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209-054
• • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. a oy - Q s W- Well History File Identifier Organizing (done) ❑ Two -sided 11! 11111111 11! 11111 ❑ Rescan Needed 1!! 111111 1111 111 R CAN DIGITAL DATA OVERSIZED (Scannable) for Items: ❑ Diskettes, No. E] Maps: Greyscaie Items: ❑Other, No/Type: ❑ Other Items Scannable by ❑ Poor Quality Originals: a Large Scanner OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: Other:: BY: Maria Date: !CI / , P Project Proofing 1111111111111111111 BY: Maria_ Date: /s/ P r Scanning Preparation x 30 = / 6 + al7'= TOTAL PAGES j (Count does not include cover she 7 1-1 BY: Maria Date: ! o p II /s/ , 1 Production Scanning III 111111 1111 ll III X Stage 1 Page Count from Scanned File: (Count does include cove heet) Page Count Matches Number in Scanning Preparation: 1,/ YES NO BY: (Mari Date: /0/4/ /i /_ 11 / rip Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: / Scanning is complete at this point unless rescanning is required. 111 I 11111 ReScanned 1111111111111111111 BY: Maria Date: / Comment about bout this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 10/6/2011 Permit to Drill 2090540 Well Name /No. NUNIVAK 1 Operator RAMPART ENERGY COMPANY API No. 50- 083 - 20002 -00 -00 MD 11136 TVD 11094 Completion Date 8/16/2009 Completion Status P &A Current Status P &A UIC N REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey a) v DATA INFORMATION Types Electric or Other Logs Run: Mud log, AIT, GR, Neutron /Density, Dipole Sonic Log, LWD Log (data taken from Logs Portion of Master Well Data Maint Well Log Information: III Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments og Analysis - Misc 2 Col 200 7613 ELAN Petrophysical , I ,/.- Analyisis, RWA 4- Aug -2009 QED C Las 18499 'rosity 195 7635 Open 9/2/2009 Tens, SPHI, NPHI, GR, RWA. DPHZ Plus PDS Graphics TD C Las 18500 onic 169 7618 Open 9/2/2009 Depth,DSI, BDT REVISED Plus PDS Graphics teog Sonic 5 Col 150 7650 Open 9/2/2009 BestDT* Proc DS! og Cement Evaluation 5 Col 200 7613 Open 9/2/2009 MD Cement Volumes, Power Position Caliper, 4 arm Caliper, GR ** *Field Print * ** og Porosity 25 Col 200 7613 Open 9/2/2009 MD Plat Ex, Por, EWR, Microlog, GR, SP ** *Field III Print * ** Log Porosity 25 Col 200 7613 Open 9/2/2009 TVD Plat Ex, Por, EWR, Microlog, GR, SP ** *Field Print * ** I / Q ED C Las 18509 le duction /Resistivity 0 0 Open 9/3/2009 Res Poro Dense LAS, PDS GIF Graphics, ACSII and Directional Surveys lVog Induction /Resistivity 2 Col 7330 11089 Open 9/3/2009 TVD Vision Service Lbg Induction /Resistivity 5 Col 7330 11089 Open 9/3/2009 TVD Vision Service dog Induction /Resistivity 2 Col 7330 11089 Open 9/3/2009 MD Vision Service "tog In 5 Col 7330 11089 Open 9/3/2009 MD Vision Service C 18700 'S ee Notes 0 7600 Open 9/21/2009 VSP, Check Shot Survey DATA SUBMITTAL COMPLIANCE REPORT 10/6/2011 Permit to Drill 2090540 Well Name /No. NUNIVAK 1 Operator RAMPART ENERGY COMPANY API No. 50 -083- 20002 -00 -00 MD 11136 TVD 11094 Completion Date 8/16/2009 Completion Status P &A Current Status P &A UIC N Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Cores and /or Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 6/9/2009. ADDITIONAL INFORMATION • Well Cored? Y /® Daily History Received? / N Chips Received? — Y.L.QI Formation Tops / N Analysis 14. Received? Comments: Compliance Reviewed By: __ Date: 6 RAMPAR -� October 7, 2009 Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 Anchorage, Alaska 99501 RE: Report of Annular Disposal: Rampart Energy Company, Nunivak #1 Dear Mr. Seamount, Rampart Energy Company hereby submits the required Report of Annular Disposal for our Nunivak #1 gas exploratory well for the 3rd quarter, 2009. Attached please find the Form 10 -423, Report of Annular Disposal and supporting documentation. This will be the only Report of Annular Disposal submitted for the Nunivak #1 well as it has been permanently plugged and abandoned and can no longer receive any injections of fluids or other materials. If you have any questions or require additional information, please contact me at (303) 460 -1132 or Alexey Sachivichik at 258 -3446. Sincerely, RAMPART ENERGY COMPANY Van Spence President cc: Alexey Sachivichik — Fairweather enclosures Rampart Energy Company 1512 Larimer Street Bridge Level Denver, CO 80202 303.460.1132 Fax 303.460.1205 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic U Service U 6. Permit to Drill Number: 209 -054 Rampart Energy Company Development _ Exploratory 0 7. Well Name: Nunivak #1 2. Address: 4b. Well Status: Oil ❑ Gas U WAG U 8. API Number: 1512 Larimer Street, Bridge Level, Denver, CO 80202 GINJ _ WINJ 0 WDSPL 0 50- 832 - 00020000 3. (Check one box only) 5a. Sundry Number: 5b. Sundry approval date: 9. Field: Exploratory Initial Disposal n Continuation _ Fing Fin 309 -280 8/13/2009 10 (h)(1) drilling mud, drilling (h)(2) drill rig wash fluids (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids and drill rig domestic waste approved substances (include days Beginning Dates: Ending cement- contaminated drilling water descriptions in block 12) disposal Dates: IP mud, completion fluids, occurred: formation fluids and any necessary water added. Previous totals 0 0 0 0 0 N/A N/A N/A (bbls): 2009/Q3 2633 0 0 2633 3 08/13/09 08/15/09 Nunivak #1 YYYY /Q# YYYY /Q# YYYY /Q# Total Ending Report is due on the 20th Volume of the month following the final month of the quarter. Ex. (bbls): April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time U Step Rate Test n October 20 for the third quarter, and January 20 for the Other (Explain) n fourth quarter. 12. Remarks and Approved Substances Description(s): This will be the only report submitted for this well as it has been permanently plugged and abandoned, and thus unable to receive any further injections. I hereby certify that the foregoi is tru n correct to the best of my knowledge. Signature: Date: 10/7/2009 Printed Van ence Title: President Phone 303-460-1132 Name: Number: Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate Nunivak #1 Annular Disposal Injection Log Flow Start End BBL's Time DIF Time (hrs) CUM Pumped MW Remarks Date SPM BPM Pressure Pressure Pumped Start Stop Volume 8/13/2009 3 500 600 1551 15:09 23:46 8.62 1551 9.8 8/14/2009 3 400 600 543 10:18 13:19 3.02 2094 9.5 3 400 22:52 Pumping stopped 8/15 at 0:42 • 8/15/2009 650 329 0:42 1.83 2423 9.4 3 600 600 210 2:09 3:19 1.17 2633 9.3 0 • t F 1 + NR 'A00°°07:00 MiiiiSillarrimilimiftwAllilimimil \ •0° OW.W....wolammow=a1,.__AftWfteft44414' , 7 z alleillf,....nrearl 17 4)63 poir,...1„„wa...m......._ ro 00 ••• fanWair y 0111 y po �EiSstill: _ e, 4 coo A lioomisraffir 7 Itileittiff4tilfit #'*t°1■ OW ft _, 00 ts‘oo o 1 . , cb Ws. Sillita 49.* 1 hi lt e -7- .8 '411161111101 - 1 L n 1 klikettlinliellikt 3 % 4. ° i 4 1 4 111111111111 � � *14 "1111410 1 kl‘t o � ov ........ 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P,,,■Immr,miumm Nommr----0, t>. 5/62 7 , 1 1 I 4 s iu 40 I I .. 7 I I 11 i lizi r o II r rAtill IL li II I ww= Wa I im . j 21.11111111WIlrilllijoi I 01/01W° 2 4, 6 wsi ,- - ------ - ---- - -I1d4 ................................................................................................i o c4 \ t, siiiiiiiihr=f,immor -1 *'" 7 . _.iiiiiiii, liorma...,..,.........ri it; oc °11. Pi I - " IP. .111"011`.- 1 ° • 0 r + o ` P 4/ . 401, }1110 6000 steaS t * \•:, 1 0011,6 airem,W4k i 441p 1 ,,, I - $011 „,.....„.' : elir 4 ; I A A g l otto tilittittoti 4 0°1 PA /44Z 0 Si 11 0' . 4 'Jiij 1 H1 R II 1 Mara S ** • 4 1 . .v : : ItteSS Ai ilia 10410 C 111 g ' 0006 ft* 0068 SIS � ooL � ��� 09 411.4 I Akillto or:00■raiwwarufeWIM•Ail 1rAitim,M0,1 _, - 4 11 1 ii " I ' i mly=iW I O MI 4t Alok io °, 0 0 41 / 1111° "= "Mill -1q111 II Pip-ir •=milivilie"-- o > >3M .41/./ 0 i, w / t co- • 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ��� � i7' DATE: Aug. 28, 2008 P. I. Supervisor I\ (`� FROM: Bob Noble SUBJECT: Location Clearance Petroleum Inspector Nunivak #1 Rampart Energy Co. PTD — 209 -054 Auq 28, 2008: On arrival at the Fairbanks airport I met with Rampart Energy Rep. Johnny O'Hare (Fairweather). We traveled to the Nunivak #1 location outside of Nenana. The road to location had grass planted along the sides giving it a nice clean look. I found the location to be very clean and well kept, with no traces of spills or trash left behind. It appeared as if they had 2 or 3 more loads of material to remove off of location. The well had about a 4 feet high mound over it. I found no debris or cement in the mound. The cut -off was not witnessed by the AOGCC so I ask Johnny O'Hare for details and some pictures. Johnny told me that the plate was 1 /2" thick and had a 1" larger diameter ., than the largest casing. He said that the well was cut off 7' below the grade line and full of good hard cement. Summary: On completion of the inspection we had an informal meeting with the Nenana Mayor, State of Alaska Fish and Game, DNR, DEC and myself. Everyone seemed to be pleased with the condition that Rampart Energy was leaving the location. I wish all the operators in the State would take this kind of pride in their operations. Attachments: photos • • Location Clearance — Nunivak #1 (Rampart Energy) PTD 209 -054 Photos by AOGCC Inspector Bob Noble and Rampart August 28, 2009 Access road; grass planted along corridor Casing cut -off; cement to surface 2009 -0829 Location Clearance Nunivak -1 bn.doc 2 • . o ff reed i II FIPIIIP * o f r + ..., .... ,,.... ---• \ A "\ 1 001011111.111%1 C, .• 0 ‹. V \ ,,# \ i ce . Well marker f '�"� Oil.. � plate �,,,� N r� • ' " „i ' , .,,, : a • , •---, ,.. .. ., ,. , ,„„),... v . ) r, ......, - 0 , '' , S . , � Cut -off with ,S „� .ik- ` v-. marker plate � - - 1 v -....• r •.'1` 4 . installed , 1;;;‘, V � , , ��(. . -. .r. .. . i �,�, .� - - n 4-.4' y . r - ' ' 10 14 44 `` •.,' ,�y; Y '.r. rye. n .. Q , - <. ' y • •_ N _ , .,,.‘,..,',11 ', . , 2009 -0829 Location Clearance Nunivak -1 bn.doc 3 • • • K r .+rs.r _. a _ 1j .. I I -- Drillsite; mound over buried well s • t _ Y *..' •tom 0 ',.....---" , * �: °'`' �? '� ' • 4 2009 -0829 Location Clearance Nunivak -1 bn.doc 0 • RECEI'VtD ',u u 2 .7 2009 ni rvAMP -� .m,5,_ ; :MIIT August 21, 2009 Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7tn Ave., Suite 100 Anchorage, Alaska 99501 RE: Well Completion Report Rampart Energy Company, Nunivak #1 PTD No. 209 -054 P & A Sundry No. 309 -281 Dear Commissioner Seamount, Rampart Energy Company hereby submits its Well Completion Report for the work performed in drilling its Nunivak #1 exploration well in the Nenana area. Please find enclosed the following information for your files: 1) Form 10 -407 Well Completion or Re- completion Report and Log 2) Well As -Built Survey 3) Wellbore Schematic 4) Well Operations Summary 5) Wellbore Directional Survey Copies of the mud log and all wireline logs run were submitted earlier under separate cover. If you have any questions or require additional information, please contact me at (303) 460 -1132, or Alexey Sachivichik at (907)258 -3446. Sincerely, Ram Ene Co pally I { Julie L. Weber Vice resident Attachments Cc: Alexey Sachivichik - Fairweather Rampart Energy Company 1512 Larimer Street Bridge Level Denver, CO 80202 303.460.1132 Fax 303.460.1205 STATE OF ALASKA , "°4 ` = '� 9� ALASAIL AND GAS CONSERVATION COMMI WM WELL COMPLETION OR RECOMPLETION REPORT AN 'L o & ° 33 9 1'/ t la. Well Status: Oil ❑ Gas ❑ Plugged 0 Abandoned in Suspended ❑ 1 b. Well Class; „ ° ' „ r,rprr?i sir`rt 20AAC 25.105 20AAC 25.110 Development ❑ g , xp!oratory El GINJ❑ WINJ❑ WDSPL❑ WAG Other❑ No. of Completions: Service ❑ Strat(graphicTest❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Pt, Rampart Energy Company Aband.: 8/16/2009 J 209 -054 - 0 11...4..g/ ( 7 , 3. Address: 6. Date Spudded: 13. API Number: 1512 Larimer Street, Bridge Level, Deriver, CO 80202 *62009 50- 083 - 20002 -0000 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 91' FWL & 1175' FNL T4S, R8W, Sec 17 FM 7/31/2009_ Nunivak #1 Top of Productive Horizon: N/A 8. KB (ft above MSL): , 376.6' 15. Field /Pool(s): Ground (ft MSL): 18.8'- Exploratory Total Depth: 865' FWL & 1025' FNL T4S, R8W, Sec 17 FM 9. Plug Back Depth(MD +TVD): Surface 4b. Location of Well (Stat ase Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 6233 7 y- 3864363.1 Zone- 4 '11,136' MD/11,074' TVD MHT 9300028' TPI: x- N/A J P"" ' y- N/A Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 624167 y- 3864462 Zone- 4 N/A N/A 18. Directional Survey: Yes 0 No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) - 1,700' 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): Mud Log, AIT, GR, Neutron /Density, Dipole Sonic Log, LWD Log. 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 84 N -80HC 0' 80' 0' 80' 16" J r) 9.625" 40 L -80 0' 2513' 0' 2513' 12.25" -A5 ibI5/O; -8 -sm-- 5 1 bbl s Welk 23. Open to production or injection? Yes Noll/ If Yes, list each 24. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) N/A 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 26 PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): No production test Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate - 27. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. N/A iCOMPLEi'i0 1 BFI.- ":tP 4 2F 2000 Form 10 -407 Revised 2/2007 CONTINUED ON REVERSE 6. • • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes , /1 No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Nenana gravel - Top 0' 0' needed, and submit detailed test information per 20 AAC 25.071. Nenana gravel - Base 4017' 4003' Grubstake - Base 4633' 4610' Lignite - Base 5800' 5762' Suntrana - Base 7005' 6952' Sanctuary - Base 7590' 7534' Healy Creek - Base 9650' 9592' Lower most Usibelli - Top 9650' 9592' Base 11136' 11075' Formation at total depth: 30. List of Attachments: As -built survey, wellbore schematic, directional survey, mud log, SLB BestDT* Processed DS! log, SLB Platform Express - Measured Depth Porosity /Resistivity/Microlog /GR/SP and the same with TVD Iogs,SLB Power Position Caliper - MD log. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Alexey Sachivichik: 258 -3446 Printed Name: Julie eber Title: Vice President Signature: I 1 2 Phone: (303) 460 -1132 Date: U ' Z/. d y INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 2/2007 • 0 IX A P RT > ---. . Nunivak #1 Wellbore Schematic P &A x ' 1 conductor at 80' ryc Bridge Plug at 200' , ti3 ,µ a; 10mud .25 ppg 12-1/4" hole • TOC at 2,385' MD Cement retainer at 2,440' MD +: t' er ce " 9 -5/8 ", 40 #, L-80, BTC ., p casing at 2,513'MD BOC /OH Packer at 2,700' MD i 2 z 0 2 2 0 2 0 8 -1/2" hole c 10.3 ppg 2 mud 2 2 4 2 0 2 2 0 z TD at 11,136' MD/TVD aar r a rAssocIates, Inc. 9Q7- 479 -$$3d p.2 H • IP. SEC 7 SEC 8 SEC 8 SEC 7 SEC 18 SEC 17 ; SEC 17 SEC 16 -41 1140` NORTH TO N-UNIVAK NO. I WELL LO 4 SECTION LINE NAQ27 1 5' WEST TO GEODETIC POSITION SECTIO LINE LATITUDE = 64'34'19.281" NOR1'li WELL LONGITUDE = 14912'55.200" WEST • I ALASKA STATE PLANE ZONE 4 MC NORTHING = 3864313.1 FEET EASING = 623376.7 FEET I 1 t1AD 83 I I GEODETIC POSITION f I LATITUDE = 64'34'17.605" NORTH 1/4 ' rx/ LONGITUDE = 149'13'03.83e WEST COR I 0 . I v ALASKA STATE PLANE ZONE 4 . I NORTHING = 3864065.8 FEET -- 11-•r- -100' SECTION UNE EASTING = 1763413.2 FEET � EASEMENT I UNIVERSAL TRAVERSE MERCATOR ZONE 6 NORTHING = 23499178.7 FEET EASTING = 1291873.4 FEET GRAPHIC SCALE LOCATED WITHIN 1 500 0 500 1000 f TOWNSHIP 4 SOUTH I RANGE 8 WEST • MC FAIRBANKS MERIDIAN 1 INCH = 1000 FT. SEC 18 I � SEC 17 ,E SEC 16 SEC 19 SEC 20 SEC 20 SEC 21 i I �.,tit�t11l1 4 OF A 11 h GLO OFFICE MONUMENT RECOVERED Ay Je ' lam _ \1 1 * i� ,� 49 �H t.. * 0 SURVEYOR'S CERTIFICATE , pi 0 0 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO 0 KA f PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS PLAT / # p, 1 PATRICK • c REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION, f !j,• °. U a ,. THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST AS DESCRIBED, AND • � THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. 0 e d ap °• • ...... • .` �o , 1 DRAWN BY ERK CHECKED BY: PHK I SHEET 1 OF 2 Location Survey For: C[��II � p 200 E. 88TH AVE. F J r E PHONE (907 -3446 RAMPfiRT •trauma ed FAX: (907) 2 -5740 1512 DENVER, CO R 802 STREET, BRIDGE LEVEL KA 1041 IIRBANKS, ALASKA 99709 PHO (303) 339 -4400 & ASSOCIATES, INC. (907) 479-2628 • -_. _ . ...,. ..�.... , " ,-,...,.,,,,0„..., , , I V . w, U /- 4l- t�2S�U P.3 0 • II CENTER OF PAD NUNIVAK Na 1 WELL I,QCATION N� I i sEcnoN s 1140' NORTH TO LINE NAD22. ALASKA STATE PLANE ZONE 4 GEODETIC POSITION NORTHING = 3864210 FEET LATITUDE = 64109.281" NORTH EASTING = 523320 FEET LONGITUDE - 14912'55.200" WEST I l ALASKA STATE' PLANE ZONE 4 f t. WI NORTHING = 3864313.1 FEET f EASTING 623376.7 FEET r' NM) 93 GEODETIC POSITION LATITUDE = 64734'17.605" NORTH .+ WELL LONGITUDE = 1 WEST 15' WEST TO ALASKA STATEPLANE ZONE 4 SECTION LINE NORTHING = 3864065.8 FEET / CENTER OF PAD EASTING = 1763413.2 FEET UNIVERSAL TRAVERSE MERCATOR ZONE 6 NORTHING = 23499178.7 FEET EASTING = 1291873.4 FEET i FIELD 1942 WC 1AD27 1 GEODETIC POSITION 100' SECTION LINE EASEMENT I - - LATITUDE = 64'32'41.578" NORTH GRAPHIC SCALE ! LONGITUDE = 149'05'05.698* WEST 150 0 150 300 ALASKA STATE PLANE ZONE 4 =M NORTHING = 3854662.48 FEET o EASTING = 644025.01 FEET 1 INCH = 300 FT. f I NOTES: 1. NUNIVAK WELL NO, 1 IS LOCATED WITHIN SECTION 17 AND 18, TOWNSHIP 4 SOUTH, RANGE 8 WEST, FAIRBANKS MERIDIAN, ALASKA AND IS MORE PARTICULARLY LOCATED 1140 FT FROM NE NORTH UNE AND 15 FT FROM THE WEST LINE OF SECTION 17. 2. POSITIONAL INFORMATION OF THE NUNIVAK WELL NO, 1 WAS DETERMINED ON JULY 13, 2009 USING THALES Z —MAX GPS RECEIVERS AND STATIC GPS PROCEDURES, BASED ON NGS MONUMENT FIELD 1942. 3. COORDINATE VALUES SHOWN REFLECT THE POSITION OF THE CENTER OF THE WELL. 4. ALL DIMENSIONAL INFORMATION IS IN US SURVEY FEET. DRAWN BY: ERK CHECKED BY: PFIK SHEET 2 OF 2 Location Survey For 200 E. 88TH AVE. ANCHORAGE, AK 99507 RirR PHONE: (907) 258 -3446 RAM r.k. saw= ,.c FAX: (907) 279 -5740 1512 LARIMER STREET, BRIDGE LEVEL I= 1041 CHENA RIDGE ROAD DENVER, CO 80202 KALEN FAIRBANKS, ALASKA 99709 PHONE: (303) 339 - 4400 /\ a ASSOCIATES, INC. " (9tI7) 479-2628 I • OPERATIONS SUMMARY Rampart Energy Company Nunivak #1 June 26, 2009 100' MW N/A Vis N/A Incl 0.00 deg Set matting boards. Unload subase and spot it on pony base. Rig up shaker pit. Mount shakers, install hand rails on sub. June 27, 2009 100' MW N/A Vis N/A Incl 0.00 deg Prepare subase for setting mast, spot mud tanks and motors. Set pits and pump modules. Spot mast by sub. Hook up service lines. Continue trig up of the rig. June 28, 2009 100' MW N/A Vis N/A Inc10.00 deg Cut off 16" conductor 39.975" BGL. Install Vetco Gray 16" VG LOC starting head, test to 500 psi for 10 minutes — test good. Load draworks skid and derrick into top sub and continue rig up. Begin work on pad for 40 man camp. June 29, 2009 100' MW N/A Vis N/A Inc10.00 deg Begin setting 40 man camp. Start NU diverter and knife valve. Continue landscaping of the road. Working on barge ramps due to river level drop. June 30, 2009 100' MW N/A Vis N/A Inc10.00 deg Continue setting 40 man camp. Continue RU Arctic Wolf #2 rig. NU diverter system. July 1, 2009 100' MW N/A Vis N/A Incl 0.00 deg Install service loop for top drive, set choke house, install electrical and hydraulic lines from top drive unit to rig floor, function test top drive. Complete setting 40 man camp. Tighten all studs and nuts on diverter lines and spools. Install 6" liners in mud pumps. Dress out mud pumps with valves and seats and 6" liners. I • July 2, 2009 100' MW N/A Vis N/A Incl 0.00 deg Continue rig up of camp and rig. Begin function testing rig equipment. Set berms for mud storage tank. July 3, 2009 100' MW N/A Vis N/A Incl 0.00 deg Continue with rig up, function test the rig. Work on 40 man camp electrical, water and septic lines. Continue with installation of Horizon rig monitoring system. July 4, 2009 100' MW N/A Vis N/A Incl 0.00 deg Commission the rig. P/U drill pipe. Complete rig up of mud loggers, MWD cabin and mud lab. July 5, 2009 100' MW N/A Vis N/A Incl 0.00 deg Commission the rig. Set felt and liner for cuttings /waste mud pumps. Evacuate all personnel from location due to forest fire. July 6, 2009 100' MW N/A Vis N/A Incl 0.00 deg Call out crews. Resume operations suspended due to forest fire. Set and berm up 400 bbls tanks. Build cell for excess cement. P/U jars, HWDP, 8" drill collars. July 7, 2009 100' MW N/A Vis N/A Incl 0.00 deg Mix spud mud. Test diverter system, witnessed by AOGCC's Jeff Jones. Set cement van and silo. July 8, 2009 100' MW N/A Vis N/A Incl 0.00 deg Wait for Forestry Division approval to spud. Set up sprinkling system around location. Test HP mud lines, spud well at 1845 hrs. Drill 12 -1/4" hole to 312'. POH to motor, MU BHA except for HWDP, RIH. Drill from 312" to 524'. POH to PU HWDP. July 9,2009 2525' MW 9.1 ppg Vis 255 sec Intl 2.0 deg PU HWDP and RIH to 524'. Drill 12 -1/4" hole from 524' to 2008'. Observe 500 psi pressure loss. POH to 1509' looking for washout. Regain pressure at 1509'. Suspect faulty pump • • pressure sensor. RIH, drill from 2008' to 2525' section TD. Pump carbide lag around and short trip to BHA. July 10, 2009 2,525' MW 9.1 ppg Vis 140 sec Inc12.00 deg Make short trip to conductor shoe and back to bottom. CBU and POOH, L/D BHA. Begin running 9 -5/8" casing. July 11, 2009 2,525' MW 9.1 ppg Vis 54 sec Inc12.00 deg Finish running 9 -5/8" casing to 2,515' w/ port collar installed at 515'. Circ one csg vol while R/U to cement. Mix and pump 224 bbls permafrost lead cmt followed by 62 bbls Class G tail cmt. Displace w/ mud, bump plug w/ 1,250 psi. Received dyed pre -flush to surface but no cement. Shift open port collar and circulate out cement above it in annulus. July 12, 2009 2,525' MW 9.1 ppg Vis 54 sec Inc12.00 deg R/U cementers and pump Stage 2 cement job: 29 bbls lead and 36 bbls tail. Good cement to surface. Shift port collar closed and test to 1,000 psi. WOC. Rough cut 9 -5/8" csg and remove stub. N/D diverter equipment. Make final cut on casing, prep for wellhead installation. July 13, 2009 2,525' MW 9.0 ppg Vis 54 sec Intl 2.00 deg Attempt to set wellhead w/ o -ring, would not set to mark. Remove o -ring and weld WH to casing. Pressure test weld to 5,000 psi — found two leaks. Grind and dress in prep for re -weld while assembling BOP components. July 14, 2009 2,525' MW 8.9 ppg Vis 48 sec Inc12.00 deg Weld on wellhead. Let cool while M/U and S/B 4" DP stands in derrick. Conduct H2S drill and ADEC spill drill. M/U BOP components and hang in subbase trolley. Remove insulation f/ WH. July 15, 2009 2,525' MW 9.0 ppg Vis 52 sec Inc12.00 deg Let WH cool. Pressure test to 4,600 psi — good test. Assemble and N/U BOPE. • July 16, 2009 2,525' MW 9.0 ppg Vis 56 sec Inc12.00 deg Finish N/U BOPE. Test BOPE to 5,000 psi, witnessed by AOGCC's John Crisp. Replace kill - side HCR w/ manual valve. Repair leak in standpipe. Replace IBOP in top drive. July 17, 2009 2,525' MW 9.0 ppg Vis 54 sec Inc12.00 deg Complete changing out IBOP in top drive. Test 9 -5/8" csg to 3,750 psi for 30 min. Test IBOP to 250/5000 psi. Test witness waived by AOGCC's John Crisp. M/U BHA and RIH on drill pipe. Tag float collar. Drill out float collar and cement in shoe track. July 18, 2009 3,875' MW 9.1 ppg Vis 50 sec Incl 8.80 deg Drill out FC, cmt, FS and 20' of new formation to 2,545'. C &C mud. Perform LOT to 12.4 ppg EMW. Drill 2,545' to 2,561'. Perform second LOT — same EMW. Directionally drill 8 -1/2" hole from 2,561' to 3,056'. Perform LOT to 12.7 ppg EMW. Drill from 3,056' to 3,875'. July 19, 2009 5,445' MW 9.1 ppg Vis 53 sec Inc19.30 deg Directionally drill 8 -1/2" hole from 3,875' to 4,614'. Short trip to 2,995' and back to bottom. Hole in good condition. Drill from 4,614' to 5,445'. July 20, 2009 6,036' MW 9.2 ppg Vis 53 sec Inc18.60 deg Directionally drill 8 -1/2" hole from 5,445' to 6,020'. Wash pipe in top drive blew. POH to 4,565'. Change out wash pipe and pressure test to 3,000 psi. RIH to 6,020'. Drill to 6,036', bit stopped drilling. POH for new bit. July 21, 2009 6,445' MW 9.3 ppg Vis 53 sec Inc19.65 deg Change out bit. RIH with BHA #5. Pulse test MWD. RIH to 6,036'. Directionally drill from 6,036' to 6,445'. July 22, 2009 7,310' MW 9.1 ppg Vis 62 sec Inc16.7 deg Drill from 6,445' to 7,310'. Service rig. • I July 23, 2009 7,610' MW 9.3 ppg Vis 66 sec Incl 1.37 deg Drill from 7,310' to 7,610'. Circulate sweep. Trip out of hole. Lay down 18 joints of 5" drill pipe, pony collar, sub, MWD and motor. Prep for BOP test. July 24, 2009 7,825' MW 9.4 ppg Vis 68 sec Incl 1.80 deg Test BOPE to 250 psi — low /5000 psi - high. Good. Test witness waived by AOGCC's Jim Regg. Make up BHA #6. TIH. Drill from 7,610' to 7,825'. July 25, 2009 8,665' MW 9.4 ppg Vis 66 sec Incl 1.97 deg Drill /slide from 7,610' to 8,647'. Work and free stuck drill pipe at 8,640'. Drill from 8,647' to 8,669'. Circulate. Wiper trip from 8,669' to 7,860'. July 26, 2009 9,165' MW 9.6 ppg Vis 69 sec Incl 2.10 deg Finish wiper trip. Circulate. Drill from 8,669' to 8,844'. Repair rig (wash pipe). Drill from 8,844' to 9,109'. Repair rig (wash pipe). Drill from 9,109' to 9,165'. July 27, 2009 9,313' MW 9.7 ppg Vis 86 sec Incl 0.40 deg Drill from 9,165' to 9,313. Repair wash pipe assembly. Wiper trip to 7,392'. Repair rig (wash pipe packing assembly). POH to 2,500'. Repair rig. July 28, 2009 9,450' MW 9.9 ppg Vis 105 sec Incl 0.25 deg Repair swivel. POOH from 2,498'. Check motor and bit. RIH to 2,498'. Cut drilling line. TIH to 9,316'. Circulate and condition mud. Drill from 9,316' to 9,450'. July 29, 2009 10,104' MW 9.6 ppg Vis 72 sec Incl 0.47 deg Drill from 9,450' to 10,104'. Circulate. Wiper trip from 10,104'. July 30, 2009 10,740' MW 9.6 ppg Vis 70 sec Incl 1.60 deg Wiper trip. Service the rig. Drill from 10,103' to 10,740'. • • July 31, 2009 11,136' MW 9.7 ppg Vis 61 sec Incl 10.19 deg Drill from 10,745' to 11,136' TD. Pump hi -vis sweep, hole packed off, pipe stuck. Work pipe free. C &C hole for POH, BOP test and OH logs. August 1, 2009 11,136' MW 9.8 ppg Vis 66 sec Incl 10.19 deg C &C hole. POH, L/D BHA. Test BOPE (test witness waived by AOGCC's Jim Regg). August 2, 2009 11,136' MW 9.8 ppg Vis 70 sec Incl 10.19 deg Finish testing BOPE. R/U wireline for OH logs. RIH, tag up at 7,610'. Could not work past 7,620'. Log 7,620' to 2,515' (surface casing shoe). POH, R/D logging equip. M/U cleanout assy and RIH. No bobble at 7,600', hole tight commencing at 9,800'. August 3, 2009 11,136' MW 9.9 ppg Vis 77sec Incl 10.19 deg Spend all day washing and reaming 9,900' to TD. C &C hole and POH. August 4, 2009 11,136' MW 9.9 ppg Vis 61 sec Incl 10.19 deg Cont. POH, S/B BHA. R/U wireline for open hole logging. RIH, tools stopped at 7,620'. Would not work through. Log out to surface. R/U to run VSP survey. RIH and run VSP survey 7,600' to surface. R/D wireline equipment. August 5, 2009 11,136' MW 9.9 ppg Vis 84 sec Incl 10.19 deg M/U 8 -1/2" cleanout assy, RIH. Clean up interval across 7,600' and continue in hole. Took weight at 9,791'. Wash and ream to 10,540'. August 6, 2009 11,136" MW 10.10 ppg Vis 80 sec Incl 10.19 deg Wash and ream to TD. C &C hole. POH - many tight spots requiring pumping out. L/D BHA. August 7, 2009 11,136' MW 10.3 ppg Vis 74 sec Incl 10.19 deg Test BOPE, P/U HWDP. Wait on MWD/LWD tools from Deadhorse. i I August 8, 2009 11,136' MW 10.2 ppg Vis 64 sec Incl 10.19 deg LWD tools arrived at 13:30. Test tools. M/U BHA, RIH. Pulse test MWD. TIH. Circulate. August 9, 2009 11,136' MW 10.3 ppg Vis 78 sec Incl 10.19 deg TIH with LWD/MWD and log hole from 7,400' to 9,120'. August 10, 2009 11,136' MW 10.2 ppg Vis 90 sec Incl 10.19 deg Log with LWD /MWD from 9,120' to 11,038'. August 11, 2009 11,136' MW 10.3 ppg Vis 105 sec Incl 10.19 deg Finish logging to TD with LWD/MWD, circulate. POOH, L/D drillpipe and BHA. Download data from LWD. RIH with 4" drillpipe. August 12, 2009 11,136' MW 10.3 ppg Vis 110 sec Incl 10.19 deg L/D 4" drillpipe. RIH w/ open hole bridge plug on DP and set at 2,700', POH. RIH w/9 -5/8" cement retainer and set at 2,440'. Perform injectivity test through retainer. August 13, 2009 11,136' MW N/A Vis N/A Incl N/A Wait on AOGCC approval of annular disposal permit. Begin annular disposal of drilling mud. Clean mud storage tanks. August 14, 2009 11,136' MW N/A Vis N/A Incl N/A Prepare drilling fluids for injection. Inject fluids. Follow w/ cement P &A plug: 22 bbls Class G below retainer at 2,440' and 5 bbls above. Witnessed by AOGCC's Low Grimaldi. August 15, 2009 11.136' MW N/A Vis N/A Incl N/A L/D drill pipe. Test casing to 1500 psi for 30 minutes - OK. Test witnessed by AOGCC's Lou Grimaldi. Set bridge plug at 196'with surface cement plug above it to surface. L/D last of drill pipe, N/D BOPE. • • August 16, 2009 11,136' MW N/A Vis N/A Incl N/A Rig down. Load out rig and support equipment. Install well identification plate on cut -off 9- 5/8" casing and 16" conductor. • • Nunivak #1 Survey Report Schlumberger Report Date: August 2, 2009 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: Rampart Energy Company Vertical Section Azimuth: 73.340° Field: Nenana River Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: Nunivak #1 / Nunivak 1 TVD Reference Datum: Rotary Table Well: Nunivak #1 TVD Reference Elevation: 375.9 ft relative to MSL Borehole: Exploration Sea Bed I Ground Level Elevation: 375.930 ft relative to MSL UWIIAPI #: Magnetic Declination: 20.498° Survey Name I Date: Nunivak #1 Field Surveys / July 8, 2009 Total Field Strength: 56808.320 nT Tort I AHD 1 DDI I ERD ratio: 72.059° / 897.84 ft / 4.813 / 0.081 Magnetic Dip: 76.792° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: July 08, 2009 Location Lat!Long: N 64 34 19.280, W 14912 55.208 Magnetic Declination Model: BGGM 2005 Location Grld NIE YIX: N 3864312.995 ftUS, E 623376.408 ftUS North Reference: True North Grid Convergence Angle: +0.70865877° Total Corr Mag North -> True North: +20.498° Grid Scale Factor: 0.99991731 Local Coordinates Referenced To: Well Head Measured Vertical Mag 1 Gray Tray Cyl Dist Tray Cyl Survey Tool Comments Depth Inclination Azimuth TVD Sub -Sea TVD NS EW DLS Section Tool Face Ct -Ct Azim -North Model (ft ) (deg) (deg) (ft) (ft ) (ft) (ft) (ft ) (deg /100ft ) (deg) (ft) (deg) fie -In 0.00 0.00 0.00 0.00 - 375.93 0.00 0.00 0.00 0.00 63.36M N/A N/A SLB_INC -ONLY 269.58 0.21 63.36 269.58 - 106.35 0.49 0.22 0.44 0.08 82.16M 0.49 63.36 SLB_INC -ONLY 393.15 0.33 82.16 393.15 17.22 1.06 0.37 1.00 0.12 46.57M 1.06 69.55 SLB_MWD -STD 506.30 0.29 46.57 506.30 130.37 1.64 0.61 1.53 0.17 55.42M 1.65 68.13 SLB_MWD -STD 631.65 0.13 55.42 631.65 255.72 2.06 0.91 1.87 0.13 69.30M 2.08 64.07 SLB_MWD -STD 756.43 0.10 69.30 756.43 380.50 2.30 1.03 2.09 0.03 194.45M 2.33 63.79 SLB -STD 881.07 0.10 194.45 881.07 505.14 2.35 0.96 2.17 0.14 271.68M 2.37 66.03 SLB_MWD -STD 1005.74 0.11 271.68 1005.74 629.81 2.18 0.86 2.02 0.11 325.39M 2.20 66.91 SLB_MWD -STD 1130.13 0.43 325.39 1130.12 754.19 1.93 1.25 1.64 0.30 290.75M 2.06 52.64 SLB_MWD -STD 1254.49 0.45 290.75 1254.48 878.55 1.39 1.81 0.91 0.21 305.20M 2.02 26.86 SLB_MWD -STD 1379.86 0.72 305.20 1379.84 1003.91 0.52 2.44 -0.19 0.24 321.41M 2.44 355.56 SLB_MWD -STD 1506.06 0.83 321.41 1506.03 1130.10 -0.31 3.61 -1.41 0.19 334.23M 3.87 338.68 SLB_MWD -STD 1628.95 0.90 334.23 1628.91 1252.98 -0.80 5.17 -2.38 0.17 342.36M 5.69 335.27 SLB_MWD -STD 1753.78 1.01 342.36 1753.72 1377.79 -0.97 7.10 -3.14 0.14 350.34M 7.77 336.14 SLB_MWD -STD 1942.32 1.23 350.34 1942.23 1566.30 -0.76 10.68 -3.98 0.14 332.74M 11.40 339.54 SLB_MWD -STD 2065.50 1.30 332.74 2065.38 1689.45 -0.85 13.23 -4.85 0.32 334.92M 14.09 339.88 SLB_MWD -STD 2190.61 1.34 334.92 2190.45 1814.52 -1.33 15.81 -6.12 0.05 330.86M 16.96 338.85 SLB_MWD -STD 2315.01 1.82 330.86 2314.80 1938.87 -1.97 18.86 -7.70 0.40 335.49M 20.37 337.80 SLB -STD 2459.74 2.02 335.49 2459.45 2083.52 -2.81 23.18 -9.87 0.17 341.06M 25.20 336.93 SLB_MWD -STD 3HA4 2657.86 2.58 341.06 2657.41 2281.48 -3.47 30.58 -12.77 0.30 12.01M 33.19 336.60 SLB_MWD +DMAG 2750.41 2.76 12.01 2749.87 2373.94 -2.48 34.73 -12.98 1.55 17.86M 37.39 335.01 SLB +DMAG 2813.04 3.60 17.86 2812.40 2436.47 -0.64 38.08 -12.06 1.44 37.47M 40.47 334.04 SLB_MWD +DMAG 2876.63 5.70 37.47 2875.78 2499.85 3.05 42.48 -9.53 4.10 58.94R 43.98 334.31 SLB_MWD +DMAG 2938.53 7.04 52.54 2937.30 2561.37 9.09 47.23 -4.65 3.44 79.16R 46.94 336.23 SLB_MWD +DMAG 2999.46 7.69 67.72 2997.74 2621.81 16.64 51.05 2.09 3.36 40.98R 48.48 338.48 SLB_MWD +DMAG 3063.59 9.30 75.90 3061.16 2685.23 26.08 53.94 11.09 3.13 76.25L 48.53 341.16 SLB_MWD +DMAG 3126.70 9.39 73.80 3123.43 2747.50 36.33 56.62 20.97 0.56 81.03R 48.22 343.68 SLB_MWD +DMAG 3250.23 9.62 80.26 3245.27 2869.34 56.65 61.17 40.83 0.88 115.99L 46.94 345.85 SLB_MWD +DMAG 3375.08 9.32 76.16 3368.42 2992.49 77.10 65.36 60.92 0.59 172.68R 45.25 347.20 SLB_MWD +DMAG 3499.15 8.83 76.57 3490.94 3115.01 96.65 69.97 79.94 0.40 116.81L 44.23 347.53 SLB_MWD +DMAG 3624.94 8.75 75.51 3615.25 3239.32 115.85 74.61 98.59 0.14 161.22R 43.30 347.04 SLB_MWD +DMAG 3750.11 7.99 77.38 3739.09 3363.16 134.04 78.89 116.30 0.64 5.10L 42.26 345.30 SLB_MWD +DMAG 3874.62 8.95 76.83 3862.24 3486.31 152.34 82.99 134.18 0.77 104.12L 41.03 343.76 SLB_MWD +DMAG 3999.02 8.88 74.90 3985.13 3609.20 171.59 87.69 152.87 0.25 52.01R 40.18 343.55 SLB_MWD +DMAG 4122.83 10.29 84.11 4107.22 3731.29 192.01 91.32 173.10 1.68 131.43L 37.87 345.25 SLB_MWD +DMAG 4245.75 9.96 81.90 4228.23 3852.30 213.31 93.94 194.54 0.41 111.17L 34.39 349.04 SLB_MWD +DMAG 4372.00 9.79 79.15 4352.61 3976.68 234.78 97.50 215.89 0.40 154.59L 31.93 352.75 SLB_MWD +DMAG 4496.60 9.23 77.48 4475.49 4099.56 255.29 101.66 236.05 0.50 106.52L 30.37 355.31 SLB_MWD +DMAG 4622.30 9.15 75.69 4599.58 4223.65 275.33 106.32 255.58 0.24 69.34R 29.35 356.60 SLB_MWD +DMAG 4748.42 9.60 81.96 4724.02 4348.09 295.75 110.27 275.71 0.88 85.01R 27.62 359.06 SLB_MWD +DMAG 4872.71 9.68 85.89 4846.56 4470.63 316.19 112.47 296.39 0.53 142.09L 24.32 3.95 SLB_MWD +DMAG 4997.34 9.46 84.84 4969.45 4593.52 336.46 114.14 317.04 0.23 109.67L 20.70 10.35 SLB_MWD +DMAG 5121.99 9.32 82.26 5092.43 4716.50 356.47 116.42 337.25 0.36 113.10L 17.87 17.26 SLB_MWD +DMAG 5247.42 9.26 81.37 5216.22 4840.29 376.49 119.30 357.29 0.12 165.61R 15.79 24.73 SLB +DMAG 5371.39 8.87 82.02 5338.64 4962.71 395.82 122.12 376.62 0.33 143.99L 13.78 32.51 SLB_MWD +DMAG 5495.94 8.55 80.44 5461.75 5085.82 414.50 125.00 395.26 0.32 164.03L 11.60 39.77 SLB_MWD +DMAG 5619.58 8.24 79.82 5584.07 5208.14 432.42 128.09 413.04 0.26 109.62L 9.33 46.03 SLB_MWD +DMAG 5743.26 8.12 77.28 5706.49 5330.56 449.94 131.58 430.28 0.31 106.87L 7.02 50.92 SLB_MWD +DMAG 5866.98 8.04 75.28 5828.98 5453.05 467.31 135.70 447.18 0.24 37.37L 4.87 51.84 SLB_MWD +DMAG 3HA5 5995.11 8.46 73.13 5955.79 5579.86 485.69 140.71 464.86 0.41 149.57L 3.27 45.75 SLB_MWD +DMAG 6120.60 8.04 71.35 6079.98 5704.05 503.69 146.20 482.01 0.39 51.50R 2.26 18.39 SLB_MWD +DMAG #1 Field Surveys Generated 8/2/2009 2:05 AM Page 1 of 2 DDToolBox Ver SP 2.1 Bld(doc40x_100) \\ \Nunivak # y • • 6244.77 9.64 82.16 6202.68 5826.75 522.64 150.39 500.54 1.85 22.35R 1.04 40.84 SLB_MWD +DMAG 6369.29 10.08 83.19 6325.36 5949.43 543.68 153.11 521.69 0.38 77.13L 3.84 122.48 SLB_MWD +DMAG 6493.42 10.10 82.70 6447.57 6071.64 565.13 155.78 543.27 0.07 74.01R 8.01 128.06 SLB_MWD +DMAG 6618.87 10.19 84.39 6571.06 6195.13 586.87 158.26 565.22 0.25 99.87L 12.49 130.17 SLB_MWD +DMAG 6744.03 10.05 77.25 6694.27 6318.34 608.63 161.75 586.89 1.01 151.76L 16.13 128.99 SLB_MWD +DMAG 6868.52 9.77 76.36 6816.91 6440.98 630.02 166.64 607.75 0.26 162.66L 18.35 126.16 SLB_MWD +DMAG 6992.59 8.65 74.02 6939.37 6563.44 649.86 171.69 626.95 0.95 178.95L 19.17 126.19 SLB_MWD +DMAG 7116.60 7.10 73.79 7062.21 6686.28 666.85 176.40 643.28 1.25 159.86L 18.23 131.31 SLB_MWD +DMAG 7179.80 6.68 72.46 7124.95 6749.02 674.43 178.60 650.53 0.71 72.22L 17.81 133.40 SLB_MWD +DMAG 7242.42 6.76 70.45 7187.14 6811.21 681.75 180.93 657.48 0.40 157.43L 17.63 132.84 SLB_MWD +DMAG 7304.78 5.57 65.25 7249.14 6873.21 688.41 183.42 663.69 2.11 170.99L 17.34 130.55 SLB_MWD +DMAG 7367.03 4.69 63.54 7311.14 6935.21 693.91 185.82 668.71 1.43 172.46R 16.80 128.10 SLB_MWD +DMAG 7429.83 4.13 64.57 7373.76 6997.83 698.68 187.94 673.05 0.90 175.77R 16.50 124.99 SLB_MWD +DMAG 7491.75 3.22 65.77 7435.55 7059.62 702.61 189.61 676.65 1.47 172.63R 16.56 121.67 SLB_MWD +DMAG 7554.31 1.37 75.94 7498.06 7122.13 705.09 190.51 678.98 3.02 79.65M 16.62 120.41 SLB_MWD +DMAG 3HA6 7679.35 1.58 79.65 7623.05 7247.12 708.30 191.18 682.12 0.18 85.69M 18.11 116.68 SLB_MWD -STD 7804.12 1.80 85.69 7747.77 7371.84 711.93 191.64 685.77 0.23 98.48M 21.26 111.16 SLB_MWD -STD 7929.09 1.92 98.48 7872.68 7496.75 715.74 191.48 689.80 0.34 97.33M 25.11 108.18 SLB_MWD -STD 8052.47 2.34 97.33 7995.97 7620.04 719.91 190.85 694.34 0.34 112.61M 29.63 106.59 SLB_MWD -STD 8176.47 1.68 112.61 8119.89 7743.96 723.63 189.83 698.53 0.68 131.91M 33.94 106.23 SLB_MWD -STD 8301.52 2.15 131.91 8244.87 7868.94 726.27 187.56 701.97 0.63 139.16M 37.89 108.07 SLB_MWD -STD 8426.79 2.35 139.16 8370.05 7994.12 728.55 184.05 705.40 0.28 131.56M 42.30 111.16 SLB_MWD -STD 8551.75 2.77 131.56 8494.88 8118.95 731.19 180.11 709.33 0.43 123.47M 47.45 113.88 SLB_MWD -STD 8676.92 1.97 123.47 8619.95 8244.02 734.16 176.91 713.39 0.69 109.44M 52.47 115.28 SLB_MWD -STD 8801.24 2.18 109.44 8744.19 8368.26 737.44 174.95 717.40 0.44 110.85M 56.94 115.34 SLB_MWD -STD 8925.68 2.61 110.85 8868.52 8492.59 741.60 173.15 722.28 0.35 120.96M 62.12 114.91 SLB_MWD -STD 9050.49 2.10 120.96 8993.22 8617.29 745.40 170.96 726.90 0.53 236.33M 67.23 114.94 SLB_MWD -STD 9175.76 0.31 236.33 9118.47 8742.54 746.62 169.59 728.58 1.80 205.17M 69.33 115.38 SLB_MWD -STD 3HA7 9300.16 0.24 205.17 9242.86 8866.93 746.13 169.17 728.19 0.13 159.90M 69.16 115.84 SLB_MWD -STD 9425.02 0.92 159.90 9367.72 8991.79 746.01 167.99 728.43 0.62 132.22M 69.89 116.62 SLB_MWD -STD 9549.84 1.67 132.22 9492.50 9116.57 747.01 165.83 730.12 0.77 104.84M 72.38 117.55 SLB_MWD -STD 9673.28 2.11 104.84 9615.88 9239.95 749.88 164.04 733.65 0.80 99.69M 76.34 117.52 SLB_MWD -STD 9798.12 2.58 99.69 9740.62 9364.69 754.36 162.98 738.64 0.41 100.81M 81.27 116.56 SLB_MWD -STD 9923.70 1.65 100.81 9866.11 9490.18 758.49 162.16 743.20 0.74 21.55M 85.73 115.68 SLB_MWD -STD 10049.02 0.47 21.55 9991.41 9615.48 760.41 162.30 745.16 1.30 7.09M 87.44 115.04 SLB_MWD -STD 10172.82 1.06 7.09 10115.20 9739.27 761.19 163.91 745.49 0.50 21.73M 87.07 113.99 SLB_MWD -STD 10296.26 1.02 21.73 10238.62 9862.69 762.33 166.07 746.04 0.22 20.60M 86.72 112.55 SLB_MWD -STD 10421.62 1.36 20.60 10363.95 9988.02 763.92 168.49 746.97 0.27 82.62M 86.69 110.82 SLB_MWD -STD 10547.72 1.58 82.62 10490.02 10114.09 766.54 170.12 749.22 1.21 109.34M 88.25 109.32 SLB_MWD -STD 10672.60 2.78 109.34 10614.81 10238.88 770.69 169.34 753.79 1.23 115.88M 92.82 108.84 SLB_MWD -STD 10795.93 4.08 115.88 10737.91 10361.98 776.35 166.43 760.56 1.10 115.11M 100.17 109.17 SLB_MWD -STD 10920.25 5.83 115.11 10861.76 10485.83 784.31 161.82 770.25 1.41 53.83R 110.85 109.77 SLB_MWD -STD 11046.97 9.19 138.23 10987.41 10611.48 793.41 151.54 782.83 3.52 55.31R 126.27 112.23 SLB_MWD -STD 11078.76 10.19 145.72 11018.74 10642.81 795.34 147.32 786.10 5.06 - -- 130.93 113.40 SLB_MWD -STD ) rojection to TD 11135.00 10.19 145.72 11074.10 10698.17 798.35 139.10 791.71 0.00 - -- 139.44 115.58 SLB_BLIND Survey Type: Non -Def Survey ANTICOLLISION NOTES: 2nd Traiectorv: Nunivak 1 (P1) - PRIMARY Analysis Well Analysis Method: Normal Plane Confidence: 3 -D 95.00% Confidence 2.7955 sigma Prob = 1 : 25959 Survey Error Model: SLB ISCWSA version 24 * ** 3 -D 95.00% Confidence 2.7955 sigma Surveying Proq: MD From (ft 1 MD To ( ft) EOU Freq Survey Tool Type Borehole -> Survey 0.00 269.58 Act -Stns SLB_INC -ONLY Exploration -> Nunivak #1 Field Surveys 269.58 2459.74 Act -Stns SLB_MW D -STD Exploration -> Nunivak #1 Field Surveys 2459.74 7554.31 Act -Stns SLB_MWD +DMAG Exploration -> Nunivak #1 Field Surveys 7554.31 11078.76 Act -Stns SLB_MWD -STD Exploration -> Nunivak #1 Field Surveys 11078.76 11135.00 Act -Stns SLB_BLIND Exploration -> Nunivak #1 Field Surveys DDToolBox Ver SP 2.1 Bld( doc40x_100) \\ \Nunivak #1 Field Surveys Generated 8/2/2009 2:05 AM Page 2 of 2 • R AMPART -� WELLSITE CLOSE -OUT Rampart Energy Company Nunivak #1 Final plugging and abandonment of the Nunivak #1 was accomplished on August 16, 2009 with cutting off of all casing strings at seven feet below ground level, verification of cement at the surface in the 9 -5/8" x 16" annulus and inside of the 9 -5/8" casing and welding on of an 18" diameter identifying marker plate on top of the casing stubs. The rig was subsequently torn down and moved out, giving access to the well cellar. The cellar was dug out along with the cement slab that had been poured at the bottom during conductor installation. The hole, now containing only the well stub with a welded on base plate, was then filled with material from the pad. A five -foot mound of fill material was left on top to compensate for any future settling. As soon as all equipment and drilling materials were removed from the location, the pad was picked clean of detritus and graded smooth. The slash piles of wood around the edges of the pad were consolidated at one corner of the location. The larger timber was bucked to length and trucked to Nenana for the use of local residents. On August 28, the site was inspected by: Bob Noble AOGCC Ellen Lyons USACOE Jim Durst ADF &G A.J. Wait ADNR Mike Franger ADNR /MHT Jason Mayrand City of Nenana All agency representatives approved the site close -out and final site condition for their respective agencies. The day after the multi - agency inspection the barge and tug used to cross the Nenana River were released. No further Rampart- controlled equipment, materials or personnel remain on the west side of the river. Attached to this report is the following photo documentation: Photo 1 Well identification marker plate Photo 2 Cement at surface in the casing stub Photo 3 Welding on the well identification marker plate Photo 4 Marker plate installed Photo 5 Removing the well cellar Photo 6 Well stub after cellar removal, just prior to burial Photo 7 Building mound over buried cellar hole Photo 8 Cleaned -up site — View #1 Photo 9 Cleaned -up site — View #2 wjp 9/1/09 * ' �` "'t i000.l.IIIIIr, ....,,,, \ \ ,„.„ r ...., . .- .. • c 0. ....-„ kA, It , LL ate-- , .,., i Le, "., f '` i ........ ........, ,.. ., . .,. *, ..._... , _ , . . ,, . „..... y .i t rM ' / . ....,„ 0 .” . .. ter• M .�� ♦ gy p Marker Plate a s , r . �/L ?WW ' ' t 4r, " » x i r * t � . .:,�..� .t / ,..3L,r ,,,,,, e«F ' ��� r '''''',4t ��' �' r *.t f-,\....... vas r w, r <. 9las., 1 'ms a. h 0 4R H '. • 4 a Cement in Casing -‘91441111111 rr at.# • 1�x i Welding Marker Plate 0. 1. . k •Y, • V t * ,� .1 \ , . �.. ' _ .r / V �:p . 14 0 r , "c ***-••••••, i t - . ti Z. I . '.'� .� . ; � _ . e mss ‘,...../ �. :• ,, 0 • 0 M • 4 ' . ' / ` • ■ N. i . 1 Marker Plate Installed A: 4- 19111r1,11111M 6, ,._ - f," i« t : 1 ..«., 1 • .,- i .. ..w.,, -•`r._ --.fir ., 0 `a V 44 4 4 4 'IL', ."""11111b,- yyO J I r � — .� w ...: 3 r .V' s r ... . i G, . • ° tea. i` �+ n J .4 - *0 , �! Removing Cellar I e + c. `. 