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Home My WebLink About202-180 .,; ... e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '-:/ / f? i rllCe 10 P. I. Supervisor ",f:'f1 J" t·· (., DATE: May 8,2005 ..;~~jlO, FROM: John Spaulding, Petroleum Inspector SUBJECT: Location Clearances Pioneer Unit Pioneer Natural Res. The following wells in the Pioneer Unit were inspected for location clearances: Bering 03 PTO: 202-177 Baranoff 04 PTO: 202-178 /Cook 01 PTO: 202180 Lowell 02 PTO: 202-179 1702-14CC PTO: 199-065 1702-150A WOW PTO 199-064 1702-1500 PTO: 199-066 Cornhusker 04 PTO: 202-181 RL Smith 03 PTO: 202-182 OL Smith 01 PTO: 202-184 Stromberg 02 PTO: 202-183 BL T 01 PTO: 199-068 'C"' i....1...ì1~'·ri It !''.1 'i .1. ;") J''\¡':'O!.:'./ v ~ hi ... _ All locations were found to be in excellent shape, well graded with some small amounts of debris. I requested that the debris be cleaned up and Joe Polya Pioneer Nat. Resources rep. agreed. He will inform as to when the final cleanup has been made so that I may make one last pass over the locations. SUMMARY; I found all locations in very good condition with small amounts of tidying up to be done. Attachments: photos on CO NON-CONFIDENTIAL ~ . . ······r··················..· " -:"."_.:"",, ',,, .. , .... . .. MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc _ STATE OF ALASKA e ALASKA ""AND GAS CONSERVATION COMMISSION RECEIVED oc¿ 1 7 2005 WELL COMPLETION OR RECOIVjPLETION REPORT ANJ:) ~.O 1 a. Well Status: OilD GasD Plugged 0 Abandoned 0 Suspended D WAGD 1b. Well Class~"'''·na VII at baS L;ons. 20MC 25.105 20MC 25.110 Development D E_IWn~ GINJD WINJD WDSPL D No. of Completions Other Service D Stratigraphic Test 2. Operator Name: 5. Date Comp., Susp., or 12. ,permit to /t,t~: Pioneer Natural Resources Alaska, Inc. Aband.: Aug 14, 2005 . 2.02..t8f) " 3. Address: 6. Date Spudded: 18'. API Nurnber: 700 G Street, Suite 600 Anchorage, AK 99501 November 21,2002 50-009-20022-00 ,/ 4a. Location of Well (Governmental Section): 7. Date TO Reached: 14. Well Name and Number: Surface: 991' FSL, 888' FEL, Sec 30, T18N, R1W, SM November 24, 2002 Cook #1 ,,/ Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): Same 413 Total Depth: 9. Plug Back Depth(MD+ TVD): Pioneer Unit Same Surface 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 1724538 y- 2783102 (NAD 83) Zone- 4 3740' MD, TVD ADL 384685 TPI: x- Same y- Same Zone- 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- Same y- Same Zone- NA NA 18. Directional Survey: Yes D No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost: NA feet MSL NA 21. Logs Run: None 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 12.75 NA NA Surface 245 Surface 245 16" 40 sx class A None 8.625 23 J-55 Surface 384 Surface 384 11" 35 bbls class A None 5.5 17 J-55 Surface 3701 Surface 3701 7-7/8" 150 bbls class A None 23. Perforations open to-PI.O.dI.l.di,gQí!YID + TVD 0J.lo.p and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 2.875 3445 NA 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED SCANNED DEC r 9 2005 '1 (ó b b \ \. (\ JiltA.r ,') J ~r1d. 1.U6A , 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: IGaS-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 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None n R 1 h \ t\t A , f:\ /J A í) fJ1 AA/I ." I I "-../ I , I ....... . . '~" l fT liV'M '0 (fY! tõ [ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ornmíssíon /' . \&. <~ \"'"' 0 .... \1/0\ ,0\ ~~ NAME GEOLOGIC MARKERS MD 29. RMA TION TESTS 28. TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None 30. List of Attachments: Final Well Schematic, Operations Summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Printed Name: Joe Polva Signature: Title: Sr. Staff Drilling Engineer Phone: 907-343-2111 Date: INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for I njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional 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: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 e e Pioneer Natural Resources Alaska, Inc. Pioneer Unit Cook #1 Plug and Abandonment Operations Summary July 22, 2005 Check well, well dead. Pulled drive rods and rotor fÌ'om well to prepare for cement circulating job. July 23,2005 Spot equipment around well, rig up circulating lines on tubing with returns line on tubing/casing annulus. Confirm ability to circulate down tubing buy pumping 5 bbls water down tubing to fill well. Clear water returns fÌ'om annulus verified. SDFN. July 24,2005 Mix and pump 70 bbls 15 ppg Type I cement down tubing taking returns out casing/tubing annulus to tank. Pumped entire batch at 1400 psi with returns just starting to show at returns tank. Mixed additional 3 bbls cement and pumped down tubing. Pump pressure came up to 3500 psi after 1.5 bbl pumped, shut in well. Cleaned up equipment. Moved to Stromberg #2 location. July 25, 2005 Dug out cellar to 7 feet below grade. July 28, 2005 Cut off wellhead at 5.5 feet below pad level. Cook #1 well requires top job in 5.5 x 2.875 annulus where cement fell back. July 29, 2005 Inspect cutoff well, tubing full of cement, depth to cement in 5.5 x 2-7/8 inch casing/tubing annulus at 622 feet. Run in tubing casing annulus with 160 feet 12 inch steel pipe to 165 feet below grade. Mix and pump 2.75 bbl cement top job plug in casing/tubing annulus with good cement returns. Unable to pull 12 inch pipe, left same full of cement and cemented in annulus. AOGCC inspector Chuck Sheve on-site to witness top job and inspect other Pilot 2 group wells. July 30, 2005 Inspect top job cement job on well, cement to surface. Move batch unit, tool trailer and miscellaneous equipment to Cornhusker #4. August 9, 2005 Matt Rader of ADNR and Chuck Sheve of AOGCC inspected well for final P&A. August 14, 2005 Installed marker plate on well. Backfill to be completed when surface equipment removed. - 1 - equipment rigged up on - 2 - ,." - .;) - PBTD 3670 Well Cook #1 API 50-009-20022-00 Qtr/Qtr Sec 30 Pioneer Natural Resources AK, Inc. Twp 18N Rng 1W Size Weight Grade Thread Depth County Matanuska, Susitna State Alaska Casing 8-5/8 24 J-55 ST&C 384 Field Pioneer Unit Country USA Casing 5-1/2 17 J-55 LT&C 3701 GUKB 409/413 Tubing 2-7/8 6.3 J-55 8rd 3445 No. Depth Lenç¡th 00 10 Description 1 3462 11.51 2.88 N/A 40N006 Insert Pump 2 3416 4 N/A N/A Perforate 3416-3420 wI 4spf 23 gram charges 3 3356 4 N/A N/A Perforate 3356-3360 wI 4spf 23 ç¡ram charç¡es 4 3120 4 N/A N/A Perforate 3120-3124 wI 4spf 23 ç¡ram charç¡es 5 3090 4 N/A N/A Perforate 3090-3094 wI 4spf 23 gram charges 6 2954 4 N/A N/A Perforate 2954-2958 wI 4spf 23 gram charges 7 2908 4 N/A N/A Perforate 2908-2911 w/4spf 23 gram charges 8 Surface Well cutoff 5.5 feet below ç¡round level. 9 622 TOC in 5.5 x 2.875 inch annulus. 10 165 160 Surface cement plug in 5.5 x 2.875 inch annulus. 1(160 feet of 1/2 inch steel pipe left in annulus) e e Pioneer Unit Cook #1 Final Well Schematic 8 10 Modified by JRM 9/12/05 e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, .~t;íq 1116101; DATE: P. I. Supervisor r July 29, 2005 FROM: Chuck Scheve, SUBJECT: Petroleum Inspector Surface Abandonment Pioneer Unit Lowell #2 PTO# 202-179 Baranof #4 PTO# 202-178 Bering #3 PTO# 202-177 Cook #1 PTDtl202-180 Fridav. Julv 29.2005: I traveled to Pioneer's Coal Bed Methane exploratory locations to inspect the casing cut off and abandonment of the above listed wells. All casing strings on the above listed wells were cut off at approximately 5' below original ground level. The Lowell 2, Baranof 4 and Bering 3 wells were found full of cement to within 18" of surface in all strings and will be topped off prior to installation of the marker plates. The Cook 1 well had cement to surface in all strings except the tubing by production casing annulus. 150' of %" pipe was run in this annulus and I witnessed cement circulated back to surface. The marker plates with the required information bead welded to them were On location and will be welded to the outer most casing. SUMMARY: I inspected the casing cut off depth, and the P&A marker plates on the Lowell 2, Baranof 4, Bering 3 and Cook1 wells and found all to be in order. Attachments: Lowell 2.JPG Baranof 4.JPG Bering 3 .JPG Cook 1 .JPG ~CANNEC "1 'Hi')\' k LI.l;" e e Pioneer Unit Suñace Abandonments Photos by AOGCC Inspector Chuck Scheve July 29, 2005 ,-~:.~:;-';;:~;. -,:." ,~~~>.~ ,__~,$i_-~">, -.___~ ~~~~_~:~'!-fi.~ ,.<jo",~ '." ~~-.-'~~¡~ .- -- :~- , c'-". ":'->,..'::';" .,:",,', """"" ',-' -,-,"'; ~'~~~"-~~~M~~~;_-'::'~;...c--~·;:?·:,,~?1;;t~L - ~..:.;:~ .. , -'--'-'-- - ',:: -,~:\ ." ~:_,:-:.~ÀS;;~~~~'·~~-i~;~L;~·: . ". ." t '. ·';L.;,...ë':,; ,.'" . . ~"-"?i'" 'i .',.- ;j..:'i:", . .' ...0. ...... $> --. ~ -~ ._;;. 'Ä, ~ :'-"'; ..~_..",. ;}<".;; .." .> -,.;;:.:,:~ ,þ- j> '". , . ~ ,,:,::~,:.:~rjil~':"~::.·' . . " .- ¥i €s1!'J .!;i:i ~. . "'>'J ":'Ji#:~'" ',. .~l~~~I>."· . . .:'.;.? .~: ·':;:::;7;~t,. ....:. . :",,'" :~'~~t:~·"':1~J:L~;;,,:';~·:~ ~ 'Y-- Baranof #4 Casing Cut and Marker Plate Bering #3 Casing Cut and Marker Plate 2 e e ,..... _._7!'"""'.... I, .J<-\ ~'..tl"': .. ;'''-,'-'\- ?~ "1 ,," .,~ .~:¡ .¢ .:'*t~4:;;;'~? ,. .....-..ii: . .. .",,"'~;: . ,¡.. ~ ... :~ ~ ',.1 ¡¡¡.,. '1, ~~~i);~~ J.':;-"" . ..:.. ...::"}t:;, "~y '·':'}"'i..~. ...." .~y~/.~. .""'.'.:~~,.....,~";",.:...-,", .. Cook # I Casing Cut and Marker Plate Lowell #2 Casing Cut and Marker Plate 3 )' J \J-~ }- ß ~ .;- DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 Permit to Drill 2021800 Well Name/No. COOK 1 ip u.¿ :? I ItJ tv À~'" ~ Operator EVERGREEN RESOURCES (ALASKA) API No. 50-009-20022-00-00 MD 3740 /' TVD 3740 / Completion Date 6/5/2003 ~ Completion Status 1-CBNG Current Status 1-CBNG UIC N - - ------ -_._-~- ~- ----- REQUIRED INFORMATION Mud Log No _c _ __ ____________ - ----- ------- Samples No Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: DNL, GR, NEU, BL,Mud log, Inc. survey Well Log Information: Log/ Data Type , Rpt Electr Digital Dataset Med/Frmt Number Name Directional Survey ~Og i . . . tJd)g :tt6'g ,~g ./Log .J!c>g /Mud Log ~ment Evaluation ~duction/Resistivity VDensity i/í nduction/Resistivity £)Sensity ---------- Well Cores/Samples Information: Name ADDITIONAL INFORMATION ~N Chips Received? v0 ~/N Well Cored? Analysis Received? - ---- -- --- --- -- ---------- Comments: (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH/ -- Scale Media No Start Stop CH Received Comments 250 3665 9/16/2003 Patterson Wireline Inclination Survey 5 Blu 470 3750 2/16/2005 Columbine Logging, Inc.lPatterson 5 Blu 0 3670 2/16/2005 Dual spaced Cement Bond log 5 Blu 3 380 3735 2/16/2005 I nd uction/G RlPatterson 5 Blu 4 380 3735 2/16/2005 Compensated Density Neutron Log/Patterson 5 Blu 2 245 390 2/16/2005 Dual Induction Gamma Ray/Patterson 5 Blu 245 390 2/16/2005 Compensated Density Log Sample Interval Set Start Stop Sent Received Number Comments ~- 4!'O .