0 @ 0.3 HYDROCARBON SHOWS No oil indicators. Continue tiny amount of C5 in sands with highest peaks. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION All sand sections had Diversity of sand types: tuffcaeous ss, non- Maximum 787 Many SD/SS/CGL variations: maximum gas over 100 units, differentiated ss, silty ss, "clean" ss, different units from top of overall med gray and lighter, but continued pattern of gas appearing disaggregated sd and coarse conglomerate at full range vf-granule, mod-poor rapid gas fall off after peaks. sand/conglomerate. When poosible, Por 6753' srtd, ang-rd, most (esp tuff ss) determinations are mostly poor due to tightness appears tight. and matrix fill Major Sand/Sandstone, Silty Sandstone, Tuffaceous Sandstone, Very Coarse Sand/Conglomerate, Tuffaceous LITHOLOGY Siltstone, Volcanic Ash, Coal/Carbonaceous Shale. Minor Calcareous Tuff, Tuffaceous Claystone, Tuffaceous Shale, Non-Differentiated Shale. PRESENT .TUF FACEOUS SANDSTONE.......... ........, LITHOLOGY DAILY Drill from 6335' to 6559'. Circulate bottoms up and circulate and condition mud. Survey (at 6529', 3.0 degrees). Pull file://D:\Aurora\Morning%20Reports\20060419.htm 5/25/2006 Daily Report Page 2 of 2 ACTIVITY out of hole from 6559' to 4500' on wiper trip. Lubricate rig. Run in hole from 4500' to 6559'. (Work through tight spots SUMMARY at 5303', 5335', 5453', 5529', and 5629'). Drill from 6559' to 6807'. Circulate bottoms up and circulate and condition mud. Survey (at 6776', 3.75 degrees). EPOCH PERSONNEL ON BOARD 4 DAILY COST ML: 2050 RW: 275 REPORT BY Craig Silva r~ r U file://D:\Aurora\Morning%20Reports\20060419.htm 5/25/2006 Daily Report Aurora Gas, LLC • Exploratory Endeavour1 REPORT FOR Jon West DAILY WELLSITE REPORT DATE Apr 20, 2006 DEPTH 7021 TIME 24:00 YESTERDAY 6807 24 HOUR FOOTAGE 214 CASING INFORMATION 9 5/8" @ 2457' DEPTH INCLINATION SURVEY DATA 6985 3.75 Page 1 of 2 AZIMUTH VERTICAL DEPTH 6978.61 BIT INFORMATION INTERVAL CONDITION REASON SIZE TYPE NO SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED . 2 8.5 SEC FS 2653 10884401 6x13 2465 7021 4556 103.7 4-8-WT-S-X-1-BT-PR Slow ROPs DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 121.0 @ 6810 2.4 @ 6913 23.3 13.6 SURFACE TORQUE @ ~° AMPS 7 KLBS 13 WEIGHT ON BIT 19 @ 7009 0 @ 6833 5.2 . RPM ROTARY RPM 114 @ 6808 56 @ 6928 101.1 86.8 PSI PUMP PRESSURE 1760 @ 7001 639 @ 6994 1390.7 1604.2 DRILLING MUD REPORT DEPTH 7021 / 7014 TVD MW 9.3 VIS 44 PV 12 YP 12 FL 5.0 Gels 2/5/- CL- 30000 FC 1 SOL 2.5 SD 0.30 OIL 0195 MBL 7.5 pH 9.2 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 441 @ 6810 10 @ 7018 46.4 TRIP GAS @ @ WIPER GAS CUTTING GAS SURVEY 321 CHROMATOGRAPHY (ppm) METHANE (C-1) 88011 @ 6810 1896 @ 7008 9198.6 CONNECTION GAS HIGH ETHANE (C-2) 163 @ 6810 4 @ 6999 20.9 AVG CURRENT PROPANE (C-3) 45 @ 6811 0 @ 7015 7.6 CURRENT BACKGROUND/AVG N/A BUTANE (C-4) 16 @ 6811 0 @ 1.0 PENTANE (C-5) 3 @ 6811 0 @ 0.1 HYDROCARBON SHOWS Trace to very poor oil shows in (Starichkoff) sands from 6735' to 7015'. One interval with very high gas. INTERVAL LITHOLOGYIREMARKS GAS DESCRIPTION High gas in sand at 6808'- Tuffaceous Sandstone that is locally Max 441 units gas ti l Note oil cut fluor is from air dried Wet samples would not les sam 8815'. Consistent trace or c omera conglomeratic; fining upward; mod sortd; from Cong but some fair sand at 8810'. Low bnt vole ash matrix fill G . p cut,did not have oil stain or sample better oil fluorin air dried samples from 8735'-7017' , en a or better vis Por. Trace good Por in consol gas thereafter. clut fluor from oarsel~ ooking splster Cg I. Sand/Sandstone, Conglomeratic SandlConglomerate, Tuffaceous Siltstone, Major Tuffaceous Sandstone , Minor Tuffaceous Claystone. LITHOLOGY Volcanic Ash Shale Coal/C . , arbonaceous PRESENT ...., TUFFACEOUS SILTSTONE..........TUFFACEOUS CLAYSTONE...... .... ..... LITHOLOGY DAILY ACTIVITY Finish survey at 8778'. Drill from 8807' to 7021'. Circulate bottoms up. Pump sweep around. Survey (at 8985', ' ' SUMMARY 3.75 t degrees). Monitor well for 10 minutes. Pull out of hole (from 7021 ) on bit trip. o 1800 [~ EPOCH PRESENT OPERATION Pulling out of hole for new bit file://D:\Aurora\Morning%20Reports\20060420.htm 5/25/2006 • • • Daily Report EPOCH PERSONNEL ON BOARD 4 REPORT BY Craig Silva DAILY COST ML: 2050 RW: 275 file : //D : \Aurora\Morning%20Report s\20060420. htm Page 2 of 2 5/25/2006 • Daily Report Page 1 of 2 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT ~,~Q~;H Endeavour1 REPORT FOR Jack McDade Jon West DATE Apr 21, 2006 DEPTH 7107 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 7021 24 HOUR FOOTAGE 86 CASING INFORMATION 9 5/8" @ 2457' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7107 (Projection) 3.75 7100.38 (Calculated) BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5 SEC FM2643 1040485 3x13 3x15 7021 86 5.5 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 111.5 @ 7084 1.8 @ 7080 31.7 36.1 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 13 @ 7021 2 @ 7065 7.7 12.4 KLBS ROTARY RPM 110 @ 7078 72 @ 7089 96.1 94.1 RPM PUMP PRESSURE 1604 @ 7021 963 @ 7107 1317.1 963.1 PSI DRILLING MUD REPORT DEPTH 7107 / 7100 TVD MW 9.3 VIS 44 PV 11 YP 11 FL 6.0 Gels 2/7 CL- 31000 FC 1 SOL 2.4 SD 0.3 OIL 0/95 MBL 10 pH 9.3 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 145 @ 7097 2 @ 7050 26.2 TRIP GAS 200 CUTTING GAS @ @ W-PER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 28838 @ 7097 190 @ 7050 4877.9 CONNECTION GAS HIGH ETHANE (C-2) 147 @ 7097 0 @ 17.4 AVG PROPANE (C-3) 31 @ 7097 0 @ 3.4 CURRENT BUTANE (C-4) 11 @ 7097 0 @ 0.3 CURRENT BACKGROUND/AVG 7 / 48 PENTANE (C-5) @ @ HYDROCARBON SHOWS No sample fluorescence and not cut fluorescence from wet samples. Air dried sample not yet ready to be checked for cut fluorescence at report time. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPT-ON Apparent continued Continued Tuffaceous Sandstone, that No high IMPORTANT NOTE:Baroid mud engineer is Starichkoff Sands from is locally conglomeratic in part. gases from adding Baranex to drilling mud to reduce water 7040-7095 so trace oil show Generally poor vis Por due to hi volume tuff ss in this loss. Baranex cuts in solvent and fluoresces is anticipated ash matrix interval (pale yellow), so lower grade cut fluorescence is no longer going to be reliable. LITHOLOGY Major Tuffaceous Sandstone, Volcanic Ash, Conglomeratic Sand/Conglomerate. Minor Coal/Carbonaceous Shale, T uffaceous Siltstone, Calcareous Tuff. PRESENT .....„..,TUFFACEOUS SANDSTONE.......... LITHOLOGY Continue pulling out of hole on bit trip (from 1800' to 419'). Pull bottom hole assembly out of hole. Break bit. Pull wear ring. Make up test joint. Fill stack. Test Hydril to 250psi Low/3500psi High. Test top rams, kill line valves, choke line DAILY valves, floor valves, Topdrive valves, lower pipe rams to 250psi Low/5000psi High. Do accumulator performance test. file://D:\Aurora\Morning%20Reports\20060421.htm 5/25/2006 • Daily Report Page 2 of 2 ACTIVITY Test blind rams to 250psi Low/5000psi High. Set wear ring. Lay down test joint. Make up bit. Run in hole with drill SUMMARY collars to 414'. Continue running in hole to 2256'. Fill pipe. Slip and cut 65' of drill line. Lubricate rig. Continue running in hole from 2256' to tight spot at 6979'. Kelly up and wash down to 7021'. Drill from 7021' to 7107'. Change shaker screens. EPOCH PERSONNEL ON BOARD 4 DAILY COST ML: 2050 RW: 275 REPORT BY Craig Silva • • file://D: \Aurora\Morning%20Reports\20060421.htm C/7c/~nn~ • ICJ Daily Report Page 1 of 1 Aurora Gas, LLC r t l E ~~~~~ DAILY WELLSITE REPORT y ora o xp Endeavour1 REPORT FOR Jack McDade, Jon West DATE Apr 22, 2006 DEPTH 7360.00000 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 7107.00000 24 HOUR FOOTAGE 253 CASING INFORMATION 9 5/8" @ 2457' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7206' 4.0 7199.1' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5 SEC FM2643 1040485 3x13, 3x15 7021 339 21.9 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 199.2 @ 7199.00000 1.3 @ 7334.00000 42.5 10.27000 FTIHR SURFACE TORQUE IT 21 @ @ 00000 2 @ 7258.00000 @ 7335 AMPS 12.3 14.76000 KLBS WEIGHT ON B ROTARY RPM 117 . @ 7242.00000 48 @ 7177.00000 93.4 93.14000 RPM PUMP PRESSURE 1703 @ 7336.00000 66 @ 7238.00000 1286.2 720.91998 PSI DRILLING MUD REPORT DEPTH 7361 MW 9.3 VIS 45 PV 13 YP 13 FL 6.0 Gels 216/0 CL- 31,000 FC 2 SOL 2.4 SD 0.30 OIL 0195 MBL 10.0 pH 9.1 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 132 @ 7293.00000 2 @ 7359.00000 17.6 TRIP GAS CUTTING GAS 0 @ 7360.00000 0 @ 7360.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 25922 @ 7293.00000 467 @ 7359.00000 3410.2 CONNECTION GAS HIGH ETHANE (C-2) 203 @ 7293.00000 0 @ 7243.00000 14.6 AVG PROPANE (C-3) 40 @ 7293.00000 0 @ 7258.00000 3.8 CURRENT BUTANE (C-4) 1 @ 7107.00000 0 @ 7111.00000 0.0 CURRENT BACKGROUND/AVG 4112 PENTANE (C-5) 0 @ 7360.00000 0 @ 7360.00000 0.0 HYDROCARBON SHOWS rvone INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone, Volcanic ash, Minor coal/ carbonaceous shale, Conglomeratic sand, Tuffaceous siltstone, PRESENT Tuffaceous sandstone and Tuff LITHOLOGY DAILY ACTIVITY Drill from 7107' to 7236'. Survey @ 7206', 4 deg. TVD 7199.1' Drill from 7236' to 7351'. Circ while change SUMMARY swab in pump #1. Drill from 7351' - 7360'. EPOCH PERSONNEL ON BOARD 4 DAILY COST ML: $2050, RW: $275 REPORT BY Ralph Winkelman file ://D:\Aurora\Morning%20Reports\20060422.htm 5/25/2006 Daily Report Page 1 of 1 Aurora Gas, LLC DAILY WELLSITE REPORT ~~~ ,.