1 •m '' t " At ' ,7 : * Sa. ' 44 ' ' • eibr ,r ' / 0 :�. .:: f i f: . , r , ''''. - 4111/ ''''.... , ' . , 10 is. 6 . it 441 rf Ar ,i } »� 1 110 l i ..., * giro yy r 33 7 : , . 1 . 0 4 4 . itio. . _ 'a , , , „ 4 .„,..r tfio t dd ,ter . ,_ '` _� ' J .„„. Well Stub Before Burial +Y , ryQ * • 5 Yr 7 , r { 1 .. 1 . r . .fin 9 5 y . f i I ! . , � ..- ,. , 'r iiiw' ♦ " — . k • t ‘1111117 ` � + ,y • i • • t-. J . Burying Well Stub i 4 � � 41 • I • ,, I t ' , j ' i A , _?'' ° , a 7rF - • • c • • • F • I. Final View 1 • • 7. I # 14 `-- r..... .... , ,„ ,. s� z i � • ! Y ■ a i ' ' zC. � o ; I :. r _ `` � t•, i f! k f .. a Ni Y w A l ♦ e W 4 aa , co C MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 6 ,1 ( 07 DATE: August 15, 2009 P.I. Supervisor J l ( � SUBJECT: Plug & Abandonment THRU: Nunivak #1 Rampart Energy Company Exploratory FROM: Lou Grimaldi PTD #209 -054 Petroleum Inspector Sundry #309 -281 Section: 17 Township: 4S Range: 8W Meridian: Fairbanks Drilling Rig: Doyon Akita 2 Rig Elevation: 16.6 feet Total Depth: 11,136 feet Lease No.: MHT9300028 Operator Rep.: Myers /Nicholson Casing/Tubing Data: Casing Removal: Conductor: 16" O.D. Shoe@ 80' Casing Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 2513' 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 Bottom of T.O.C. Mud Weight Pressure (bottom upl Founded on Cement T.O.C. Depth Verified? above plug Test Surface shoe Retainer 2700 RKB 2390 (est.) No 10 ppg yes 1500psi Surface plug Retainer 195.6 RKB surface No N/A No 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 Shoe plug pressure tested after 22 Bbl's 15.9 ppg cement squeezed away, and 5 Bbl's laid on top. Good Plugs witnessed at shoe and surface. Chart recorder stopped turning during test of shoe plug; good thirty minute test observed. -1 Attachments: none Distribution: -Well File (original) -Read File -DNR /DOG Rev.:01/26/09 by L.R.G. Wellbore Plug Nunivak #1 08 -15 -09 LG.xls 8/18/2009 • - criis IVA 1, 1, t 1 fu p SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Ms. Julie L. Weber Vice President Rampart Energy Company 1512 Larimer Street, Bridge Level Denver, CO 80202 Re: Exploratory Field, Nunivak #1 Sundry Number: 309 -280 Dear Ms. Weber: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above - referenced well. Please note that any disposal into the surface /production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cathy . Foerster f Com issioner DATED this / day of August, 2009 Encl. a61--05-1 � C� • STATE OF ALASKA III ,g1 ,,� I `tt7 Vey ALASKA OIL AND GAS CONSERVATION COMMISSION f : r r� aI �� �2O0 ANNULAR DISPOSAL APPLICATION 20 MC 25.080 `;.,.t,., . , 1. Operator Name: 3. Permit to Drill No: 209 -054 Rampart Energy Company 4. API Number: 50- 083 - 20002 -0000 2. Address: 5. Well Name: Nunivak #1 1512 Latimer Street, Bridge Level Denver, CO 80202 6. Field: Exploratory 7. Publicly recorded welts 8. Stratigraphic description: a) Interval exposed to Usibelli Formation a) All wells within one- open annulus: quarter mile: None / b) Waste receiving Usibelli formation zone: b) water wells within one mile: 0 c) Confinement: Top: Usibelli Coals Base: Usibelli Coals 9. Depth to base of 10. Hydrocarbon zones permafrost above waste receiving 1,700' / zone: None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: No Previous Disposal in well 9.1 ppg 883 psi 14. Estimated volume to be disposed with thls request: 15. Fluids to be disposed: Drilling mud 2,000 bbls / 16. Estimated start date: Beginning of August 2009 17. Attachments: Well Schematic (Include MO and ND) II Cement Bond Log (if required) ❑ FIT Records w! LOT Graph IN Information req'd in 20 AAC 25.080(b) Surf. Casing Cementing Data ID Other lei (FIT /LOT and casing cementing data to be submitted when available.) 18. I hereby certify that the fore - ng is t and correct to the best of knowledge. r Signature: k 4.4.4........-- Title: Vice President Printed Phone Name: J e L. Weber Number. 303 -460 -1132 Date: S • //' o Commission Use Only Conditions of approval: $ a.b N t i N.' 44, f y i h1 j-e$ t LOT review and 4 +o /'{ tlt� C c- l approval: t!T , Subsequent form Approval ,��1/ _ /� 4 required: I D — 4 2 3. number: (' �UQ D Approved / APPROVED BY r • by: 4. /1 /, / 4 0" 4 ,. / 4,,,a n iy COMMISSIONER THE COMMISSION Date: • ' Tr a . _ .J l t ,, Form 10 -403AD Rev.6/2004 INSTRUCTIONS ON REVERSE Submit in Duplicate R . ! $ BBL AUG 14 2009 ! 0 RAMPART - - Annular Disposal Procedure Nunivak #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 9 -5/8" surface casing set at 2,513' and cemented to the surface and an open -hole packer set at 2,700', rig up the mud pumps to pump down the 9 -5/8" casing. 2. Close the casing valve and pressure test lines and connections with water to 3,000 psi. 3. Bleed off lines, open the annulus valve and slowly pressure up on the casing using drilling mud until the formation b w the shoe begins to take fluid. Do not allow the casing pressure to exceed 4 02 psi (70% of the burst rating of the 9 -5/8" 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 bbl /min and record the stabilized injection " pressure at that rate. 7. Slowly increase the injection rate to 1.5 bbl /min 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 pumps and record pressure fall -off on chart. 10. Bleed off casing 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 waste drilling mud on location down the casing at or below the allowable injection rate while continuously monitoring the injection pressure and keeping it below 4,025 psi. • • 12. Periodically dispose of excess mud down the casing at convenient times during the remainder of drilling and completion operations on this well. 13. At the completion of the well and just before releasing the rig, dispose of all excess mud on location (including in the rig's mud pits) down the well, again observing injection rate and pressure limitations. 14. As pits and tanks are emptied, wash them out with water and send the rinse water down the well. 15. 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. • Nunivak #1 Step -Rate Test for Annular Injection Discussion Prior to commencing large -scale injection of mud, a step -rate test must be performed so that the Sate or Federal agency representative on site can determine the maximum injection rate allowable. The following is the procedure for the step -rate test. Considerations A minimum of three, and ordinarily a maximum of five, rate -and- pressure -pair points are required. The stabilized rate and pressure are always included as the first point. At least three points are needed to reveal the character of a curve. Five points are usually enough to ensure that a large enough rate change exists between points to emphasize any water hammer effects that might be present. Job Procedure 1) Pressure test surface lines. 2) Establish minimum pump rate and gradually increase it to 0.5 bpm and hold until pressure stabilizes. 3) Record first rate and pressure pair. 4) Increase the pump rate in 0.5 bpm increments (check for changes in the slope of the pressure curve at stable rates). 5) Plot pair points on a pressure- versus -rate graph and determine fracture extension pressure. • 0 R AMPART Nunivak #1 W el or Schematic rAnnularDispo a 2 � : \ % \ a 16 conductor k 8& ,o � : r : :‘'. . 12-1/4" hole s . o k (\ / k 9-5/8", 40, b8,BTC \ $ casing k 2,513'MD OH Packer k %7 & MD \�i Cemented to surface $ $ $ \ 5 4 [ 812 "o e hole { 10.0 pp $ k mud \ 5 4 $ } ( { $ \ § . . TD m]f]3`MD/TVD !► R AM PART NUNIVAK #1 DISPOSAL OF DRILLING WASTE The following information is provided in support of Rampart's request for authorization for disposal of waste drilling mud through injection down the 9 -5/8" casing in the Nunivak #1 well in accordance with AOGCC Regulations in Title 20, Chapter 25, 20 AAC 25.080. 1) Well to receive drilling waste: Nunivak #1 (at the 9 -5/8" casing shoe). The 9 -5/8" casing is set at a depth of 2,513'RT. i 2) Depth to base of potable freshwater aquifers: 380 feet. The closest water wells to the Nunivak #1 are in the town of Nenana, more than three miles to the east. The deepest well there is 380'. All of the rest vary in depth from 35' to 160'. 3) The interval exposed below the shoe of the 9 -5/8" casing is the Usibelli Formation. The receiving zone will be Usibelli sandstone. 4) The waste to be injected will be used drilling fluid. While the injected drilling fluid will contain formation fines resulting from normal drilling operations, the injectant will not contain cuttings intentionally ground at the surface for disposal. All such rock cuttings have been hauled for disposal at a local landfill. The estimated volume and maximum density of injectant are 1,000 barrels and 9.1 ppg, respectively. The average slurry density is anticipated to be approximately 9.1 ppg. 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 Nunivak #1 including associated rheologic modifiers, minor amounts of excess cementing materials, wash water and other fluids as allowed under 20 AAC 25.080(h)(3). 7) The maximum anticipated pressure at the 9 -5/8" casing shoe during disposal operations will be at or near the formation fracture pressure of 1,325 psi (12.4 ppg EMW at the casing setting depth of 2,500'). 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 II ill = (2,500') (12.4 ppg) (.052 psi /ft -ppg) + 100 psi - (2,500') (9.1 ppg x 0.052) = 529 psi This calculation is for the worst case (highest pressure): the average 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. I 8) The 9 -5/8" casing is set at 2,513' TVD /MD. It has been cemented to the surface. Cementing records for this casing string are submitted with this application. 9) Casing Safety Factors during Injection below 9 -5/8" casing. Injection of fluids will be down the 9 -5/8" casing. 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 9 -5/8" bursting stress and burst safety factor are calculated as follow: 1 Bursting Stress = Surf. Injection pressure — friction pressure losses + (hydrostatic pressure of injectant at shoe — formation pore pressure at shoe) = 529 —100 psi + (2,500' x .052 x (12.4 -8.9) = 555 - 100 + 455 = 884 psi Safety Factor = Burst rating of 9 -5/8" casing / bursting stress = 5,750 psi / 884 psi =6.5 0 10) The downhole pressure obtained during the LOT at the 9 -5/8" casing shoe is 1,325 psi. — 11) No hydrocarbon- bearing zones exist anywhere in this well. This has been confirmed by the AOGCC upon examination of available well logs.. 12) The duration of disposal in this well is not anticipated to excee 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 of this well. 15) Rampart intends to comply with all limitations set out in 10 AAC 25.080(d). 1 16) Rampart will, to the best of its abilities, provide any additional data required by the Commission to confirm containment of the drilling waste. Run 1 Run 2 Run Schlumberger Company: Rampart Energy Co. Well: Nunivak #1 Field: Wildcat Borough: Denali State: Alaska Power Position Caliper - Measured Depth 4 Arm Caliper / Cement Volumes / GR Z o ** *FIELD PRINT * ** u- 0 in r:23 91' FWL & 1175' FNL Elev.: K.B. 375.93 ft N. 05 w Z At Surface G.L. 357.80 ft T (a - D.F. 375.93 ft c - U 'E E 0 Permanent Datum: Ground Level Elev.: 357.80 ft O 0 , Z LY _1 Log Measured From: Drill Floor 18.13 ft above Perm. Datum t c Drilling Measured From: Drill Floor rn o m o o o A Serial No. Section Township Range m it _i 0 085200020000 17 4S 8W Logging Date 4- Aug -2009 Logging Date Run Number 1 Run Number Depth Driller 11186 ft Depth Driller Schlumberger Depth 7622 ft Schlumberger Depth Bottom Log Interval 7613 ft Bottom Log Interval Top Log Interval 200 ft Top Log Interval Casing Driller Size @ Depth 9.625 in @ 2515 ft @ Casing Driller Size @ Depth @ Casing Schlumberger 2513 ft Casing Schlumberger Bit Size 8.500 in Bit Size Type Fluid In Hole Water Based Mud Type Fluid In Hole o Density Viscosity 9.9 Ibm /gal 65 s o Density Viscosity Fluid Loss PH 4.2 cm3 9.2 Fluid Loss PH Source Of Sample Circulation Tank Source Of Sample RM @ Measured Temperature 1.567 ohm.m @ 87 degF @ RM © Measured Temperature @ RMF @ Measured Temperature 1.249 ohm.m @ 87 degF @ RMF @ Measured Temperature @ RMC @ Measured Temperature 2.351 ohm.m @ 87 degF _ @ RMC @ Measured Temperature @ Source RMF RMC Measured Calculated Source RMF RMC RM @ MRT RMF @ MRT 0.872 @ 162 0.697 @ 162 @ @ RM @ MRT RMF @ MRT @ @ Maximum Recorded Temperatures 162 degF Maximum Recorded Temperatures Circulation Stopped Time 4- Aug -2009 2:30 Circulation Stopped Time Logger On Bottom Time 4- Aug -2009 17:07 Logger On Bottom Time Unit Number Location 2145 Prudhoe Bay 1 Unit Number I Location Recorded By Ben Belknap Recorded By Witnessed By Donna Messer I Witnessed By • @@Cep l� DEPTH SUMMARY LISTING Date Created: 4 -AUG -2009 23:21:33 Depth System Equipment Depth Measuring Device Tension Device Logging Cable Type: IDW -B Type: CMTD -B /A Type: 7 -46P XS Serial Number: 777 Serial Number: 2320 Serial Number: -999 Calibration Date: 5 -Jul -2009 Calibration Date: 23 -Jul -2009 Length: 24000 FT Calibrator Serial Number: 6720 Calibrator Serial Number: 265 Calibration Cable Type: 7 -46P XS Calibration Gain: - 50000.00 Conveyance Method: Wireline Wheel Correction 1: -6 Calibration Offset: - 50000.00 Rig Type: LAND Wheel Correction 2: -5 Depth Control Parameters Log Sequence: First Log In the Well Rig Up Length At Surface: 0.00 FT Rig Up Length At Bottom: 0.00 FT Rig Up Length Correction: 0.00 FT Stretch Correction: 9.50 FT Tool Zero Check At Surface: 0.50 FT Depth Control Remarks 1. Schlumberger Depth Control Policy Followed 2. 3. 4. 5. 6. DISCLAIMER THE USE OF AND RELIANCE UPON THIS RECORDED -DATA BY THE HEREIN NAMED COMPANY (AND ANY OF ITS AFFILIATES, PARTNERS, REPRESENTATIVES, AGENTS, CONSULTANTS AND EMPLOYEES) IS SUBJECT TO THE TERMS AND CONDITIONS AGREED UPON BETWEEN SCHLUMBERGER AND THE COMPANY, INCLUDING: (a) RESTRICTIONS ON USE OF THE RECORDED -DATA; (b) DISCLAIMERS AND WAIVERS OF WARRANTIES AND REPRESENTATIONS REGARDING COMPANY'S USE OF AND RELIANCE UPON THE RECORDED -DATA; AND (c) CUSTOMER'S FULL AND SOLE RESPONSIBILITY FOR ANY INFERENCE DRAWN OR DECISION MADE IN CONNECTION WITH THE USE OF THIS RECORDED -DATA. OTHER SERVICES1 OTHER SERVICES2 OS1: PPC OS1: 0S2: DSI 0S2: 0S3: 0S3: 0S4: 0S4: 0S5: 0S5: REMARKS: RUN NUMBER 1 REMARKS: RUN NUMBER 2 Tool ran as per tool sketch, 3 centralizers on DSI, 1.5" standoffs on AIT Log run on a Sandstone Matrix: 2.65 g /cc, DT matrix = 56 us /ft Mud cake resisitivity calculated due to lack of quality sample ICV and IHV caculated using PPC four arm calipers, PPC not powered Log run with Monopole (Even), Upper Dipole (Odd), Lower Dipole (Even) All intervals logged as per client request TD not taaaed due to Door borehole conditions. Loaaina tools bridaed out at 7622', same as the two attempts made before per trip. lil Chlorides: 550 ppm Porosity repeatability below 7500' affected due to delayed opening of calipE r after logging up from bridge out depth Resistivity repeatability affected above 7374' due to delayed AIT data computing Crew: Capen, Drover, Simones RUN 1 RUN 2 SERVICE ORDER #: AV1 H -00022 SERVICE ORDER #: PROGRAM VERSION: 16C0 -147 PROGRAM VERSION: FLUID LEVEL: FLUID LEVEL: LOGGED INTERVAL START STOP LOGGED INTERVAL START STOP EQUIPMENT DESCRIPTION RUN 1 RUN 2 SURFACE EQUIPMENT GSR -U/Y WITM (EDTS) -A NCT -B CNB -AB NCS -VB DOWNHOLE EQUIPMENT LEH -QT Ai 115.1 LEH -QT Mud Tempe _ 112.2 EDTC -B CTEM 108.7 112.2 EDTH -B Gamma Ray r 7 106.8 EDTC -B 8273 TelStatus EDTG -A/B EDTCB Ele 105.7 SAH -F 105.7 SAH -F 832 HGNS HMCA x 100.8 HILTB -FTB HGNS Gamm 100.0 100.8 HGNSD -B 850 HMCA HGNS Neut 94.2 HGNH HGNS Neut I E ! 93.7 NLS -KL HGNS sens s r , — 91.4 HACC 340 HRCC cart 87.4 HCNT 340 MCFL II 7 HGR HILT - 81.5 / HRCC -B 1741 HRDD-LS S HRMS-B HRDD -SS HRGD -B 8424 HRDD -BS r — 81.1 GLS -VJ 5449 "" MCFL Device ■ HILT Nucl. LS 42767 all DSST -B 75.1 SPAC -B 8111 ECH -SD SMDR -BD 8114 SSIJ -BA 8117 SMDX -AA 8113 is ®m " s= 4,„F PWF — 24.1 PPC1 - Calipers 23.0 24.1 PPC1 -B 8359 PPC_CAL_STD PPC Cartr 17.6 HAIT - H N AHHF A 122 Induction g Temperate Power Sup Ism 9.5 SP SENSOR 0.1 DF ACCZ HTEN HMAS HV Accelerom Mud Resis Tension 0.0 1.5 1N TOOL ZERO Standoff MAXIMUM STRING DIAMETER 6.88 IN MEASUREMENTS RELATIVE TO TOOL ZERO ALL LENGTHS IN FEET Schlumberger Main Pass 2" / 100' MAXIS Field Log Input DLIS Files DEFAULT AIT_CAL_DSI_TLD_CNL_024LUP FN:47 PRODUCER 04- Aug -2009 17:04 7626.0 FT 150.0 FT Output DLIS Files DEFAULT AIT_CAL_DSI_TLD_CNL_031PUP FN:68 PRODUCER 04- Aug -2009 20:23 CUSTOMER AIT_CAL_DSI_TLD_CNL_031PUC FN:69 CUSTOMER 04- Aug -2009 20:23 BACKUP AIT_CAL_DSI_TLD_CNL_031PUP FN:70 PRODUCER 04- Aug -2009 20:23 OP System Version: 17C0 -154 HAIT -H 17C0 -154 PPC1 -B 17C0 -154 DSST -B 17C0 -154 HILTB -FTB 17C0 -154 EDTC -B 17C0 -154 PIP SUMMARY I- Integrated Hole Volume Minor Pip Every 10 F3 1— Integrated Hole Volume Major Pip Every 100 F3 Integrated Cement Volume Minor Pip Every 10 F3 -I Integrated Cement Volume Major Pip Every 100 F3 —1 Integrated Hole Integrated Cement Volume (IHV) Volume (ICV) ii Vi / / iiii iii i iii :iii 7'5/ / / /iii i i / ii i i iii 1 // Ceme %�77 7" % /,. Cement 9%���� Washout Cement Washout Cement Future Casing Diameter Tool Temp. (HTEM) (DEGF) %/////////////// Tool/Tot. Drag _ HILT Caliper (HCAL) HILT Caliper (HCAL) _ From D3T 23 (IN) 3 3 (IN) 23 .ii .i�i Cable Tension (TENS) Drag FCD2 (FCD) FCD3 (FCD1 21000 (LBF) 1000 From STIA 23 (IN) 3 3 (IN) 23 to STIT !' Stuck Gamma Ray (GR EDTC) Stretch Bit Size (BS) Bit Size (BS) 0 (GAPI) 150 (STIT) 23 (IN) 3 3 (IN) 23 0 (F) 50 iimillion 104.41 /I ■s STIR ■■M 2513.0 FT ` IIMUMIMMIlill MI�MINNI�IN�� Casing 2200.00 _ r . .. - CAL �MM1EINIIMIII�N HCA!_ c`` 106.57 / IIIIIMIMMMMIIIMIIIIIMIN / , - ■�F�MMIN�M� � FCD MINES�11.� .1� FCD v MERI011.1.11.1. 2600 1.1.■0i ■111■ ■® % .— I■��■11.1■1� /..: BS IMMIEVIMIIIMIE�E BS ' 108.36 111.1101.1.11111.111. 2150.00 II 1 .1.M .111111.1. I: ■meammE■N. MMIIIMIESMINNIE 2700 IIIIIM , ������� 1 10.16 � .11.� / 800.00 „1.11,,,,I 2100.00 I S p. , LA CEMENT JOB REPORT CUST° Fa Waage:at Expl & Prod lac IDATE 13-JUL-09 frit- 4 1001467510 SSW SUPV. David Wsuinfdatd -.1' ..... -----'"------- ---• • ' - ' LEASE # WELLMNIE ir Fakitk _ CATION COONTY4 ara Imams - Oisneicr MULLIN 43 CONTRACT OR RIG N TYPE OF .101 r. : -.• 15 - 1:: rrre' 111.1111111 711111111011111111111=11111111111111111111MINC:'.7 , '"? - 7i" - 4 1 7 - 71.7•77 • . •• • , • . • . • BM Obi Conant Mk Robbat, Bottom 9 Float Shoe11 " 1 8 81 l w Puk ....... TOW SWRRY MIX Catnent Pug. Rubber. Top 9-5414 =SENT PPG Fro MUM WAWA • ...... ....,.._... ....__ ......._. MATERIALS FURNISHED EY EJ r 1 Mud an 11 I 1 20 TypTiU __ 12 2.50 10.42 61.98 34.45 Oleptecumont Flu i . -4-- Cold Eot Load 6221 11.9 2.031 10.95 ! 224.$2 152.23 ---- • - - -- M ud Clean 11 ;_ 20 Cold Set Ill 157 11. .0'3 10.95 55.671 40.91 _...... ......._ :121 Fluid -I- 2 i -. i - - Available Mix WaNw $ bl. Avails NIA Pluld TOTAL I 004.5E1 247.63 1: ..•'....',"'. ' ''" ...M , i. ' '• ' ... ,,..••:y.'... ••.:4 ''":7;%:":',.;z11.'.7.71' ^ ' , Agiiiagif..., '• ■ ' . : •••" 7 7 • 7 1111111ii*: -7 11Wia: .... ,nliiiingliiiii ' • . . ) • • • lialii.' • - '.- . ■ ..; ": ; 'It 12.25 2500 9.52$ 40 C$G 2500 500 . . _ .. .. ... . . - 1111 1 rf,7 -,. 1 ,.. •• • 11; f.i 1! IMAM ' Tr"-s.v."Vi . . 4101111.1117': , . . '; _Mr -3 iftir " -4 ' V r•'?_,M 7 - , , , :, .,, '." 7t, fer" - 7 ._.. 15 . 109 I 100 WATER eA$E0 9 •-• •' " .' ' ": ' - : ' -• " :- ••--- ' :. :_.' '..• :410...!. • . : • , -I.,_,C r .....-.1 -7 '' 017.73. ---'-- - ,...-...... .. 7 , . . , , .., - .• •o .,. ..;,,-,,-',....,..::,,, ' x...aligii= •:• ' - , EiN - • ' ---- , '....•:, ' .', ' k• A. ! 1 65 664...5 DiselOCdrOont Mid 400 • Fresh . i Displacement Fluid 1 1 I 1 1 ---......, EXPLANATION: TROU111.4 sirrnme TOOL. RUNNING OM ETC. TO MEMENTING: , , -• .-. ...r. . L.• "., -: • .. .......,' •••• • ,..:: ...:••• • ..•;:q-it" ..,...-.., . I ,.- • • - • - • •,•••• •, 1 l' . ? b " , ' . • irtigia))If - PIN IN171 I Ilbl. FLUID FLUID saiirii 11.) 'memo - (xl . oaRtio. HM Os. W • N 1 . ....... TEST ......._ . .. . ATM , ... 1 .04444 ..... t PUMP Ells ,i . Mig , { t.04211 1 cmtouuLTINO WELL ! 11 m, .... R.)._.i_L___:.:.:....... ...: 2. .1. i 1 1 1 1 I i Tostod Van 1 to 3000pel .... . ‘. .. ...... .. . „ . . ..... . --.1 1 I Jimmy and Joreroy arrived 7-10 at 1830 11 . 1 . • „ :20 i I -1 ..1. Safety meetino 1-11-09 --. - - . ....„ ... 1210 • - • . 12 A l ' i 20 SKOP i Aid iiiti ------------ - ---- --, - ,12:30 . ____: ._ L . ... .. 2 WATER 1 MU ithos -"" 12.33 I 3006 - - - ---- .-- j Te 12 st fine* • ...____+ St J SLURRY t C __. _. . - -.. ____ __________ • „ . . :35 1 !arOI 12:56 I. . - 1-----1. ----- " ..----"------ -------------- ---- --- -- ----''.-- 400 I 5 771 SLURRY 1 13•35 1 -1-...-- -235 ........_-_______ .. .. -- 1„End of Lug. - 1 - 3:31 4 TAIL 1 Switt! to tail lEnd of Tell --- ----- PT-t - - i " - - - - - - - - - - -- - -- D r o p 1351 I - 1 - • 1 j_ 6TWATER Kidc out lug . - ... ...r.--- Turn oer I .. ----- .1 ..----- - i . - I 1 vV + bido rpd Prouc rstu dt iretd to oder • , . . 1 , 1 ' 1 ' ..... 8 ..1. 1tf t - , . . .. = PO: Ph I I TOP JOB 7-12.09 1 : 'Tested Vtio to 4000 poi . , ' 10:30 j . „ . . _.4.....„___....., I 1 j ._,....._.___ . ,..._ .. .. . - Ronan IMMO on: .N.11,124Rgtwin Page i 4%004 4101. /3 t 39Vci 0>itiVaVNV SSAT.ILL /. T. :F.! SGIFIT./R7./iO • 0 Li P CEMENT JOB REPORT :. 'i - : . : ; 4 •: ! , . t. �' _ •. .. gi6G1. }5'Y1`# a i ^ 37Y �, L ilia- i ; $ . ra+ } A y �` o...4 S ri {�,�{��'� y : .1 " ' I :. t r s;� i .. ' ':Yt. X .iR i��� � � M1wFE�v�+l; '»H l'.t�' :f. IIY ��5f .. TAW PREUWR -PS1 RATE 15b1 FLUID FLUID SAFETY MEETING: NJ CREW X CO. REP. ci H:: y PIPE , ANNULUS ,,. ,- I PUMPED TYPE - TEST um* 4000 PS1 .. _..__.-�...r .=...�:. . ' . __� .._ _ 1 __. , II 9IR�CULAIUr6 VELL _- RIG ,�„X,�,,. BJ TIT ,.. -_ _, r.. t 0:5o • • .... - - -. 