- J' s-~ II t ( Daily History Received? W>N Formation Tops 6tN Permit to Drill 2021800 MD 3740 TVD 3740 , I --.------ -- ---------- Compliance Reviewed By: __ DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 Well Name/No. COOK 1 Operator EVERGREEN RESOURCES (ALASKA) API No. 50-009-20022-00-00 Completion Date 6/5/2003 Completion Status 1-CBNG Current Status 1-CBNG UIC N ~ Date: ! 7 {f.J Á.N-J- .z~ I ~ .-- ~. .~I l!:f?l'~' ~ !1r;¡.:::J ~'" ~ ' I' ¡ ,i I, I~, j i i,1 II ;ú'.. If h"\ II liF ì I I' I I I I I [ 1,,1 lJ! ,'r'1J U Lb fTfJI 'tl Ufb \~,~) I ¡ ) //~ \ n¡i ¿/M ((ù n(fl(/ ¡1M /!1J\ ¡ /ß~ \..: ¡ ~I\ /'U\~ ;' , 'i I , I, ,I ¡,~ '. I, , Ul~ lL h ,Fij Qi) U \u u-U / ,/ ¡ I j ¡ / I J / ) FRANK H. MURKOWSKI, GOVERNOR AI,ASKA. OIL A1Q) GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Joe Polya Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska, Inc 700 G Street Ste 600 Anchorage, AK 99501 clOd.- ~ IF5Ô Re: Cook #1 305-189 Dear Mr. Polya: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a ho' ay or weekend. A person may not appeal a Commission decision to Superior C rt, unless rehearing has been requested. DATED this I~y of July, 2005 Encl. ) ) July 13, 2005 RECEIVED JUL 1 8 2005 Alaska Oil & GIS C Anch ems. Commission Drage Mr. Winton Aubert Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 RE: Sundry Approval (Form 10-403) Pioneer Unit - Cook #1 Well Plug and Abandon Dear Mr. Aubert: Attached is the 10-403 form requesting approval to Plug and Abandon the Cook #1 well. Pioneer Natural Resources acquired the Pioneer Coal Bed Methane Project through the acquisition of Evergreen Resources Corporation. Evergreen Resources attempted various stimulation techniques in an effort to produce the methane from these wells; however, the wells did not prove economical. Pioneer has determined that this project is not economically feasible at this time based on a thorough evaluation which included peer assists with experts involved in the profitable coal bed methane projects in Colorado and Canada. Pioneer is requesting a BOP waiver for the proposed Cook #1 P&A work. This * well can be killed with fresh water and has been granted BOP waiver's in the past by the AOGCC. If you have any questions, please feel free to contact me at 907-343-2111 or polyaj@pioneernrc.com. Sincerely, ~~~ Joe Polya Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK (-.", I I \,. J il ¡. r \ ' /-'\ ~ \t-IGI\- 1 /!4/zctJ ~ RECEIVED JUL 1 3 2005 r:n-s 7/14/5 n ,..,. , STATE OF ALASKA 7 -I'--~O S AlA~ ,) Oil AND GAS CONSERVATION OMM, þN APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: / Abandon GJ I Alter casing D Change approved program D 2. Operator Name: 1. Type of Request: Suspend U Repair well D Pull Tubing D Pioneer Natural Resources Alaska, Inc. 3. Address: 700 G Street Suite 600 Anchorage, AK 99501 7. KB Elevation (ft): 278 ft KB (4' AGL) 8. Property Designation: ADL 384685 11. Total Depth MD (ft): 3740' MD Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 2908-3420 Packers and SSSV Type: Total Depth TVD (ft): 3740'TVD Length n/a 245 feet 384 feet n/a 3701 feet n/a Perforate U Ahtp.éI OihiJi~~ons. Conll'R{!J Stimulate D Time ExtensiAn~rage Re-enter Suspended Well D 5. Permit to Drill Number: / Development Stratigraphic D D Exploratory 0 Service D ~02-1 a:> - 1,...C l.. - , f 0 6. API Number: 50-009-20022-00 /' 9. Well Name and Number: Cook#1 /' 10. Field/Pools(s): Pioneer Unit (610500) PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 3670'MD 3670'MD N/A Size n/a 12.750 inches 8.625 inches n/a 5.500 inches n/a Perforation Depth TVD (ft): 2908-3420 N/A 12. Attachments: Description Summary of Proposal U Detailed Operations Program 0 BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: 7/19/2005 Date: MD TVD n/a n/a 245 feet 245 feet 384 feet 384 feet n/a n/a 3701 feet 3701 feet n/a n/a Tubing Size: Tubing Grade: 2-7/8 6.4 ppf Packers and SSSV MD (ft): 13. Well Class after proposed work: Exploratory 0 ('/ Development 15. Well Status after proposed work: Oil D Gas D WAG D GINJ D Burst n/a NA 2950 psi n/a 5320 psi n/a J-55 N/A W&\-- Junk (measured): N/A Collapse n/a NA 1370 psi n/a 4910 psi n/a Tubing MD (ft): 3445 D Service D /' 0 Abandoned 0 D WDSPL D Plugged WINJ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Polya Printed Name Joe Polya Title Sr. Staff Drilling Engineer Signature C"'\~~.....c--- Phone 907-343-2111 Date 7/,3/?ooS ? \ n-,.. COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ .3~S'-1 ~7 Mechanical Integrity Test D Other: Pu 2.;; ML 1 S , 2- f s (h \ J ~D P t t~'¡; W (I.l. hIL.e4 l' ':. w;:J "e.d. J RBDMS BFL JUll 9 2005 Plug Integrity D BOP Test D Approve Form 10-403 Revised 11/2004 4 (.:'7 . Location Clearance COMMISSIONER APPROVED BY THE COMMISSION Date: 1/{£ Submit in Duplicate ) ) Pioneer Natural Resources Alaska, Inc. Plug and Abandon Procedure Pioneer Unit Cook #1 Well The Cook #1 well was drilled in November 2002 and has been shut in since October 2003. The well has a 12-3/4 inch conductor, 8-5/8 inch surface casing set at 384 feet and 5-1/2 inch production casing set at 3701 feet. The 8-5/8 inch casing string was cemented back to surface and the 8-5/8 x 5-1/2 inch annulus has been squeezed from the surface with 30 bbl cement. The well is perforated at various intervals from 2908 to 3420 feet. The completion in the Cook # 1 well consists of a progressive cavity pump (PCP) hung at 3462 feet on 2-7/8 inch tubing. Inside the tubing are 138 ea 7/8 inch diameter drive rods above the PC rotor that is set in the stator. A current schematic of the Cook #1 well is presented in Attachment 1. Pioneer Natural Resources Alaska, Inc. (Pioneer) proposes the following P&A procedure to plug the well in accordance with AOGCC regulations. Based on previous reports, the well can be killed easily with fresh water and BOP waivers have been granted by the AOGCC in the past for work on this well and other similar nearby wells. Pioneer hereby requests a BOP waiver for the operations described below. The proposed final Cook # 1 well diagram is presented in Attachment 2. 1. Verify all permit paperwork is in place and give AOGCC 24 hour notice of intent to begin well work operations and intent to cement well and give AOGCC representative chance to witness same. Obtain BOP waiver before starting work. 2. Mobilize necessary equipment and personnel to location. Tasks 3 and 4 will be done prior to moving cementing equipment to the Cook # 1 location. 3. Remove hydraulic rod drive head from well. Check for pressure on casing and tubing and bleed off if necessary. Well should kill itself on water. 4. Rig up over well with water well rig, release stuffing box and pull 138 ea drive rods and pump rotor from tubing. Move water well rig off location. 5. Rig up cementing lines on tubing and returns line on tubing/casing annulus. Test cementing line to 1500 psi. Verify ability to circulate down tubing and up annulus. 6. Mix and set 61bl cement plug in tubing and annulus by pumping down tubing and taking returns out annulus into open top tame Shut in annulus when good cement returns at surface and squeeze away any remaining cement down tubing. Clean up equipment and save cement cleanup water for injection test at next well or dispose of in an approved sanitary sewer system. WOC. Cook #1 P&A procedure.doc Page 1 7/13/2005 ) ') 7. Excavate around casing to minimum six (6) feet below existing ground level. Install guillotine saw on well and cut off well a minimum of 5 feet below grade or original ground level, whichever is deeper. Remove wellhead for backhaul to D&J yard. Top off any unfilled annuli with cement. Collect photo documentation of surface cement and cutoff well. 8. Weld on well ID marker plate (114" x 24" x 24") with the following information bead welded on plate: Pioneer NRA APD: 202-180 Pioneer Unit Cook #1 API: 50-009-20022-00 Backfill well excavation and grade for positive drainage. Perform complete site inspection immediately after P&A operations if AOGCC inspector is available. Cook #1 P&A procedure.doc Page 2 7/13/2005 PBTD 3670 ) ) Attachment 1 : Pioneer Unit Cook #1 Current Well Schematic Well Cook #1 API 50-009-20022-00 Qtr/Qtr See 30 Pioneer Natural Resources AK, Inc. Twp 18N Rng 1W Size Weight Grade Thread Depth County Matanuska, Susitna State Alaska Casing 8·5/8 24 J·55 ST&C 384 Field Pioneer Unit Country USA Casing 5·1/2 17 J·55 LT&C 3701 GLlKB 409/413 Tubing 2·7/8 6.3 J·55 8rd 3445 No. I Depth I Length I 00 10 Description 1 3462 11.51 2.88 N/A 40N045 pump wi torquestopper No-turn. 2 3416 4 N/A N/A Perforate 3416-3420 wi 4spf 23 gram charges 3 3356 4 N/A N/A Perforate 3356-3360 wi 4spf 23 gram charges 4 3120 4 N/A N/A Perforate 3120-3124 wi 4spf 23 gram charges 5 3090 4 N/A N/A Perforate 3090-3094 wi 4spf 23 gram charges 6 2954 4 N/A N/A Perforate 2954-2958 wi 4spf 23 gram charges 7 2908 4 N/A N/A Perforate 2908-2911 wi 4spf 23 gram charges 6 5 4 3 2 Modified by JRM 7/11/05 ) ) Attachment 2: Pioneer Unit Cook #1 Proposea Final Well Schematic PBTD 3670 8 Well Cook #1 API 50-009-20022-00 Qtr/Qtr See 30 Pioneer Natural Resources AK, Inc. Twp 18N Rng 1W Size Weight Grade Thread Depth County Matanuska, Susitna State Alaska Casing 8·5/8 24 J·55 ST&C 384 Field Pioneer Unit Country USA Casing 5·1/2 17 J·55 LT&C 3701 GUKB 409/413 Tubing 2·7/8 6.3 J·55 8rd 3445 No. I Depth I Length I 00 10 Description 1 3462 11.51 2.88 N/A 40N006 Insert Pump 2 3416 4 N/A N/A Perforate 3416-3420 wI 4spf 23 gram charges 3 3356 4 N/A N/A Perforate 3356-3360 wI 4spf 23 gram charges 4 3120 4 N/A N/A Perforate 3120-3124 wI 4spf 23 gram charges 5 3090 4 N/A N/A Perforate 3090-3094 wI 4spf 23 gram charges 6 2954 4 N/A N/A Perforate 2954-2958 wI 4spf 23 gram charges 7 2908 4 N/A N/A Perforate 2908-2911 wI 4spf 23 gram charges 8 Surface Well cutoff 5 feet below ground level. 3 2 Modified by JRM 7/11/05 '~~ ~ ~ E ~. ) } ~~~~~~l ') ~ FRANK H. MURKOWSKI, GOVERNOR AI~A.~KA OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~ 0 J-'-{ ttD Shane Gagliardi Petroleum Engineer Pioneer Natural Resources Alaska Inc. P.O. Box 871845 Wasilla, Alaska 99687 Re: Cook #1 Sundry Number: 304-464 Dear Mr Gagliardi: 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. 