•~~- T ( J'jH1 • Exploratory L Endeavour1 REPORT FOR Jack McDade, Jon West DATE Apr 23, 2006 DEPTH 7449.00000 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 7360.00000 24 HOUR FOOTAGE 89 CASING INFORMATION 9 5/8" @ 2457' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7206' 4.0 7199.1' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5 SEC FM2643 1040485 3x13, 3x15 7021 428 43.3 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 57.1 @ 7372.00000 1.5 @ 7408.00000 15.4 2.79000 FT/HR SURFACE TORQUE @ @ 20 0 AMPS 68000 KLBS 28 WEIGHT ON BIT 33 @ 7448.00000 8 @ 7403.00000 . . ROTARY RPM 115 @ 7439.00000 57 @ 7421.00000 98.3 108.09000 RPM PUMP PRESSURE 1580 @ 7425.00000.720 @ 7360.00000 1116.4 942.06000 PSI DRILLING MUD REPORT DEPTH 7450 MW 9.3 VIS 47 PV 12 YP 16 FL 6.0 Gels 318/0 CL- 31000 FC 2 SOL 2.4 SD 0.30 OIL 0/95 MBL 10.0 pH 9.1 Ca+ 160 CCI • MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 10 @ 7368.00000 2 @ 7449.00000 4.8 TRIP GAS CUTTING GAS 0 @ 7449.00000 0 @ 7449.00000 0.0 WIPER GAS CHROM ATOGRAPHY(ppm) SURVEY METHANE (C-1) 2051 @ 7368.00000 319 @ 7446.00000 917.8 CONNECTION GAS HIGH ETHANE (C-2) 7 @ 7426.00000 0 @ 7441.00000 0.8 AVG PROPANE (C-3) 0 @ 7449.00000 0 @ 7449.00000 0.0 CURRENT 0000 0 @ 7449 00000 0 0 CURRENT BACKGROUND/AVG 3 / 4 BUTANE (C-4) 0 @ 7449.0 PENTANE (C-5) 0 @ 7449.00000 0 @ 7449.00000 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous claystone, Tuffaceous siltstone, Minor coal/ carbonaceous shale, tuffaceous sand, tuff PRESENT LITHOLOGY Tuffaceous clayatone and siltstone DAILY ACTIVITY SUMMARY Drill 7360' - 7449'. EPOCH PERSONNEL ON BOARD 4 DAILY COST ML: $2050, RW: $275 REPORT BY Ralph Winkelman • file://D:\Aurora\Morning%20Reports\20060423.htm 5/25/2006 n U • • Daily Report Page 1 of 1 Aurora Gas, LLC lorator Ex ~~~,~ DAILY WELLSITE REPORT ~ y p , Endeavourl REPORT FOR Jack McDade, Jon West DATE Apr 24, 2006 DEPTH 7470 PRESENT OPERATION Trip in Hole TIME 24:00 YESTERDAY 7449 24 HOUR FOOTAGE 21 CASING INFORMATION 9 5/8" @ 2457' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7206' 4.0 7199.1' SURVEY DATA 7450 2.5 7442.5' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/BIC PULLED 3 8.5 Sec FM2643 1040485 3x13, 3x15 7021 7470 449 53.3 5-8-WT-N-X-1-CT-PR ROP 4 8.5 Sec FM3649 10749119 5x13, 15 7470 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 9.3 @ 7452.00000 1.7 @ 7461.00000 3.1 2.17000 FT/HR SURFACETOROUE @ @ AMPS WEIGHT ON BIT 34 @ 7459.00000 26 @ 7468.00000 32.3 27.88000 KLBS ROTARY RPM 108 @ 7449.00000 91 @ 7466.00000 98.6 97.27000 RPM PUMP PRESSURE 1153 @ 7466.00000 942 @ 7449.00000 972.5 1054.98999 PSI DRILLING MUD REPORT DEPTH 7470' MW 9.3 VIS 48 PV 14 YP 12 FL 4.9 Gels 3/6/0 CL- 30000 FC 1 SOL 3.5 SD .25 OIL 0194 MBL 9.0 pH 9.0 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 5 @ 7463.00000 2 @ 7449.00000 4.1 TRIP GAS CUTTING GAS 0 @ 7470.00000 0 @ 7470.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 1148 @ 7463.00000 406 @ 7449.00000 717.0 CONNECTION GAS HIGH ETHANE (C-2) AVG 7 @ 7450.00000 0 @ 7458.00000 1.9 PROPANE (C-3) CURRENT 0 @ 7470.00000 0 @ 7470.00000 0.0 BUTANE (C-4) 0 @ 7470.00000 0 @ 7470.00000 0.0 CURRENT BACKGROUND/AVG 0 / 4 PENTANE (C-5) 0 @ 7470.00000 0 @ 7470.00000 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous claystone/ siltstone, sand PRESENT LITHOLOGY Tuffaceous claystone/ siltstone Drill 7449' - 7470'. Condition mud. CBU. Pump dry job. Drop survey @ 7450'. POOH to 2100'. Level derrick. DAILY ACTIVITY POOH to 1025'. Monitor well for 10 minutes at BHA. Stand back BHA. Break off bit. Clean rig floor. Make up new SUMMARY bit. RIH w/ BHA. EPOCH PERSONNEL ON BOARD 4 REPORT BY Ralph Winkelman DAILY COST ML: $2050, RW: $275 file ://D :\Aurora\Morning%20Reports\20060424.htm 5/25/2006 • ~• Daily Report Aurora Gas, LLC Exploratory Endeavour1 REPORT FOR DAT DAILY WELLSITE REPORT E Apr 25, 2006 DEPTH 7705. TIME 24:00 YESTERDAY 7470. 24 HOUR FOOTAGE 235 CASING INFORMATION 9 5/8" @ 2457' DEPTH INCLINATION SURVEY DATA 7450 2.5 BIT INFORMATION NO. SIZE TYPE 4 8.5 Sec FM3649 [~ EPOCH PRESENT OPERATION LD BHA, PU CORE BARREL INTERVAL S/N JETS IN OUT 10749119 5x13,15 7470 7705 AZIMUTH FOOTAGE HOURS 235 9.8 HIGH LOW 60.1 @ 7545.00000 2.2 @ 7470.00000 @ @ 27 @ 7470.00000 0 @ 7471.00000 107 @ 7662.00000 3 @ 7599.00000 1622 @ 7484.00000 1054 @ 7470.00000 DEPTH 7705 51 PV 18 YP 14 FL 4.1 3.5 SD .25 OIL 0/94 MBL .10 Page 1 of 1 VERTICAL DEPTH 7442.5' CONDITION REASON T/B/C PULLED Core point AVERAGE CURRENT AVG 31.3 22.55000 FT/HR AMPS 6.0 10.05000 KLBS 93.8 98.94000 RPM 1369.4 1417.38000 PSI Gels 4/6/8 CL- 31000 pH 8.9 Ca+ 120 CCI GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 46 @ 7645.00000 2 @ 7501.00000 6.6 TRIP GAS 23 CUTTING GAS 0 @ 7705.00000 0 @ 7705.