2 WATER FI Lines 10 :54 4 -- 0601__ � _ �! Tasted Lines - ._....._._ 10:66 0 Bleed off' 1059 _ I T _ . '_, _ . 3 . _WATER Start water t rough MIA ___� ....... 11= L ..._ _ { _. _. _.. { ..__ t • Slurry _.,..._ _.�.... .. _. �.....- .�.___..� .. i..__...__._ . -- ..._.,_ .�_.. 4. _. —,,,. Couldn't get w.ight orgropercirculation r_....., __. I - '... - ..... ._ ._.... Shut down and dean tub tcroen __ . ■ Cleaned kni#. Qate and d piping to Wb .. _ ._ . ..� . Cleaned bulk truck vavla or paper and rock _. - .. 13:08 . ... �- ....� ._.. _ .. ..1, . _r I.I, AQ { Pumpint lead Tie 1 19'14 .. I ._. . .. __... i LW ... � f_End of bad switching to tall V r _ ._. 13:15 ( f _� _ 1 {TAIL 'x and pump tail _ _ _ —_. _ _ ... , .. ti i t Getting good returns __. _ -. I_ _J._.. 36 1325 1 _.. 1 _ ShutdGNY�tanent 13:26 _ ( ; .._... I 4 . 5 TAtL WATER 1 Map cement totool _ t __f xsa i _ .._.....� . �_. _ 1 Close tool _.�,_ 13:35 7000 ' Y WATERst CasUtO make sure tool was doted 1 13:97 _ .__ ......- __ . I _._ ._;... __..._.. _._. o and pull '.1' - - -� ....... ..._.. �- ----__ 13+10 3200 { I WA'r ti R { Shear hall seat ___ 13:41 4 . i _ _ _ , _ f Ciro up caeing to clean caging _ _ -. -_ .. . _ _ . __. �. -- _ �. -- -« t -- — .. .. { .— ..._ .� Eiig down and clean up. „ .....�- _...... __. -. - ........ . - P911 TEST r -- CAtTT TOTAL i PSI 1 8POT BUMPED RUMP FLOAT + RETURNS! MN- ■ LEFT ON ■ Toe OuT I SERVICE 1P B R1 ..... S I . '. PLUG { PLUG i ECUs. REVER8EDi PUMPED I CSG I N CEMENT 1 �e J .11 .1 . N. _ I ....... _ ...I.. CY7 N _ 74 , 436 I a - !!3 Awe: P.MR4 on: JUL.12.02 41,4114 PSge 2 Jr4101 r it 39t1d 0>lerOCIAMV FRtaTT // /T:PT FR13- 7. /117 /tA • 7 13.1 Services JobMaster Program Version 3.20 • Job Number: 1001467510 Customer: Rampart Energy v 1 Wolf Name: Nunlvak 1 P C e u Rampart Surface 741 -09 5000 20 t- - r Fill Lines Mix and pump Lead - i i Test i r Mix and pump Tail - t End of Lead --1 u l 4Q00 - ; 1 T over to Rig to Disp -1 15 _ ! . j i ' 1 * i is 30 00 — ! - rretwvAl a _ a t CI, ' a ' .. 10 " E F . + to t a i i 30 i 2 1 2000—i \ N I ! 1 0 x _ E txf of Tall r tf k out plug 4- X Eli O - • ' - Ti `..-/ i i __1 0 , N._,....-- = • ..........._ft,, . t 90 , 400F4 0 I w :: 0 ". ---- 0 0 50 100 p Elapsed Time (min) :A N Si Services Job Start Saturday, July 11, 2009 i Q ? n , a u s . 41 � 80��8$��808$$9�+' � S$$ w gge8'��321 SS��R2888.2egf $ r+ deiriria�iein M ca M f 1 :h rrr'ti4figOi� M.- ` tt . w c1M rlqq O lhAotrl flActggq P. r1 gRgrY �y .a k woia�irmft s�iwiee m0000aooen4 **- d��' ermmes(�e�yirmrw m4'� m ' i s�'� iQ t 4 I 0 el 2 0 '1 [ 7 t i7 r. -P.-Cl q ".,, +V. 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L= 1 _ „,„. ,....„,--- ,,..„. _.<.,,, 44.444r,, - -. 113N1 H/ • • CASING AND LEAK -OFF FRACTURE TESTS Well Name: Nunivak #1 Date: 7/18/2009 Csg Size/Wt/Grade: 9 -5/8" L -80, 40# BTC -M Supervisor: Larry Meyers Csg Setting Depth: 2515 TMD 2515 TVD Mud Weight: 9.1 ppg Leakoff pressure = 435 psi LOT= 12.43 ppg r Hole Depth = 2515 and Fluid Pumped= 1.8 Bbls Volume Back = bbls Estimated Pump Output: 0.003 Barrels /Stroke LEAK - OFF DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here Here Here Here a 0 0 a 200 7 a 100 46 -> 400 153 a 200 170 -> 600 542 -> 300 274 a 800 1133 a 400 358 a 1000 1786 .> 500 423 a 1200 2440 a 600 444 a 1400 3107 ..> 700 435 ✓ a 1600 3745 .> 9 a a 10 > a a a a Enter Holding Enter Holding Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here a 0 435 a 0 a 1 300 -> -> 2 227 a a 3 187 .> - 4 156 -? a 5 139 ->. 5 .> 6 117 a 10 a 7 104 a 15 „> 8 96 -> 20 -> 9 89 a 25 -> 10 82 -> 30 a a a • • -a- LEAK-OFF DATA --II-- CASING TEST DATA 4000 3900 3800 3700 3600 3500 3400 3300 3200 3100 3000 2900 2800 2700 2600 2500 2400 2300 2200 O 2100 E 2000 co w • 1900 • 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 .1111111101 400 ;,:mmaI 300 ( h1II1 200 III I 100 �l10 III II I�Q��� Strokes (# of) • • f- LEAK -OFF DATA t CASING TEST DATA 4000 3900 3800 3700 3600 3500 3400 3300 3200 3100 3000 2900 2800 2700 2600 2500 2400 2300 2200 a 2100 e 2000 m 1900 Q. 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) • • CASING AND LEAK -OFF FRACTURE TESTS Well Name: Nunivak #1 Date: 7/18/2009 Csg Size/Wt/Grade: 9 -5/8" L -80, 40# BTC -M Supervisor: Larry Meyers Csg Setting Depth: 2515 TMD ..254'5" TVD Mud Weight: PP9 Leakoff pressure = 628 psi LOT= 13.80 ppg Hole Depth = 3056 and i I.1 V ►tC rr Fluid Pumped= 1.8 Bbls Volume Back = bbls Estimated Pump Output: 0.003 Barrels /Stroke LEAK - OFF DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here Here Here Here -> 100 15 a 200 7 ,> 300 40 a 400 153 500 102 a 600 542 .>. 700 217 a 800 1133 a 900 364 a 1000 1786 a 1100 473 a 1200 2440 oI 1300 563 a 1400 3107 a 1500 628 / a 1600 3745 a 1700 599 -> 4 10 ->. ..> 4 a a a -> a -> Enter Holding Enter Holding Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here -> 0 630 -> • 0 a 1 546 -> 1 -> ' 2 476 a 2 a 3 431 3 4 402 .? . 4 5 380 a . 5 a 6 380 .? 10 -> 7 380 .> 15 a 8 380 4 20 t>: 9 380 a 25 10 380 -m 30 4 • • t LEAK -OFF DATA t CASING TEST DATA 4000 3900 3800 3700 3600 3500 3400 3300 3200 3100 3000 2900 2800 2700 2600 2500 2400 2300 2200 . 2100 E 2000 3 d 1900 a 1800 1700 1600 1500 1400 1300 1200 1100 1000 I ,- 900 I 800 700 Igdlll I I .. �..._ I -.... !. i 60o IIIIIIIrr' 1 IIIIIIIIIII�IIIIII��I ..• VI I I " I ( 500 II...n 400 IIIo�0IH I, lull�IIII�I���lo���������I�I�I�III I 0 1111111 1111 I I 1111111 11 I II IDr " " 20 0 Illlllllllllllllllllllllllllllllllllll1111 1illlllllllllllllllllllll II !, 2 111llllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllll11111l 100 IIIIIIIII .1 1 1111111 IliiiIIII�IIIIIIIIIIIIIIIIIIII11IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII 0 Strokes (# of) • • —f— 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 fl, 2100 92 2000 N m 1900 a 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 0 0 5 1 0 15 20 25 30 Time (Minutes) R'''' AM PAR Nunivak #1 Annular Disposal of Drilling waste Casing Properties Internal Collapse Tensile Strength Setting Size Weight Grade Cnxn Yield Ressistance Joint Body Depth (in) (1b /ft) (psi) (psi) (10001bs) (10001bs) 0 9 -5/8" 40# L -80 BTC 5750 3090 979 916 2,513' • • R nEiVED RAMPAR'T' Aisska August 11 2009 Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Annular Disposal Permit: Rampart Energy Company, Nunivak #1 Dear Mr. Seamount, Rampart Energy Company hereby applies for an Annular Disposal Permit to inject used drilling mud into the formation at the shoe of the surface casing in the Nunivak #1 exploratory well during P &A operations. Injection is expected to commence in the i beginning of August 2009 and last less than 30 days. Nunivak #1 was drilled as a gas exploration well to test the production potential of the Cantwell Formation near the city of Nenana Rampart proposes to dispose of used drilling fluid down the 9 -518" casing and out the shoe. The injection interval will be constrained at the top by the cemented casing shoe at 2,513' and at the bottom by a packer in the open hole at 2,700' . Attached find a Form 10 -403AD Annular Disposal Application, supporting documentation required in 20 AAC 25.080(b) and a proposed wellbore schematic. A formation injectivity test in the receiving zone will be performed and the results transmitted to the Commission as soon as it becomes available. If you have any questions or require additional information, please contact me at (303) 460 -1132 or Bill Penrose at 258 -3446. Sincerely, RA " • RT RGY COMPANY 1 J e L. Weber Vib e President enclosures 1512 Larimer Street, Bridge Level, Denver, CO, 80202, t: 303 -460 -1132, far: 303 - 460 -1205 • • R AMPART August 17, 2009 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Rampart Energy Company: Nunivak #1 (PTD # 209 -054) Dear Mr. Seamount, This is a report of Rampart's well operations on the Nunivak #1 for the period August 7 through August 16, 2009, inclusive. August 7, 2009 11,136' MW 10.3 ppg Vis 74 sec Incl 10.19 deg Test BOPE, P/U HWDP. Wait on MWD/LWD tools from Deadhorse. August 8, 2009 11,136' MW 10.2 ppg Vis 64 sec Intl 10.19 deg LWD tools arrived at 13:30. Test tools. M/U BHA, RIFL Pulse test MWD. Till. Circulate. August 9, 2009 11,136' MW 10.3 ppg Vis 78 sec Ind 10.19 deg TM with LWD/MWD and log hole from 7,400' to 9,120'. August 10, 2009 11,136' MW 10.2 ppg Vis 90 sec Ind 10.19 deg Log with LWD/MWD from 9,120' to 11,038'. August 11, 2009 11,136' MW 10.3 ppg Vis 105 sec Intl 10.19 deg Finish logging to TD with LWD/MWD, circulate. POOH, L/D drillpipe and BHA. Download data from LWD. RIH with 4" drillpipe. • • August 12, 2009 11,136' MW 10.3 ppg Vis 110 sec Ind 10.19 deg L/D 4" drillpipe. RIH w/ open hole bridge plug on DP and set at 2,700', POH. RIH w /9- 5/8" cement retainer and set at 2,440'. Perform injectivity test through retainer. August 13, 2009 11,136' MW N/A Vis N/A Incl N/A Wait on AOGCC approval of annular disposal permit. Begin annular disposal of drilling mud. Clean mud storage tanks. August 14, 2009 11,136' MW N/A Vis N/A Incl N/A Prepare drilling fluids for injection. Inject fluids. Follow w/ cement P &A plug: 22 bbls Class G below retainer at 2,440' and 5 bbls above. Witnessed by AOGCC's Lou Grimaldi. August 15, 2009 11.136' MW N/A Vis N/A Incl N/A L/D drill pipe. Test casing to 1500 psi for 30 minutes - OK. Test witnessed by AOGCC's Lou Grimaldi. Set bridge plug at 196'with surface cement plug above it to surface. L/D last of drill pipe, N/D BOPE. August 16, 2009 11,136' MW N/A Vis N/A Incl N/A Rig down. Load out rig and support equipment. Install well identification plate on cut- off 9 -5/8" casing and 16" conductor. THIS IS A FINAL REPORT. If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, For RAMPART ENERGY COMPANY r� Saes 4 Alexey Sachivichik Senior Drilling Engineer Fairweather E &P Services, Inc. 2 201 osci- )-SCINIUMberger Misc. umping Service Job iaport CemCATv1.0 Well Nunivak #1 Client Rampart Field Nenana SIR No. B5G0 00007 Engineer Job Type Injection Test Country United States Job Date 08 -13 -2009 Time Pressure Rate Messages 03:38:50 ..—.�, 03 :44:00 • 03:49:00 Begin water for PT Reset Total, Vol = 5.61 bbl 03:54:00 Reset Total, Vol = 2.47 bbl 03:59:00 Shut down, Reset Total, Vol = 4.50 bbl Shut down, bleed off 04 :04 :00 Reset Total, Vol = 7.34 bbl Shut down, Bleed off, Check Returns 04:09:00 Reset Total, Vol = 9.11 bbl Shut Down, Bleed off, Check Returns 04 :14 :00 04 :19:00 Reset Total, Vol = 15.72 bb! Shut Down, Bleed off, Check returns Total Barrels Injected 39.14 04:24:00 Unstung Stopped Acquisition 04:31:15 I hh:mm:ss SW 1030 2030 3330 4W) 'QOD QW 2.0 4.0 6.0 8.0 100 08/13/7079 0,31:15 -- PSI B/M 08/13/2009 04:32:44 Customer. Rampart i District Sckkoderips Represerre: DS Supervisor. Job Date: 08-13 -2009' Welt Nunwak #1 Time Treating Pressure GMT RATE mm:dd:yyyy:hh:mm:ss psi bbtlmin 08:13:2009:03:38:50 150 0.2 08:13:2009:03:39:50 1071 3.7 08:13:2009:03:40:50 646 0.0 08:13:2009:03:41:50 620 0.0 08:13:2009:03:42:50 614 0.0 08:13:2009:03:43:50 3867 0.0 08:13:2009:03:44:50 118 0.0 08:13:2009:03:45:50 459 0.0 08:13:2009:03:46:50 119 0.0 08:13:2009:03:47:50 120 0 0 08:13:2009:03:48:50 124 0 0 08:13:2009:03:49:50 122 0.0 08:132009:03:50:00 Begin vrser for PT 08:132009:03:50:00 122 0 0 08:13:2009:03:50:50 121 0.0 08:13:2009:03:51:50 119 0.0 08:13200903:5143 Reset Total, Vol = 5.61 bbl 08:132009:03:52:43 121 0.0 08:13:2009:03:52:50 125 0.2 08:132009:03:53:50 136 0.5 08:13:2009:03:54:50 138 0.0 08:132009:03:55:50 459 0.5 08:132009:03:56:50 453 0.5 08:132009:03:57:50 435 0.5 08:13200900:5826 Reset Total, Vol = 2.47 bbl 08:132009:03:58:26 424 0.0 08:132009:03:58:27 Shutdown, 08:132009:03:58:27 423 0.0 08:132009:03:58:50 414 0.7 08:132009 :03:59:50 425 1.5 08:13:2009:04:0050 386 1.5 08:132009:04:01:50 394 1.5 08:132000:04 :0220 Reset Total, Vol = 4.50 bbl 08:132009:04:0220 372 0.0 08:132009:04b221 Shut down, bleed of 08:13:2009:04:02:21 373 0.0 08:13:2009 :04:02:50 112 0.0 08:132009:04:03:50 173 0.0 08:13:2009:04:04:50 818 2.4 08:132009:04:05:50 877 2.4 08:132009:04:06:50 789 2.4 08:132009:04:07:16 ResetTotal, Vol= 7.34 WI 08:132009:04:07:16 573 0.0 08: 132009:04:07:17 Shut down, Bleed off, Check Returns 08:132009:04:07:17 572 0.0 08:13:2009:04:07:50 229 0.0 08:132009 :04:08:50 122 0.0 08:132009:04:09:50 738 2.9 08:13200904:1050 782 2.9 08:13:2009:04:11:50 810 2.9 08:132009:04:1239 Reset Total, Vol = 9.11 bbl 08:132009:04:1239 554 0.0 08: 132009:04:1240 Shut Down, Bleed off, Check Returns 08:13200904:1240 552 0.0 08:13:2009:04:12:50 514 0.0 08:13:2009:04:13:50 386 0.0 08:132009:04:14:50 949 4.0 08:132009:04:15:50 976 4.0 08:13:2009:04 :16:50 942 4.0 08:13:2009:04:17:50 855 4.0 08 :132009:04:18:50 184 0.0 08:13:2009:04:19:50 122 0.0 08:132009:04:20:43 Reset Total, Vol= 1572 bbl 08:13:2009:04:2043 83 0.0 08:132009:04:20:44 Shut Down, Bleed off, Check returns 08:132009:04:20:44 84 0.0 08:13:2009:04:20:50 81 0.0 08:132009:04:21:34 Total Barrels Injected 39.14 1 08:13:2009:04:21:34 73 0.0 08:13:2009:04:21:50 72 0.0 08 :132009:04:2150 68 0.0 08:13:2009:04:23:50 65 0.0 08 :132009:04:24:50 63 0.0 08:132009:04:25:50 62 0.0 08 :1320090426:30 Unstung 08:13:2009:04:26:30 61 0.0 08:13:2009:04:26:50 61 0.0 08:13:2009:04:27:50 59 0.0 08:13:2009:04:28:50 60 0.0 08:13:2009:04:29:50 59 0.0 08:13:2009:04:30:50 59 0.0 Page 1 of 1 Li \6...11,,KIR\ / SEAN PARNELL, GOVERNOR 4110 dik* — - - \ - K 1 FA (-- 1 ' t 'E C qr r if L DI A c LIB ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Julie L. Weber Vice President Rampart Energy Company 1512 Larimer Street Bridge Level Denver, CO 80202 Re: Exploratory Field /Pool, Nunivak #1 Well Sundry Number: 309 -281 Dear Ms. Weber: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager) . As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, i , / / 9 Cathy • . Foerster Corn issioner DATED this /Z day of August, 2009 Encl. _AE. ' A STATE OF ALASKA , 3 I. 'i. L.00 r 1 ALASKA OIL AND GAS CONSERVATION COMMISSION W6 � `�► � IIV _ ail {;� 9 1 APPLICATION FOR SUNDRY APPROVALS ''° , '' ;.. �'- 20 AAC 25.280 1. Type of Request: Abandon El Suspend ❑ Operational shutdown ❑ Perforate [ ] Waiver Other ❑ Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ Change approved program ❑ Pull-tubin El Perforate New Pool ❑ Re -enter Suspended Well El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Rampart Energy Company Development ❑ Exploratory 0 209 -054 - 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: 1512 Larimer Street, Bridge Level, Denver, CO,80202 50-083- 20002-0000 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number property fine where ownership or landownership changes: N/A Spacing Exception Required? Yes ❑ No ❑ Nunivak #1 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s) MHT 9300028 18.8 Ex . loratory 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth 'R/D (ft): Plugs (measured): Junk (measured): 11135' 11074' 11135' 11074' None None Cuing Length Size MD TVD Burst Collapse Structural Conductor 80' 18' 80' 80' 5740 3080 Surface 2513' 9.625 2513' 2513' 5330 3810 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 'Tubing Size: Tubing Grade: Tubing MD (ft): NIA N/A NIA WA WA Packers and SSSV Type: NIA Packers and BSSV MO (ft): N/A 13, Attachments: Description Summary of Proposal E 14. Well Class after proposed work: Detailed Operations Program 12 BOP Sket,hfl ❑ Exploratory Ell Development ❑ Service ❑ 15. Estimated Date for August/ ,4 16. Well Status after proposed work: Commencing Operations: �/ Oil ❑ Gas El Plugged In Abandoned 17. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18. I hereby certify that the foregoing Is true and correct to the best of my knowledge. Contact Bill Penrose (900258 -3446 Printed Name / JJ le L. W ber Title , ' //• 2 } Vice President - _ Signature Adi fiaWIT Phone 303 460 -1132 Date COMMISSION USE ONLY Conditions o f approval: Notify Commission so that a representative may witness Sundry Number. / _ aol3'/ Plug Integrity (1 BOP Test ❑ Mechanical Integrity Test El Location Clearance LJ Other: Subsequent Form Required: i 0 - 4-0 7 . / / APPROVED BY Approved by: / i 2 COMMISSIONER THE COMMISSION Date: 6 /? "' Q, Form 10-403 lead 06J2006 0 R I G 1 N A LRB Submit in Duplicate ..e.� e e-e S BFL AUG 1 N B I • RAMPART Rampart Energy Company Nunivak #1 Plug and Abandonment Procedure General There are no hydrocarbon - bearing zones required by the AOGCC to be covered with ,- cement during abandonment of the open hole. The plugging and abandonment of this well will be accomplished by setting a cement plug across the 9 -5/8" surface casing shoe at 2,513' MD and setting a surface cement plug. The AOGCC field inspector should be notified at least 24 hours before beginning this procedure and kept informed of the timing of all steps in order to allow him to witness those the Commission wishes confirmed. Casing Shoe Plug 1. RIH with a 9 -5/8" Weatherford open hole packer and set it at +/- 2,700'. 2. RIH with a 9 -5/8" cement retainer on drill pipe and set at 2,440'. Weight test retainer and remain stung into it. 3. Perform 4 -point injectivity test required for the Annular Disposal permit application. Immediately submit the results of the injection test to the Anchorage Fairweather office for submission to the AOGCC. 4. Upon receipt of the annular disposal permit, RU and inject all Class II waste liquids through the retainer and into open hole section below the 9 -5/8" shoe within the pressure and rate limitations contained in the permit. 5. Unsting from the retainer and, with the retainer running tool located just above the retainer, use water to displace cement to the running tool then sting into the retainer and squeeze cement through it to achieve a plug across the casing shoe as follows: Pump 10 bbl Spacer. Follow with 25 bbls. (94 sx) Class G Cement+ 0.7 %D65 + 0.7 %D167 + 0.3% D800 + 0.2 %D46 +35 %D66. Follow with 4 bbls Spacer • S 6. Displace 21 bbls (79 sx) of cement through the retainer, un -sting from the retainer and dump the remaining 4 bbls on top. 7. POH five stands, CBU and POH, L/D drill pipe, leaving 200' in the derrick. 8. Pressure test the 9 -5/8" casing to 1,500 psi for 30 minutes. Record test on chart. Surface Plug 9. P/U a 9 -5/8" bridge plug on drill pipe and RIH to 200' RKB. Set the bridge plug, weight -test it and release from it. l Mix and pump 15.2 bbls Class G cement to fill the 9 -5/8" casing from the bridge plug to the surface. Cement to be Class G mixed as: 57 sx of Class G + 6.3 gal /sx fresh water Surface Abandonment 10. Rinse out the wellhead and BOP stack, clean pits and release the rig. 11. After the rig has been moved off location, use a backhoe to remove the well cellar and cement in the bottom of it. 12. Cut off the wellhead and send it back to Vetco Gray to be refurbished. 13. Cut off all casing strings at least 5' below pad level. Ensure there is cement at the surface in the 9 -5/8" x 16" annulus and in the 9 -5/8" casing. AOGCC inspector to verify. 14. Weld onto the 16" conductor a' /4" thick, 18" diameter well identification marker with the following information bead - welded onto it: Rampart Energy Company PTD No. 209 -054 7 Nunivak #1 API # 50- 083 - 20002 -0000 AOGCC inspector to witness installation of the marker plate. 15. Bury the well marker and fill the cellar hole with local construction fill material. The pile over the well marker should be mounded at least 3' above pad level to compensate for settling. • • 16. Clean up the drilling location and demobilize all P &A equipment, materials and refuse. • S RAM P AR Nunivak #1 Webor Schematic Proposed P &A / W < \ Q 16 conductor m 82 —41111 Bridge Plug at 200 531' 10.O pp ®} mu d \ 12-1/4" hole • .� I I � { TOC at 2,385' MD } ) Cement retainer at 2,440' MD ) \ ( ! \ % 9-5/8", 40,b80, BTC ` casing at 2, 51& M D ! � ; BOC OHPakrat 2,700' MD [ I t i t i [ I [ I ( ( { 8-1/2" hole [ 10 0 pp } { mud [ [ 5 s 5 4 � 4 5 5 > i > . TD m1f13'eD ND • i ;t. 't R AMPART -- -^--, .: ;1,r... , , ; August 11, 2009 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Application to Plug and Abandon Rampart Energy Company, Nunivak #1 (PTD: 209 -054) Dear Mr. Seamount, Rampart Energy Company proposes to plug and abandon its Nunivak #1 well. It is intended to plug the well back to surface, install the required marker plate and bury the stub. Two cement plugs are planned, one across the surface casing shoe and one surface plug as indicated on the enclosed wellbore schematic. The mud log from this well has been reviewed with AOGCC staff for their concurrence on the cementing requirements for the open hole. The abandonment of Nunivak #1 will be accomplished as indicated on the attached wellbore diagram and P&A procedure. If you have any questions or require additional information, please contact Bill Penrose at 258 -3446. Sincerely, (.,) RA ' ART RGY COMPANY Ali . ' Juli L. Weber Vic • President cc: Bill Penrose 1 Attachments • F A iPART August 7, 2009 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Rampart Energy Company: Nunivak #1 (PTD # 209 -054) Dear Mr. Seamount, This is a report of Rampart's well operations on the Nunivak #1 for the period July 31 through August 6, 2009, inclusive. July 31, 2009 11,136' MW 9.7 ppg Vis 61 sec Incl 10.19 deg Drill from 10,745' to 11,136' TD. Pump hi -vis sweep, hole packed off, pipe stuck. Work pipe free. C &C hole for POH, BOP test and OH logs. August 1, 2009 11,136' MW 9.8 ppg Vis 66 sec Incl 10.19 deg C &C hole. P011, L/D BHA. Test BOPE (test witness waived by AOGCC's Jim Regg). August 2, 2009 11,136' MW 9.8 ppg Vis 70 sec Incl 10.19 deg Finish testing BOPE. R/U wireline for OH logs. RIH, tag up at 7,610'. Could not work past 7,620'. Log 7,620' to 2,515' (surface casing shoe). POH, R/D logging equip. M/U cleanout assy and RIH. No bobble at 7,600', hole tight commencing at 9,800'. August 3, 2009 11,136' MW 9.9 ppg Vis 77sec Incl 10.19 deg Spend all day washing and reaming 9,900' to TD. C &C hole and P011. August 4, 2009 11,136' MW 9.9 ppg Vis 61 sec Incl 10.19 deg I I Cont. PO11, S/B BHA. R/U wireline for open hole logging. RIH, tools stopped at 7,620'. Would not work through. Log out to surface. R/U to run VSP survey. RII1 and run VSP survey 7,600' to surface. R/D wireline equipment. 