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, qv~t'Jr. Commissioner DATED this ,-i day of November, 2004 Encl. ßCAN~\!EC DEC 0 1 20 oz.;· I, . , STATE OF ALASKA ALASI )IL AND GAS CONSERVATION COMMlr 'YN APPLICATION FOR SUNDRY APPRúJAL 20 MC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Abandon U Alter casing D Change approved program D 2. Operator Name: 1. Type of Request: Suspend U Repair well D Pull Tubing D Pioneer Natural Resources Alaska Inc. 3. Address: P.O. Box 871845, Wasilla, AK 99687 7. KB Elevation (ft): 8. Property Designation: 11. Total Depth MD (ft): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 2908- 3420 Packers and SSSV Type: 278 ft KB (4' AGL) ADL 384685 V,iG A- ¡ 1/2.4 (lð04 r7T5 tll2Fìj ~ Perforate U I Waiver U Annular Dispos·U Stimulate D Time ExtensionD Other EJ /' Re-enter Suspended Well D Long Term Shut In 5. Permit to Drill Number: Development Stratigraphic D D / o D / 50-009-20022-00 ~202 182- '¡é:rl - ¡ 'eO Exploratory Service \t.I~ 6. API Number: 9. Well Name and Number: Cook #1 10. Field/Pools(s): Pioneer Unit (610500) Total Depth TVD (ft): PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): Length N/A 241 380 N/A 3697 N/A Size N/A 12-3/4 8-518 N/A 5-1/2 N/A MD TVD Burst Collapse N/A N/A N/A N/A 245 245 N/A N/A 384 384 2950 1370 N/A N/A N/A N/A 3701 3701 5320 4910 N/A N/A N/A N/A Tubing Size: Tubing Grade: Tubing MD (ft): 2-7/8 6.4 ppf J-55 3445 Packers and SSSV MD (ft): N/A 12. Attachments: Description Summary of Proposal U Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name o_ Title Signature .u 907-357-8130 Date COMMISSION USE ONLY Perforation Depth TVD (ft): 2908 - 3420 N/A 11/8/2004 Date: /" 13. Well Class after proposed work: Exploratory 0 Development D Service D 15. Well Status after proposed work: Oil D Gas 0 / Plugged D Abandoned D WAG D GINJ D WINJ D WDSPL D Shane Gagliardi Petroleum Engineer 11/8/2004 Conditions of approval: Notify Commission so that a representative may witness , Sundry Number: ~ L, I' ~ tJ ~ Plug Integrity D Other: BOP Test D Mechanical Integrity Test D Location Clearance D -s "- {,{,. t- ; v,- Subsequent Form Required: ({ Yl I'lIÁ.CL- ( Approved by v;;i/f Form 10-403 Revised 06/2004 RBDMS BFL NOV 3 0 2004 ~¡{ t'-€-fO r t r~ 20 A-/Ì-L 1-<;, US' , COMMISSIONER APPROVED BY THE COMMISSION Date II f'2~ / 4- ORIGINAL Submit in Duplicate .......... ') STATE OF ALASKA ) ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: OilD Gasl2J PluggedD AbandonedD SuspendedD WAGD 20AAC 25,105 20AAC 25.110 1 b. Well Class: Development D Exploratory I2J Service D Stratigraphic Test D 12. Permit to Drill Number: 202-180 GINJD 2. Operator Name: Evergreen Resources Alaska Corp. WINJD WDSPLD No. of completions _ Other 5. Date Comp., Susp., or Aband.: 6/5103 3. Address: P.O. Box 871845 Wasilla, AK 99687 4a. Location of Well (Governmental Section): 6. Date Spudded: 11/21/02 13. API Number: 50-009-20022-00 7. Date TD Reached: 11¢02 nP'",A / ~4 or"""- 8. KB Elevation (ft): 413 ft KB 14. Well Name and Number: Cook #1 Surface: SW/SE Sec 30 Twn 18N Rng 1W, Seward Meridian 15. Field/Pool(s): Pioneer Unit Top of Productive: Same Horizon: Same 9. Plug Back Depth (MD + TVD): 3670' KB MD Total Depth: Same 4b. Location of Well (State Base Plane Coordinates): Sec 30 Twn 18N Rng 1w Surface: x- 991' FSL y- 888' FEL 10. Total Depth (MD + TVD): 3740' KB MD 11. Depth where SSSV Set: 16. Property Designation: State 17. Land Use Permit: Zone-4 TPI: x- Same y- Same Zone-4 NIA feet MD ADL 384685 TotalDepth: x- Same y- Same Zone-4 19. Water Depth, if Offshore: 20. Thickness of Permafrost: NIA 18. Directional Survey: YesD Nol2J NIA feet MSL 21. Logs Run: Compensated Density Neutron Log; Induction; Gamma Ray; Cased Hole Neutron; Dual Spaced Cement Bond Log; Mud log, Inclination Survey 22. CASING, LINER AND CEMENTING RECORD CASING WT. SETTING DEPTH MD SETTING DEPTH TVD AMOUNT SIZE PER GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED FT. 12-3/4 36 NIA 0 245 0 245 16 40 sx Class A 8-518 23 J-55 0 384 0 384 11 35 bbls Class A 5-1/2 17 J-55 0 3701 0 3701 7-7/8 150 bbls Class A 23. Perforations Open to Production (MD + TVD of Top and Bottom Interval, Size, and Number; if none, state "none"): 3416-3420,0.45" 23 gram, 32 holes @ 4 spf 3356-3360,0.45" 23 gram, 28 holes @ 4 spf 3120-3124,0.45" 23 gram, 16 holes @ 4 spf 3090-3094,0.45" 23 gram, 16 holes @ 4 spf 2954-2958, 0.45" 23 gram, 24 holes @ 4 spf 2908-2911,0.45" 23 gram, 16 holes @ 4 spf 24. TUBING RECORD DEPTH SET (MD) 3461 SIZE 2-7/8 PACKER SET (MD) NIA 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 3356-3420 Borate x-link gel frac wI 50,200 3094-3120 Borate x-link gel frac wI 45,230 2911-2954 Borate x-link gel frac wI 45,780 26. Date of First Production: 5 June 03 PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): PC Pump Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: I Gas-Oil Ratio: 5 June 03 Test Period .. NIA NIA Flow. Tubing Casing Pressure: Calulated .. Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press: 24-Hour Rate NIA NIA 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water (attach separate sheet, if necessary). ~. Ci)\~ ;)1_::': ::':ì'~ Submit core chips; if none, state "none". '. .... .' ~ 4': TE Interbedded sandstone, siltstone, carbonaceous shale and coal seams. No porosity measurements taken. ~~áètùrès áhd7é1e1:l1s ,~/ ih;s present. Apparent dip less than 5 degrees. Gas and water present wI gas desorbing from chips under microsèope. . , ;fE.R.:!la¡ \.'~ -" 1k ( Form 10-407 Revised 4/2003 CONTINUED ON REVERSE SIDE ORIGINAL 1.(- -~ \B~I¡ '~r:p "'\ ""~'i'1,,·~â~~,. NAME GEOLOGIC MAl MD 1s I TVD 29. Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". '~MA TION TESTS --'I 28. None None 30. List of Attachments: Daily Completion Reports; Treatment Reports; all above listed logs 31. I hereby certify that the foregoing' true and correct to the best of my knowledge. Contact Shane Gagliardi Title Petroleum Enqineer Phone 907-355-8569 Printed Name S~ Gaqli di Signature ~ . Date 7/2/03 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 1 a: 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 elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional 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: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 4/2003 ORIGINAL w .. " ') Current 50~09-20022~O =\'=I~GI~== 1'1 ) Well Cook #1 Qtr/Qtr Twp 18N See Rng API 30 1W Size Weight Grade Thread Depth County Matanuska, Susitna State Alaska Casing 8-5/8 24 J-55 ST&C 384 Field Pioneer Unit Country USA Casing 5-1/2 17 J-55 LT&C 3701 GLlKB 409/413 Tubing 2-7/8 6.3 J-55 8rd 3445 No. I Depth I Length I 00 10 Description ... ~ 1 3462 11.51 2.88 N/A 30N045 pump wI torquestopper No-turn. 2 3416 4 N/A N/A Perforate 3416-3420 wI 4spf 23 gram charges 3 3356 4 N/A N/A Perforate 3356-3360 wI 4spf 23 gram charges 4 3120 4 N/A N/A Perforate 3120-3124 w/4spf 23 gram charges 5 3090 4 N/A N/A Perforate 3090-3094 wI 4spf 23 gram charges 6 2954 4 N/A N/A Perforate 2954-2958 wI 4spf 23 gram charges 7 2908 4 N/A N/A Perforate 2908-2911 w/4spf 23 gram charges = IE 7 I/iË 6 = liE 5 1æ4 :~c: "00:- ~ .... ~ ~ ...... ... ~ ....~\'..~ PBTD 3670 Modified by STG 7/3/03 ) IReport No 11 Begin 111-21-020600 Daily Drilling Report lEnd 1# supervisor 10. WALTERS Well ICOOK Qtr/Qtr ¡see 130 ¡NO 11 Twp IT18N IAPI 150-009-20022-00 loperator IRng R1W Icounty !MAT-SU f# Ri9 Name EWS RIG #1 IEVERGREEN RESOURCES ALA: Field IPIONEER UNIT !state ALASKA Country I USA Project IPIONEER UNIT Target Planned TD(ft) Current Depth (It KB) I Current Activity DRLG 7 7/8" HOLE AFE I DailYTotal ($) 140830 Well Total ($)1 1140830 Conductor 1123/4" @ 245'surf Csg. 185/8",23# @ 384' Int Csg Spud Date (MMIDDIYYYY) 111-21-02 lEnd Date (MM/DDIYVYY) 24hr Forecast IDRILL TO CORE POINT,CORE ACCident (y/n) I I Last Safety Meeting Date I # Prd Csg I I Driller TD (It KB) I Bottom Csg (ft KB) Start End Duration Activity 0600 1100 5.0 WAIT ON MECHANIC TO REPAIR COMPRESSORS .. ~.. "" ." . 1100 1600 5.0 MIRU EWS #1 , ". ,. d.. .,,, ., "'"''''~''''' . 1600 1730 1.5 ~UDIVERT~R,II~W/11" 1730 1900 1.5 DRILL 11"F/245'T/390' 1900 2000 1.0 CIRC & TOOH '.','. ' ..-"'. .'. -----2PÜO~,-_:~PQ·_-,-,h---hD~=~-::.-·- MIRU-~A-!--¡:ERSQN-W-IR§~IN~bº(?ïRg-:-Wb---~-------------'---"-'-~:_:-~-:---'-'-------------_._------_..------_.._-- 2100 2145 0.75 RUN13 JTS8 5/8"23#,K-55,STCCSG,!OTALING=379.T,~~T@383.7' ?145 2230 1.25 ' RÜ èMTRS"pu'MPjº"ê'~~~,H~ö.,1º,~Ø~§Q~.~lÞX(YYÄj~Rjq,~ªÇ§8~q!~?ê.ê~§_ÇMI @ 15.:$.# ,... pI§P W/22 BBL§ H?Op~UG paWN @h?213 ~R§CIRC 11 BBLS CMT TO PIT,ISIP=150# 2230 0600 7.5 wac ... . ~ '-' ".~, ..- Notes I Summary I Ver 1,0 lit· 1/ 8-28-99 ) ) Daily Drilling Report [~~~~~~~~~]jr]~~~~~~~I~~f§'~~2f~~~~~~~=~~~:~:~~~~:~::~::::::::~I~~~~~:~~Jñ~~~~9.?~~f~~~:~~=::~:~::~~::~~~:~I~~~~~~~~]II~~f.~~~::=~::::~::=:::~:~:~:~~~:~~~] ."'" ']"""'~ ,~-"""~ " ,~, - .~'--' ;r" '1>~~~""'"~'''']''~''''''''''»''''''' ", ~-"""V"'--"1:^'~~ ""~~"Ir»; "'~..w "~-'-"-'.- .. m"~_~"-''''''''~'''''''I::::~::' ''''''~~'''''''''-¡ ~Well ¡tOOK jNo ¡'~j¡ API ~I-009-20022-00 J?perator rQ!ERGREEN RESOURCES AIjField lmpNEER UNIT ! ¡~~I~=:~=_I~~=i~~~~~:F~~_!~~ir~i~~=~==:~~~~f~~~~~~~t_t~t!~-=::] ... ---..-"'--, - -m..-.---1(->.-'...-.'.-'''o"'..-.....'----.'--...''''..''.---..^'m_ _._n___ .. n.. "........-...~,,-- '..' .n^'n..-m'.]..m....-.."'^"---^fi...~.. _._.,,_..._.^~'_~...n.. "'."'.-....."...^-. "'-" ",' ¡Current Depth (ft KB) è¡@ ¡Current Activity ¡¡1IH wn 7/8I1DHD 24hr Forecast J~ILL TO CORE POINT,CORE ~ ~~i~ii~~!i~~~~~~~~~~~:-~~~-¡~!;~~~:~_~:~~---~===~~~ ~~~~~~-~=ti~~ft;~~~;~:~i~~~~~~f:-=-:n~n--~-=~~oi-~~~~-::~-:-:=~~:-====~=~~~-~-:==-~=:~=---~~~=:---~:~-=-~--==-~:-~I 11400 .i 1630 12.5' ¡ClRC HOLE CLEAN, TOOH " , , i ~1639 ,!1830 ¡2.0 ¡PU CORE BARREL,TlH j1830 ¡1900 10.5 ¡CORE F/1631' T/1661' 11900 ~2100 12.0 hOOH.LD CORE ~' "': ¡ . , - ;2100 - --;22-30----:1.5- ~~ -HtH-Wfl-7I8am"lD-' : 3 ¡ ¡223O !qDOO ~0.5 ¡DRL~ F/1661' T/1895' ¡DODO W130 ¡1.5 ¡TOOH j0130 i0300 j 1.5 ~TIH W/~ORE BARREL ¡0300 i0400 p.O ¡CORE F/1895' T/1925' j0400 ~0530 ~ 1.5 ITOQH 10530 ~0600 ;0.5 !lD CORE : : ¡ ~ 3 3 : ¡ ~ f ~ ¡ ~ ; ~ ; : , . ! ¡ ¡ ¡ : ~ ¡ ¡ : ; ~ . ¡ } ; ¡ 1 I I I i j' ! ! ¡ ¡ j ~: j ¡ . . ¡ ¡ 1 ~ '~:..~.~.'~.:.:~.:.:, ~:..~.~.':.:,:.:....::, :........ !, :,':,:.;:.:.:~.:,~.: ¡¡, ~;;/:~: I: ~: 3 1:::: ~ ¡ i I. i ¡::', ¡ ¡, ¡ i ¡ ? . . ,!:,' ~:::: j ¡ ¡ ¡ 1:': ~"::~. i ! ,_ _mL _ . .J" -' _ _ J" __. _, . , _ . . _.. _ ___m. m . ~ _ ... _ __m._ __. _ , __~ f~;~^' tmmr ..... _. -.. .. -- m --.-,-^---^"-. mm ^-- ... ..- .,.----- ._- d .. ..on" - "'" -- m no '_.' m _, ._ m ,_ - m_ ,. , . ____w ",. ... --- - "¡ h~~~. ................ ........... .......... ....n..... ....... .................... ......... ...................... ..... ......... ........ ....... .......... .............. ............ ............... ...... .. . ................. ........ .._... .................... .........; 1~·~=:í.1f¡:..~-~:~~-:~::~·:_·n- .:~.~_.^:._-~~..