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 9165 @ 7645.00000 488 @ 7501.00000 1245.0 CONNECTION GAS HIGH ETHANE (C-2) 28 @ 7645.00000 0 @ 7521.00000 1.2 AVG PROPANE (C-3) 7 @ 7530.00000 0 @ 7641.00000 0.1 CURRENT BUTANE (C-4) 0 @ 7705.00000 0 @ 7705.00000 0.0 CURRENT BACKGROUND/AVG 0 / 6 PENTANE (C-5) 0 @ 7705.00000 0 @ 7705.00000 0.0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAYSTONE/ SILTSTONE, ASHY TUFF, TUFFACEOUS SAND SAND , PRESENT LITHOLOGY SAND, ASHY TUFF/ SILTSTONE DAILY ACTIVITY SUMMARY Cont trip in hole to 7294'. Ream 7294' - 7470. Drill 7470' - 7705'. CBU. Drop survey. POOH 7705' - 2400' Mild ' ' . swabbing 7300 - 7200 . Lubricate rig at shoe. Cont POOH. Stand back HWDP, L/D jars. DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 VIS FC 1 SOL MWD SUMMARY INTERVAL. TO TOOLS EPOCH PERSONNEL ON BOARD 4 DAILY COST ML: $2050, RW: $275 REPORT BY Ralph Winkelman file://D: \Aurora\Morning%20Reports\20060425.htm S/7S/7nnti Daily Report Page 1 of 1 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT EI'O~.~I Endeavour1 REPORT FOR Jack McDade, John West DATE Apr 26, 2006 DEPTH 7735 PRESENT OPERATION LD Core #1 TIME 24:00 YESTERDAY 7705 24 HOUR FOOTAGE 30 CASING INFORMATION 9 5!8" @ 2457' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7450 2.5 7442.7 7705 3.5 7697.4 BIT INFORMATION INTERVAL NO. SIZE TYpE CONDITION REASON S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5 Reed CD 93 core bit 4980966 9x13 7705 7735 30 2.7 4 8.5 SEC FM 3649 10749449 5x13, 15 7470 7705 235 9.8 1-1-NO-A-X-1-NO-CP core point DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 47.5 @ 7732.00000 1.3 @ 7706.00000 21.4 44.47000 FT/HR SURFACE TORQUE @ @ WEIGHT ON BIT 15 @ 7711.00000 6 AMPS ROTARY RPM @ 7734.00000 10.4 8.21000 KLBS 98 @ 7705.00000 52 @ 7706.00000 61.0 59.52000 RPM PUMP PRESSURE 1417 @ 7705.00000 556 @ 7707.00000 628.8 624.10999 PSI DRILLING MUD REPORT DEPTH 7735 • MW 9.3 VIS 49 PV 15 YP 14 FL 4.3 Gels 3/5/7 CL- 31000 FC 1 SOL 3.5 SD 0 OIL 0/94 MBL 8.0 pH 8.9 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 11 @ 7705.00000 4 CUTTING GAS 0 @ 7725.00000 6.4 TRIP GAS 22 @ 7735.00000 0 @ 7735.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 2166 @ 7705.00000 784 @ 7725.00000 1189.6 CONNECTION GAS HIGH ETHANE (C-2) 7 @ 7705.00000 0 @ 7709.00000 0.6 PROPANE (C-3) 0 @ 7735.00000 0 @ 7735.00000 0.0 AVG BUTANE (C-4) 0 CURRENT @ 7735.00000 0 @ 7735.00000 0.0 CURRENT BACKGROUNDlAVG 0 / 6 PENTANE (C-5) 0 @ 7735.00000 0 @ 7735.00000 0.0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SANDSTONE/ CONGLOMERATIC SANDSTONE PRESENT LITHOLOGY TUFFACEOUS SANDSTONE/ CONGLOMERATIC SANDSTONE DAILY Cont POOH. LD stabs. Break off bit. Remove survey tool. Clean floor. PU core barrel and jars. RIH to 1018'. Fill pipe. ACTIVITY RIH 1018' - 7662'. Ream 7662' - 7705'. Tag bottom. PU single, drop ball. Circ and condition mud. Core 7705' - 7735'. SUMMARY CBU at 6 bpm. LD single. POOH 7735' - 2400'. Work thru tight hole at 7570' - 7050'. Monitor well at shoe and service rig. POOH 2400 - 1020'. Monitor well at BHA and stand back HWDP. EPOCH PERSONNEL ON BOARD 4 DAILY COST ML $2050, RW: $275 REPORT BY Ralph Winkelman file://D: \Aurora\Morning%20Reports\20060426. htm • • Daily Report Page 1 of 1 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT ~,~Q~,H Endeavour) REPORT FOR Jack McDade, John West DATE Apr 27, 2006 DEPTH 8006 PRESENT OPERATION Drill ahead TIME 24;00 YESTERDAY 7735. 24 HOUR FOOTAGE 271 CASING INFORMATION 9 5/8" @ 2457' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7705' 3.5 7697.4' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR4 8.5 SEC FM3649 10749119 5x13,15 7735 271 12.6 In hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 70.3 @ 7886.00000 4.3 @ 7884.00000 28.0 27.00000 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 11 @ 7777.00000 2 @ 7736.00000 7.6 7.00000 KLBS ROTARY RPM 113 @ 7815.00000 58 @ 7736.00000 96.3 95.51000 RPM PUMP PRESSURE 1751 @ 8005.00000 624 @ 7735.00000 1548.3 1751.43994 PSI DRILLING MUD REPORT DEPTH 8000 MW 9.3 VIS 52 PV 21 YP 15 FL 3.8 Gels 4/6/8 CL- 30000 FC 1/3 SOL 3.5 SD 0.25 OIL 0/94 MBL 7.0 pH 8.9 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 77 @ 7901.00000 5 @ 7972.00000 14.3 TRIP GAS 14 CUTTING GAS 0 @ 8006.00000 0 @ 8006.