1512 ;r rt;: O?r c , '} t CO 'O2;:}2 • IP August 5, 2009 11,136' MW 9.9 ppg Vis 84 sec Incl 10.19 deg M/U 8 -1/2" cleanout assy, RIH. Clean up interval across 7,600' and continue in hole. Took weight at 9,791'. Wash and ream to 10,540'. August 6, 2009 11,136" MW 10.10 ppg Vis 80 sec Incl 10.19 deg Wash and ream to TD. C &C hole. POH - many tight spots requiring pumping out. LID BHA. If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, For RAMPART ENERGY COMPANY Saciteadd Alexey Sachivichik Senior Drilling Engineer Fairweather E &P Services, Inc. cc: Van Spence — Rampart Energy Company 2 S • • RAM PART July 31, 2009 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Rampart Energy Company: Nunivak #1 (PTD # 209-054) Dear Mr. Seamount, This is a report of Rampart's well operations on the Nunivak #1 for the period July 24 through July 30, 2009, inclusive. July 24, 2009 7,825' MW 9.4 ppg Vis 68 sec Incl 1.80 deg Test BOPE to 250 psi — low /5000 psi - high. Good. Test witness waived by AOGCC's Jim Regg. Make up BHA #6. TI-1. Drill from 7,610' to 7,825'. July 25, 2009 8,665' MW 9.4 ppg Vis 66 sec Incl 1.97 deg Drill /slide from 7,610' to 8,647'. Work and free stuck drill pipe at 8,640'. Drill from 8,647' to 8,669'. Circulate. Wiper trip from 8,669' to 7,860'. July 26, 2009 9,165' MW 9.6 ppg Vis 69 sec Incl 2.10 deg Finish wiper trip. Circulate. Drill from 8,669' to 8,844'. Repair rig (wash pipe). Drill from 8,844' to 9,109'. Repair rig (wash pipe). Drill from 9,109' to 9,165'. July 27, 2009 9,313' MW 9.7 ppg Vis 86 sec Incl 0.40 deg Drill from 9,165' to 9,313. Repair wash pipe assembly. Wiper trip to 7,392'. Repair rig (wash pipe packing assembly). POH to 2,500'. Repair rig. July 28, 2009 9,450' MW 9.9 ppg Vis 105 sec Incl 0.25 deg Repair swivel. POOH from 2,498'. Check motor and bit. RIH to 2,498'. Cut drilling line. TIH to 9,316'. Circulate and condition mud. Drill from 9,316' to 9,450'. 3 -512 • • July 29, 2009 10,104' MW 9.6 ppg Vis 72 sec Incl 0.47 deg Drill from 9,450' to 10,104'. Circulate. Wiper trip from 10,104'. July 30, 2009 10,740' MW 9.6 ppg Vis 70 sec Incl 1.60 deg Wiper trip. Service the rig. Drill from 10,103' to 10,740'. If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, For RAMPART ENERGY COMPANY S Alexey Sachivichik Senior Drilling Engineer Fairweather E &P Services, Inc. cc: Van Spence — Rampart Energy Company 1 2 `.� • 1111 RAMPART : July 24, 2009 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Rampart Energy Company: Nunivak #1 (PTD # 209 -054) Dear Mr. Seamount, This is a report of Rampart's well operations on the Nunivak #1 for the period July 17 through July 23, 2009, inclusive. July 17, 2009 2,525' MW 9.0 ppg Vis 54 sec Incl 2.00 deg Complete changing out IBOP in top drive. Test 9 -5/8" csg to 3,750 psi for 30 min. Test IBOP to 250/5000 psi. Test witness waived by AOGCC's John Crisp. M/U BHA and RIH on drill pipe. Tag float collar. Drill out float collar and cement in shoe track. July 18, 2009 3,875' MW 9.1 ppg Vis 50 sec Incl 8.80 deg Drill out FC, cmt, FS and 20' of new formation to 2,545'. C&C mud. Perform LOT to 12.4 ppg EMW. Drill 2,545' to 2,561'. Perform second LOT — same EMW. Directionally drill 8 -1/2" hole from 2,561' to 3,056'. Perform LOT to 12.7 ppg EMW. Drill from 3,056' to 3,875'. July 19, 2009 5,445' MW 9.1 ppg Vis 53 sec Incl 9.30 deg Directionally drill 8 -1/2" hole from 3,875' to 4,614'. Short trip to 2,995' and back to bottom. Hole in good condition. Drill from 4,614' to 5,445'. July 20, 2009 6,036' MW 9.2 ppg Vis 53 sec Incl 8.60 deg Directionally drill 8 -1/2" hole from 5,445' to 6,020'. Wash pipe in top drive blew. POH to 4,565'. Change out wash pipe and pressure test to 3,000 psi. RIH to 6,020'. Drill to 6,036', bit stopped drilling. POH for new bit. w • • ■ July 21, 2009 6,445' MW 9.3 ppg Vis 53 sec Incl 9.65 deg Change out bit. RIH with BHA #5. Pulse test MWD. RIH to 6,036'. Directionally drill from 6,036' to 6,445'. July 22, 2009 7,310' MW 9.1 ppg Vis 62 sec Incl 6.7 deg Drill from 6,445' to 7,310'. Service the rig. July 23, 2009 7,610' MW 9.3 ppg Vis 66 sec Intl 1.37 deg Drill from 7,310' to 7,610'. Circulate sweep. Trip out of hole. Lay down 18 joints of 5" drill pipe, pony collar, sub, MWD and motor. Prep for BOP test. If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, For RAMPART ENERGY COMPANY rOgezef Sae/dada Alexey Sachivichik Senior Drilling Engineer Fairweather E &P Services, Inc. cc: Van Spence — Rampart Energy Company 2 • jog -054 • R AMPART = July 17, 2009 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Rampart Energy Company: Nunivak #1 (PTD # 209-054) Dear Mr. Seamount, This is a report of Rampart's well operations on the Nunivak #1 for the period July 10 through July 16, 2009, inclusive. July 10, 2009 2,525' MW 9.1 ppg Vis 140 sec Inc12.00 deg Make short trip to conductor shoe and back to bottom. CBU and POOH, L/D BHA. Begin running 9 -5/8" casing. July 11, 2009 2,525' MW 9.1 ppg Vis 54 sec Inc12.00 deg Finish running 9 -5/8" casing to 2 515' w/ port collar installed at 515'. Circ one csg vol g g Po g while R/U to cement. Mix and pump 224 bbls permafrost lead cmt followed by 62 bbls Class G tail cmt. Displace w/ mud, bump plug w/ 1,250 psi. Received dyed pre -flush to surface but no cement. Shift open port collar and circulate out cement above it in annulus. July 12, 2009 2,525' MW 9.1 ppg Vis 54 sec Incl 2.00 deg R/U cementers and pump Stage 2 cement job: 29 bbls lead and 36 bbls tail. Good cement to surface. Shift port collar closed and test to 1,000 psi. WOG Rough cut 9 -5/8" csg and remove stub. N/D diverter equipment. Make final cut on casing, prep for wellhead installation. July 13, 2009 2,525' MW 9.0 ppg Vis 54 sec Incl 2.00 deg Attempt to set wellhead w/ o -ring, would not set to mark. Remove o -ring and weld WH to casing. Pressure test weld to 5,000 psi — found two leaks. Grind and dress in prep for re -weld while assembling BOP components. 1512: «..I'.. t mi.�. } :. }. {iE �i ..., .... _i ''!.}.r m . f _ ... t�.,� r. •. [� .: � 0 . July 14, 2009 2,525' MW 8.9 ppg Vis 48 sec Incl 2.00 deg Weld on wellhead. Let cool while M/U and S/B 4" DP stands in derrick. Conduct H2S drill and ADEC spill drill. M/U BOP components and hang in subbase trolley. Remove insulation f/ WH. July 15, 2009 2,525' MW 9.0 ppg Vis 52 sec Incl 2.00 deg Let WH cool. Pressure test to 4,600 psi — good test. Assemble and N/U BOPE. July 16, 2009 2,525' MW 9.0 ppg Vis 56 sec Incl 2.00 deg Finish N/U BOPE. Test BOPE to 5,000 psi, witnessed by AOGCC's John Crisp. Replace kill -side HCR w/ manual valve. Repair leak in standpipe. Replace IBOP in top drive. If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, 1 For RAMPART ENERGY COMPANY ,ReZef S Alexey Sachivichik Senior Drilling Engineer Fairweather E &P Services, Inc. cc: Van Spence — Rampart Energy Company 2 • • Page 1 of 1 Aubert, Winton G (DOA) 2.0q - From: Bill Penrose [bill @fairweather.comj Sent: Thursday, July 16, 2009 4:24 PM To: Aubert, Winton G (DOA) Cc: Regg, James B (DOA); FepsiCoMan Subject: Rampart Energy Nunivak #1 Winton, Rampart Energy Company proposes to convert the originally proposed hydraulic valve on the kill line to a manual one for the subject well. This will result in the kill line having two manual valves in lieu of one manual and one hydraulic valve. Please let me know if you have any questions or concerns with this modification. Thanks and regards, Eitt Peonewe Vice President / Drilling Manager Fairweather E &P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907 -258 -3446 7/17/2009 410 ?0q, osq_ • RAMPART July 10, 2009 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Rampart Energy Company: Nunivak #1 (PTD # 209 -054) Dear Mr. Seamount, This is a report of Rampart's well operations on the Nunivak #1 for the period July 2 through July 9, 2009, inclusive. July 2, 2009 100' MW N/A Vis N/A Intl 0.00 deg Continue rig up of camp and rig. Begin function testing rig equipment. Set berms for mud storage tank. July 3, 2009 100' MW N/A Vis N/A Ind 0.00 deg Continue with rig up, function test rig. Work on 40 man camp electrical, water and septic lines. Continue with installation of Horizon rig monitoring system. July 4, 2009 100' MW N/A Vis N/A Ind 0.00 deg Commission rig. P/U drill pipe. Complete rig up of mud loggers, MWD cabin and mud lab. July 5, 2009 100' MW N/A Vis N/A Ind 0.00 deg Commission rig. Set felt and liner for cuttings /waste storage area and mud pumps. Evacuate all personnel from location due to nearby forest fire. July 6, 2009 100' MW N/A Vis N/A Incl 0.00 deg Recall crews to location. Resume operations suspended due to forest fire. Set and berm up 400 bbls tanks. Build cell for excess cement. P/U jars, HWDP and 8" drill collars. o July 7, 2009 100' MW N/A Vis N/A Ind 0.00 deg Mix spud mud. Test diverter system - witnessed by AOGCC's Jeff Jones. Set cement van and silo. July 8, 2009 522' MW 9.1 ppg Vis 318 sec Inc10.37 deg Wait for Forestry Division approval to spud. Set up sprinkling system around location. Test HP mud lines, spud well at 1845 hrs. Drill 12 -1/4" hole to 312'. POH to motor, MU BHA except for HWDP. RIH. Drill from 312" to 524'. POH to PU HWDP. July 9,2009 2525' MW 9.1 ppg Vis 255 sec Incl 2.0 deg PU HWDP and RIH to 524'. Drill 12 -1/4" hole from 524' to 2008'. Observe 500 psi pressure loss. POH to 1509' looking for washout. Regain pressure at 1509'. Suspect faulty pump pressure sensor. RIR, drill from 2008' to 2525' section TD. Pump carbide lag around and short trip to BHA. If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, For RAMPART ENERGY COMPANY "Rex, Sacluviclda Alexey Sachivichik Senior Drilling Engineer Fairweather E &P Services, Inc. cc: Van Spence - Rampart 2 rTT r;. . _ '. °' V SARAH PALIN, GOVERNOR A OIL AND ALASKA OIL N GAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMPIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Van Spence President Rampart Energy Company 1512 Larimer Street Bridge Level Denver, CO 80202 Re: Exploratory Field, Exploratory Pool, Nunivak #1 Well Rampart Energy Company Permit No: 209 -054 (Corrected) Surface Location: T4S, R8W, SEC. 17, 91' FWL, 1175' FNL Bottomhole Location: T4S, R8W, SEC. 17, 753' FWL, 973' FNL Dear Mr. Spence: Please disregard the original transmittal letter that was sent to you on June 8, 2009 it contained a typographical error, note the changes in the first paragraph. It should have indicated that the transmitted letter approved an application was for an exploratory well not a development well. Sincerely, ijfr Daniel T. Seamount, Jr. Chair DATED this � T day of July, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 0 • 4 ' , ° I, F, ■ ` ; '` -- -''' \\ I—, p i SARAH PALM, GOVERNOR GAS ALASKA OIL AND GAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION / PHONE (907) 279 433 -3539 I FAX (907) 276 -7542 Van Spence President Rampart Energy Company 1512 Larimer Street Bridge Level Denver, CO 80202 Re: Exploratory Field, Exploratory Pool, Nunivak #1 Well Rampart Energy Company Permit No: 209 -054 Surface Location: T4S, R8W, SEC. 17, 91' FWL, 1175' FNL Bottomhole Location: T4S, R8W, SEC. 17, 753' FWL, 973' FNL Dear Mr. Spence : Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional pen nits or an approval 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. 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 representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (90 ��59 -3607 (pager). .�j o � 4 '. I l Y ` an f 4 ••:sione DATED this L day of June, 2009 • ' cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o end. iki4Ir STATE OF ALASKA ReceivE - pit AL /IA OIL AND GAS CONSERVATION COMMIS. PERMIT TO DRILL ivlAY 0 4 20U::, 20 AAC 25.005 1a. Type of Work: lb. Current Well Class: Exploratory El Development Oil ❑ lc. Specify if well is mimosa r r Drill 0 Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas ❑ Coalbed Methane as ra es Re -entry El Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ Anc 2. Operator Name: 5. Bond: Blanket ❑ Single Well 0 11. Well Name and Number: Rampart Energy Company Bond No. 7110024912 Nunivak #1 3. Address: 6. Proposed Depth: 12. Field /Pool(s): 1512 Larimer Street, Bridge Level, Denver, CO, 80202 MD: 11652' / TVD: 11600' Exploratory 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: T4S, R8W, Sec 17, 91' FWL & 1175' FNL MHT 9300028 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: T4S, R8W, Sec 17, 753' FWL & 973' FNL N/A /15/2008 Total Depth: 9. Acres in Property: 14. Distance to Nearest 11600' T4S, R8W, Sec 17, 753' FWL & 973' FNL 9468' Property: 5200' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface: x- 623390.5 y 3864303.7 Zone- 4 (Height above GL): 18.8 feet Nenana #1, 12.5 miles 16. Deviated wells: Kickoff depth: N/A feet 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) / Maximum Hole Angle: 0 degrees Downhole: 5791 psi Surface: -459.2 psi 45 12 ii. , 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 16" 84 N -80HC PEB 80' 18.8' 18.8' 80' 80' N/A 12.25" 9.625" 40 L -80 BTC 2481.2' 18.8' 18.8' 2500' 2500' 1553 cf (incl 100% OH xs) 8.5" 7" 26 L-80 BTC 11581.2' 18.8' 18.8' 11652' 11600' 855 cf (incl 50% OH xs) 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑ BOP Sketch 0 Drilling Program 0 Time v. Depth Plot 0 Shallow Hazard Analysis ❑ Property Plat El Diverter Sketch Ei Seabed Report ❑ Drilling Fluid Program Ei 20 AAC 25.050 requirements ❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Alexey Sachivichik (907) 575 7315 Printed Name Van S.ence Title President Signature V Phone (303) 460 -1132 Date ` 136 l n ` Commission Use Only Z / Permit to Drill A,. umber: Permit Approval ( See cover letter for other Number: ��OS'!�Q 50 0f3�OQ�Q.000O Date: CQ I / �� requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed met ane, gas hydrates, or gas contained in s❑es: Other: Samples req'd: YesE' No ❑ Mud log req'd: Y4[ NL H measures: Yes Yesg No ❑ Directional svy req'ces No Pe 2 A-A C. 2S, 0 35 (k) (z) � d.<,�e-r Jo-wf li, . Le is uPpr d APPROVED BY THE COMMISSION DATE: 16 If '� �. COMMISSIONER 1 ORIGINAL Form 10-401 Revised 12/2005 Submit in Duplicate r lilk N be 1 , N t t n _ 0 N h � titi1 ,� ' . N 43v le N 43n3 N ^ 43 t 4 . �h h�O .�ti^,� �... n a N 43 ,.� � f -� ;�. � m,. , Nena Y 4 I °`.^�. e ms " Y , ; . r• m N 0 µL 0 :.;'.*- . Legend 0 Pad Corners ROW W (a E Access Routes Area Map R AMPART - s Section Grid Pad Polygon Project No. Checked By: 0 1,250 2,500 3,750 5,000 Date: 04/02/2009 File: Master.rnxd Feet i RAMPART Summary Drilling Procedure 1. Prior to moving in drilling rig, drill /drive a 16" conductor to +80' below ground level then excavate around it and install a cellar. 2. Move in, rig up Doyon/Akita Arctic Wolf Rig #2. Notify AOGCC of intention to spud. Rig up diverter on 16" conductor and function test. Rig up mud loggers. 3. M/U 12 -1/4" drilling assembly with MWD tools and drill a vertical hole to 2,500'. 4. Run 9 -5/8 ", 40 #, L -80, BTC surface casing and cement to surface per cementing -' program. WOC. 5. N/D Diverter. Install wellhead, N/U 10K WP BOPE and test to 10,000 psi. 6. M/U 8 -1/2" drilling assembly with MWD tools. 7. RIH with 8 -1/2" drilling assembly, clean out to float collar and test -5/8" casing to 3,000 psi.'Drill out float collar, cement, float shoe an 20' of new hole. Conduct leak -off test. Displace spud mud from well with LSND polymer % mud system. 8. Drill 8 -1/2" shallow S -shape hole to 11,652'. 9. Condition the hole, POH and run open -hole logs. 10. Run 7 ", 26 #, L -80, BTC production casing and cement per cementing program. 11. N/D BOPE, N/U 10,000 psi WP tree and test tree. 12. RDMO Arctic Wolf #2. 13. After completion of the well, it will be perforated and tested. • . Nunivak #1 Drilling Planning Data I I Introduction The Nunivak #1 is a planned wildcat well to be located approximately 3 miles west of the town of Nenana. It will be drilled as a gas exploration well by Rampart Energy Company to approximately 11,600' MD/TVD as a near - vertical hole. Surface and bottomhole coordinates, in Alaska State Plane NAD -27 Zone 4, are: Surface hole X = 623391 Y = 3864304 Bottom hole X = 624050 Y = 3864518 Well Geometry The bottomhole location for the Nunivak #1, given above, is located at Shot Point 1505 on Seismic Line 5004. The surface location, however, is located approximately 692' to the west - southwest at the closest point of approach without encroaching on sensitive wetlands. The well will have a very shallow S -shape in order to penetrate the sequences of interest (7,800' - 11,600' TVD) with a vertical wellbore on the desired shot point. Offset Wells The Nenana Basin is completely unexplored. The nearest offset wells are two basin -edge wells: the Union Oil Company Nenana #1 located 12.5 miles to the west and the ARCO Totek Hills #1 located 28.5 miles to the southwest of the Nunivak #1 location. (See Figure 1) Neither of those wells exceeded 3,500' in depth and have little to offer in terms of planning information (stratigraphy, lithology, pore pressures, rock strength, etc.) for the subject well. Most of the planning data presented here is derived from the inferred basin geological history and geophysical data. Geology The basin depositional history is postulated to be very similar to Cook Inlet's and the entire section in the Nunivak #1 will be Tertiary rocks, not unlike those in Cook Inlet. TD will probably be in the Paleocene Cantwell Formation. See Figures 10, 11 and 12 for an annotated seismic section and generalized basin geological sections. The stratigraphic column in the Nunivak #1 is expected to generally appear as follows (Note: The depths given are drawn from seismic data and are very approximate): Surface - 1000' Pleistocene fluvio- glacial gravels with possible permafrost to - 1,700'. Seismic data indicates little or no permafrost present at the proposed drilling location, though there are definite indications of permafrost on adjoining seismic lines and to the west on the seismic line being drilled. Figure 8 is a permafrost map for • • this area derived from seismic data. The map indicates the Nunivak #1 well location to be slightly outside the area of permafrost, but the well design conservatively assumes that some amount of permafrost will be present at the drilling location. Drilling concerns: unconsolidated gravels, possible gas hydrates in permafrost (if present), possible shallow gas below permafrost (if present) 1000' -6000' — Pliocene Nenana Formation, 95% sand /cgl, except for the Grubstake Formation. The Nenana Formation should be composed of lithic, quartzose gravels and sands, with some claystone. In age, this is like the Sterling Formation of Cook Inlet, but the rocks are more immature, meaning the sand grains will be more angular, probably larger and more poorly sorted. The entire section should be more sand -rich than the Sterling, with fewer significant shale layers. There may be some coals but none are expected to be significantly thick. There are expected to be some lacustrine shales, or at least a clay -rich section, that ties to seismic markers at 2,500' — 3,000'. This may be the Grubstake Formation shale with thin coals. Beneath the Grubstake there should be a more sand -rich section. Drilling Concerns: Possible gas hydrates in permafrost (if present), possible shallow gas below permafrost (if present). Numerous gas sands possibly will be penetrated during the course of drilling this well. Gas entries into the mud column can cause serious problems. Care, therefore, must be exercised at all times to prevent gas entries by either swabbing the well or hydraulicing the formation (and associated lost circulation) on trips. Rapid penetration rates cause an increase in mud weights and increase the risk of lost circulation and subsequent kicks. Penetration rates will be restricted. 6000' -9000' — Miocene Usibelli Group. Contains 60% sandstone /cgl, 25% shale, 15% coal. This section is similar to the Beluga and Tyonek sections in Cook Inlet. The primary target in this well will be the Usibelli Group. This is expected to lie in the interval 7,800' — 8,300', though seismic uncertainties may have the target come in a little deeper. The target may adjoin some coaly sections. Drilling Concerns: Coal beds can cause serious loss -of -hole problems. They may contain some gas and /or present sloughing /packoff problems. Packing off can cause lost circulation, kicks and a stuck drilling assembly. However, the main area of concern with coals, especially if they resemble those in the Cook Inlet Basin, is their tendency to plastically swell into the wellbore behind the bit and stick the bottom hole assembly if drilled too fast. While roller cone bits exhibit a dramatic increase in penetration n this problem, PDC bits slow down when the rate in coals, exacerbating t s p they encounter coal seams. This allows the coal to be reamed out while it is relaxing against the bit and reduces the tendency for BHA sticking. For this reason, PDC bits will be used exclusively below the surface casing shoe. The first target for this well is at approximately 7,829' MD/TVD, therefore, heavier mud will be prepared, in case a gas kick is encountered. 