~::~:.^:::--:-..^-^j , ~ . ..... ..... ... ,. - , ' ---....-+ Ver 1,0 jjl-11 &-28-99 ') ) Daily Drilling Report l~~~~~~~~~]j[J?~~~~=~I~~~~~~~~P£~.~~~~~~~~~~~~~~~~~:~:~:~:~~~:]~~~~~~:]i1ª~~~9.I2~~p.:~~~~~~::~::::=:~~~I~~~i.~~~~]lf~1.~i.~~~~~~~:~:::~::~~:~~~:~:=~~:~~~~:~] :~~'-'Œ»--~-'''-- ,.w ~- ~ _'__"'m- n~rw--'I»>'~" --'1:--' "r"">' '---~~""'''~~'-~-'J~--,,~,_v'f¡'''''''''' _v,,'_--__~ ,~ '" -"",,,-,, ""; ,-,~ "]"'':'::'''''' -, W"~W_~-"""1 ¡Well f@þOK ~NO ¡1¡¡~ J~PI ~1-009-20022-00 Operator t§¥ERGREEN RESOURCES AU{Field R!PNEER UNIT ~ r~~.-~.-==j~]i[::":E~'~:~ :~JlVr-~~:I~~:"T:~~=~=-=-:-::-:~J~'~~~A':-~~~~=:-:-=='i ¡Target ~tfj ¡Planned TD(ft) IiI: tRig Name JijfJS RIG #1 fproject T¡'~pNEER UNIT ¡ .....--......._____"'___ -,.'"^"'-.~~,-.r' --~_______...--"._ - _,___,., --......---,., --...~...---,,____ --_...__.....___ _.._______.,~--_ _____-...j. - ~_ --'V',._.----.....t-- a_ ____,..___~.._.....,,- "þþ"." _,._.........._..___.___ _____ -.-A--' ,,~_.....__...._ f~ þ__..._. ______...... __..a.....'......._""'...._,,......_,., ..__,.__....~ ~"..~, '"·-...-----~-~..--~nr':'~----'- ~.~ -...,,~~..,,--~'.-."-- -v,->.-,~- -- -" .-~ ,'" -~-, -_v. --- ...n_~'__ -...-......--'-...-.-w----n'...r.:'-- __,~v" - - -'-·..~r-.-.-'-·"--"-~~...·-,,w~_.--- _,~_.~~_..___~'._..'"._~.n w" ¡current Depth (nKB) &f [current Activity ¡¡tþOHF/CORE#4 J24hrForecast l~þRE.DRILL TOTD í f~~-~II~ô~~~~~,~.!~~~~~~:~;~~~~~~;~~;~~~~~:..~~~~=~J .....__...---....~_..........~......":I-. oR___........___·___....".__~___......._. ------..:-~.. ...-..--...----- -....... w......__...........-.· --__ .._. ...~___- _....."... - _~ _. __. _w_ _____....-.....-. -... ........___....................._....___...._____ - .._.......""-,. .__.- ......-._-..... ..................----. -,,""'"',.- ---......,,---. _..__...---~...----- -.......-- ""----'"'-$ ¡ Start ¡ End ¡ Duration ¡ Activity ¡ ~œôõ~-'~~1øf~",w-'''fjJJ5-' --n~n-tfiH 'wÏi-7ïiFõHî:)-"'--'---""-'"-~'-''''''' _""__"_M'__ ~-.--"---"'--~.~. ~- ._...,,__,_,___"..."'n. '"-- ~-. ~-- ---. - ___n___.____....,,_~'W____m_W~"__ -1 ¡Q73O 11200 14.5 ;DRLG 7 7/S" F/1925' T/2423' . ~ . ~ ! 1200 j 1330 i 1.5 ìCIRC & TOOH ~'~ ~ ¡ 11330 ~1500 ~1.5 !TIH W/CORE BARREL .. ~ . ~ i 1500 ~ 1600 j 1.0 ¡CORE F/2423' T 12453' 3" '. . ' -----i 1600--! 17Je--¡ 1-.5--1 TeeH- -- - -- -.. . ~ . ~ 1739.. ,PlµO ¡ 1.0 jLD CORE 1#3 ¡ 1830 å2000 ¡ 1.5 ¡ TlH WI? ìl8" DHD 1200'0 ;0530 j9.5 IDRLG F/2453' T/3415' 10530 msoo 10.5 ¡CIRC & TOOH I I I i ¡ ¡ i ~ ~ ¡ ~ : . Iii i j ; : ~ ; ¡ ¡ i ¡ ; ¡ i ¡ I ¡ :.....-.____J____......;,w__ __ L __ ____ _ n _ __ n - -- -.. - , ' - - - _.- --. - -- . . - - - - - - - - -- -- - .. . - ..... .,.. , ! i .--_.._-......_~......... - - -- -- - -- --. - --.- --- ,~f-]¡~l¡L:~·,..-.:-~,~~,~..~.~·-,~:w,~.~-.-,~-,-·,~--,..,'-,-~,'.--.=,.,.:,-.....:--.,",.:--,=,'.-,-.,.'.~.."....,',:..,~,.-.".,.:..-"..,--.,..,.-----.-...--.--,..',-".,--.:,'-,~~~....,:-:,-~"..--,:,-.~~~,:,''".,~.,~..~-,~,~~-~.~,,:~~.-,-~~--,..~~~~-....:-:~~,-.,---,,:~.:..,:,.,,:--.,..~~:.-.--:,-,:-:,-~-.,""---.-,-.~-~.:.--'~.:.:-,.,~,:.".=.:.,-,.,w.._-.,w·.~ ~ ~ f::::;::::················ .... .................................... ............................. ...............................................................................................................................................................................~ t.~~~~ t );,~;;:.;;;,...........-.........-......................-.........-................................................................................................................................................"''''............'''...'''..............'''.....................................................................................) I~.f~~·.·:.i·i·n-:~:~- ,,··:~:::in::·.::._::..."n~.~·..·:j Ver 1,0 jt'1/8-28-99 ) ) Daily Drilling Report [~~~~~~?~:]I]~~~~~:]n~~:tQI2~~P~~~~~~=:::::::::~~~=::::=:::]~~~~~~=:I~?~~:9.g?:2.~QP::::::=:~~:::~:::~::::]~~~.~~~~.~~..JIÜ!~~i~~f:==::~::~:~:::::::::::::::::::=] :"'''--~l~''<''~''- "'m~ .'n .,- ,'''''''', '",,?'"''''']''''''''' "" '-'lvn-::""",,-~'''w'_'--~n''n'''' "'"1:--'--~ .".r"""n''.--- . __"w__",,_ .,,--------"':-. "--]-:::~~'-~"--.-,." ~ ¡Well iBþOK iNo ¡1.~[ JAPI ~M-009-20022-00 J?perator iÎVERGREEN RESOURCES AL4Field fJPNEER UNIT. ! ê:~E~_~'1~~~~¡~~ª1i~~1~~~!~~~~ª~1~.~===~~~~1~;~==~'::::-="; ""_'m ....-.--. -.---.h--r·.-.-.h..- _______.'_hW.__'____.____.h..h._..,.....,. '... '.~n_.'__.__. -,w--------....~'--_'--m--.m·~'-·-T·h . .m___"""'n 1......,...-.--- ..____ .mm______...h_...n.__h'..n -. ""'n, ¡Current Depth (ftKB) i:¡:} fcurrentActlvity Wø WL,RU CSG TOOLS .l24hrForecast llWN & CMT PROD CSG,RDMO ; ~~~~!~~~~~!~~~~~~~~~~~~i~?~~~~~~~;~~;~~~~~] !............. -........... __"W; ". --.......... -- ---.-·t....................-...-...........;-....... -- ..--..... .-..............--.... ..........-,...."..,..---- _....w..-.....___ -, ................w ...-------...........--.. .......-.....,....- ...............--............_____ ___..........-,______, -..._ _....-_......,_.._............... .........-.............-.- - --... -............... -_......_......~....,...........~ å Start = End : Duration i Activity ¡ f.ô6Õo··--"1øß.3õ··'-··~t!~lr~m. ·1!ÖÔ~iïNfi·7Î8;õ·H'Ò--··---'~w..-~---..~~-.~.----.-...,--.~_w._~~_.___M_W_.....~~·~._..,.. . n_ ^-. . "...--...."...--..- _.._.'h~____...__ --~ 10830 ~ 1100 :2.5 ; TlH W/CORE BARREL #4 :., ~ i 1100 ; 1200 ¡ 1.0 ¡REPAIR DIVERTER & BLOW LINE 11200' ~1300 ¡to ~COREFI3415"TI3445' ~13QO, J1600, ¡3.0 ¡TOOH W/CqRE #4 --i 1600--i'1800-- - -¡ 2;0-- - -fflH-Wf{-7f8"lJHEJ ¡ 1800 !2200 14.0 1DRLG 77/8- F13445' TI3740' !2200' '~0100¡3,O 1CIRC HOLE CLEAN, TaGH ., 10100 J0600 ¡S.D JM1RU PATIERSON WIRELlNE,LOG OH INTERVAL.RD WL ¡ . ¡ ~ ¡ ¡ : ¡ ! . ! ¡ ~ : : i ¡ ¡ ~ 1 ¡ i 1 . : ! . . ~ ~% [Æ f@ ¡ i ¡ i J : : : ~ i ¡ ¡ r~~) f~~J~: ~:}~;~: ~~{t j ¡ ¡ ~ ; ¡ i ¡ ¡ : , ~ ~}}: rt=~:,_::·,···I:I=,::::~·==::::=:=:::======::,:·::',·::.......::.::::::=.:=.=:..=::::::::::=.j ¡~~- - TIi~ - ~ m m.m -- .- -----. - m m_m , ..- - ,. -. no _w___ -- -- - ___.m _m m mnmh. _, _' m - _._ __m ._ _'_.m. ~. m __'n - __ n ,_ _j ~~~l·--·::::::::~--,·-v...--...,."wN".,.w,-..,..w".".'w-"'".w.W'-"-,W"W'·'''_·''__W.__,',-,W,WN.,·,'.W,'W.',-,-,',w,·,·.'.·.,·,.',',·"w,~,·,.,-,'w,,·,,·.w..,,"''',·.w.·,_,,,.·."w,·~·,w,·~·.w.·,w.,·,,·,",,.'.·.'.·,,w._'w,w,w,"_.,.~w~-"-.,,~-"'-".,.,,-.,-,w,.w..,w.í ~~~L:~::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~::::::::::::::~::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::J 1~~~-~11:^·:.:..:^·:·~ -".:.^ ^·.'~::~:i.::~.-^~::··'~-'::,.-::-'::. :.<;.-:~j --------- ---- -~------- -.--- - ---....~........ ~ , i -"..-, r---- ! Ver 1.0 j-1/8-28-99 ';) ) Daily Drilling Report ,.~--,-- u_,,~u ~W~-"1:-U-'W~-lVi.~-,---.w-----.w~",_--mu------ ___u_w-., ~.,.].-~w--'- "rz-",,,u,,,,,w-~-u-,,u-u,--,~,w,,u~-'''l''~---v-u,,-----~,,.m._'....'m.'..wvvu--.v---.u--..u----U--] i~~~~.~_JI....L~~~?~~.JI:~~:~~.2~P.~~....................~............. :~~.......f11~~!3.~~?...q~~.~~..._......_............. ~~~~~~..JI.Y.Y~~!§~~....................................~ ......~w r---'- ,ww,,,,,w__ w.w" , ,,",' ":r""~t;rw' ." '1 ,.w'¥:_""w,_'" W ww"""-"wI'w,,,,~, w, WtW~" "",,,,,,,"v - _w,,~_ -"",-,,,,,w""""WW_V]__~' " -w v,'_' '1 iWell ícboK ¡NO l'¡¡¡ .tP1 ~M·009-20022-00 Operator fiVERGREEN RESOURCES ALÅField ì~þNEER UNIT < r;;}i-~:"_=~_-=~~~":]~~.~~~Ei2~Jl&~~-Î=~=n~=:~~"~~~~~~i!~n:n,,:="=,j [~~~~~~~~~:=~IJ·T~~--;~~·~J~~~;JÎ~~J~~~":·-:·~~I=·="~:::~:"n:'J ¡Conductor l1:ï:3I4· @ 245jsuñCsg. I~~~8·,23# @ 384' rl~tCsg ltt jPrd Ceg iJI2-,17# @ 3700' ¡ t~~~~~~~~~~~~~~~ll~~1~~~~~~~~.::~~~]~~~~~~~~~~~~JM~~~?:~~~~~:~~::~~~~~~~~:~~~~~~~~~~~~~~]~fC~~~=~:~I~~~~ji~~~~~~~~~:wL~~'~~~~:::~~~:::J tI~~-~~:~1i~~:~~~R~~~;~~i~·~::~:::=:~~::==:~-~":~-:--=::~~:-=-:-:::~~=:-:~::=.-=-:=::~=.:-=-=:=\ 10630 . ;0900 ¡2.5 ¡RUN 5 1I2D,1ì#,K-55.LTG SGG " ) . ~ ". ~ 1.0900 ;0930 10.5 ¡POWER TONG ENGINE FAILED. HOOK UP TONGS TO RIG HYD ¡09~' 'j 1130 12.0 ¡RUN 5 1/~t T/3695.97' . ' . ' " " , , p130 ~1200 ,¡O.5 ,¡LAND GSG @ 3700.97'!RDRD-20 , _11?00 ª 1230--10.5-- -~RU-GM+RS-- -----.------- ~ ~,. . 1 . ¡ 1230 ~1430 12.0 ¡WAIT ON CMTRS TO MIX GMT 11430 11530 11.0 ¡PUMP 60 BBLS H20',1O BBLS GEl!DYE VvATER,20 BB'LS H20, 150 BBLS' CMT @ 13.7#,DISP W185 ~ } i IBBLS H20.BUMP PLUq W/1400#,PLUG DOVYN & 1530 HRS,DID NOT, CIRC CMT TO SURF [, î ~ ¡GOOD CIRC THRU OUT,FLOAT HE~D,RD CMTRS ¡ 1~, P990 ~3.5 ~MOVE RIG & COMPS T/DJ YARD, p900 ~0600 111.0 ¡NO ACTIVITY ¡ ~ 1 ¡ , , ¡ ¡! ~ i ~ ¡ ~ ¡ ¡ !.¡ : ~ ~ ; !, I! ! ¡ ¡ ¡ i \,.....:.:....:.....:... I:..::.:.':,:.....:...,.: , I i.':.:..:.:..::.:.:.:.,: ~ : . 1::.::::::::: ~ ~ ~ ¡. ¡ ¡ =:. ':. 1:.' ~ ; = ~ ~ i=:~=::~¡Î=:~=:::i~,~:=:í:,:.:==::::~~::·:::^-:=-=,-=:~~:::..::_.':,~:=~~-::_~:=:'::.::~~':'::=-':-~:~~~:m~::'-:_~~-:=-::.::.."~"::::=~--~::.-:::m.:i f~~u . EK,.:w,~.:.:~~~~~."..·~,:~.:~.:~.-..~.:~.:_-~~~.:..w,.,w".,'~,-""~~:..,~~~~~~~,..,~~..~~:,,~.~,~,~~.·.-~,~~~~~,~~.~,,~~~~~~,:,,~~_,~,:~..~~~,,~~~~~~:~,~~w:~~~.~~.~~,~:,~.:~~_~~~"'~.·~,~.:.,,~~~~~_~.:,,~.:.·~_..w..,,'w,,"~..~~_w,.:~~,~,,~.:.,'~,.:~~'''~~w..:~'''~,.:.:~~~: I::::::~:~:==~::::::"::::":~~::::::::::::::::~::.:~:~:::::::::::::::::::::::::~:::~:::~:"::":::~:::::::=~:~:=~::::~:::::=:::::::::::::~:::::~:::::~:~:::=:~:::::~:::::::::=:~:~:::::=,:::::::::::::=::=::::::::~:::::J ~f~-~~;' J¡¡L.... .~:. ~~..... ..~... ..~.. ...~......--:. ~~... .-... .'...., ~.-.~... ~.~.................... ~~.-.~~. ,..... ..:.... .~...~.'... ....-...........~.. ::. ~'..... ~.~........... ~..~.. ........-.=~-~...~. ~.m......~. ..... :..~... .~.':~ .......... J ~:~:¡)........ ............,....................".....................,....,.........".......................... .-. .. -................ ........'.........................................,.............. ...................... .................................. .....,.j ~,:,;;;.,--.. '___m__ __. .___, _ _____, __ ___. __'m __m.._ _u.. .. m .m , __.m___ '..__ u.. " ..o m' ____ __...o__ __ _'m'. ., __ . m u .' _ ___ u . u ,__ __m ___..., , . , . , I _______ ________.____ ______1___-_- i . ¡ ~ ~ Ver 1.0 jjI-1/8-28-99 Report No 12 IBegln 105/23/03 Well Ilþok QIr/Qtr ~rv/SE Contractor po# I (jiaoo Ô900 1200 1400 see & Patterson Daily Total (S) Start End Duration Daily Completion Report lEnd NO TWP IAPI l§i~-009-200022-00 I Rn 9 :iill:'¡t1:ii ) 15/23/2003 supervisor Trout county loperator I State I!¡!~ska Field ¡Itoneer Country I:~:ßA 0900 "'200 1400 2 2900 9 currentAetiVity~êying Gas Sales Line and Water Line $21,735.00 Well Total (S) I , $24,385.00 Tying in Production Equip. I m~ul in & off load gas & water line, 400 bbl water tank. DIg ditches for gas & water lines. Welding together 3" gas water lines. RU Patterson to 5 1/2" production csg and ran GR CBl CCl from loggers 1 (log indicating good bonding from TO to 450' and fair to good bond from 450' to surface). RO Patterson and secure well. laying lines into ditches. Backfilling ditches. InstaJ.!.