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 14644 @ 7901.00000 857 @ 7763.00000 2473.1 CONNECTION GAS HIGH ETHANE (C-2) 100 @ 7901.00000 0 @ 7740.00000 11.1 AVG PROPANE (C-3) 21 @ 7901.00000 0 @ 7855.00000 1.6 CURRENT BUTANE (C-4} 0 @ 8006.00000 0 @ 8006.00000 0.0 CURREN T BACKGROUND/AVG 7/ 10 PENTANE (C-5) 0 @ 8006.00000 0 @ 8006.00000 0.0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous claystone/ siltstone, ashy tuff, sand PRESENT LITHOLOGY tuffaceous sand, ashy tuff POOH w/ BHA. LD core barrel ans swivel assembly. Make up new core barrel and swivel assembly and LD. PU DAILY ACTIVITY BHA and Trip in hole from 1020' to 2450'. Fill pipe at shoe. RIH, fill pipe at 5250'. Cont RIH to 7662'. Cond mud and SUMMARY circ. Wash core section and CBU. Change shaker screens. Drill 7735' - 8006'. EPOCH PERSONNEL ON BOARD 4 DAILY COST ML:$2050. RW:$275 REPORT BY Ralph Winkelman file : //D :\Aurora\Morning%20Reports\20060427. htm 5/25/2006 • • r Daily Report Page 1 of 1 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT EI'Q~,H Endeavour) REPORT FOR Jack McDade, John West DATE Apr 28, 2006 DEPTH 8333 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 8006 24 HOUR FOOTAGE 327 CASING INFORMATION 9 5/8" @ 2457' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8241' 4.25 8232.1' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR4 8.5 SEC FM3649 10749119 5x13,15 7735 598 31.8 In hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 95.0 @ 8111.00000 1.9 @ 8316.00000 29.3 24.13000 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 15 @ 8275.00000 2 @ 8148.00000 7.8 9.43000 KLBS ROTARY RPM 107 @ 8177.00000 55 @ 8264.00000 95.5 86.69000 RPM PUMP PRESSURE 1976 @ 8221.00000 849 @ 8034.00000 1655.0 1796.89001 PSI DRILLING MUD REPORT DEPTH 8320' MW 9.3 VIS 48 PV 16 YP 13 FL 3.7 Gels 3/5/7 CL- 29000 FC 1 SOL 4.1 SD 0.25 OIL 0/93.5 MBL 7.0 pH 8.9 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 107 @ 8063.00000 2 @ 8317.00000 13.8 TRIP GAS CUTTING GAS 0 @ 8333.00000 0 @ 8333.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 21661 @ 8063.00000 535 @ 8317.00000 2545.5 CONNECTION GAS HIGH ETHANE (C-2) 275 @ 8183.00000 0 @ 8021.00000 23.7 AVG PROPANE (C-3) 57 @ 8274.00000 0 @ 8150.00000 6.9 CURRENT BUTANE (C-4) 20 @ 8246.00000 0 @ 8241.00000 0.3 CURRENT BACKGROUND/AVG 4i 7 PENTANE (C-5) 0 @ 8333.00000 0 @ 8333.00000 0.0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY coal/ carbonaceous material; tuffaceous sand/siltstone/claystone, ash PRESENT LITHOLOGY ash, sand DAILY ACTIVITY Drill 8006' - 8216'. CBU. Survey @ 8182', 4-5 deg inc. Drill 8216' - 8276'. CBU. Resurvey @ 8241', 4.25 SUMMARY inc. Drill 8276' - 8333'. EPOCH PERSONNEL ON BOARD 4 DAILY COST ML: $2050, RW: $275 REPORT BY Ralph Winkelman file://D:\Aurora\Morning%20Reports\20060428.htm 5/25/2006 i U • Daily Report Page 1 of 1 Aurora Gas, LLC lorator Ex DAILY WELLSITE REPORT EPOCH y p Endeavour1 REPORT FOR Jack McDade, John West DATE Apr 29, 2006 DEPTH 8373 PRESENT OPERATION CBU/ Drill TIME 24:00 YESTERDAY 8333 24 HOUR FOOTAGE 40 CASING INFORMATION 9 5/8" @ 2457' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8241' 4.25 8232.1' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR4 8.5 SEC FM3649 10749119 5x13,15 7735 8373 638 36 BOP test RR4 8.5 SEC FM3649 10749119 5x13, 15 8373 0 0 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 111.8 @ 8358.00000 1.3 @ 8373.00000 36.8 1.30000 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 16 @ 8346.00000 7 @ 8361.00000 11.3 13.00000 KLBS ROTARY RPM 107 @ 8364.00000 79 @ 8339.00000 92.7 98.00000 RPM PUMP PRESSURE 1797 @ 8336.00000 1233 @ 8353.00000 1534.0 1555.00000 PSI DRILLING MUD REPORT DEPTH 8373' MW 9.3 VIS 52 PV 18 YP 14 FL 3.7 Gels 4/6/8 CL- 30000 FC 1/3 SOL 4.1 SD 0 OIL 0/93.5 MBL 7.0 pH 8.8 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 7 @ 8369.00000 1 @ 8350.00000 4.2 TRIP GAS 67 CUTTING GAS 0 @ 8373.00000 0 @ 8373.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 1339 @ 8366.00000 379 @ 8350.00000 707.7 CONNECTION GAS HIGH ETHANE (C-2) 14 @ 8348.00000 1 @ 8333.00000 7.4 AVG PROPANE (C-3) 0 @ 8373.00000 0 @ 8373.00000 0.0 CURRENT BUTANE (C-4) 0 @ 8373.00000 0 @ 8373.00000 0.0 CURRENT BACKGROUND/AVG 7/ 10 PENTANE (C-5) 0 @ 8373.00000 0 @ 8373.00000 0.0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND/ ASHY TUFF, TUFFACEOUS CLAYSTONE PRESENT LITHOLOGY tUFFACEOUS SANDSTONE, SAND, ASH DAILY ACTIVITY Drill 8333' - 8373'. CBU, pump dry job. POOH. Stand back BHA, cle an rig floor. Test BOP, gas alarms and SUMMARY Koomey. Break out bit. Pick up motor, make up bit. RIH. Wash 8302' - 8373', and tag bottom @ 8373. CBU. EPOCH PERSONNEL ON BOARD 4 REPORT BY Ralph Winkelman DAILY COST ML:$2050, RW: $275 file://D :\Aurora\Morning%20Reports\20060429.htm 5/25/2006 • Daily Report Page 1 of 1 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT EI'O~H Endeavour1 REPORT FOR Jack McDade, John West DATE Apr 30, 2006 DEPTH 8697 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 