9,000'- 11,600'TD — Cantwell Formation. Non - marine section — sand /shale with 10% coals. This section may have some volcanic ash layers in it, as much as 10% of the section. Drilling Concerns: The second target for this well is at approximately 9,900' TVD. TD is anticipated to be ±11,600'. Heavier mud will be ready for use in case the target interval feeds gas into the mud system. • Fracture Gradient There is no fracture gradient or rock strength data extant for the Nenana basin. Neither of the two basin - edge offsets, the Nenana #1 or the Totek Hills #1 had any leak -off tests conducted in them. Given the complete lack of direct data, the Nunivak #1 fracture gradient is assumed to be similar to that established for Cook Inlet. This is justified on two grounds: 1. The Nenana Basin geological history (rock sequences, age, etc) is expected to be similar to that of the Cook Inlet Basin 2. The established Cook Inlet Basin fracture gradient is relatively weak, yielding a conservative gradient for Nunivak planning purposes. Figure 2 shows the fracture gradient used for planning the Nunivak #1. Pore Pressures Seismic data was used to detect any potential abnormally - pressured intervals by plotting interval transit times (ITT's) versus depth on a semi -log plot. (See Figure 3) The seismic velocity analysis was conducted on Seismic Line 5003 which is one line over from that on which the well is to be drilled (Line 5004). However, this analysis is spatially close enough to the planned drilling location to remain valid there. Figure 3 indicates a shallow reverse trend resulting from permafrost under Line 5003 (discussed under "Permafrost" below). Below the permafrost, the ITT vs depth trend is normal (i.e. approximately 8.6 ppg MWE), with no deviations to indicate abnormally pressured intervals above TD. Geothermal Gradient The geoscientists who developed the Nenana basin history postulate that the geothermal gradient here will be slightly higher than Cook Inlet's and will approximate 1.7 °F /100' TVD. This gradient will commence at 32 °F at the base of the permafrost, if any, or at ground level if there is no permafrost present. This implies approximate static downhole temperatures of: 165 °F at the first target depth of 7,829' 200 °F at the second target depth of 9,900' 230 °F at the planned TD of 11,600' These temperatures are not extreme and should present no drilling or logging difficulties. Permafrost The presence of permafrost is clearly indicated in the seismic data as abnormally fast travel times from the surface to the depth at which the travel times abruptly drop to normal and then resume their expected gradual increase with depth. • Figures 4 - 7 show RMS velocities along four of the five seismic lines run over the prospect. The white and yellow (hot) colors at and near the surface of each of them indicate the depth and aerial extent of the discontinuous permafrost on each line. Figure 8 is a "permafrost map" generated from the seismic data. Note that the location of the Nunivak #1 well lies immediately outside the outermost outside edge of the mapped permafrost. While this is also indicated in more detail on the RMS velocity slide for Line 5004 at SP 1510 (the well location, see Figure 8), it is too close to definitively claim that there will be no permafrost at the well location. For drilling planning purposes, it will be assumed that some amount of permafrost will be present. The implications of this from a drilling perspective are 1) the potential for frozen methane hydrates within the permafrost interval, and 2) potential free gas trapped under the impermeable permafrost lens. Drilling planning will take into account these possibilities. Geo- mechanical Plot The information discussed above has been generalized and placed on a "geo- mechanical plot ", Figure 9, which will be utilized in all aspects of planning and permitting this well. 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• S a i 8 a 1 boo fao asca Figure 4 RMS Velocity Plot 5003 Line I I. I,1 1,1 ,121°111 1215t 1 , 1 ,12t°t 1 , 1 12t5t . 12t °t. t 1.1!111, 1,1111,1, 1 I , I.12 I t 12fotIII2It I . ! 12t°t I.112tt L I.1 I, 11 I, I,12t°t I. I, 12t5t I, I, 13ti, I, I, 1 3 t l I, I, 13t° 200— . ' , tom ? 400— S . w 600— *a 800— 1000— = 1200 — 4* • 1400— ....`'i 1600 — ^ 1800 —. ax > ,p, 1 2000 — s, ,r'.. ,3... 2200 — ..... c 2aoo- 1 2600— - 2800— ,,. 3000— y 3200 ts,* 3400 3600 3800 — _... ._..__ _. _..._ _.... 4000— ._ _. ._.. 4200 — �; aa-ot x 4400 — R* *- t .. 4600 ,,.,.::. Nunivak #1 Well Figure 5 RMS Velocity Plot 5004 Line • I. I. i�1 tI Ltzt °tI,t1211i,I,121 °tI.i,L 1° ti, I,121StII °t I,I,1215�1,T,I ° t. tt�f t, I.I,MtI,I, Iti'I, I.I2ttI 127I.t I. ,I,I,Itt,tI,IA0 /, ,txl 2 5 00 - f 900 1000— 1200 1400 — 1600 �k s '& `a i 1800 as 2000 2200 — • 2400 — 2600 — 4 2800 j�� 3000 1. 1St �,� .. -...- � � ... ... .... ..... ._.. -.. 3400 ,� 4 �r 3600 � � � � r c i vy 3800 m ; ✓ � iii �i°/' �� 40 � 4200 "" ice f. ac f% 4400 4600 4800 r a ���y i __ _- Figure 6 RMS Velocity Plot 5005 Line 111'I 1 Ittiiittii i iii11 Itti,Iitti l Iffc r 'f +1,i itti,1,i17 1,1,1,17t1,1 I i i ,i i I I I I i13ti i 1 1 i i, 1,i,i 200 — 400 — 600 800— 1000 — 1200— • 1400 1600 — 3 , 2000 - s '� " R -. "a 1 r .u;. 2200 � -* .,..... .. n <:. . , 1 , 2600 .. .. 2900 „c ,..% 3000 —1 ! r 3200 3400 — - i 3600 'yy 7 • 3800— - _.. __ _. _. _ _ ✓ .: f �9 . s y 4000— ._ _.. ,,, > ...'. . ,%es,'...,.. .. , ..., ..;...., .. :. ._r. .._ 4200 ' 4400 — .. .. ..... .... 4600— ^-" �' x sir >> �� , , , ,; ue y am. r " ,,, �_......... Figure 7 RMS Velocity Plot 5006 Line x �, 1115t l �, IPI °t. �, I I215t 1, 121 °t. �, 121 t. I I.121°t x,121 ,1. �, i t. , I l r , �, I I 21 5t , 11. 1211 II. 1215t I I, ftt, I, I, Iz15t I, I, I111,1,Ii 1, I I ,1 3 Wt I, I. 13 t � t 111 , 200 ` ' 400— ,,;_ `' , � 600 600 — loon • 1200 —' 1400 1600 — .` s , 1600 — ; a, .ate 2000 .. ..... _ E 2400 -' _ - .4�,... 2600 2800 i 3000 —! 3200 3400— y 3600— .. 3800 — 4000 — - v 4200 4400 — - _.. ._ .. ... . .... .... ...._. ... __. _ _.. ___ °,v 4600 —_. Figure 8 Permafrost Map d , -0,,r ev '? /0 O o 00 0 o 91 T3.0S1 r T3 9. T3.OSR8.OW T3 III ._ _ de. °` 0 . � 'moo ,.d 8 7004 �` A �' „...,- „ mows ca , ,. li Maill --,st,._ * - ' ' ' Illr N #1 �° / �p� � ' o a ° _ , 00 i B o 745 P `.a... X0._0. i z , .h y =o rLb o 0. T4.0� 1 W P,;Y � �' Ya- a� 4 �4 02.= '�' T . fik4R 8.OW Ti e Ry / 1... � - CD as 40 -- -e, ^° � � ” roos Nunivak #1 Location 1 • -a T S B , ,. w A l'0 0' ^ T.+ ,s2s/ Co `��Yg,O ^O M + 73 Oo 7;5' ^q ^p ,¢ 7 � l 0' 1E?10.OV1¢/ T5.O;3 -9.OW T5.0SR 8.OW 4.00' �l/ db I 0 Figure 9 Geo- mechanical Plot 8 10 12 14 16 1S 20 o - — ' { litlikh■ Hydrates 1000 P. — Inil bas @ 1800' +/ 150' 2000 -�� Potential far gas below permafrost 9 -5/8" 3000 4000 5000 6000 ud Weigh ihk iocene Usib - II 7000 Pore Press Il G oup 6000` -:000` a rifling Ma 8000 9000 – MEM 1 II 10000 -w- 1 for atior► 9000 1 11000 TD 12000 — 1111 Figure 10 Seismic section Seismic Line SW Nurivak oi Nov 1 Mile - Proposed Loco* ...:;E 104.141 0141,44$ t ■ 4++ ■ OP NI; INC I b liz,, - , , _,,..,.._,,,,, .„.„. ., , l , eiti , , 1411 , , , 14, , , „ , , 141).1) , , '4.,*.■• 4 .4444. ,,* , i 1 ' TA S f 0114 13 31 _ - . - - - -t- - . . - - - . ' ..... - , .. 1 mi ,- . Az Via ' + +4 .,„.. * n ,. ,i i i rms s ., .-1,... -1- - ,-', - vi=ir.. i . ft k 4 - i---- \ , / • - 0 ____ _____ I MINE IZIL ° - 1106g .. , .... ..-7-.... ,.. 44 - ..4ii... .. 4 I ..., 1P3 11111111 - ' .it "'Nis il .. -...........- - ---- ...VV/0ft*. 5 - Arai ,...-- ,......-.......... 1:3 _ _ —__ _ _ 1311 -- , !:' "': Ma. ' '" z.___ 1 ll imp - - — 0 . ... 004 .,. 4011..1 -...- ■ NA: , V2 , 1 - -,, .- , -------Z --a---- .---- 3:0 ID ",-- . -- , „ • - m II& , -*---..-- .......,...V . - . .• - - geo • • . - - . _.• -'''' - 4 01."-- ..4 - - -.4.--,---j-`-' . .. '''' .,,... , --. L "..--."' IKO - ----..."----" ---- _. . , , .7' 1 - ---..,---....-..-..., ,....... Z , . ,. .- '- - • . ZIG _ - .,. . .r. ‘ i% lk ' ' '''' '. - '' • _ , - - - ,,.. _ _ ,,, - ..., : • Figure 11 Nenana Basin Cross Section NENANA BASIN CROSS SECTION SE NW POSE EXTENSIONAL • SAG SEQUENCE ° . ° , ' • STRUCTURAL INVERSION • ` ° , LOWER GRABEN FILL \ . , - . , . , . ., - .. .. • .". „. ' „ 4 { . 1 . . , : ' , • . EXPLANATION L. - "'^"s - - PLEISTOCENE TO RECENT - -"417'64.4...."."'""• ' ` . * \ " �^ Sand grave 4 gat bore and plant. fragments ‘‘,..,\--,--,..... l Sar1. toll 3rrd g444 I USMELLI GROUP w Sards rgaa :one comerake• coal art.. shalt \_ `_ �4 =. POST ` ., �"� INFILL SEQUENCE ° "" ; FLUVIAL SEQUENCE \"`,.. -, - -.� -, .. , San:P anne and oak, r . - LACUSTR w SEQUENCE l Sr Snae dominated so me sandstone a e ° , S OAi28E F LASE 14 5 .° Conglomerate elm elsrsLr s 4 P < - .� - $ ...� ._._.: SOU1�El RESERV'Q�ROCI(S CC w f 0 • EXTENSIONAL dry 1 2000 FEET *-*+� FAULT ;ts rx4ng recd r din eon of rn9�rdmprS SEQUENCE ' \ ,,, HORIZONTAL SCALE s all 1111•1 1 0 u2 1 2MILES Figure 12 Nenana Basin Stratigraphic Sections NENANA BASIN STRATIGRAPHIC SECTIONS NCRTH FLAW( ARCO UtOCAL DEEP NENANA BASIN A " RANGE TOTEK HI i s /1 PENANAli ',EXPECTED) Zsf4P4ML ,, ,- . 7!" eSUPF4Ca, d-,r4 .1 c, Nil 41 !IL Pli0 ) (POO } 440Lo los r ' . GO LOKI ' s*: P11° 3 4..‘ • „, .4 00O NI RLI P .1711,C6 , „. •'" •"," 1 1 l' 1 A , - • 1 ,, to •,,,,,,„,?„ 7.Aki , "M 7 ''- LteustriFe Sc - 7,00a 01 and gas generation windowS Lana prolected Totek Hills #1 maturetoon profile -8,50G (2 8 fl 00 calculated gootnerrnat gradient) trirtitliWid AtipArto ANA,* a " R al ' 01 anti gas we-ration windovvs Lain() i r loom el IS protected Totek His #1 4flaturatoon profile a ! .11,2scr (2 0 /1013' p al gracilednOs In the ueII Is Description Of Geologic Units E OF a II:71 GRAVEL SAND M LT MO CLAY sispo44441/4 - 14 4 000 ' SAWN OONGLo !AERATE ANO Abbarevkttions M COARSE SANDSTONE • NON CONG_CMEgATESANDBIONE 40s) MJRFICIALDEPOSITs MUDETONE COAL AND Mt4OR TUFF MUD 4 PLIOCENE III LAC uSTRINEIALLUvi AL FAN SECluENCE (I/A,MHO ) MIDDLE MIOCENE VOL CANICS 1- 1/10 ) EMILY MIOCENE METAUORPHC BASEMENT i 4E 4 EOCENE FAULTS FF1 F. )T, Ff...i -r `r - ' f.• wow. Lt4CONIFORIVITY I • Nunivak #1 0 1000 Drilling _2 -1/4 hole to 2500' 2000 • • Set 9 -5/8" Casing, Change 3000 Mud Sjstem, Conduct LOT 4000 5000 6000 Drill 8 -1/2" hole d 7000 8000 9000 10000 \\\I/ Set 7" Casing 11000 • • A • • • • 12000 - - Well completion and Testing 13000 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 Days • R A P T --- Nunivak #1 4 l 16" conductor set 100' MD /TVD F'� 12 1/4" Hole /30---., (Freeze protect) - 1700' - Possible Permafrost 1000' -6000' Pliocene Nenana Formation 9.5/8 ", 40 #, L -80, BTC csg 1 2500' MD /TVD Mud 6000' -9000' Miocene Usibelli Group Shallow S -shape @2500' -7000' TOC - 7200' 8.5" Hole 4 -Class 15.8# cement 9000'- 11,600' Cantwell Formation ii TD 11652' MD /11,600' TVD 7 ", 26 #, L -80, BTC csg • • Nunivak #1 Proposed Estimated Depths in Feet TVDSS Surface Fluvio- glacial gravels (Quaternary) and "Nenana Gravel" (Pliocene): — - 1000' sandstone, conglomerate - -1700' B/ Permafrost — -2000' -2200' Coal- bearing Interval: shallow, high amplitude reflectors; 3000' coal, lacustrine shales, sandstone /conglomerate — - 3200' Transparent Seismic Interval: few reflectors; — - 4000' sandstones, shales -4250' — -5000' Coherent Low Amplitude Seismic Reflectors Interval: ® coherent, low amplitude reflectors; possible interbedded coals, shales, and sandstones — -6000' -6400 Coherent Seismic Reflectors Interval: 7000' coherent reflectors; lacustrine or fluvial /deltaic sandstones, conglomerate, and shales — -8000' - -8150' PRIMARY TARGET: coherent seismic reflectors, AVO Nolommimmn — -9000' - -9400' SECONDARY TARGET: coherent seismic reflectors, AVO - 10 ,000' r Key — - 11,000' I I imemin■i P ermafrost 11,600' TO n G ravel ' I S andstone/ Conglomerate/ Shale r — u Sandstone or sandier interval Coal Shale or shalier intervals • • irX AM PART -. Maximum Anticipated Surface Pressure: 12 -1/4" Hole Section This hole section will be drilled with a diverter only, no BOPs. While MASP will equal the formation pore pressure at the surface casing shoe depth of 2,481' less a gas gradient to the surface, it cannot be shut in, only diverted. Well information indicates that the pore pressure at 2,500' TD will be a maximum of 8.9 ppg (or 0.463 psi/ft). Calculations for MASP (12 -1/4" hole) = 2,500' (0.463- .11) = 883 psi 8 -1/2" Hole Section The maximum anticipated pressure (MASP) for the 8 -1/2" hole section in this well will be the formation pore pressure (less a full gas column to the surface) at 11600' MD. Seismic data indicates that the pore pressure at TD will be a maximum of 9.6ppg (or 0.499 psi /ft). Calculations: 8 -1/2" hole section MASP (pore pressure) = 11600'* (0.499- .11) = 4512 psi MASP in the 8 -1/2" open hole section is expected to be 4512 psi, however 10,000 psi BOPE system be used since this well will be drilled in an unknown area. Well Proximity Risks: The closest wellbore to this one is Nenana #1 located approximately 12.5 miles West. Directional simulation indicates there will be no interference expected between wellbores. Disposal of Muds and Cuttings: Drill cuttings will be disposed of at the Nenana landfill. Waste drilling fluid will be retained on location until an annulus is available in the well. Waste drilling fluid will then be disposed of down the annulus per an Annular Disposal Permit from the AOGCC. sios AMP RT - --�. Nunivak #1 Casing Design Verification Planned Casing program 9 -5/8" 7" Surface Casing Production Casing Depth (MD) 2,500' 11,652' Depth (TVD) 2,500' 11,600' Hole size 12 -1/4" 8 -1/2" Weight (ppf) 40.00 26.00 Grade L -80 L -80 Connection BTC BTC -M Nominal ID (in) 8.835" 6.276" API Casing Design Factors Design factors are essentially "safety factors" that allow the design of safe, reliable casing strings. Each operator may have his own set of design factors based on his experience and the condition of the pipe. Here we use standard recommended design factors. Design Factors: Tensile Joint Strength: Nt = 1.8 Collapse (from external pressure): Nc= 1.125 Burst (from internal pressure): Ni = 1.1 The pore pressures and fracture gradients used here are those derived from geological and seismic work performed in development of this project. • Design Factor Calculations Burst Requirements Use maximum anticipated surface pressures (MASP) for each casing string. For each casing string MASP is the formation pressure at the next casing point less a gas column to surface. 9 -5/8 ", 40 #, L-80, BTC Surface Casing: MASP at 8 -1/2" hole section TD of 11,600': MASP = (11,600') ((9.6 ppg x 0.052) -0.11 psi/ft) = 4512 psi Frac Pressure at 9 -5/8" casing shoe = 12.6 x 0.052 x 2,500' = 1638 psi DFb = burst strength / burst stress = 5,750 psi / 4512 psi = 1.27 7 ", 26 #, L-80, BTC -M Production Casing: Maximum burst stress is formation hydrostatic pressure at TD less a gas column to surface: Burst stress = (11600') ((9.6 ppg x 0.052) -0.l 1psi/ft) = 4512 psi DFb = burst strength / burst stress = 7240 psi / 4512 psi = 1.6 Collapse Requirements Use an external pressure consisting of the formation pore pressure at the casing shoe and an internal pressure of a gas column to surface. 9-5/8", 40 #, L-80, BTC Surface Casing: External pore pressure = 8.9 x 0.052 x 2,500' = 1157 psi Internal pressure w /gas only = 0.11 x 2,500' = 275 psi Collapse stress = 1157 psi - 275 psi = 882 psi DFc = collapse rating / collapse stress = 3,090 / 882 = 3.5 % • 7", 26 #, L-80, BTC -M Production Casing: External pore pressure = 9.6 x 0.052 x 11600' = 5791 psi Internal pressure w /gas only = 0.11 x 11600' = 1276psi Collapse stress = 5791 psi — 1276 psi = 4515 psi 0 DFc = collapse rating / collapse stress = 566psi / 4515 psi = 1.2E( c; Lei 0 Tension Check Use buoyed weight of casing in mud having the expected density when running the pipe. 9-5/8", 40 #, L-80, BTC Surface Casing: Weight in air = 2,500' x 40 lb/ft = 100000 # Pipe weight in fluid = Pipe wt.(in air) x Buoyancy Factor 100000 # x 0.8548 = 85480 # DFt = body tensile strength / buoyed wt = 916,000 # / 85480 # = 10.72 7", 26 #, L-80, BTC -M Production Casing: Weight in air = 11600' x 26 lb/ft = 301600 # Pipe weight in fluid = Pipe wt. (in air) x Buoyancy Factor Pipe weight in fluid = 301600 # x 0.8365 = 252288# b DFt = joint tensile strength / buoyed wt = 604000 # / 252288 # = 2.39 • • RAMP R Nunivak #1 8 10 12 14 16 18 20 0 likli 6• Hydrates 1000 b ase @1800' +1 - i50' 2000 ` for gas � Potential below permafrost Frac Grad • - 5/8" 3000 - -- Pliocene Nenana Form. 1000'- 4000 6000' 5000 6000 i 6000 ud Weight ocene Usib- Ili Pore Press. oup 6000' - 9000' rilling Mar: in) 8000 9 I 1 1 000 Some Coal layers 1 1 1 — 10000 III C. ntwe orm . tion 1 9100' - TI 11000 TD 12000 • • Incorporation and Use of a 10K psi BOP stack on Arctic Wolf #2 The drilling fluid circulating system on the Arctic Wolf #2 is rated to 5K psi WP, but Rampart Energy plans to utilize a 10K psi WP BOP stack for drilling the Nunivak #1. The BOP stack will be utilized with the rig systems for well control as follows (refer to the diagram on the following page): The BOP rams and the manual and HCR valves on both the choke and kill sides will be rated to 10K psi WP. Also rated to 10K psi will be the choke manifold and choke line between the choke HCR and the choke manifold. The kill line between the kill HCR and the standpipe will remain rated a�iisi. Should a kick occur requiring less than 5K psi to kill, the circulating and well control system will be used as -is. If a kick occurs that requires more than 5K psi applied to the kill line, the existing 5K psi kill hose N , would be disconnected at the double studded adapter outboard of the kill -side HCR valve and a high- pressure cementing pump connected to pump into the kill side of the stack (see the diagram on the following page). N. 4W/ N.:`, r \ I /' 1 ARCTIC WOLF 10M SHAFFER 5M STAND PIP STACK LAYOUT • 6 0 3-118" 5M GATE VALV ---- l 3' 5M KILL LINE HOS J . - h 11111L!,...tmi L* * we . . !MI! 1 ( I 11W L i 71 • , fit- !� - ∎ *Dy we ∎!,I, WELL CONTROL OVER 38101 MN WOULD REQUIRE BREAKING DSA —` Y� t FROM HCR AND CONNECTING • r l �� 1 �I, iM ' } 1041 I-- C RCULATING OV R M N. Ni tOM CHOKE HOSE.. I,_ I ... HALLIBURTON LINE 1116" 10M x 3-1,8" 5M DSA 3- 1116° 10M HCR VAL •, r i �. i 71„ . �.'� 1116" 10M HCR VALVE 3 -1/16" 10M MANUAL VALV 11! CI '' _ 11 1 0. � '� �` _ � � � / 3- 1116" 1 OM MANUAL VALVE me • • 1 v....., ..,, t i , / / NIII ' I — [ ,.. r --, P ill , ., . , . . .,.. ..,,,, ) ) • - 1 ... . I ... n i . r . - 1 co 11 11.1 -.. • . AP" , , ... ., —.war •• -, ,-.4 , ,,,,;„ , , i, ,... . . . .. .. .... . A - - ‘, . . — .. . gialmumummin io, i J , A #4‘ ' . • Mir . ' k ,. ... .... ... .,... . • ' *., 11. WOW, 111114, • • M AERO RENTAL SERVICES Customer: Doyon Drilling Inc. 3201 C Street, Suite 700 Anchorage, Alaska 99503 Attention: Ron White 907 -565- 4255/907 -563 -5530 email: rwhite a(�doyondriIIinq.com Rig Doyon Drilling Location : Fairweather E & P Services Inc. Fairbanks Alaska Qty Descriptions 1 11" 10,000# Shaffer Spherical Annular Bop 1 11" 10,000# Shaffer Type SL Double Gate Bop Studded Top / Bottom c/w Pipe Rams / CSO Blind Rams Finings etc. 1 11" 10,000# Shaffer Type SL Single Gate Bop Studded Top /Bottom c/w Pipe Rams , Fittings etc. 1 11" 10,000# x 11" 10,000# Rotating Drilling Spool c/w 3 1/16" 10,000# Flanged Outlets 2 31/16" 10,000# Flanged Nace Trim Gate Valves 2 3 1/16" 10,000# Flanged Nace Trim HCR Valve 7 31/16 "10, 000 #x31/16'10, 000# x31 /16 "10,000 #x31/16 "10,000 #4 Way Studded Blocks 2 31/16" 10,000# x 3 1/16' 10,000# x 3 1/16" 10,000# x 3 1/16" 10,000# 4 Way Rotating Studded Blocks 4 31/16" 10,000# Blind Companion Flange 1 3 1/16" 10,000 x 3" 1502 Weco Companion Flange c/w 1/2" NPT Test Plug 1 3 1/8" 5,000# x 31/16" 10,000# DSA Flange 1 3 1/16" 10,000# Double Flow Choke Manifold c/w Heater , 4 Wire 4 Pole Extension Cord & Stand Pipe Hose and Gauge 3 31/16' 10,000# x 20' Flanged Flow Line Nace Trim 2 31/16' 10,000# x 15' Flanged Flow Line Nace Trim 2 3 1/16' 10,000# x 10' Flanged Flow Line Nace Trim 1 3 1/16' 10,000# x 4' Flanged Flow Line Nace Trim 1 31/16' 10,000# x 3' Flanged Flow Line Nace Trim 1 31/16' 10,000# x 2' Flanged Flow Line Nace Trim 14 Sets 1" x 71/4" L7M Flange Bols & Nuts Totals Doyon Drilling Preferred Customer Discount 11" 10,000# Flow Nipple and Ring Gaskets Sale Items Prices May Change With The Addition or Subtraction of Equipment Any third party equipment required to complete this order will be charged back at the the current rate. All Inspection Charges, Repairs and/or Replacement Costs Would be for the Account of the Lessee at the Then Current New Replacement Cost Aero Rentals would like thank you for the opportunity to provide a cost for your up coming Project and if you have any questions please contact us. Either Ken Keith In Red Deer 403 - 340 -0800 or Cell 403 -506 -3199 or Scott Odegard 403 - 340 -0800 or Cell 403 - 896 -1727 1 co) :•=-=--- =.. _1 1 0 1 IL ......... i..., 1=--.: M 1110 C: l'ilT - ' 1 ti r, pliic)41-* I , 1 3 1/16" 10,000 HCR L1 V likitri . 1 - *--4■,_ _ At - `' 1110 Valve 1.1 US Gallons 'ttliP ■•■■>;t1 VA ' to close 11" 10,000 Shaffer Wedge Top Spherical 53 isp1!ifr4,11:70.,,,' i. 11117 •. .1 . . I.. 30.50 uS Gal to Close 1114:4 "N ••11 - ...'N ,./(,..., 1■11114 III •.1. r - o pi MI fl. C:1 11 10,000 Shaffer SL 1 1 , , M11111211111 0 .1101■1 , Double Gate Studded 3 1/16 10,000 x . E■Eimi • all imi■ . Top/Bottom 145.5 3 1/8" 5000 ■ 9.45 US Gal to Close 42 Total Stack DSA Flange ' ...-.11111M1 hi I I IL IVINI : Per Cavity ID MME3111111 bizi Illa ci c/w one set of Pipe Rams Height and CSO Blind Rams ■111 ' . = WIN11117— , . ... _.. . .. 11" 10,000 x 11" 10,000 - -.41 4 l■ - 4 V*:44tti!: Ir.