~on 75% complete. SOON. --.. ----. ----- ----.-- --.-- ---- "------ -- ----------------- ---- - - -------------------------- ---------------- - "---.---.--- Notes Summary COST ESTIMATE; Patterson (Including air fare) O. J Excavation Supervision National Misc. $7,935.00 $7,000.00 $300.00 $5,000.00 $1,500.00 $21,735.00 Ver 1.0 lit-1/8-28-99 Vet 1,0 it. 1/8-28-99 Summary $3,600.00 $1,000.00 $100.00 $8,000.00 $5,000.00 $500.00 $18,200.00 COST ESTIMATE; gåtterson D. J. Excavation S:ûpervision Water Tank & Seperator Water & Gas Lines Misc. .- - - .- Tieing in water tank and seperator. 1700 9 0800 Secure well. RD & MO. End Duration 1000 2 1015 1/4 1000 RU Patterson & boom truck.lnstalllubercator & perforate'3416' to 3420',3356 to 3360' w/4 HPF using 4" HSC wI DP charges. 0800 ActJvity Start 124hr Fallen! Perpare to frac. I Accident (¡In) IN 0 I Last Safety MeetJng Date I $42,585.00 Prepare to Perf. Well Total (S) I I I Begin 105/27/03 ¡NO 11 ¡sec 130 TWP 118 Patterson. & D. J. Current Activity Daily Total (S) $18,200.00 POI I Contractor I Evergre~n Resources Alaska Field \PiOneer 1,,·,. IAlaSka Country IUSA loperator Mat-Su ¡ County IAPI 150-009-200022 Rng I 1 Well ¡Cook atr/Qtr SE/SE Isupervlsor ¡Trout Daily Completion Report I End [5/27/2003 I Report No 13 ) ") I Report No Segln liª~$1/03 Well liþok QIr/Qtr 1,~tI/SE NO Isec liª~ TWP ) ) Daily Completion Report lEnd 1§~ß1/03 supervlsor II~gliardi IAPI 1:§~-009-20022-00 Rng 1:,1:~ operator I'i~ergreen Resources Alaska county IM~tanuska,Susitna IState ~Jþska Field lil~neer Country li~$A Contractor PO# I ¡~iVS . Current Activity :~timulate well Daily Total ($) $112;500.00 Well Total ($) II $155,085.00 124hr Forecast liiçpduction Test , Accident (y/n) I No I Last Safety Meeting Date 15/31/03 Start End Duration Activity rø,lRU EWS International Frac fleet and Patterson Wireline. Wßld job safety mtg and pressure test lines to 4650 psi· held. ~¡rst stage: 3416-3420 and 3356-3360. Frac wI 20-25 borate cross link gel. Pumped total of 53,780 Ibs g,Q/40 Ottowa sand. Break @ 3470 psi and avg treating pressure of 3200 psi. Pressureqeclined @a ¡~,~þadY rate once the 4 ppg sand hit and continued to decline throughout the rest of the job. 'I~;IP: 2540 psi. r&µ Patterson Wireline and full bore lubricator. Open frac valve; pressure pushed WRP to top of lubricator 'ª,Ôd cut wireline. NO lubricator and remove plug. Redress rope socket and repair packing head. '~!;FrWI-5::17ZWRP:--Sël'prü£r@-3-1'70rKS:'-PerfÖratenJ1Z0:3T24aña'ja9-0~JÕ94'wT23g-ram-premrü-m--"'--"----~-- cHarges @ 4 spf and 120 degree phasing. 1600 1800 2 Attempt to frac second stage. Pumped 1 ppg slug ahead. When sand slug hit perfs, pressure out @ 4100 psi. Make several attempts to re-establish injection - unsuccessful. Attempt to surge well to clean perfs - unsuccessful. 1800 SWIFN wI 2200 Ibs sand in well bore. Wait on rig for clean out. Notes Summary ESTIMATE $100,000.00 $8,000.00 $1,000.00 $1,000.00 $1,000.00 $1,500.00 p'åtterson Supervision Water Equipment Rental Misc. TOTAL $112,500.00 V'" 1,0 lil-II &-2&-99 ') ) Daily Completion Report lEnd 1:ª~~/03 Report No I~I":¡ IBegln "~~i~/03 supervlsor I,~!~gliardi INO Isec I'ß@ IT~ , Field I¡;:¡pneer ,Country Im,$A Well ,I\pok Qtr/Qtr 1:~,ÿV/SE IAPI 1~.@-009-20022-00 Rng li~:W operator II,tergreen Resou~~es Alaska I,W~tanuska,Susitna I Stale I~¡~ska , /county 24hr Forecast 1:~I:þan out well Accident (y/n) I No I Last Safety Meeting Date '15/31/03 ~,î{Vs CUlTent ActiVity~heck Sand DailyTotal(S) $4,000.00 Well Total (S) I I $159,085.00 Contractor po, I End Start Duration Activity i~~30 [Qß~O ~.woo ,~Z30 ~.ª30 &1JRU Patterson Wireline. ~¡H wI junk basket and collar locator. Tag sand @ 3100'. Have 70' of sand to WRP @ 3170', ~~IFN. Wait on rig for clean out. ~¡!lH?: :W . __~.. __"_,,..___.__..__..__....__...._...____._..._._.._.__.__...._~'._ _, .._, "'H_·_.__"'_ . -..,.-..,...- ."'-" - -------------..--..-----....-.-- - .-.....-. .,,---,.--..---'-"..'"-.--" <--.-.-------. .., ....".....-..-,,---."'.-."'........ COST ESTIMATE Patterson Supervision [;quipment Rental Misc. $1,000.00 $500.00 $1,000.00 $1,500.00 $4,000.00 TOTAL Notes I,' Summa¡y Vel 1.0 jjl·1I6-28-99 Report No 16 IBegln 106/02103 Well 11!I:þok Qtr/Qtr I:~~/SE sec Contractor po# I ~¥VS Unit # 9619 Start End Duration Daily Total (S) 'jlª30 '~¡~45 i1[9115 Notes Summary ~!1 /2 ) ) NO 130 TWP 118 Current Activity $89,800.00 Daily Completion Report lEnd 6i2/2003 IAPI 1'50-009-20022-00 Rng I 1 I County supervlsor IT rout /iÊvergreen Resources Alaska Field ¡rpjon, I State IAlaska Country I U~ ;repare to clean out trac sand tram 2nd stage trac. Well Total (S) I 1 $248,885.00 24hr Fore~astl:;il!l!il Prepare to trac. IAccldent (v{ No ILast Safety Meeting'Date 6-2-03 :~pread plastic. Spot equipment. RU unit # 9619. Install BOP. Changed pipe rams to 2 7/811. PU retrieving head w/o grapples. PU 27/811 tbg & TIH to TOS @ 31 DO'. EWS frac equipment to 5 1/2" x 2 7/8" annulus & reverse circulate 60' of frac sand off WRP @ 3170 using fresh water 10' left WRP. m!~H w/2 7/811 tbg & retrieving head. ~JPple down BOP g~ EWS frac equipment & frac perfs 3120' to 3090' wI 798 bbls 20# BXL, 420 gals 10% HCL & 45,780# 20/40 sand as follows: i~i~: Pumped 13 bbls of water & loaded hole @ 3.3 BPM. ·~~pumped-13-bbl$10%HCL-@-2:TBPrvr- ;~:)i Pumped 90 bbls 20# BXL pad containing 180# slug @ 15 BPM :~¡¡ Pumped 340 bbls 20# BXL containing 1 ppg 20/40 sand @ 24.2 BPM :~~!I Pumped 102 bbls 20# BXL containing 2 ppg 20/40 sand @ 23.7 BPM. ~)¡ Pumped 48 bbls 20# BXL containing 3.0 ppg 20/40 sand @ 22.9 BPM ~~; Pumped 31 bbls 20# BXL containing 4.0 ppg 20/40 sand @ 22.1 BPM ,S~¡J Pumped 92 bbls 20# BXL containing 5.0 ppg 20/40 sand @ 20.8 BPM ª)i Pumped 9 bbls 20# BXL containing 6 ppg 20/40 sand @ 19.7 BPM '~lo Flushed w/ 71.5 bbls fresh water ~\ . ""{ ;'~,¡:œ,t: '~þST ESTIMATE; 'Ë{ig $µpervision Þåtterson Western EWS frac Misc $2,700.00 $600.00 $6,500.00 $3,000.00 $75,000.00 $2,000.00 $89,800.00 v.... 1.0 lil-1/8-28-99 Report No 16 IBegln 106/02/03 Well 1¡lipOk Qtr/Qtr li!tJ/s E Contractor po# I Start Notes Summary I : (Page 2) sec ~~s Unit # 9619 Daily Total (S) End Duration NO TWP Current Activity ) Daily Completion Report I End 16/2/2003 IAPI li!~-009-20022-00 Rng I ' operator I!~~t-Su I Supervisor IT rout I::;vergreen Resources Alaska Field lillonl I State 1,!J~ska Counb"j :~~ 124hr Forecastll!i!li;! Prepare to trac. I No Last Safety Meeting Date '6-2-03 page 2783 psi, Maximum treating pressure 4400 psi, average treating pressure 3600 psi @ average treating rate of 21 BPM load 797.5 bbls. 5 minute SIP 2488 psi, 10 minute SIP 2476 psi, 15 minute SIP 2434 psi, 20 min SIP 2395 psi Patterson. PU 51/2" WRP under full lubricator & TIH. Electric line hanging up in pack off on lubricator & line jumped sheave on Placed line in sheave. Found crimp in line where it had jumped sheave. TOH. SI & SOON I County ;~'[epare to clean out trac sand trom 2nd stage trac. Well Total(S) I $248,885.00 Accident (y/n) Activity ESTIMATE; V9I 1.0 lil·1f 8-28-99 Report No 17 IBegln 106/03/03 Well 'I'bok Qtr/atr ISW/SE Contractor POll 1 Start Þžbo Notes Summary /sec !~ŸVS Unit # 9619 Daily Total (S) End Duration ) ) Daily Completion Report lEnd 16/3/2003 supervlsor Trout 130 NO TWP 118 'Evergreen Resources Alaska Field Pioneer St.11e IAlaska Country I USA IAPI 1:'50-009-20022-00 Rng I County operator Mat-Su Current Activity 124hr Forecastlt!~;i!! Prepare to pull plugs 1 No ILast Safety Meeting Date : 6-2-03 $86,300.00 " $335,'185.00 Activity ~,~ Patterson. PU 5 1/2" WRP under full lubricator & TIH. Set WRP @ 3020'. RU EWS frac pump to 5112 csg & pressure test p!yg to 4600 psi. Perf. 2954' to 2958' & 2908' to 2911' using 4" HSC wI DP charges 4HPF. PU dump bailer TIH to perfs @ g~:54' to 2958' & dump acid. ß~ EWS frac equipment & frac perfs wI 85,200# of 20/40 sand, 779 bbls BXL gel & 250 bbls 13% HCL as follows: ~)';[pumped 7 bbls water & broke perfs down @ 2699 psi @ 4.1 BPM. I,~)) Pumped 7 bbls 13% HCL @ 3.0 BPM ~~:i Pumped 67 bbls & SD to let acid soak ~~¡ Pumped 148 bbls 20# BXL containing .9 ppg 20/40 sand. Radiator hose broke on trac pump. ?~!Flushedw/ 92 bbls BXL @ 12.3 BPM. Made repairs on trac pûh1þ. g}; Pumped 45 bbls 20# BXL pad @ 22 BPM ~~1 Pumped 77 bbls 20# BXL containing .8 ppg 20/40 sand @ 23.3 BPM ¡~~; pumped 50 bbls 20# BXL containing 1.7 ppg 20/40 sand @ 23.1 BPM 9ji Pumped 90 bbls 20# BXL containing 2.9 ppg 20/40 sand @ 21.1 BPM 10) Pumped 60 bbls 20# BXL containing 4.0 ppg 20/40 sand @ 19.5 BPM 11) Pumped 75 bbls 20# BXL containing 5.0 ppg 20/40 sand @ 18.8 BPM 12) Pumped 164 bbls 20# BXL containing 6.0 ppg 20/40 sand @ 18.1 BPM 13) Flushed w/ 66 bbls water. COST ESTIMATE; Rig Supervision Misc. Western påtterson $2,700.00 $600.00 $2,000.00 $1,500.00 $4,500.00 $75,000.00 VfJ( 1.0 lit-118-28-99 Report No IT Begin 106/03/03 Well lim:pok Qtr/Qtr i~&V /SE Contractor po# Notes I, Summary Start (Page 2) Isec EWS Unit # 9619 Daily Total (S) End Duration NO 130 TWP 18 Current Activity ) ) Daily Completion Report lEnd 16/3/2003 IAPI 150-009-20022-00 Rng I 1 supervlsor Trout operator IMat-Su ¡Evergreen' Resources Alaska Field lipIonl ISla'" IAlaska Country I U~ Icounty Flbwing 3rd stage frac. Back Well Total (S) I I 124hr Forøcast"i{!!t Prepare to swab test AcCident (yJnJ I No ILast Safety Meeting Date 6-2-03 Activity (§!ip 2699 psi. Average treating pressure 3000 psi @ average treating rate of 23 BPM. Total load 858 bbls. 5 Min SIP 1798 psi :,~:º Min SIP 1691, 15 Min SIP 1667 psi, 20 Min SIP. RO & MO frac equipment. SI & SOON ~'þst job frac gradient 1.07 ESTIMATE; Vør 1.0 ~1-118-28-99 Report No Is,: Begin 106/05/03 Well I¡ipok atr/alr I:~~/SE Isec Contractor po# I Start :~,~oo i~'ßOO ~~]iøoo ¡'~¡~30 :~'¡~OO ::~W::ti;~ Notes Summary r~~s Unit#9619 Daily Total (S) End Duration Daily Completion Report lEnd NO TWP IAPI 1!~)~-009-20022-00 Rng l:ii¡iil!:ii¡!~!:: Current Activity ,~f,epare to swab test Well Total (S) I I $341,085.00 $5,900.00 ) 16/5/2003 I Supervisor I Trout county I¡~ State lil!~ska Field 1[llonl Country I~~ ACCident (y/n) Prep to set prod. Equip. I, . 