8373 24 HOUR FOOTAGE 324 CASING INFORMATION 9 5/8" @ 2457' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8241' 4.25 8232.1' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR4 8.5 SEC FM3649 10749119 5x13, 15 8373 324 20.6 In hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 51.3 @ 8543.00000 1.3 @ 8373.00000 19.5 4.00000 FT/HR SURFACETOROUE @ @ AMPS WEIGHT ON BIT 17 @ 8591.00000 4 @ 8401.00000 10.0 13.73000 KLBS ROTARY RPM 98 @ 8373.00000 13 @ 8594.00000 65.5 48.80000 RPM PUMP PRESSURE 2461 @ 8433.00000 357 @ 8537.00000 2123.5 2181.79004 PSI DRILLING MUD REPORT DEPTH 8690' MW 9.3 VIS 52 PV 16 YP 15 FL 3.7 Gels 4/6/0 CL- 29000 FC 1/3 SOL 4.1 SD .25 OIL 0/93.5 MBL 7 pH 8.8 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 48 @ 8518.00000 2 @ 8509.00000 7.5 TRIP GAS CUTTING GAS 0 @ 8697.00000 0 @ 8697.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 9140 @ 8518.00000 311 @ 8509.00000 1357.7 CONNECTION GAS HIGH ETHANE (C-2) 155 @ 8518.00000 0 @ 8647.00000 14.9 AVG PROPANE (C-3) 54 @ 8518.00000 0 @ 8448.00000 3.4 CURRENT BUTANE (C-4) 20 @ 8518.00000 0 @ 8691.00000 0.4 CURRENT BACKGROUND/AVG 4 / 6 PENTANE (C-5) 0 @ 8697.00000 0 @ 8697.00000 0.0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous claystone/ siltstone, sand, carbonaceous shale/ silt PRESENT LITHOLOGY Tuffaceous clay/ silt, ashy tuff DAILY ACTIVITY SUMMARY Drill 8373' - 8550'. CBU and look at samples. Drill 8550' - 8697'. EPOCH PERSONNEL ON BOARD 4 DAILY COST ML: $2050, RW: $275 REPORT BY Ralph Winkelman file://D :\Aurora\Morning%20Reports\2006043 O.htm 5/25/2006 C: • Daily Report Page 1 of 1 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT -~~~~H Endeavour1 REPORT FOR Jack McDade, J ohn West DATE May 01, 2006 DEPTH 8805.00000 PRESENT OPERATION POOH TIME 24:00 YESTERDAY 8697.00000 24 HOUR FOOTAGE 108 CASING INFORMATION 9 5/8' @ 2457 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8703' 4.75 8692 7 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR4 8.5 SEC FM3649 10749119 5x13, 15 8373 8805 432 36.6 In Hole ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 37.5 @ 8772.00000 1.0 @ 8799.00000 13.1 1.66000 FT/HR SURFACE TORQUE @ @ WEIGHT ON BIT 20 @ 8804.00000 4 @ 8734.00000 AMPS 10.4 19.67000 KLBS ROTARY RPM 110 @ 8750.00000 29 @ 8799.00000 97.2 37.98000 RPM PUMP PRESSURE 2484 @ 8805.00000 1913 @ 8734.00000 2183.6 2484.62012 PSI DRILLING MUD REPORT DEPTH 8805 MW 9.3 VIS 51 PV 16 YP 13 FL 3.6 Gels 4/7/0 CL- 29000 FC 1/3 SOL 4.1 SD 0 OIL 0/93.5 MBL 7 pH 8.8 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 29 @ 8768.00000 1 @ 8805.00000 7.3 TRIP GAS CUTTING GAS 0 @ 8805.00000 0 @ 8805.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 5011 @ 8715.00000 301 @ 8804.00000 1201.1 CONNECTION GAS HIGH ETHANE (C-2) 66 @ 8715.00000 0 @ 8706.00000 8.8 AVG PROPANE (C-3) 17 @ 8715.00000 0 @ 8799.00000 1.4 CURRENT BUTANE (C-4) 0 @ 8805.00000 0 @ 8805.00000 0.0 CURRENT BACKGROUND/AVG 0 / 5 PENTANE (C-5) 0 @ 8805.00000 0 @ 8805.00000 0.0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY sand, tuffaceous siltstone, clay, carbonaceous material PRESENT LITHOLOGY ashy tuff, tuffaceous siltstone DAILY ACTIVITY Drill 8697' - 8734'. Survey @ 8703', with 4.75 deg inc. Drill 8734' - 8805'. CBU Monitor well for 10 min SUMMARY POOH. . . EPOCH PERSONNEL ON BOARD 4 DAILY COST ML: $2050, RW: $275 REPORT BY Ralph Winkelman file://D:\Aurora\Morning%20Reports\200605 O l .htm 5/25/2006 Daily Report CJ Page 1 of 1 Aurora Gas, LLC lorator Ex ,~-I DAILY WELLSITE REPORT F,1~Q~ y p ,_ Endeavour1 REPORT FOR Jack McDade , John West DATE May 02, 2006 DEPTH 8972 PRESENT OPERATION Drill TIME 24:00 YESTERDAY 8805 24 HOUR FOOTAGE 167 CASING INFORMATION 905/8" @ 2457' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8703' 4.75 8692'7 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S!N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR4 8.5 SEC FM3649 10749119 5x13, 15 8373 8805 432 36.6 7-2-RO/PNM/T-N-NIA-IN-BU-PR ROP 7 8.5 SMITH XSC1S 10700513 3x20 8805 167 11.7 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 45.5 @ 8837.00000 1.7 @ 8805.00000 17.1 13.30000 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 19 @ 8805.00000 3 @ 8807.00000 13.9 17.64000 KLBS ROTARY RPM 95 @ 8808.00000 37 @ 8805.00000 57.3 54.26000 RPM PUMP PRESSURE 2484 @ 8805.00000 1995 @ 8959.00000 2175.7 2373.31006 PSI DRILLING MUD REPORT DEPTH 8960' MW 9.3 VIS 51 PV 19 YP 14 FL 3.8 Gels 41617 CL- 28000 FC 1/3 SOL 4.2 SD .25 OIL 0/93.5 MBL 7.5 pH 9.0 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 9 @ 8813.00000 1 @ 8805.00000 3.9 TRIP GAS 27 CUTTING GAS 0 @ 8972.00000 0 @ 8972.