`-p-Al(E*)..41 Rotatin w 1 g Drilling Spool - -.0 ag -4 a l op Ai .0 Vac c/ 3 /16 10,000 26 Flanged outlets 1 • .......,... •,919 a er • MM11111.4 III 111 1115 - 11 1_1111M Single Gate Studded 24.5 1 .._ —........ UM MERilill gip. Elm , in Tap/Bottom . ii Cl 9 45 US Gal to Close - == •11111 ! -- - i AE Ro c/w one set of Pipe Rams 1 il ..".."-•••• 18 18 _ RENTAL SERVICES __....... 4 24.375 24.375 36.5 24.375 24.375 PROPRIETARY AND CONFIDENTIAL 1 34 THE INFORMATION CONTAINED IN THIS ---- - -- _ DRAWING IS THE SOLE PROPERTY OF AERO RENTAL SERVICES ANY 1 SIZE REV REPRODUCTION IN PART OR AS A WHOLE Doyon Drilling WITHOUT THE WRITTEN PERMISSION OF AERO RENTAL SERVICES IS PROHIBITED. DO NOT SCALE DRAWING SCALE: I :50 WEIGHT: SHEET I OF 1 1 ,. _. 5 4 3 2 1 J ARCTIC WOLF 10M SHAFFER 1 • STACK LAYOUT 5M STAND PIP G 3 -118" 5M GATE VALV \- 1 ni 3" 5M KILL LINE HOS ��� - k ® ~I 1 , 4 I- i • imliFig: V,0 =Atm; - '4.... �a Vii' - • _ — II c=B !1L,,,..., ' , , r•.,., LIM 1 WELL CONTROL OVER 10M Mal WOULD REQUIRE BREAKING DSA FROM HCR AND CONNECTING j 1 � 1 HALLIBURTON LINE FOR 11101 l _ I { . I e i CIRCULATING OVER 5M _I _I 10M CHOKE HOS "" "' "' "' • • -1/16" 10M x 3-1/8" 5M DSA 3- 1/16" 10M HCR VALV !i _ W � X71= - 1/16" 10M HCR VALVE 3- 1/16" 10M MANUAL VALV ® 111:0€01: DI C4.I _ ‘:) _ - 1/16" 10M MANUAL VALVE i1MD •1 -� • 1 •- I — -L E LE . 11==":1 1 1 ... . i . i i 'EA - LL H -E I , 1 1 T. , . 4....--:-.11,L.:- , 7 LT% ° - - It • . , "1-1-- ito I . fr. 19.....a T ii...........:,...... Fl 1 - E E . I- I 1 AI. I .........—-1 • • - 4 . . 1 =11111 111.1. T , X -1rtillik-E2i " ir Ell--tri■ - :I: 1 . '11 ', 1 -U. lif L 0 r _ i r ii 1 11 2/ 1 -- 0 --z-c-r gig . , . tit 4E1 ..-- . ... .1 .05C ..ILE 1 -..auz__. .-ii 1 -.....-, '■ 10 ", . , ■ , ,ir i f . 1 ' T* =IWO. oin■ ■ R.. I 11.-- f I , it - :: I I + . . .... , ..., : I-T ;:... F L' 1 I 11111111 • I C 11 -E .TE L'Ail. I .. H. I ... illiT " LE ---- - 1 . 1-r I 1111 1 I 1'1 E 1 04t :'k - r t' tr-T 2: '4.1 1 1 ---0 = 1 EE63 .--- 1 - 1 ,-- 2- - i T 5 T 110,a. IT riTIE 711E n- I . ..- if- E ' t : l efflY an IMP III2 2 . - F - E 1E t - Xi AI .. . 111.11 IMP SYSTEM ikton teINTRCI. CC1 :=1 42 l' 7 -::' -..- C,11, I . '4111`, • • ITEM DESCRIFRON 1 279 mm .34500 kPo (11" SKI SHAFFER SPHERICAL 2 279 rnrn 34500 kP! (11" 5<) SHAFFER DOVE/LE GATE 3 279 mm 34500 kPo 11" 51() GRILLING SPOOL 4 279 mm 34500 kPo (11" ) SHAFFER SINGLE t A1E i { tr..................... ii. IiiiIiiiiiiIIIII II Mill . . t -., . . 0 as . a+ III t ` ita* — E+1 {t` ' CI ] ar, tr A '.ii i iI . „4- a a II II Aili S!” yr } . I ammo - 11"n , -- .111 l IN t t� FBI { �rl ] in tor 'w,at in r II :: P.,„, „wt .t rr+ait arabo� . *400 RVJ 6' tor *aW OMUTAdilbo Lit lug, i ssarna 7 .. f 1 nM .. w `' a.■ IffP94144;4144 he ed.i. w MiatxMwA ill. 10■109.4,.MO VIVA eSMI W.1 COCAS Stall art re 11' vows "gringo mow d MBA Mins . Mid to arm Wm Mara . IMIIIIMIIM SiR Urk lor awriliblUe. re r41 Td 0114116540101 r FIOTE: THE FLANGE ON A 20' JOINT OF ( 16" t=1NE WOULD HIT THIS ANGLE BRACE — 1I1INES MADE 21' TO AVOID THIS BRACE) 11 ' 1 w.w '1 1IIII1 1 1 ∎1 1��1 ` 111101 \ ":_li - _ - -=vat IIII', =. ���.wwwwllll IL".I ills Line must extend at least Fi fl MI .∎illar�aMI 100' past the floor motors � exhaust N. \ 21'-0" 21 P. l iona jymi • 1' -10 EMI -...=.• lailiiiIIIIIII ii al II MIMI II II■1 IMMII W. an. ow VOYON !I ll' ll.l1-- DRILLING ■ 14KR�! F wliuirlc 1Tn ,I` IA = kX T9E n (8 " 70)955-6700 I riVi i I L 1 Ji 40 „ _ _ liak 1— I , 11 I N '1 , I AKITAJV. is prohibited. � �.. � 40 — — _ M ay 31, 06 NTS / T ls�� t I ) DDI 20indiverter 11 Arctic Wolf Lid ... 21 }° 2000 psi Diverter -' Assembly General Layout '�,, K , } 300' ' + Drilling Docks Al AV .4 s/ •. /4".47,0,,, i e 4 /40,, 4 4 1 1/ ► ► f4// All, 44tfiN 4f 1► / zir 440a. ���r' t /►I- c aka i t ill 4,0 ��� it V.' � O 4 %4 ►j. 4 / fi 1 p ..if eV), 44P 4 44 4 i t cn 0 0 KITCHEN / DINING 12X60' EA. i D Ot D N y N D " r 0) o r D. 0 l • C C WATER / SEWAGE WATER / SEWAGE 12'X40' EA. 12'X40' EA. —I J 1 lirt AMPA .. $cblumberger Nunivak 1 (P1) Proposal Report Date: March 17, 2009 Client: Rampart Survey /DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 73.340° Field: Nenana River Structure / Slot: Nunivak 1 / Nunivak 1 Well: Nunivak 1 Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: KB TVD Reference Elevation: 378.00 ft relative to MSL Borehole: Nunivak 1 Sea Bed / Ground Level Elevation: 360.00 ft relative to MSL UWI/API #: 50083xxxxx00 Magnetic Declination: 20.632° Survey Name / Date: Nunivak 1 (P1) / March 17, 2009 Tort / AHD / DDI / ERD ratio: 17.954° / 695.13 ft / 4.098 / 0.060 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location Lat/Long: N 64.57199647, W 149.21524676 Total Field Strength: 56802.034 nT Magnetic Dip: 76.791 ° Declination Date: March 04, 2009 Magnetic Declination Model: BGGM 2008 Location Grid WE Y/X: N 3864303.700 ftUS, E 623390.500 ftUS North Reference: True North Grid Convergence Angle: +0.70873890° Total Corr Mag North -> True North: +20.632° Grid Scale Factor: 0.99991731 Local Coordinates Referenced To: Well Head • Measured Azimuth Vertical NS EW Mag / Gray Directional Comments Inclination Sub -Sea TVD TVD DLS Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty (ft) (deg) (deg) (ft) (ft) I (ft) I (ft) (ft) (deg) (deg/100ft ) Index (ftUS) (ftUS) KBE 0.00 0.00 73.34 - 378.00 0.00 0.00 0.00 0.00 - -- 0.00 0.00 3864303.70 623390.50 N 64.57199647 W 149.21524676 16" Conductor 100.00 0.00 73.34 - 278.00 100.00 0.00 0.00 0.00 - -- 0.00 0.00 3864303.70 623390.50 N 64.57199647 W 149.21524676 1000.00 0.00 73.34 622.00 1000.00 0.00 0.00 0.00 - -- 0.00 0.00 3864303.70 623390.50 N 64.57199647 W 149.21524676 2000.00 0.00 73.34 1622.00 2000.00 0.00 0.00 0.00 - -- 0.00 0.00 3864303.70 623390.50 N 64.57199647 W 149.21524676 9 -5/8" Csg 2500.00 0.00 73.34 2122.00 2500.00 0.00 0.00 0.00 - -- 0.00 0.00 3864303.70 623390.50 N 64.57199647 W 149.21524676 KOP Bld 1.5/100 2600.00 0.00 73.34 2222.00 2600.00 0.00 0.00 0.00 73.34M 0.00 0.00 3864303.70 623390.50 N 64.57199647 W 149.21524676 2700.00 1.50 73.34 2321.99 2699.99 1.31 0.38 1.25 73.34M 1.50 0.29 3864304.09 623391.75 N 64.57199750 W 149.21523879 2800.00 3.00 73.34 2421.91 2799.91 5.23 1.50 5.01 73.34M 1.50 1.20 3864305.26 623395.50 N 64.57200057 W 149.21521487 2900.00 4.50 73.34 2521.69 2899.69 11.77 3.38 11.28 73.34M 1.50 1.72 3864307.22 623401.74 N 64.57200570 W 149.21517503 3000.00 6.00 73.34 2621.27 2999.27 20.92 6.00 20.05 HS 1.50 2.10 3864309.95 623410.47 N 64.57201287 W 149.21511928 3100.00 7.50 73.34 2720.57 3098.57 32.68 9.37 31.31 HS 1.50 2.39 3864313.46 623421.69 N 64.57202209 W 149.215 50 End Bld 3198.47 8.98 73.34 2818.02 3196.02 46.79 13.42 44.82 - -- 1.50 2.62 3864317.67 623435.15 N 64.57203315 W 149.214 4000.00 8.98 73.34 3609.74 3987.74 171.86 49.28 164.64 - -- 0.00 3.19 3864355.01 623554.51 N 64.57213118 W 149.21419978 5000.00 8.98 73.34 4597.49 4975.49 327.90 94.02 314.13 - -- 0.00 3.47 3864401.59 623703.41 N 64.57225349 W 149.21324916 6000.00 8.98 73.34 5585.24 5963.24 483.93 138.76 463.61 - -- 0.00 3.64 3864448.17 623852.32 N 64.57237579 W 149.21229853 Drp 1.5/100 7053.65 8.98 73.34 6625.98 7003.98 648.34 185.90 621.12 LS 0.00 3.77 3864497.25 624009.22 N 64.57250465 W 149.21129690 7100.00 8.28 73.34 6671.81 7049.81 655.30 187.89 627.78 LS 1.50 3.81 3864499.33 624015.86 N 64.57251010 W 149.21125453 7200.00 6.78 73.34 6770.94 7148.94 668.40 191.65 640.34 LS 1.50 3.88 3864503.24 624028.37 N 64.57252037 W 149.21117468 7300.00 5.28 73.34 6870.39 7248.39 678.91 194.67 650.41 LS 1.50 3.94 3864506.38 624038.39 N 64.57252861 W 149.21111066 7400.00 3.78 73.34 6970.07 7348.07 686.81 196.93 657.97 LS 1.50 3.99 3864508.74 624045.93 N 64.57253480 W 149.21106252 7500.00 2.28 73.34 7069.93 7447.93 692.10 198.45 663.04 73.34M 1.50 4.04 3864510.32 624050.98 N 64.57253894 W 149.21103030 7600.00 0.78 73.34 7169.89 7547.89 694.77 199.21 665.60 73.34M 1.50 4.08 3864511.11 624053.53 N 64.57254104 W 149.21101402 WellDesign Ver SP 2.1 Bld( users) Nunivak 1 \Nunivak 1 \Nunivak 1 \Nunivak 1 (P1) Generated 4/14/2009 11:18 AM Page 1 of 2 Measured Azimuth Vertical NS EW Mag / Gray Directional Comments Inclination SulrSea TVD TVD DLS Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty (ft) (deg) (deg) I (ft) (ft) I (ft) (ft) (ft) (deg) (deg/100ft ) Index (ftUS) (ftUS) End Drp 7652.11 0.00 73.34 7222.00 7600.00 695.13 199.32 665.94 - -- 1.50 4.10 3864511.22 624053.87 N 64.57254132 W 149.21101185 8000.00 0.00 73.34 7569.89 7947.89 695.13 199.32 665.94 - -- 0.00 4.10 3864511.22 624053.87 N 64.57254132 W 149.21101185 9000.00 0.00 73.34 8569.89 8947.89 695.13 199.32 665.94 - -- 0.00 4.10 3864511.22 624053.87 N 64.57254132 W 149.21101185 10000.00 0.00 73.34 9569.89 9947.89 695.13 199.32 665.94 - -- 0.00 4.10 3864511.22 624053.87 N 64.57254132 W 149.21101185 11000.00 0.00 73.34 10569.89 10947.89 695.13 199.32 665.94 - -- 0.00 4.10 3864511.22 624053.87 N 64.57254132 W 149.21101185 TO / 7" Csg 11652.11 0.00 73.34 11222.00 11600.00 695.13 199.32 665.94 - -- 0.00 4.10 3864511.22 624053.87 N 64.57254132 W 149.21101185 Legal Description: Northing (Y) fftUSl Easting (X) (ftUSI Surface : 4106 FSL 5193 FEL S17 T4S R8W FM 3864303.70 623390.50 TD / BHL : 4305 FSL 4527 FEL S17 T4S R8W FM 3864511.22 624053.87 III III WellDesign Ver SP 2.1 Bld( users) Nunivak 1 \Nunivak 1 \Nunivak 1 \Nunivak 1 (P1) Generated 4/14/2009 11:18 AM Page 2 of 2 • • RA P Schlumberger FIELD STRUCTURE WELL Nunivak 1 (P1) Nenana River I Nunivak 1 Magnetic Parameters Surface Location NA1727 Alaska Slate Planes, Zone 04, US Feet Model. BGGM 2008 6.791° Dale Marc)) 04. 2009 tat 9643419.187 Northing. 3864303 70 BUS G7d Conv. +070873890° Sb �Ilaneo NUniva47 74/0 Ref'. KB 078 00 ft above MSL) Mag Dec. +20.632° FS 568020 n7 Lan. W109 12 54 888 East, 623390 50 BUS Scale Fad'. 09999173123 Plan Nunivak I (P1) Smy Date March 05.2009 -3000 -1500 0 1500 3000 0 KB 0 16" Conductor 1500 1500 9-51w. 110 KOP Bid ld 11.5/101 1 3000 3000 End Bld 4500 4500 0 0 10 c II 6000 6000 m To 0 Drp .51100 7500 7500 End Drp 9000 9000 10500 10500 TD 17" Csg nivak 1 pig -3000 -1500 0 1500 3000 Vertical Section (ft) Azim = 73.34 °, Scale = 1(in):1500(ft) Origin = 0 N / -S, 0 E / -V RA PART SChlumberger WELL STRUCTURE Nunivak 1 (P1) I FIELD Nenana River I Nunivak 1 Magnetic Parameters Surface Location NAP" Alaska State Planes, Zone 04, US Feet Miscellaneous Model 05502008 Dip: 76.791 Date: March 04,2009 Lat 3264 34 19 187 Northing. 386430370 flUS Grid Cony: +070873890° Slot Nunivak 1 ND Ref KB(37800 ft aeove MSL) Mag Dec: +20932° FS 56802 0 nT Lon. W149 12 54 988 Easting 62339050 SUS Scale Fact 0.9999173123 Plan: Nunivak 1 (P1) Srvy Date: March 17. 2009 0 100 200 300 400 500 600 700 300 t 300 N .- TD17 "Cs. End Drp Nunivak 1 (P1) Drp 1.5/100 A 200 200 A A Z 0 0 c_ ii 100 100 m U 1n (n V V V 0 0 • End Bld KBE KOP Bid 1.5/100 6" Conductor 9.516" Cog -100 -1 00 0 100 200 300 400 500 600 700 «< W Scale = 1(in):100(ft) E »> • • Proposal No: 1001117843E Fairweather Expl & Prod Inc Nunivak #1 Nenana Basin Field Alaska May 1, 2009 Well Proposal Prepared for: Prepared by: Alexey Sachivichik Kenneth Nix Senior Drilling Engineer District Technical Supervisor Fairweather E &P Services, Inc. Kenai, Alaska Bus Phone: 907 - 258 -3446 Mobile: 907 575 7315 aftio P0wERVIsI0N POW ERPRO • POWE RTRAX • POWERLINK Service Point: Service Representatives: Kenai Rod Edwards Bus Phone: (907) 776 -4084 Account Manager (907) 659 -2329 Kenai, Alaska Fax: (907) 776 -4087 Bus Phone: 907 - 349 -6518 Mobile: 907 - 229 -6536 Gr4105 Operator Name: Fairweather Expl Illod Inc • !_ Well Name: Nunivak #1 L Job Description: 9 5/8" Cold Set Lead / Tail Date: May 1, 2009 Proposal No: 1001117843E JOB AT A GLANCE Depth (TVD) 2,500 ft Depth (MD) 2,500 ft Hole Size 12.25 in Casing Size/Weight : 9 5/8 in, 40 Ibs /ft Pump Via 9 5/8" O.D. (8.835" .I.D) 40 Total Mix Water Required 7,977 gals Spacer Mud Clean II 20 bbls Lead Slurry Cold Set Lead 596 sacks Density 11.9 ppg Yield 2.03 cf /sack Tail Slurry Type I Tail 139 sacks Density 12.0 ppg Yield 2.50 cf /sack Displacement Displacement Fluid 184 bbls Report Printed on May 1 2009 1 35 PM Page 1 Gr4109 STIMULATION o CEMENTING o COMPLETION SERVICES o SERVICE TOOLS o COILED TUBING PRODUCTION CHEMICALS o CASING AND TUBING RUNNING SERVICES o PIPELINE SERVICES a WELL CONTROL Operator Name: Fairweather Expl eipod Inc • Well Name: Nunivak #1 Job Description: 9 5/8" Cold Set Lead / Tail k.i Date: May 1, 2009 Proposal No: 1001117843E WELL DATA ANNULAR GEOMETRY ANNULAR I.D. DEPTH(ft) (in) I MEASURED 1 TRUE VERTICAL 11.000 CASING 1 100 1 100 12.250 HOLE 1 2,500 1 2,500 SUSPENDED PIPES DIAMETER (in) WEIGHT DEPTH(ft) O.D. I.D. (Ibs /ft) MEASURED 1 TRUE VERTICAL 9.625 8.835 I 40 I 2,500 1 2,500 1 Float Collar set @ 2,420 ft Mud Density 9.60 ppg Est. Static Temp. 80 ° F Est. Circ. Temp. 80 ° F VOLUME CALCULATIONS 100 ft x 0.1547 cf /ft with 0 % excess = 15.5 cf 1,900 ft x 0.3132 cf /ft with 100 % excess = 1191.7 cf 500 ft x 0.3132 cf /ft with 100 % excess = 313.9 cf 80 ft x 0.4257 cf /ft with 0 % excess = 34.1 cf (inside pipe) TOTAL SLURRY VOLUME = 1555.2 cf = 277 bbls Report Printed on May 1, 2009 1 35 PM Page 2 Gr4115 STIMULATION . CEMENTING . COMPLETION SERVICES • SERVICE TOOLS . COILED TUBING PRODUCTION CHEMICALS a CASING AND TUBING RUNNING SERVICES . PIPELINE SERVICES . WELL CONTROL Operator Name: Fairweather Expl ed Inc • Well Name: Nunivak #1 Job Description: 9 5/8" Cold Set Lead / Tail Date: May 1, 2009 Proposal No: 100111 7843E FLUID SPECIFICATIONS Spacer 20.0 bbls Mud Clean II VOLUME VOLUME FLUID CU -FT FACTOR AMOUNT AND TYPE OF CEMENT Lead Slurry 1207 / 2.0 = 596 sacks Class G Cement + 43.4 Ibs /sack A -10 + 10.55 Ibs /sack Calcium Chloride + 0.15 Ibs /sack R- 7 + 0.25 Ibs /sack FL -52 + 4 Ibs /sack Sodium Metasilicate + 1.25 Ibs /sack A -11 + 2.5 Ibs /sack LCM -1 + 0.05 Ibs /sack Static Free + 0.001 gps FP- 6L + 339.6% Fresh Water Tail Slurry 348 / 2. = 139 sacks Type I Cement + 0.05% bwoc Static Free + 2% bwoc Calcium Chloride + 22% bwoc LW -6 + 0.1% bwoc FL -63 + 0.3% bwoc CD -32 + 0.1% bwoc ASA -301 + 1 gals /100 sack FP -6L + 2% bwoc Sodium Metasilicate + 20% bwoc MPA -1 + Displacement 183.5 bbls Displacement Fluid CEMENT PROPERTIES SLURRY SLURRY NO. 1 NO. 2 Slurry Weight (ppg) 11.90 12.00 Slurry Yield (cf /sack) 2.03 2.50 Amount of Mix Water (gps) 10.95 10.42 Amount of Mix Fluid (gps) 10.96 10.43 Cement additives are subject to change based on actual well conditions and lab testing. Lead slurry is a Cold Set cement This tail slurry is a higher quality slurry expected to gain 500 psi in 10 hours or less. (to be verified in the lab) Report Printed on May 1 20091 35 PM Page 3 Gr4129 STIMULATION a CEMENTING o COMPLETION SERVICES a SERVICE TOOLS o COILED TUBING PRODUCTION CHEMICALS a CASING AND TUBING RUNNING SERVICES o PIPELINE SERVICES o WELL CONTROL BJ Services CemFACTS Program Version 2.00 Job Number: Customer: Fairweather Well Name: Nunivak Nunivak #1 Service Information Design Date: 4/27/09 Customer: Fairweather Well: Nunivak Nunivak #1 State: AK Customer Representative: Alexey Sachivichik Service Type: Cement Service District / Boat: Kenai BJ Representative: Rod Edwards Comments: Production • Well Description Well Depth: 11600 ft Shoe Depth: 11600 ft Landing Collar Depth: 11560 ft Cement Top: 7200 ft Previous Shoe Depth: 2500 ft Surface Temperature: 32 °F Static BHT: 230 °F Circulating BHT: 140 °F Surface Line Length: 0 ft Surface Line ID: 1.750 in Cement Excess: Increase Hole Size(s) Deviation Meas. Vert. Incl. Azimuth Depth Depth Angle Angle • ft ft deg deg 11600 11600 0.0 0.0 Hole Dia. From To in ft ft 8.835 0 2500 8.500 2500 11600 BJ Services 1 04/27/09 p BJ Services CemFACTS Program Version 2.00 a Job Number: Customer: Fairweather Well Name: Nunivak Nunivak #1 Casing OD ID Weight From To in in ibm /ft ft ft 7" 26# 7.000 6.276 26.00 0 11600 Miscellaneous Treating Line Volume: 0 bbl Pipe Vol Above Collar: 442 bbl Pipe Vol Below Collar: 2 bbl 0 Annulus Volume: 326 bbl Displacement Volume: 442 bbl Total Volume: 770 bbl Casing Wt (Air): 301600 Ibf Casing Wt (Eff): 198946 Ibf Wellbore Start End Hole Casing Casing Summary MD MD TVD ID OD ID ft ft ft in in in Cased 0 2500 2500 8.835 7.000 6.276 Open 2500 7200 7200 8.500 7.000 6.276 Open 7200 11600 11600 9.158 7.000 6.276 Operating Schedule 0 Segment Volume Rate Time Cum.Time bbl bpm min min Seal Bond 20 4.00 5.0 5.0 Class G 151 4.00 37.6 42.6 Shut -Down 0 0.00 5.0 47.6 Displacement 442 4.00 110.6 158.2 BJ Services 2 04/27/09 t BJ Services CemFACTS Program Version 2.00 I Job Number: Customer: Fairweather Well Name: Nunivak Nunivak #1 Flow Inner Outer Pump Fluid Rey. Qmin Behavior Dia Dia Rate Vel. No. Turb. in in bpm ft/min bpm Drilling mud 9.625 12.250 4.00 71.7 3742 14.32 Seal Bond 9.625 12.250 4.00 71.7 24532 0.49 Class G 9.625 12.250 4.00 71.7 62 82.32 Displacement 9.625 12.250 4.00 71.7 3742 14.32 Summary • Est. Max Disp. Rate: 17.00 bpm Slurries Mixing Time: 37.6 min Displacement Time: 110.6 min Net (From Cement Mixing): 153.2 min Total (From Start): 158.2 min • BJ Services 3 04/27/09 1 p ciii j BJ Services CemFACTS Program Version 2.00 I Job Number: Customer: Fairweather Well Name: Nunivak Nunivak #1 PSI Rate and PPG 5000 20 , I 1 , 1 10 4000 • to 3000 a 15 0. 0 0. a) - 5 °r co to to - / i 2000 – 1.. — e' 0. - = U) • 1000 10 - 0 50 100 150 160 Elapsed Time (min) BJ Services 4 04/27/09 a , BJ Services CemFACTS Program Version 2.00 a Job Number: Customer: Fairweather Well Name: Nunivak Nunivak #1 ECD @ Critical Depth 16 , 1 , , , , I 1 16 i 14 - 14 O. - .� in cu 0 G 12 12 .c x c - W @ 0) o Cl .� I V W O � " / W • 10 10 8 I I I 1 I I I 1 I I I I 1 8 0 50 100 150 160 Elapsed Time (min) BJ Services 5 04/27/09 • BJ Services CemFACTS Program Version 2.00 Job Number: Customer: Fairweather Well Name: Nunivak Nunivak #1 Density Pore Den ECD Frac Den @ 613 bbl 0 • • ▪ 5000 11 \ _ , w C) N co cu E 1 I • 10000 10 12 14 16 18 19 Density BJ Services 6 04/27/09 t BJ Services CemFACTS Program Version 2.00 Job Number: Customer: Fairweather Well Name: Nunivak Nunivak #1 MD =11600 ft, Volumes are in b es e bbl b -o Design Volume Actual Stage 613 613 Slurry Total 610 Return Total 20 20 01. Seal Bond 151 151 02. Class G • 1 -2500 0 0 03. Shut -Down 442 442 04. Displacement -5000 -7500 • -10000 BJ Services 7 04/27/09 BJ Services CemFACTS Program Version 2.00 L e i 0 Job Number: Customer: Fairweather Well Name: Nunivak Nunivak #1 0 Wellbore Diagram MN Drilling mud (0 ft) I• Seal Bond (6314 ft) ▪ Class G (7200 ft) IIMI Displacement (11560 ft) 2000 2500 - • 4000 5000 - �, 6000 0 7500 - 8000 • 10000- 10000 11600- 11600 Offset, ft BJ Services 8 04/27/09 a BJ Services CemFACTS Program Version 2.00 I Job Number: Customer: Fairweather Well Name: Nunivak Nunivak #1 Critical Depth Summary Meas. Equivalent Density Reynolds Fid Foam SL 1 Depth Pore Calc Frac Number No Qual Den ft PP9 PP9 PP9 % PP9 11600 9.00 13.43 18.00 211 3 0.0 15.80 5500 9.00 10.87 14.00 890 1 0.0 9.50 2500 9.00 10.67 12.50 890 1 0.0 9.50 • • BJ Services 9 04/27/09 Operator Name: Fairweather Expl IDA Inc • Well Name: Nunivak #1 Job Description: T' Long String Date: May 1, 2009 Proposal No: 1001117843E JOB AT A GLANCE Depth (TVD) 11,600 ft Depth (MD) 11,600 ft Hole Size 8.5 in Casing Size/Weight : 7in, 26 lbs/ft Pump Via 7" O.D. (6.276" .I.D) 26 Total Mix Water Required 3,644 gals Spacer Seal Bond 20 bbls Density 12.0 ppg Slurry 15.8 ppg 741 sacks Density 15.8 ppg Yield 1.15 cf /sack Displacement Displacement Fluid 441 bbls Report Panted on May 1, 2009 1 3 PM Page 6 Gr4109 STIMULATION o CEMENTING a COMPLETION SERVICES a SERVICE TOOLS . COILED TUBING PRODUCTION CHEMICALS o CASING AND TUBING RUNNING SERVICES a PIPELINE SERVICES o WELL CONTROL Operator Name: Fairweather Expl d Inc • W r j ell Name: Nunivak #1 Job Description: 7" Long String i Date: May 1, 2009 Proposal No: 1001117843E WELL DATA ANNULAR GEOMETRY ANNULAR I.D. DEPTH(ft) (in) MEASURED TRUE VERTICAL 8.835 CASING 2,500 I 2,500 8.500 HOLE 1 1,600 11,600 SUSPENDED PIPES DIAMETER (in) I WEIGHT I DEPTH(ft) O.D. ( I.D. (Ibs/ft) MEASURED TRUE VERTICAL 7.000 6.276 I 26 I 11,600 I 11,600 Float Collar set @ 11,520 ft Mud Density 10.00 ppg Est. Static Temp. 230 ° F Est. Circ. Temp. 140 ° F VOLUME CALCULATIONS 4,400 ft x 0.1268 cf /ft with 50 % excess = 836.9 cf 80 ft x 0.2148 cf /ft with 0 % excess = 17.2 cf (inside pipe) TOTAL SLURRY VOLUME = 854.1 cf = 152 bbls Report Printed on May 1, 20091.35 PM Page 7 Gr4115 STIMULATION . CEMENTING e COMPLETION SERVICES . SERVICE TOOLS . COILED TUBING PRODUCTION CHEMICALS . CASING AND TUBING RUNNING SERVICES . PIPELINE SERVICES e WELL CONTROL Operator Name: Fairweather Expld Inc • j Well Name: Nunivak #1 LV Job Description: 7" Long String Date: May 1, 2009 Proposal No: 1001117843E FLUID SPECIFICATIONS Spacer 20.0 bbls Seal Bond + 179.5 lbs/bbl Barite - Sacked @ 12 ppg VOLUME VOLUME FLUID CU -FT FACTOR AMOUNT AND TYPE OF CEMENT Slurry 854 / 1.1 = 741 sacks Class G Cement + 0.05% bwoc Static Free + 0.4% bwoc R -3 + 0.4% bwoc FL -63 + 0.3% bwoc CD -32 + 0.1% bwoc ASA -301 + 1 gals /100 sack FP -6L + 43.6% Fresh Water Displacement 440.8 bbls Displacement Fluid CEMENT PROPERTIES SLURRY NO. 1 Slurry Weight (ppg) 15.80 Slurry Yield (cf /sack) 1.15 Amount of Mix Water (gps) 4.92 Amount of Mix Fluid (gps) 4.93 Cement additives are subject to change pending lab testing Report Printed on May 1, 2009 1 3 PM Page Gr4129 STIMULATION o CEMENTING o COMPLETION SERVICES a SERVICE TOOLS o COILED TUBING PRODUCTION CHEMICALS o CASING AND TUBING RUNNING SERVICES o PIPELINE SERVICES o WELL CONTROL L ip.7 BJ Services CemFACTS Program Version 2.00 D Job Number: Customer: Fairweather Well Name: Nunivak Nunivak #1 Service Information Design Date: 4/27/09 Customer: Fairweather Well: Nunivak Nunivak #1 State: AK Customer Representative: Alexey Sachivichik Service Type: Cement Service District / Boat: Kenai BJ Representative: Rod Edwards Comments: Production i Well Description Well Depth: 11600 ft Shoe Depth: 11600 ft Landing Collar Depth: 11560 ft Cement Top: 7200 ft Previous Shoe Depth: 2500 ft Surface Temperature: 32 °F Static BHT: 230 °F Circulating BHT: 140 °F Surface Line Length: 0 ft Surface Line ID: 1.750 in Cement Excess: Increase Hole Size(s) Deviation Meas. Vert. Incl. Azimuth Depth Depth Angle Angle ft ft deg deg 11600 11600 0.0 0.0 el Hole Dia. From To in ft ft 8.835 0 2500 8.500 2500 11600 BJ Services 1 04/27/09 L 11, i iBJ Services CemFACTS Program Version 2.00 Job Number: Customer: Fairweather Well Name: Nunivak Nunivak #1 Casing OD ID Weight From To in in Ibm /ft ft ft 7" 26# 7.000 6.276 26.00 0 11600 Miscellaneous Treating Line Volume: 0 bbl Pipe Vol Above Collar: 442 bbl Pipe Vol Below Collar: 2 bbl Annulus Volume: 326 bbl Displacement Volume: 442 bbl • Total Volume: 770 bbl Casing Wt (Air): 301600 lbf Casing Wt (Eff): 198946 lbf Wellbore Start End Hole Casing Casing Summary MD MD TVD ID OD ID ft ft ft in in in Cased 0 2500 2500 8.835 7.000 6.276 Open 2500 7200 7200 8.500 7.000 6.276 Open 7200 11600 11600 9.158 7.000 6.276 j Operating Schedule Segment Volume Rate Time Cum. Time • bbl bpm min min Seal Bond 20 4.00 5.0 5.0 Class G 151 4.00 37.6 42.6 Shut -Down 0 0.00 5.0 47.6 Displacement 442 4.00 110.6 158.2 BJ Services 2 04/27/09 Lit j BJ Services CemFACTS Program Version 2.00 Job Number: Customer: Fairweather Well Name: Nunivak Nunivak #1 Flow Inner Outer Pump Fluid Rey. Qmin Behavior Dia Dia Rate VeL No. Turb. in in bpm ft/min bpm Drilling mud 9.625 12.250 4.00 71.7 3742 14.32 Seal Bond 9.625 12.250 4.00 71.7 24532 0.49 Class G 9.625 12.250 4.00 71.7 62 82.32 Displacement 9.625 12.250 4.00 71.7 3742 14.32 Summary Est. Max Disp. Rate: 17.00 bpm • Slurries Mixing Time: 37.6 min Displacement Time: 110.6 min Net (From Cement Mixing): 153.2 min Total (From Start): 158.2 min • BJ Services 3 04/27/09 Li j j BJ Services CemFACTS Program Version 2.00 Job Number: Customer: Fairweather Well Name: Nunivak Nunivak #1 PSI Rate and PPG 5000 20 , I I I , 1 10 4000 • 3000 a 1 cn Q. O. a .0 CD C = Ci co cn i 2000 L- — LI L. cn • 1000 10 0 0 50 100 150 160 Elapsed Time (min) BJ Services 4 04/27/09 BJ Services CemFACTS Program Version 2.00 p 0 IP Job Number: Customer: Fairweather Well Name: Nunivak Nunivak #1 ECD @ Critical Depth 16 I I 16 14 14 • Q- ,n In o m 12 12 c U01 c G • (7) U V 0 — W w � \_— 10 10 0 8 I I I I I I I I I 8 0 50 100 150 160 Elapsed Time (min) BJ Services 5 04/27/09 Li BJ Services CemFACTS Program Version 2.00 Job Number: Customer: Fairweather Well Name: Nunivak Nunivak #1 Density Pore Den ECD Frac Den @ 613 bbl 0 I I I I I I I I . 