6-4-03 Activity 1/2 hr SITP 900 psi. Opened well to pit & flow estimated 10 bbls of LW & pulled pressure down to 0 psi. 27/811 notched collar, 1- 2 7/8" x 2.250 seating nipple on 27/811 tbg & TIH to TOS @ 35561 EWS unit # 402 & reverse circulate 1541 of frac sand to PBTD 37101 27/811 tbg to 34531 & RU to swab. @ surface first run wI swab. Swabbed 125 bbls L W in 5 hrs. Ending FL @ 18001 SI'& SDON COST ESTIMATE; Rig Supervision tvlisc. VMestern $2,300.00 $600.00 $1,500.00 $1,500.00 $5,900.00 Va< 1,0 lit·1f 8,28-99 =\'=I~GI~==I" .., RESOURCES (ALASKA) CORP, ) A Subsidiary of Evergreen Resources, Inc. ) October 7, 2003 Mr. Winton Aubert Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 RE: Sundry Approval (Form 10-403) Pioneer Unit - Cook #1 Dear Mr. Aubert: Attached is the 10-403 form requesting an operational shut down of the Cook #1 /' well. Production testing has been completed and data has been collected. Several other prospective coal seams exist, and other stimulation techniques should be evaluated before this section of the hole is abandoned. This shut down would provide the necessary time required to compl~te the data evaluation and formulate an effective strategy for moving forward. /" If you have any questions, please feel free to contact me at 907-355-8569 or shaneg@evergreengas.com. Sincerely, £]·ßV~ Shane Gagliardi Petroleum Engineer RE(~E~\/ED "" 'f~''I.'' i (\" Pí'':: He ~ t, /~uu':\ , \ ,;,;Qf\ A~aska O!I êt U¡,¡S ~\J" - -........ Aflchorage ORIGINAL 1075 Check Street, Suite 202 · Wasilla AK 99654 PO, Box 871845 . Wasil/a, AK 99687 · TEL 907,357,8130 . FAX 907.357.8340 WGA- 'Oltolwo ~ ~ . ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 /~ Suspend 0 Operation Shutdown IZI / Perforate 0 Variance 0 Annular Disposal 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 4. Current Well Class: 5. Permit to Drill Number: ~ Development 0 Exploratory IZI 202-180 Stratigraphic 0 Service 0 6. API Number: / 50- 009-20022-00 /' 9. Well Name and Number: Cook #1 / Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: Evergreen Resources Alaska Corp. 3. Address: P.O. Box 871845 Wasilla, AK 99687 7. KB Elevation (ft): 278 ft KB (4' AGL) 1. Type of Request: 8. Property Designation: ADL 384685 10. Field/Pool(s): Pioneer Unit (610500) 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): I Total Depth TVD (ft): I Effective Depth MD (ft): I Effective Depth TVD(ft): I Plugs (measured): 3740' MD 3740' TVD 3670' MD 3670' MD N/A Casing Length Size MD TVD Structural N/A N/A N/A N/A Conductor 241 12-3/4 245 245 Surface 380 8-5/8 384 384 Intermediate N/A N/A N/A N/A Production 3697 5-1/2 3701 3701 Liner N/A N/A N/A N/A Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: 2908-3420 2908-3420 2-7/86.4 ppf J-55 Packers and SSSV MD (ft): Packers and SSSV Type: Burst N/A N/A 2950 N/A 5320 N/A N/A N/A 13. Well Class after proposed work: Exploratory IZI Development 0 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 9 October 03 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: 15. Well Status after proposed work: Oil 0 Gas IZI Plugged 0 WAG 0 GINJ 0 WINJ 0 Contact Shane Gagliardi Printed Name Shane Gagliardi Signature 0.~ Title Petroleum Engineer Phone 907-355-8569 Commission Use Only Date 1 0/7/03 Sundry Number: Junk (measured): N/A Collapse N/A N/A 1370 N/A 4910 N/A Tubing MD (ft): 3445' Service 0 Abandoned 0 WDSPL 0 .30.3- 3/S- Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 ~KEC·EI\\lE[:1 1; 0 .t Subsequent Form Required: i 0 .- '-10 '3 to V'<.Ç. ~t\. V t ~.p....ý.(...{t"v\.~ ¡~\aska Oil & Gas Cons. Commissicc: Anchorage Other: Approved by ß--.J, µ ~ Form 10-403 Revised 2/2003) BY ORDER OF COMMISSIONER THE COMMISSION t~1¿~J'\~'~ ~~, ~~1l ~. -~! :ê\.','\ ~(i\¡~i!l(j. ' , 1\\ ,~)10U\JU~' (Oì(Clf 1 EDM5 Bfl ',) j L OR\G\NAL Date: (0/1.:>1 /7 S Su'mi~ in áuplicâte OCT 1 =\'=I~GI~==I'I RESOURCES (ALASKA) CORP. A Subsidiary of Evergreen Resources, Inc, API Permit to Drill # Survey Type Survey Date Conductor 12-3/4 Surface 8-5/8 PBTD WellTD Measured Depth 250 300 500 1000 1500 1750 2000 2070 2465 2491 2500 3000 3250 3500 3665 3680 Cook #1 Lowell #2 Bering #3 Baranof #4 DL Smith #1 Stromberg #2 RL Smith #3 Cornhusker #4 50-009-20022-00 50-009-20021-00 50-009-20019-00 50-009-20020-00 50-009-20026-00· 50-009-20025-00 50-009-20024-00 50-009-20026-00 202-180 202-179 202-177 202~178 202-184 202-183 202-182 202-181 Sure Shot Model A Sure Shot Model A Sure Shot Model A Sure Shot Model A Sure Shot Model A Sure Shot Model A Sure Shot Model A Sure Shot Model A Inclination Inclination Inclination Inclination Inclination Inclination Inclination Inclination 12/5/2002 11/6/2002 12/5/2002 11/3/2002 12/5/2002 12/5/2002 12/5/2002 12/5/2002 245 200 275 300 320 360 420 415 384 381 400 513 1038 1020 1016 539 3670 3238 3688 3697 2487 2492 2191 2577 3740 3750 3753 3750 2510 2510 2300 2600 ~ 0.5 0.5 1 5 8 14 10 10 14 9 2 0 7 4 3.5 0.5 4 7 13 14 5 6 8 13.5 14 10 8 10 14 14 14 11 14 14 14 10 9 8 10.5 11 9 14 11.5 14 13 14 _7' Surveying Compnay Patterson Wíreline ~Q~ Ç?~~~"-- Q-r2-03 Date Survey Conducted By: Pat Patterson Owner ~~~ ~.-. ~ Signature RECE\\/E[) SEP 1 4} 2003 0·\ & G Cons rot11ffl4ssíon ,Masks I ..as . v Anchorage ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Suspend D Alter Casing D Repair Welll:8J Change Approved Program D Pull Tubing D 2. Operator Name:, Evergreen Resources Alaska Corp. 3. Address: P.O. Box 871845 Wasilla, AK 99687 7. KB Elevation (ft): 278 ft KB (4' AGL) 8. Property Designation: ADL 384685 Total Depth 11. Present Well Condition Summary: Effective Depth Casing Structural Conductor Surface Production Liner Perforation depth: Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Development D Exploratory I:8J Stratigraphic D Service D Perforate D Variance D Annular Disposal D Stimulate D Time Extension D Other D Re-enter Suspended Well D 5. Permit to Drill Number: 202-180 6. API Number: 50- 009-20022-00 9. Well Name and Number: Cook #1 10. Field/Pool(s): Pioneer Unit (610500) measured 3740' feet true vertical 3740' feet measured 3670' feet true vertical 3670' feet Length Size MD TVD N/A N/A N/A N/A 241' 12-314 245' 245' 380' 8-518 384' 384' 3697' 5-1/2 3701' 3701' N/A N/A N/A N/A Measured depth: 2908' - 3420' True vertical depth: 2908' - 3420' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A 2-7/8 N/A Junk (measured) Plugs (measured) N/A N/A Burst N/A N/A 2950 5320 N/A Collapse N/A N/A 1370 4910 N/A J-55 3485' N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl N/A N/A Copies of Logs and Surveys Run N/A Daily Report of Well Operations xxx Gas-Met o o Water-Bbl 23 13 Casing Pressure o o Tubing Pressure N/A N/A 15. Well Class after proposed work: Exploratory I:8J Development D Title Petroleum Enqineer Phone 907 -355-8569 ,,..; Service D 16. Well Status after proposed work: Oil D Gas I:8J WAG D GINJ D WINJ D WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: r.nnt::lrt ~h::ln¡:> ~::I(1li::lrni Printed Name Me Ga,~ Signature ~ ~. Form 10-404 Revised 2/2003 ,"Ö¡ç.'.2,\\7i'.IfJ^\;·,' 1!'\\f._,¡,.lhfl"" ,t\\1 I" ~n~_1R? Date 8/21/03 ORIGINAL Vor 1,0 ÜI·1I8-28·99 --.---- .-- --,'-~-"- .___...~__..__.___ ___________"'______n .___.._ _ ...._._. "'__________0·. ___. _.___....____ ,,___~_.._____.'_..______.____ _ _, ___ _,_____,,_~__~__,._ --.,..--. .-.- _ "_'__'__'_'__"_'_ __ _.__._ __._._,.______ _. _ _ ....__.___ ~___.._._,_____,,_._.,____ _ ___0"_'''_._' , .'__'.__,.____,~.__.________________ ._._.__._ __._____._._.,._,...______,_ __. _.__~_.___,.___,_"_,_ __" _._._"."_._~ Summary I. ------~-,--_..~--_.'----..~..__..-_. ---------..--.----. -----."--.----------- -".--- -,~~. ----..--.".--.-...-.- ,.-... -.-..-".------.-----..-.---.---.--- -----. --'-~-- - ._-,-+._-----------_. .-----..------.. -~,-~---,_._-"._-------,-_..._-- -~,_.~-_._--.-.._-.......-_...__.__._~-- Notes I ~_.._~_._._.__._-_.. -..--.------..-,--.-..-----.- .._-~_._._.,---,- -"._-~._. -_._~_.._.._-~--_...'"--_..,-._--_._------------,-----_.---.- .._ .__.____.,,___._ .~__. ___... __",_ ~ _._,,__________._.___. ___.,.___..~__...._.___..__._.._._..._........_._.. .__..____,.._____M.._"'._'_._..,_____..__.__,.__,_...__.~__~.____~,_..._.__.........._._._.._,_.._~_'..._.._._...._.__.__".,~".".,_..__....._.,'__. ~.'_'U'_""'_'" ..._..._____...~.~.._____.__...__.._~_.~. __....___~ ._"._._ ~'._'" ....__.u______ ."..,._~..._. ....._ _ ....~......__.... _. _..___,_~.~.. __._._,.,..~_~ ....·,__·_.,____..__.__.____·__~____M"..~___ ,,~,.~~.... ,_____,.._..__.._~_.,._~._.____.._.~.._.._..~_..___..__~_.._~..,______._~_...___,.___.._..~_,___~....~.._._..._._.__,_,..~._.____...._~._____~___~_..,,___ _.__.__..~._---_..__.~......_---.,........-_......_.__..__.,,_._._.-".._....-..þ.... .___._.....__..._._...."___"_..._.~._."........._....~,~..._...._...",~.~._.n _,,~. _" . '... ._".n...._.. ,...,,, ....,~".._..__......_ _._'"..____._~._~.._...__...._....'"__ "..,,·_,.....~_.H...._.__.·___~..,,~"M~__..._.__~.·._·c~·,_".._.~.,.".~ ~._. .....-,~_._-"._...~,_.__._~_._........-_..~.~...~.......,--_._._..,,~..._....... ..."....-----...__.._'."._--~_...__.._----_.....~............ .-.-.---.."-........----.....-......---.........,,-- .-.,.... '''~'' ."-~..,,..-...._~-" ,...,....._..__..._--_..__..._-~._-.......,~--- ......,'-.-..-...-.-..-......--...--...--. ·___..____M'__.._~" ~,._. ... _............._.._ .~,,~_..._...., ,.""__,_._",_M_.__'_',_,_,_,~,,, . ~_ ,.,__......""..~.."_.....,.."._,,,._ ,_.",M,___"_-,,".,,, .__~,,,,.~.",,_...~,_,,...~.M.''''.'''''"~M.,.~,,,,~,.'M''~_'''__,,,,.,..,~_,...""_~_",M",~.__._,.".._"..",--,,._.,___,.,M._',_._..__.__..._. _.~.",._.__~__._._._.._"."...._..__..____"....,__~.~,.....~~._h."""~"",,,,,·.·.~·M''''''',,__._. -~_.._-,--~---~-~._-~"..._._. $2,000.00 $600.00 $1,000.00 ..."'.-þ'----.......- ".'~,'~....~._->-- '","_I--"·--.."..,.·_,,__.--~,,-",~·",-,,·,- __..-...._.__.....________w____._.._,___ _.._.....--,~-_.. ~..__.....'...'_m._"..'_....·_._ ~.,...".",...'...,'.~,...,_...,...-........""......,'....,. _..._'..~..... " .,'....,'--,--....".......-." ,,,.....,........,.~,_...,,,....._.,,-."-,~..~._,,...._.........""."-.......~.--..--"'.,-,......---."'.."""'.........-.-.."'....."..."'.......,...",_..............,"-"",....,..._......'.."',...'._..."..........~.....'-'"'_.",.",........",,"~.~.",.-....,'"-....~"......"",.~'._..........,..._.._,_._.-..".....~............__....__..-...,,'~~."~.~ ....,.............."..........."'...-.......'''....,.. ,.............. _,_________^___...~._~,_ KB bottom oftbg. @ 34851. Top of seating nipple @ 3454'. ~.§2-º.___.,., 15~º-__.,._,_ J{~_.._,___._ ~..lP2!~. down BOP. __.____..___._.___,__'...,________..,.___,___,_._._,~_._._..___~...___ .~.?]_º_.__._. 16_~~__._1.._...__,..,.___,..____,_.._._,~~~~~sert PC P~i11P # 24-41 O~:§.~~..~L~~º,!~~,~L~.~~ 7/8" rodsL,!~~,~~Z~~~:E~~_~~~:..1-~L~..~.,1§..~B.:_.,.___,._.._..___,..._............._... 1630 1ì30 1_ _ Loadlbgw/20b~lswa.~er&s~a_~~C@17..?hrS R~lJn'I#961~.cle~nuplocatlOn._ . ___ __ ..._..._,...__. ..~.._,_._...._.....".........._....."._......__......__,... .I~.~:91.~,~mpe~..~_~È.~,~~_~~~~~!..