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 1573 @ 8813.00000 346 @ 8805.00000 722.5 CONNECTION GAS HIGH ETHANE (C-2) 14 @ 8857.00000 0 @ 8836.00000 1.9 AVG PROPANE (C-3) 0 @ 8972.00000 0 @ 8972.00000 0.0 CURRENT BUTANE (C-4) 0 @ 8972.00000 0 @ 8972.00000 0.0 CURRENT BACKGROUND/AVG 3 / 4 PENTANE (C-5) 0 @ 8972.00000 0 @ 8972.00000 0.0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Conglomeratic sand, tuffaceous siltstone/claystone, volcanic ashy tuff PRESENT LITHOLOGY conglomeratic sand, ashy tuff, tuffaceous sift in gauge. Make up mill tooth bit, RIH. Top stab 1/2" out, Bottom stab 1/4" out of gauge. Break off bit Cont POOH ' , . . Fill DAILY ACTIVITY Cut 108' drill line. Fill pipe. Lubricate rig. RIH to 5000', fill pipe. RIH to 7000', Fill pipe. RIH to 8740 RIH to shoe ' ' . - 8972 . SUMMARY pipe and wash to bottom. CBU, bell nipple and shakers over flowing on bottoms up. Drill 8805 • EPOCH PERSONNEL ON BOARD 4 DAILY COST ML: $2050, RW: $275 REPORT BY Ralph Winkelman file://D:\Aurora\Morning%20Reports\20060502.htm 5/25/2006 U • • Daily Report Page 1 of 1 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT ~' ~~~~ Endeavour1 , REPORT FOR Jach McDade, John West DATE May 03, 2006 DEPTH- 9089 PRESENT OPERATION Break off bit TIME 24:00 YESTERDAY 8972 24 HOUR FOOTAGE 117 CASING INFORMATION 9 5/8" @ 2457' DEPTH INCLINATION AZIMUTH SURVEY DATA ' VERTICAL DEPTH 8703 4.75 8692.7' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 7 8.5 SEC XSC1S 10700513 3x20 8805 9089 284 25.8 No Cones ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 16.8 @ 9008.00000 2.0 @ 9089.00000 9.4 1.96000 FT/HR SURFACE TORQUE @ @ WEIGHT ON BIT 21 @ 9089.00000 1 @ 9073.00000 14.8 AMPS 21.32000 KLBS ROTARY RPM 87 @ 9070.00000 48 @ 9076.00000 58.0 61.75000 RPM PUMP PRESSURE 2619 @ 9089.00000 2084 @ 8982.00000 2282.1 2619.01001 PSI DRILLING MUD REPORT DEPTH 9089 MW 9.3 VIS 52 PV 18 YP 14 FL 3.6 Gels 4/8/7 CL- 29000 FC 1/3 SOL 4.1 SD 0 OIL 0/93.5 MBL 7.5 pH 8.8 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 4 @ 9079.00000 1 @ 9086.00000 2.7 TRIP GAS CUTTING GAS 0 @ 9089.00000 0 @ 9089.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 800 @ 9079.00000 237 @ 9086.00000 518.2 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 9089.00000 0 @ 9089.00000 0.0 AVG PROPANE (C-3) 0 @ 9089.00000 0 @ 9089.00000 0.0 CURRENT BUTANE (C-4) 0 @ 9089.00000 0 @ 9089.00000 0.0 CURRENT BACKGROUND/AVG 0 / 3 PENTANE (C-5) 0 @ 9089.00000 0 @ 9089.00000 0.0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAYSTONE/ SILTSTONE, CONGLOMERATIC SAND PRESENT LITHOLOGY TUFFACEOUS SILTSTONE! CLAYSTONE, CONGLOMERATIC SAND DAILY ACTIVITY Drill 8972' - 9089'. CBU, monitor well for 10 minutes. Pump out of hole 9089' - 8700 POOH 8700' - 1046' SUMMARY Monitor well for 10 minutes. Stand back HWDP, lay down jars. . . EPOCH PERSONNEL ON BOARD 4 REPORT BY Ralph Winkelman DAILY COST ML: $ 2050, RW:$ 275 file://D: \Aurora\Morning%20Reports\200605 03.htm 5/~S/~nn~ Daily Report Aurora Gas, LLC Exploratory Endeavour1 REPORT FOR Jack McDade, John West DATE May 04, 2006 TIME 24:00 CASING INFORMATION 9 5/8' @ 2457' DEPTH SURVEY DATA 8703' BIT INFORMATION NO. SIZE TYPE 8 8.5 SEC XSC1S • GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 5 @ 9091.00000 1 @ 9119.00000 2.3 TRIP GAS 28 CUTTING GAS 0 @ 9150.00000 0 @ 9150.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 872 @ 9091.00000 177 @ 9119.00000 388.2 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 9150.00000 0 @ 9150.00000 0.0 AVG PROPANE (C-3) 0 @ 9150.00000 0 @ 9150.00000 0.0 CURRENT BUTANE (C-4) 0 @ 9150.00000 0 @ 9150.00000 0.0 CURRENT BACKGROUND/AVG 3 / 3 PENTANE (C-5) 0 @ 9150.00000 0 @ 9150.00000 0.0 HYDROCARBON SHOWS NONE GAS DESCRIPTION INTERVAL LITHOLOGY/REMARKS LITHOLOGY Conglomeratic sandstone, Tuffaceous claystone/ siltstone PRESENT LITHOLOGY Conglomeratic sandstone, Tuffaceous claystone/ siltstone bit sub bit k M , e up a Cont POOH with drill collars. No cones on bit. Lay down mud motor and bit sub, break off bit. ' ' DAILY ACTIVITY RIH to 1080'. Lubricate rig and fill pipe. RIH and fill pipe and junk basket . Ream , 8950 @ 4000', 5300', 6500 SUMMARY . 8950' - 9089'. Drill 9089' - 9150'. Page 1 of 1 DAILY WELLSITE REPORT [~ EPOCH DEPTH 9150 PRESENT OPERATION Drilling YESTERDAY 9089 24 HOUR FOOTAGE 61 INCLINATION AZIMUTH VERTICAL DEPTH 4.75 8692.7' INTERVAL CONDITION REASON JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3x20 9089 61 14.0 In Hole S/N 10725472 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 25.8 @ 9091.00000 1.6 @ 9093.00000 5.2 3.96000 FT/HR SURFACE TORQUE 21 @ @ 00000 9089 @ 3 @ 9090.00000 15.6 16.18000 AMPS KLBS WEIGHT ON BIT ROTARY RPM 102 @ . 