11 1 \ E 5000 - - -- a) G cn co a) 2 I 1 1 • 10000-- I 10 12 14 16 18 19 Density BJ Services 6 04/27/09 BJ Services CemFACTS Program Version 2.00 R 0 Job Number: Customer: Fairweather Well Name: Nunivak Nunivak #1 MD =11600 ft, Volumes are in bbl - o Design Volume Actual Stage 613 613 Slurry Total 610 Return Total 20 20 01. Seal Bond 151 151 02. Class G A -2500 0 0 03. Shut -Down • 442 442 04. Displacement -5000 -7500 0 -10000 BJ Services 7 04/27/09 riii BJ Services CemFACTS Program Version 2.00 IP Job Number: Customer: Fairweather Well Name: Nunivak Nunivak #1 0 Wellbore Diagram NMI Drilling mud (0 ft) MO Seal Bond (6314 ft) In Class G (7200 ft) NM Displacement (11560 ft) 2000 2500 - 4000 5000 - 6000 a 7500 - 8000 • 1000 10000 1160' 11600 Offset, ft BJ Services 8 04/27/09 L A BJ Services CemFACTS Program Version 2.00 IP Job Number: Customer: Fairweather Well Name: Nunivak Nunivak #1 Critical Depth Summary Meas. Equivalent Density Reynolds FId Foam SI. Depth Pore Calc Frac Number No Qual Den ft PPg PPg PPg % PPg 11600 9.00 13.43 18.00 211 3 0.0 15.80 5500 9.00 10.87 14.00 890 1 0.0 9.50 2500 9.00 10.67 12.50 890 1 0.0 9.50 BJ Services 9 04/27/09 Operator: Fairweather Expl & Proc • Well Name: Nunivak #1 1 Date: May 1, 2009 Proposal No: 1001117843E PRODUCT DESCRIPTIONS A -10 An additive used for fast setting, thixotropic cements or cement systems to seal off a lost circulation zone. It has A -11 A -11 is an accelerator used to shorten thickening time and promote early compressive strength development. Functional at low to high temperatures ranges. A -11 can be used with any Portland cement -based system at densities ranging from 11.5 to 20 Ibs /gal (1378 to 2396 Kg /m ^3). ASA -301 Additive used to reduce or eliminate free water and settling in cement slurries. BJ SealBond Spacer Forms a non invasive seal to prevent filtrate invasion into the producing formation. Trademark of PFS, LLC. Barite - Sacked A naturally occuring mineral (Barium Sulfate). It is widely used as a weighting material in cement spacers and occasionally in cement slurries. It can yield a slurry density in excess of 19 Ibs /gal. CD -32 A patented, free - flowing, water soluble polymer that is an efficient and effective dispersant for primary and remedial cementing. Calcium Chloride A powdered, flaked or pelletized material used to decrease thickening time and increase the rate of strength development. Class G Cement Intended for use as a basic cement from surface to 8000 ft as manufactured, or can be used with accelerators and retarders to cover a wide range of well depths and temperatures. FL -52 A water soluble, high molecular weight fluid loss additive used in medium to low density slurries. It is functional from low to high temperature ranges. FL -63 A non - retarding, non - viscosifying fluid loss additive particularly suited for use with coil tubing and /or close tolerance liner cementing. FL -63 is effective from low to high temperatures. Concentrations of 0.2% to 1.0% BWOC are typical. FP -6L A clear liquid that decreases foaming in slurries during mixing. LCM -1 A graded (8 to 60 mesh) naturally occurring hydrocarbon, asphaltite. It is used as a lost circulation material at low to moderate temperatures and will act as a slurry extender. Cement compressive strength is reduced. Report Printed on May 1, 2009 1 35 PM Page 13 Gr4163 STIMULATION a CEMENTING o COMPLETION SERVICES o SERVICE TOOLS o COILED TUBING PRODUCTION CHEMICALS o CASING AND TUBING RUNNING SERVICES o PIPELINE SERVICES o WELL CONTROL . CHEMICAL SERVICES Operator: Fairweather Expl & Pro. 1 Well Name: Nunivak #1 1 Date: May 1, 2009 Proposal No: 1001117843E PRODUCT DESCRIPTIONS (Continued) LW -6 Natural graded hollow pozzolan microspheres, which when mixed with API cements, yield slurry densities from 8 -12 Ibs /gal. Besides having low densities and relatively high compressive strengths, these systems also offer good insulating properties for application such as steam floods. MPA -1 MPA -1 is a fine white pozzolanic type powder used to enhance various cement properties. These properties include: Enhanced Compressive Strength Development, Improved Sulfate Resistance, Increased Tensile and Flexural Strength, and Gas Control. MPA -1 is functional over a broad temperature range, and can be used in foamed lightweight, normal, and heavyweight cement designs. Concentrations range from 1 to 30% BWOC. Mud Clean II A water -base mud wash designed for use ahead of cement slurries to aid in mud and drilling debris removal and to prevent contamination of the cement slurry. It should be used only when water -base mud is used. R -3 A low temperature retarder used in a wide range of slurry formulations to extend the slurry thickening time. R -7 A retarder for artic cement systems that provides predictable thickening time control. Sodium Metasilicate An accelerator used to decrease the thickening time of cement slurries. Static Free An anti - static additive used to prevent air entrainment due to agglomerated particles. Can be used in Cementing and Fracturing operations to aid in the flow of dry materials. Type 1 Cement A Portland cement designed for use to 6,000 Ft. Type I cement can be modified for use at greater depths. Type Report Printed on May 1 2009 1 35 PM Page 14 Gr4163 STIMULATION o CEMENTING o COMPLETION SERVICES o SERVICE TOOLS o COILED TUBING PRODUCTION CHEMICALS o CASING AND TUBING RUNNING SERVICES 0 PIPELINE SERVICES o WELL CONTROL . CHEMICAL SERVICES • • RAM PART Fairweather E &P Services, Inc 2000 E. 88 Ave, Suite 200 Anchorage, AK 99507 Attn: Alexey Sachivichik Drilling Fluids Services Prepared for: Alexey Sachivichik Senior Drilling Engineer March 10, 2009 Submitted by: Dave Soquet Sr. Technical Professional Halliburton - Baroid 6900 Arctic Blvd Anchorage, Alaska 99518 (907) 275 -2642 HALLIBUPTON • • Rampart Drilling Fluids Services RFQ No. 002 IKAMPART 1.5. Materials list Proposed Materials List, including spares levels. The following tables represent estimated usage and contingency material. Product Name (Est. Usage Container Estimated Items) Size Usage AQUAGEL 50 Ib sx 560 ALDACIDE G 5 gal can 41 BARO -TROL 50 Ib sx 160 BARAZAN D+ 25 Ib sx 317 BAROID 41 50 Ib sx 3000 BAROLIFT 7.5 Ib ct 2 Bicarb 50 Ib sx 43 Caustic Soda 50 Ib sx 76 Citric Acid 50 Ib sx 53 55 gal CON DET Premix drum 12 DEXTRID 50 Ib sx 240 PAC L 50 Ib sx 180 Soda Ash 50 Ib sx 14 THERMATHIN 5 gal can 32 X -cide 207 6 Ib can 42 X -TEND II 21b sx 14 Contingency Material BARA - DEFOAM HP 5 gal can 32 BARACARB 150 50 Ib sx 140 BARACARB 25 50 Ib sx 350 BARACARB 5 50 Ib sx 210 BARACARB 50 50 Ib sx 350 BARATHIN 25 Ib sx 80 BAROFIBRE 25 Ib sx 260 BAROID 41 50 Ib sx 3300 BAROSEAL F 40 Ib sx 90 BAROSEAL M 40 Ib sx 90 CARBONOX 50 Ib sx 40 DRILLTREAT 55 gal drum 4 Lime 50 Ib sx 40 No -Sulf 50 Ib sx 40 STEELSEAL 50 Ib sx 200 WALL -NUT M 50 Ib sx 40 HALLIBURTDN CONFIDENTIAL ) 2007 Halhhurton All Rights Reserved Final Flu[ds Submittal to RFQ -002 11 • • Rampart Drilling Fluids Services No. 002 RAMPART -- --, 1.12. Fluids Design Discussion Upon award of work and final well design, Halliburton - Baroid will provide a full fluids program containing fluid recommendations, hydraulic modeling, and waste estimates. A general outline of recommendations is detailed below. 1.12.1. Surface Hole Section Surface Hole: A conventional bentonite —based spud mud system is recommended for this interval. The proposed system has proven successful for surface hole operations across Alaska. Our primary focus for surface hole drilling operations will be adequate mud weight for well control and sufficient mud viscosity and flowrates for efficient hole cleaning. Spud the well with maximum flow rates (600 -1000 gpm assuming 12 1 /4" hole w /4" drill pipe) to ensure good cuttings transport. Target an initial YP in the 45 -55 range with a 300+ viscosity. After penetrating the upper gravels and/or the permafrost (if present), gradually reduce the funnel viscosity to ca. 70 -150 sec as the hole allows. Reduce the API FL to under 12 cc /30 min with additions of PAC -L. At interval TD, pump a high viscosity or Barolift sweep and condition the mud for running casing. Once the casing is landed, pre -treat the system for cement with a minimum of 0.5 ppb citric acid and 1.0 ppb bicarb. Add 0.25- 0.5 ppg Barathin to thin mud to target properties. (Converse with the cementers to see what properties they have based there design on). With an initial mud density of 9.0 ppg, please note the other issues of concern as listed below: 1. Make sure all members of the drilling team are aware of the potential of encountering gas hydrates. 2. A mud weight increase is not currently programmed for drilling the gas hydrate interval of the well, if encountered. 3. If gas hydrates are noted, treat the system with 2.0 ppb of Driltreat (Lecithin). Some defoamer additions may also be necessary to help the gas break out. 4. Maintain the mud as cool as possible (under 60 °F if possible). Efforts to keep the fluid cool include mudding up with cold water and diluting the mud with cold water. Make every effort to maintain the system as clean as possible through the normal dilution process and maximization of solids control equipment application. Mud maintenance issues for this interval of the well are as follows: N 1. LIBUR'i" ON CONFIDENTIAL (;) 2007 Halliburton All Rights Reserved Final Fluids Submittal to RFO -002 17 • Rampart Drilling Fluids Services RFQ No. 002 IKAM 'ART 1. Use Aquagel and X -Tend II for viscosity and YP requirements. Initially target a viscosity of 300 +, allowing it to gradually decrease as the gravels are exited. 2. Use PAC -L / Dextrid LT for API filtration control. No filtrate control is planned initially, but drop the fluid loss to the 12 cc range below 800'. 3. Hold the pH in the 8.5 -9.5 range with caustic soda. 4. Condet additions will likely be required to minimize screen blinding and bit balling once sticky clays are encountered. 5. Control penetration rates based upon the ability of the surface system to process the drilling mud. 6. Daily additions of Aldacide G and/or X -Cide 207 will be necessary to control bacterial action after adding PAC /Dextrid. 7. Minimize dilution requirements and keep the mud as clean as possible through aggressive use of solids - control equipment. The basic formulation is detailed below. 9.0 ppg Formulation Fresh Water - 0.931 bbls Aquagel - 25 ppb X -Tend II - .1 ppb (300+ viscosity) Caustic soda - .2 ppb (pH 9 -9.5) Barite - as needed for 9.0ppg MW Target Properties Density Viscosity YP PV 10 S. Gel API FL Initial 9.0 300+ 45 - 55 10 - 30 10 — 15 unrestricted Final 9.Q 70 -150 25 —35 12 —25 10-15 <12 * Mud weight as needed for well control HALLIBURT0114 CONFIDENTIAL ) 2007 Hallihurtnn All Rights Reserved Final Fluids Submittal to RFQ -002 18 • +� Rampart Drilling Fluids Services RFQ No. 002 IAMPART 1.12.2. Production Hole Section Production Hole: For the production hole, a standard LSND system is proposed. The mud system will be a 9.0 ppg mud weight initially. Plan on weighting up the system as the hole dictates possibly to 9.6 ppg. This higher mud weight may be necessary, but for purposes of the RFQ, the 9.0 ppg mud weight is assumed. Mud up a standard fresh water LSND system for this portion of the well. Initially, target a mud density of 9.0 ppg and a YP of the fluid in the 15 range and maintain until out of the sticky clays just below the casing seat. Screen blinding/ balling from heavy clays can be a problem, pre -treat with Y2% Condet prior to entering this zone. Once through the sticky clays, adjust the YP up to the 15 -25 range with Barazan D to ensure good hole cleaning support. Regular sweeping of the hole with high viscosity sweeps will supplement the hole cleaning ability of the fluid. All personal should be aware of the possibility of encountering unexpected pressure. Close monitoring of return mud weights, pit volumes, and the flowline flow meter are of utmost importance at all times and will give warning of changing pressures. Maintain ample stocks of barite on location. Keep low gravity drilled solids to a minimum ( <6% by volume if possible). Maintain the API filtrate <5 with PAC/Dextrid. Maintain this tight filtration to TD of the well. Maintain the pH between 9.0 -9.5 with caustic soda. Daily additions of X -Cide 207 and/or Aldacide G should be made to control bacterial action. As coals are anticipated, treat the mud system with 2 ppb Barotrol prior to drilling coal seams. Special efforts should be made to keep ECD and surge /swab pressures to a minimum. This will reduce the chances of lost circulation and also reduce damage to any exposed coals. On the final circulation prior to running casing, sweep the hole and reduce the rheology to an 15 -22 YP to reduce the gels and minimize surge pressures while running the casing. Reduce the YP to cementing specs with Barathin or Carbonox after the casing is on bottom and prior to cementing. HALL, UPTON CONFIDENTIAL 2007 Halliburton All Rights Reserved Final Flutes Submittal to RFQ -002 19 • 1 Rampart Drilling Fluids Services RFQ No. 002 RAMPART 9.0 ppg Formulation Fresh Water - 0.968 bbls Barazan D+ - 1.5 ppb Caustic Soda - .2 ppb Dextrid - 2 ppb PAC L - 1 ppb Baroid - to a 9.0 ppg Aldacide G - .25 ppb Target Properties Density (ppg) 9.0* / Funnel Viscosity 45 -60 (seconds) Yield Point 15 -25 (cP) Plastic Viscostiy 8 -16 (lb /100 sf) 10 second gel 4 -10 10 minute gel 6-14 pH 9.0 -9.5 API filtrate <5 Solids % 6 -12 * Mud weight as needed for well control 1.12.3. Completion Actual completions fluid design will be determined by actual pore pressure and completion and testing design. For purposes of the RFQ, a 9.0 ppg sodium chloride brine is assumed. 9.0 ppg Formulation Fresh Water - 0.962 bbl/bbl Salt - 41 ppb HAL_LIEURTLIN CONFIDENTIAL 2007 Hallihurton All Rights Reserved Final Fluids Submittal to RFQ -002 20 . • RAMPART RECEIVED MAY 3 4 2109 April 30, 2009 Alaska Oil & Gas Cons. Commission Anchorage Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill: Nunivak #1 Dear Mr. Seamount, Rampart Energy Company hereby applies for a Permit to Drill a new gas exploration well from a gravel pad approximately 3 miles west of the city of Nenana. Rampart Energy Company plans to use the Doyon/Akita Arctic Wolf #2 rig to drill its Nunivak #1 well. The Nunivak #1 will consist of 16" conductor pipe, 9 5/8" surface casing and 7" production casing. The well will be drilled as a directional hole with very shallow S -shape below the 9 -5/8" casing shoe. There is a possibility of running 4 -1/2" liner as a contingency in case of hole problems. 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 to Drill 2) A plat showing the surface location of the well 3) Proposed drilling program 4) Drilling Planning Data and Drilling Risks 5) Drilling Time versus Depth Plot 6) Nunivak #1 Proposed Wellbore Diagram 7) Pressure Calculations and Waste Disposal 8) Casing Properties and Design Factors 9) Diagrams and Descriptions of the BOP Equipment to be Used 10) Directional Plan 11) Drilling Fluid Program 12) Cementing Program 13) Rampart Energy Company acknowledges the potential of H2S presence in the formation, therefore, H2S monitoring equipment and qualified contractor will be employed. 14) The following are Rampart Energy Company's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Alexey Sachivichik, Drilling Engineer (20 AAC 25.070) (907) 258 -3446 Rampart Energy Company 1512 Larimer Street Bridge Level Denver, CO 80202 303.460.1132 Fax 303.460.1205 • 2) Geologic Data and Logs Mike Richter, Geologist/Geophysicist (20 AAC 25.071) (303) 807 -4885 If you have any questions or require additional information, please contact Alexey Sachivichik at (907) 258 -3446 or (907) 575 -7315 Sincerely, Rampart Energy Company Van Spen e, President Attachments Cc: Alexey Sachivichik - Fairweather TRANSMITTAL LETTER CHECKLIST WELL NAME A 4/W/ Yi9rd / PTD# o9OS"440 Development Service /Exploratory Stratigraphic Test Non - Conventional Well FIELD: �XPLD/c" ii 770/1 POOL: Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & Pool Well Name: Nunivak 1 Program EXP Well bore seg ❑ PTD#: 2090540 Compan RAMPART ENERGY COMPANY Initial Class/Type EXP / PEND GeoArea 867 Unit 00000 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee_attached NA 2 _Lease number appropriate Yes 3 _Unique well name and number Yes 4 Well located in a defined pool No Exploratory_well in_Mid Tana Basin. 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 _Sufficient acreage valet* in, drilling unit Yes 8 If_devlated, is wellbore plet included NA 9 Operator only affected party Yes 10 Operator has Appropriate bond lnforce Yes #7110024912 11 Permit can be Issued without conservation order Yes Appr Date 12 Permit can be Issued without administrative approval Yes ACS 6/3 /2009 13 Can permit be approved before 15- dey.walt Yes 14 Wall located within _area and strata euthorized_by injection Order # (put IQ# incommente) (For NA 15 All wells within 1/4 mile area of review ldentitied_(FQr service. well only) NA 16 Pre- produced_injector:. duration of pre - production less than S months (For service well only). NA 17 _N_onconven._gas conforms_ to AS31,Q5,030(1,1_,A),(j.2.A -D). NA 18 _Conductor string provided Yes Set SI 80'. Engineering 19 Surface casing protects ell known USDW5 Yes 20 CMT_vol adequate to_ciroulate on conductor_& surf csg Yes Adequate excess. 21 CMT_vol adequate to tieinlongstring to surf cog No TOO 7200'. 22 C1v1T.will cover all known productive horizons Yes 23 Casing deslgns.adequate for C. T, J3.& permafrost Yes Min SF 1.2 24 Adequate tankage or_reaer_ve pit Yes DQyon /Akita ArctlQ Wolf 2. 25 If.a,re- drill, has a 10-403 for_ abandonment been approved NA NOW w ell. 26 Adequate wellbore seperetion_proposed Yes 27 _If_dlverter required,_does_lt_meet regulations N_o Vent line variance required, Appr Date 28 _ DrlUing. fluld_program_schematic& equip_Ilst_adequate Yes Max MW 9.6_ppg, as required. WGA 6/4/2009 29 _BOPEs, do they meat regulation Yes 10k psi rating. 30 _BOPE _press rating_appropriate;_test to_(put prig In comments) Yes _ _ _ .. _ _ MASP 4512 psi;.test BOPE to 5000 psi min. 31 _Chokemanifoldccmplles w /APl R. (May 84) Yes lokpsirating. III 32 Work will occur_without operatlonshutdQwn Yes 33 is presence of H2S gas probable No 34 _Mechanical condition of wells within AOR verified_ (For service well only) NA Exp weU. 35 Permit con be issued w/o hydrogen sulfide measures No Wildcat Exploration Jn new basin. Little is known about the sediments and their content. Geology 36 _Data presented on potential overpressure zones Yes Appr Date 37 Seismic analysis of shatlowgas zones Yes ACS 6/3 /2009 38 Seabed cQnditiQnsurvey_ (if off - shore) NA 39 Contact name /phone_for_weekry_progress reports[exploratory only] Yes Alexey Sachiyichik - _575 -7315 Geologic Engineering aim 1 Commissioner: Date: Commissioner: Date ` -* �,ner „ ate b 7s 6//1? AO" 6'049;e1 1