º!!f_9, Static 15.5, psia, gas ISTM wI 0 psi ~9f,!~?..~_~~,~..g_R~~..?.§Q;__...__._..,..._.._._....__._..__,........ ..,""....~~-_.........-_.,',',~"'--,-~-,-_..,......._. "'.......___...,.._,.....,'.,_.___..___.__.......,_,..._,...__,...._ Z:~.:º}J'.9_"!!e~d 20bbls water, DiffO, Stati.c 1.§~_e§ìJ2.!..gas TSTM w/1 psi FCP in 24 hrs. PC RPM 145. Shot FL @ 2886. ,.._._..,...,..__..,...._______......i____,........._._.__...._.___?.::~6-03 Pumped 21 bbls water, piff 0, Static 15.5 psiaLgas TSTM w/1 psi FCP .in 24 hrs. PC RPM 145. SD PC @ 0800 hrs. 9~00._.._Q9--ºº-_p1.___.. _~read plastic. RU EWS unit # 9619. 0900 0930 1/2 TOH wI 138 rods & rotor. ".,....".."...~..þ..."_."""....~_ '...".,_.._,.......~_'"'_ ,'..'.,""......_..,___"._.~_."..._~.........__._.... ,,,r,,,' .. . .......__...___......... _'"_..-........__._,....._....,....~...._..___.._.......,_ º~30 ..".._,~,,!~-º-...... ,~...._..___.._..__......,__._...,_~.ipple up BOP. !~~!~~~~~~,.EI.u.~1~.!~,~_.~~~~~~!!~~~~~.!~~~9P t~ 3000 psi. Held OK. ,_____..._.__.._..._ .~..1~..º_.._.1~Qº_.,.,.~.".y~.,___.__...._,_____ ,!OH w/111 jts 2 7/8" tbg. LD Stator ..._....._____,___ ...____..._~__ ,.1}ºº..__.,t~00 . ~ " TIH wl111 jts2 7/8" tbg as foll9ws: .,"...,___...,....._..,_"..........."..___._..,__............_ JJ1. jts 2 7/8" 6.5# EUE J-55.!Þ.1J...:....__.. __.__,.......,___,..._. 3444.57 ....._____..,.......____,_ 1- 27/8" 6.5 # EUE J-55 tbg. Sub 6.00 2 7/8" x 2.250" seating nipple 1.10 7/8" 6.5# E~.~ J-55 mu9.,~~..~~~!.~r.~~~,~pealed. ,.....,_......_.__..30.2.1 3481.88 --"'......... ~--_.,...._"._. "'''''''''''''''--''-'-' Activity End Duration Start 124hr Faracast I T esti ng Accldant(Yln) I No ILaet Safety Meeting Date I 7-26-03 $443,885.00 Prepare to change pump Well Total ($) I $3,600.00 Dally Total ($) Contractor po# I Current Activity Evergreen Resources Alaska Field Pioneer I State IAlaska Country I USA 1 Operator I Mat-Su Daily Completion Report I End 17/26/2003 IAPI 150-009-20022-00 Rngl 1 Isec I County INO 11 130 ITWP 118 I Report No 142 I Begin 107/26/03 Well I Cook QtrlQtr ISW/SE Isupervlsor I Trout ) :) =\I=I~GI~==I'~ ') RESOURCES (ALASKA) CORP. . A Subsidiary of Evergreen Resources, Inc, ) July 9, 2003 Ms. Sarah Palin Dr. Randy Ruederich Mr. Daniel Seamount Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 RE: Sundry Approval (Form 10-403) Pioneer Unit - DL Smith #1, Stromberg #2, RL Smith #3, Cornhusker #4, Cook #1 and 1702-15DA Dear Commissioners Palin, Ruederich and Seamount: Attached are the 10-403 forms for the following wells. The proposed workover operations will ~~~tl, '·..8-1 fpump changes and running cement bond logs on two wells squeezed via the&n head. Well Work Over Description RL Smith - Down size pump and Run CBL DL Smith - Downsize pump Stromberg - Downsize pump Cornhusker - Upsize pump and run CBL Cook - Downsize pump ¿' 1702-15DA - Clean to PBTD If you have any questions, please feel free to contact me at 907-355-8569 or shaneg@evergreengas.com. Sincerely, ß~ Shane GagliaJi Petroleum Engineer :'f: :e; E '~ JUl 0 9 2003 I" (. 1075 Check Street, Suite 202 · Wasilla AK 99654 PO, Box 871845 . Wasil/a, AK 99687 · TEL 907,357,8130 · FAX 907.357,8340 ') ) W6A- l' 10/ Z-OO ~ OV5 7//0/3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 1. Type of Request: Abandon D Suspend D Alter Casing D Repair Well IS! Change Approved Program D Pull Tubing 0 2. Operator Name: Evergreen Resources Alaska Corp. 3. Address: P.O. Box 871845 Wasilla, AK 99687 7. KB Elevation (ft): 278 ft KB (4' AGL) 8. Property Designation: ADL 384685 Operation Shutdown D Plug Perforations D Perforate New Pool 0 4. Current Well Class: Development 0 Exploratory IS! Stratigraphic D Service D Perforate D Variance 0 Annular Disposal D Stimulate 0 Time Extension D Other 0 Re-enter Suspended Well 0 5. Permit to Drill Number: /" 202-180 6. API Number: /" 50- 009-20022-00 9. Well Name and Number: Cook #1 1 O. Field/Pool(s): Pioneer Unit (610036) 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): I Total Depth TVD (ft): I Effective Depth MD (ft): I Effective Depth TVD(ft): I Plugs (measured): 3740' MD 3740' TVD 3670' MD 3670' MD N/A 12. Attachments: Description Summary of Proposal IS! Detailed Operations Program IS! BOP Sketch D 14. Estimated Date for Commencing Operations: 22 July 03 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Length Size N/A N/A 241 12-3/4 380 8-518 N/A N/A 3697 5-1/2 N/A N/A Perforation Depth MD (ft): I Perforation Depth TVD (ft): I 2908-3420 2908-3420 Packers and SSSV MD (ft): Casing Structural Conductor Surface Intermediate Production Liner N/A Date: Printed Name ~ Gaqliardi /ZJ) Signature ~ ~ MD TVD N/A N/A 245 245 384 384 N/A N/A 3701 3701 N/A N/A Tubing Size: Tubing Grade: 2-7/8 6.4 ppf J-55 Packers and SSSV Type: Burst N/A N/A 2950 N/A 5320 N/A N/A 13. Well Class after proposed work: Exploratory IS! Development D 15. Well Status after proposed work: Oil D Gas IS! Plugged 0 WAG 0 GINJ D WINJ 0 Contact Shane Gaqliardi Title Petroleum Enqineer Phone 907 -355-8569 Commission Use Only Date 7/3/03 Junk (measured): N/A Collapse N/A N/A 1370 N/A 4910 N/A Tubing MD (ft): 3445' Service D Abandoned D WDSPL D Plug Integrity D BOP Test ~ Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: ~tJ 3../81- Mechanical Integrity Test D Location Clearance D , Other: Te....s t E () P E ~ (COO r ~ . p~ý 2,.0 AM 1.S. 2~5 (I-.,) 1 ú-Ltwn.ø-t~ y-oL{ Subsequent Form Required: 1\ :¡ ßOPE I f(, ""-'fJ r yvc.lid. Approved by: ~ ~~~ COMMISSIONER Form 10-403 Revised 2/2003 - L- :" \ ,~~~t ], ',' 'l@~~ BY ORDER OF THE COMMISSION ORIG'NA_ Dat~¿~upLe ') \ -' Pump Change Procedure Pioneer Unit: Cook #1 API: 50-009-20022-00 Section 30 Township 18 North Range 1 West Matanuska Susitna Borough, Alaska Elevations: GL: 409 ft KB: 413 ft (4 ft AGL) Objective: Pump change and place on production test. History: This well was initially drilled wi air in October 2002. The well was fracture stimulated and completed on 31 May 03. Initially a 40N045 pump was /' run; at this time, the pump is oversized for the current amount of water production. Preparation: 1 '13 - J L ~ I 1. AOGCC: Contact Winton Aubert (907...27Q 1433) 48 hours prior. 2. Tanks: Reverse tank for flow back. 3. Water: OJ will provide drivers for EWS water trucks. 4. Pumping Services: EWS Cmt Unit 402. 5. Wireline Services: None 6. Workover Rig: EWS Wilson Super 38 rig #9619. 7. Tubing: None Spill Prevention: Alaska Department of Environmental Conservation has strict regulations regarding spills. All equipment will have plastic liners underneath them. Liners will be run around wellhead. All water will be run to the pit. Casing and Tubing Data: Size Weight ID Drift Collapse Burst Yield Capacity Capacity (in) (ppf) (in) (in) (psi) (psi) (klbs) Bbls/ft Ftlbbl Casing 5-1/2" 17 4.892 4.767 3928 4256 273 0.02325 43.015 Tubing 2-7/8" 6.4 2 .441 2.347 7680 7260 120 0.00579 172.765 Annulus 2-7/8 to 5-1/2 0.01522 65.710 Tight Hole: No information from this well may be shared with anyone outside of Evergreen Resources Inc. ) ) Procedure Pump Chanae Procedure 1. MIRU EWS Rig 9619 and EWS cement unit #402. a. Install and test BOP (pipe and blind rams). /" 2. POOH wI 3445' 7/8 rods. 3. Tag PBTD @ 3670. Clean to PBTD if necessary. 4. POOH wI 3445' 2-7/8 tbg and 40N045 PC pump. 5. TIH wI 3445' 2-7/8 tbg wI tag bar and seat nipple. 6. TIH wI 7/8 rods and 40N006. /' 7. Seat pump wI 500 psi using Cmt unit 402. 8. Start pump @ 300 RPM. Place on production test. ,r'. 1f 11,1:(,'I,.',i,",\ '::/! (:111 ì/ì ~'~,,~ 11;,1,1 ",:¡ ~ '¡;,:,',,',:,I,' ... ¡'''J: 1,}:1 11t::~ ~1;~ j.'I,,',I.,,:,'.,,'.'. :I!:II 1~(1 ,¡rill 1'1111, 1',"'.,",[1 ,j'I" I'I' ~\': ji;'! il, i,¡I'!,i,lil 1'li,II' I¡IIII {:il I,!.II ~ ~1!iii:,:I! 'I I: ~ : I '!I ¡I' II )"'il ¡iI! 1"i,"¡I,;~, '1\! ¡il::" I'::'! ~:"'I :=ø: l,i,I;:! -= 7 ==- ~';!:::~ ¡¡¡::: ªII Ii:'}!' IE 6 ,,11:..,1 ;;1:1 0!':':~ =I'11C5 ~I',"',I ::~J :1 4 !!I ',i:J ,I,' I I r.;~ :::iI i, ',~ 1!!8:: 3 ::::::i1i. ~".'7 -== 1.1 , .~ ::::::::::!i!I tr'¡ .ø:= 2 ::::iiI ~', I IIi!i:= ~ .. ~ ~ t PBTD 3670 " Well Cook #1 Qtr/Qtr Twp 18N Current 50-009-20022~O =\'=I~GI~==I'I See Rng API 30 1W Size Weight Grade Thread Depth County Matanuska, Susitna State Alaska Casing 8-5/8 24 J-55 ST&C 384 Field Pioneer Unit Country USA Casing 5-1/2 17 J-55 LT&C 3701 GL/KB 409/413 Tubing 2-7/8 6.3 J-55 8rd 3445 No. I Depth I Length I 00 10 Description 1 3462 11.51 2.88 N/A 40N045 pump wI torquestopper No-turn. 2 3416 4 N/A N/A Perforate 3416-3420 wI 4spf 23 gram charges 3 3356 4 N/A N/A Perforate 3356-3360 wI 4spf 23 gram charges 4 3120 4 N/A N/A Perforate 3120-3124 wI 4spf 23 gram charges 5 3090 4 N/A N/A Perforate 3090-3094 wI 4spf 23 gram charges 6 2954 4 N/A N/A Perforate 2954-2958 wI 4spf 23 gram charges 7 2908 4 N/A N/A Perforate 2908-2911 wI 4spf 23 gram charges Modified by STG 7/3/03 ~',~1j,i,;' ';fri! "f ~I,I ~,:¡t I;::! liil ~til' 1,'11~1 'i,!r r¡\ .41 ~J~ .. I,ii,',il, rl ,!II - ¡r:l ¡'Ii ¡~!I¡ '¡I'i' J¡li:¡! I,I',I,II,I,' II!':!I i¡:III'11 I"" ti;\ ~,I, !:!:,Iil !I~'il \),:\ 1,\1',',:;11, ¡illl:: \'1!11 1.¡tll!l, ,:1.;:11, Ii" ¡iillll ¡llii:1 j1:\ 1!:11 jiliil ,;!'t j~l~ II~I ' II!{II; ¡11!i:' ='!~IC7 ¡II ¡III 6 '1111 ~;:t =~¡c: 11 I,}) 3iI I:'} C 3 ! "~ L'I 31 ;" 2 il z ~ ~ ~ t PBTD 3670 ) Well Cook #1 Qtr/Qtr See Twp 18N Rng ,) Proposed f~' 50~09-20022-00 =\'=I~GI~==I'I Size Weight Grade Thread Depth County Matanuska, Susitna State Alaska Casing 8-5/8 24 J-55 ST&C 384 Field Pioneer Unit Country USA Casing 5-1/2 17 J-55 LT&C 3701 GUKB 409/413 Tubing 2-7/8 6.3 J-55 8rd 3445 No. I Depth I Length I OD ID Description 1 3462 11.51 2.88 N/A 40N006 Insert Pump 2 3416 4 N/A N/A Perforate 3416-3420 wI 4spf 23 gram charges 3 3356 4 N/A N/A Perforate 3356-3360 wI 4spf 23 gram charges 4 3120 4 N/A N/A Perforate 3120-3124 wI 4spf 23 gram charges 5 3090 4 N/A N/A Perforate 3090-3094 wI 4spf 23 gram charges 6 2954 4 N/A N/A Perforate 2954-2958 wI 4spf 23 gram charges 7 2908 4 N/A N/A Perforate 2908-2911 wI 4spf 23 gram charges ) Program Summary Pioneer Unit Cook No 1 API: 50-009-20022-00 Permit: 202-180 SW/SE of Section 30 Twp 18 North Rng 1 West Matanuska Susitna Borough, Alaska Evergreen no proposes making several pump changes in currently completed wells. Evergreen will utilize its single-double work over rig and water trucks currently residing in Wasilla. As specified in 20 MC 25.280 (b)(4), fresh water will be used to control the well. A high pressure cementing or fracturing pump will be on location to kill the well if necessary. We do not expect well control issues since this well was previously drilled with air. As specified in 20 MC 25.280 (b)(5), the pressure gradient is normal. Thus bottom hole pressure on the bottom most interval is (2,500 ft x 0.435 psi/ft) or 1,085 psig. We plan on using 3,000 psi BOPE. ~/ Regulation Exceptions 20 MC 25.285: Evergreen requests that our manual BOPEs, as illustrated on /' the next page be acceptable for the frac and the clean-out operations. J! 