9102.00000 47 @ 9098.00000 86.9 72.41000 RPM PUMP PRESSURE 2619 @ 9089.00000 1099 @ 9150.00000 1869.4 1099.85999 PSI DRILLING MUD REPORT DEPTH 9140' MW 9.3 VIS 51 PV 20 YP 14 FL 3.4 Gels 3/5/7 CL- 28000 FC 1l3 SOL 4.2 SD 0.25 OIL 0/93.5 MBL 7.5 pH 9.0 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS EPOCH PERSONNEL ON BOARD 4 DAILY COST ML: $2050, RW: $275 REPORT BY Ralph Winkelman file : //D :\Aurora\Morning%20Reports\200605 04.htm 5/25/2006 u • Daily Report Page 1 of 1 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT E'I'C~~H Endeavour1 REPORT FOR Jack McDade, John West DATE May 05, 2006 DEPTH 9153.00000 PRESENT OPERATION Trip in hole TIME 24:00 YESTERDAY 9150.00000 24 HOUR FOOTAGE 3 CASING INFORMATION 9 5/8' @ 2457' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8703' 4.75 8692 7 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 8 8.5 SECXSC1S 10725472 3x20 9089 9153 64 15 6-1-BT/UVT-M/G-E-IN--PT/TQ ROP/TORQ 9 8.5 HUGHES MXLI8DX 6046677 3x20 9153 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 4.8 @ 9152.00000 3.5 @ 9153.00000 4.1 3.52000 FT/HR SURFACE TORQUE @ @ WEIGHT ON BIT AMPS 16 @ 9152.00000 15 @ 9153.00000 21.5 15.61000 KLBS ROTARY RPM 72 @ 9150.00000 67 @ 9152.00000 93.1 67.38000 RPM PUMP PRESSURE 2100 @ 9152.00000 1099 @ 9151.00000 2130.4 2091.37988 PSI DRILLING MUD REPORT DEPTH 9153' MW 9.3 VIS 53 PV 20 YP 13 FL 3.8 Gels 4/6/0 CL- 28000 FC 1/3 SOL 4.2 SD 0 OIL 0/93.5 MBL 7.5 pH 8.8 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 3 @ 9150.00000 2 @ 9153.00000 4.1 TRIP GAS CUTTING GAS 0 @ 9153.00000 0 @ 9153.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 653 @ 9150.00000 531 @ 9153.00000 811.7 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 9153.00000 0 @ 9153.00000 0.0 AVG PROPANE (C-3) 0 @ 9153.00000 0 @ 9153.00000 0.0 CURRENT BUTANE (C-4) 0 @ 9153.00000 0 @ 9153.00000 0.0 CURRENT BACKGROUND/AVG 0 / 1 PENTANE (C-5) 0 @ 9153.00000 0 @ 9153.00000 0.0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CONGLOMERATIC SANDS, TUFFACEOUS SILTSTONE AND CLAYSTONE PRESENT LITHOLOGY CONGLOMERATIC SANDS, TUFFACEOUS S{LTSTONE AND CLAYSTONE DAILY ACTIVITY Drill to 9153' . CBU. POOH to 8530', pump dry job. POOH. Break off bit stabs wore out Test BOP Perform , . . SUMMARY Koomey test. Change out lower pipe rams, replace rubbers. Cont BOP test: Make up bit and trip in'hole. EPOCH PERSONNEL ON BOARD 4 REPORT BY Ralph Winkelman DAILY COST ML: $2050, RW: $275 file : //D : \Aurora\Morning%20Reports\200605 O S . htm si~si~nnti • • Daily Report Page 1 of 1 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT ~,~~~H Endeavour1 REPORT FOR Jack McDade, John West DATE May 07, 2006 DEPTH 9225 PRESENT OPERATION WIRELINE LOGGING TIME 24:00 YESTERDAY 9225 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 2457' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9225' 4.0 92.13.2' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 9 8.5 HUGHES MXL18DX 6046677 3x20 9153 9225 72 10.3 0-0-NO- -E-IN- -TD TD WELL DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9225' MW 9.3 VIS 53 PV 20 YP 15 FL 4.2 Gels 4/510 CL- 28000 FC 1/3 SOL 4.2 SD 0 OIL 0/93.5 MBL 7.5 pH 8.7 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 ( 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY NO DRILLING LAST 24 HOURS DAILY ACTIVITY Finish POOH. Break off bit, pull survey tool, make up bit. Pre job safety meeting with Schlumberger for wireline SUMMARY logging. Rig up Schlumberger. Make up tool, load sources. RIH and log Platform express with CMR. Lay down Platform express and pick up FMIiDSI tools. RIH and log. EPOCH PERSONNEL ON BOARD 2 REPORT BY Ralph Winkelman DAILY COST ML: $1400, RW: $275 file://D:\Aurora\Morning%20Reports\20060507.htm 5/25/2006 • • • Daily Report Page 1 of 1 Aurora Gas, LLC Exploratory DAILY WELLSITE REPORT r,~~~,~ Endeavour1 REPORT FOR Jack McDade, John West DATE May 08, 2006 DEPTH 9225 PRESENT OPERATION RIH W/MULE SHOE TIME 24:00 YESTERDAY 9225 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 2457 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9225 4,0 9213.2' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9225' MW 9.3 VIS 53 PV 19 YP 15 FL 4.3 Gels 5/7/0 CL- 28000 FC 1/0 SOL 4.2 SD 0 OIL 0/93.5 MBL 7.5 pH 8.8 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CH ROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 / 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY NO DRILLING LAST 24 HOURS DAILY ACTIVITY Wreline log. Rig down Schlumberger. RIH to 2051'. POOH and lay down pipe. Move Schlumberger unit from end SUMMARY of catwalk. Mix and pump dry job. Cont POOH and L/D drill pipe, HWDP, collars and bit. Make uo mule shoe and RIH. EPOCH PERSONNEL ON BOARD 2 REPORT BY Ralph Winkelman DAILY COST ML: $1400, RW: $275 file://D:\Aurora\Morning%20Reports\20060508.htm 5/25/2006