'I u_ ~) ~~1 'î r) ,~ .~ Street: 1075 Check Street, Suite 202 Wasilla, AK 99654 Mailing: P.O. Box 871845 Wasilla AK 99677 Tel 907-357-8130 Fax 907-357-8340 www.EvergreenGas.com " ) ) BOP DETAIL FOR CLEAN-OUT OPERA TlONS (AFTER FRACTURE TREA TMENT) A schematic of Evergreen's BOPE for well clean- outoperations is shown in the adjacent figure and detailed in the table below. We will utilize this set-up after the fracture treatment to retrieve (via tubing) the bridge plugs and to clean-out sand in the wellbore. Here we propose using / 3,000 psi, 7-1/16 inch BOPE manually operated system. The BOP is attached to the 8-5/8" casing head which is also our spool in this operation. /" 8 I Strip Head I I 7 ql q I 6 I Pipe Rams Ib Ib s: II) ::¡ c: ~ Blind Rams 1 2 5 To pummD= Well Head 3 4 =InJ] To Tank No Item Manufacturer Size Psi (in) Rating 1 Valve FMC or equivalent 2 3,000 2 Valve FMC or equivalent 2 3,000 3 Valve FMC or equivalent 2 3,000 4 Valve FMC or equivalent 2 3,000 5 Tbg head and spool Wellhead Inc 5-1/2 x 2-7/8 3,000 6 BOP: Blind Ram Townsend Manual Operated 7-1/16 3,000 7 BOP: Pipe Ram Townsend Manual Operated 7 -1/16 3,000 8 Stripping Head High Tech Tools The blowout preventer is a Townsend (Odessa, TX) double gate with blind rams on the bottom and pipe rams on the top. This BOP is manually operated using two wheels. Above the BOP is a High Tech Tools (Aztec, NM) stripping head which functions as an annular preventer. The body is rated to 3,000 psi and the insert rubber, manufactured by Triple M (Odessa, TX), designed for 2-7/8" tubing, is pressure rated to 1,000 psi. Four manually activated FMC block valves are attached to the spool - two for the kill like and the remaining two to the choke line. The kill line is attached to an Evergreen Well Service frac truck or cement truck. Three inch 15M psi treating iron and/or 3 inch 3M psi hose will be used to connect the pump to the spool. A 15M psi valve and check valve also exists at the pump truck. The choke line connects the wellhead to a 500 bbl frac tank. Two 3,000 psi block valves at the spool will be connected to two or three inch 3M pipe running to the 500 bbl frac tank. In line with the choke line are two 3M psi block valves located at least 20 feet from the wellhead. A conventional choke manifold is not specified in this procedure due to the shallow depths, lack of hydrocarbons, and due to our prior experience with this well bore. ¡\~ t.p\ 1 Street: 1075 Check Street, Suite 202 Wasilla, AK 99654 Mailing: P,O, Box 871845 WasilìaAK 99677 Tel 907-357-8130 Fax 907-357-8340 JUI_ 10 0, 'ìnn" www,EvergreenGas,com V a ~ ') I ~ : . ;I~ ) ') =\I=I~GI~==II'I rt~:!µ()¡1,I::<:¡¡: $ +II~¡!l$K,I(1 ¡!;:'Oî!J þ, .¡!¡'¡:¡¡ji:I!U(¡¡m)¡:'¡j~ ~:mh:m:lii:!¡!'. lihnÎI:liJil!¡m!¡, ;'¡t¡¡:. March 23, 2003 Ms. Sarah Palin Dr. Randy Ruedèrich Mr. Daniel Seamount Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 RE: 10-403 - Fracture Stimulation Evergreen Cook No 1 Pioneer Unit ,/ API: 50-009-20022-00 Permit: 202-180 SW/SE of Section 30 Twp 18 North Rng 1 West Matanuska Susitna Borough, Alaska Dear Commissioners Palin, Rued~ich and Seamount, Evergreen Resources Alaska Corporation submits the following 10-403 to hydraulically fracture stimulate the subject well. We plan to commence work on this well on 8-Apr- 03. Attached is the 10-403, a summary of operations, a blowout prevention sketch used during this program, a procedure and a wellbore diagram. Thank you for your help. Please contact me if you have any questions. Sincerely, Attachments ,:- "~ --', ", '," . .,~ ." '-,,",,' '\'1) , ',r ',...JI - 1,-.....-c -\ :\ ::.:: ':':'11"'11 ,~,~, U u J >L,.:.~,~··· ,~ ,. :' :~"""i'~ ",.; ',_ .'~. ¡.,...I¡.JI~on Street: 1075 Check Street. Suite 202 Wasilla, AK 99654 Mailing: P,O, Box 871845 Was ilia AK 99677 Tel 907·357·8130 Fax 907-357-8340 www.EvergreenGas.com ORIGINAL \,' ') Operation Shutdown Plugging Variance Development 0 Exploratory 1:&1 P.O. Box 871845 Stratigraphic 0 Was ilia, AK 99687 Service 0 4. Location of well at surface: SW/SE of Sec 30 Twp 18 North Rng 1 West, Seward Meridian 991' FSL & 888' FEL OF SEC At top of productive interval: Same 1. Type of Request 2. Name of Operator 3. Address: At effective depth: Same Total depth: Same 12. Present well condition summary Total depth: Effective depth: Measured true vertical Measured true vertical Length Size Cemented 3740 feet feet feet feet 3740 Casing: Structural Conductor Surface Intermediate Production Liner Perforation depth: 12-3/4" 8-5/8" 70 sx on bot & 10 sx on top 146 sx 15.8 ppg Class G, Circ to Surface 245' 380' 3701' 5-1/2" 511 sx 13.7 ppg Class G, TOC +/- 450 ft 3,416' - 3,420',3,356' - 3,360',3120' - 3,124',3,091' - 3,095'2,954' - 2,958',2,908' - 2,91V Measured ) \¡..J(;¡ A- 3/ LvI ~t.,"1o ~ Û'rS G W <-<;'/03 o Re-enter suspended well 0 [J Stimulate ŒI 0 Other D none none True vertical depth True vertical 3,416' - 3,420',3,356' - 3,360',3120' - 3,124',3,091' - 3,095'2,954' - 2,958',2,908' - 2,911/ Tubing (size, grade, and measured depth) +/- 2870 ft KB with Progressing Cavity Pump on Bottom STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT FOR SUNDRY APPROVALS Abandon 0 Suspend [J After Casing 0 Repair Well [J Change Approved Program [) Pull Tubing [J Evergreen Resources Alaska 5. Type of Well Packers and SSSV (type and measured depth) none 13. Attachments: Description Summary of Proposal 1:&1 Detailed Operations Program 1:&1 o Time extension Ci Perforate 6. Datum elevation (OF or KB): 413 ft KB (4 ft AGL) 7. Unit or Property Name: Pioneer Unit 8. Well number: Cook No 1 9. Permit number: 202-180 /' 10. API Number: /' 50-009-20022-00 11. Field and Pool: Pioneer Plugs (measured) Junk (measured) Measured Depth 249' 384' 3705' BOP Sketch 1:&1 16. If proposal was verbally approved Oil 15. Status of well classification as: Gas 1:&1 Suspended 0 14. Estimated date for commencing operation 8-Apr-03 Service 0 Name of approver Date Approved 17. I hereby certify that t~ejr~oing is true and correct to the best of my knowledge. Signed ~ ~ - - , TItle Alaska Projects Manager FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so re~resentative may witness t L Approval N?·3 0 3 -Dý~ P~t wAtK-15, L-VS(h..)LU.~ uM<.. If;. ¿fl (t-)) J W¡"L··~-rL IM-l-t( ~~~l UJ~PÌ'1l~+ I~ CVPf~¡¡tJ. Plug integrity 0 BOP test ~ Location clearance 0 Mechanical integrity test 0 Subsequent form required 10- i.{o 7 Date March 23, 2003 Approved by order of the Commission ~ ~ ?~ Commissioner Form 10-403 Rev 06/15/88 ~ / ;\líð? ? 6 RBDMS BFl ORIGINAL Date ,I o 3/ z.¿l"'W S.~IT~NîIlBlfC¡ 5 r: r>l 'ì ~. ,~_ ,J i.." J _. (', :....~~; '~~ 1""", " ') ) :'::\f=llGI'l==I'\1 1:~~:hl~h'U IH::~ $ I I4L;!l$KJI. I. !LI'I;Ji~~ 1:1. ¡II ,¡:¡[j~,!¡¡¡¡I\!II:i; :¡¡¡J, flI!¡~¡j;qt;!!:i', ¡;f¡!g;:i¡Ji+¡jl!I!~. ;\'11:. Program Summary Pioneer Unit Cook No 1 API: 50-009-20022-00 Permit: 202-180 SW/SE of Section 30 Twp 18 North Rng 1 West Matanuska Susitna Borough, Alaska The subject well was spud on November 21, 2002 and the rig moved off on November 26, 2002. The well was drilled to 3740 ft KB and 5.50 inch casing was run to 3701 ft KB and cemented with 511 sx 13.7 ppg Class G sx of Class G Cement. Plug back total depth is 3670 ft KB. Evergreen now proposes stimulating the subject well via hydraulic fracture treatment. The treatment will be pumped in three separate stages down 5-1/2", 17 ppf, casing. Wireline conveyed retrievable bridge plugs will separate each stage. Shown below are the proposed perforation intervals and a summary of the designed stimulation. Proposed Perforations & Fracture Treatment Stage Interval Formation Shotslft Frac Description 1 3,416' - 3,420' Tyonek 4 64,000 Ibs 20/40 proppant 3,356' - 3,360' N2 Foam Fluid 3120' - 3,124' 64,000 Ibs 20/40 proppant 2 3,091' - 3,095' Tyonek 4 N2 Foam Fluid 3 2,954' - 2,958' 56,000 Ibs 20/40 proppant 2,908' - 2,911' Tyonek 4 N2 Foam Fluid Following this procedure, production equipment will be set and the well will be placed on production test. Evergreen will utilize its own international frac fleet, single-double work over rig and water trucks currently residing in Wasilla. This same frac procedure has been done several thousand times by Evergreen in the US and abroad. As specified in 20 AAC 25.280 (b )(4), fresh water will be used to control the well. A high pressure cementing or fracturing pump will be on location to kill the well if necessary. We do not expect well control issues since this well was previously drilled with air. As specified in 20 AAC 25.280 (b)(5), the pressure gradient is normal. Thus bottom <"~' hole pressure on the bottom most interval is (2,500 ft x 0.435 psi/ft) or 1,085 psig. We plan on using 3,000 psi BOPE. Reaulation Exceptions 20 AAC 25.285: Evergreen requests that our manual BOPEs, as illustrated on the next S two pages be acceptable for the frac and the clean-out operations. 20 AAC 25.287: Evergreen requests that our Fullbore lubricator and spool on top of the Demeo Frac Valve is acceptable. Street: 1075 Check Street, Suite 202 Wasilla, AK 99654 Mailing: P,Q. Box 871845 Wasilla AK 99677 TeI907-357-8130 Fax 907-357-8340 www.EvergreenGas.com ) / ) =\1":1 !I~==II'I 1:~j~:·~I~::~¡:::';.:'~'''~'~;'~'~~I~:~::;,¡:~,~.;~·I:I.. BOP DETA/L FOR FRACTURE ST/MULA TlONS Evergreen proposes fracturing the subject well in a series of successive stimulation treatments. This method, typically referred to as "stage work", generally consists of the following steps: 1. Perforate coals; 2. Stimulate coals down casing; 3. Flow well to the pit or tank and allow the well to fill-up with sand/water so that flow stops; 4. Wireline set a retrievable bride plug to isolate the interval. 5. Repeat steps 1 through 4 until all selected coals are stimulated. Here, only a group of coals over a small interval - roughly 100 feet - is completed per stage. Each stage typically takes a few hours and this procedure is repeated until all of the targeted coals are stimulated. During stage work, two BOPE configurations are needed: one for the fracture treatment and the other for the wireline operations. Detailed below are the BOPE Evergreen plans to utilize. Evergreen is very comfortable with this setup. We have stimulated thousands of treatments in this manner. BLOW OUT PREVENTION EQUIPMENT FOR FRACTURING DOWN CASING A schematic of Evergreen's BOPE for fracturing is shown in the adjacent figure and detailed in the table below. Here we propose using 5,000 psi rated (10,000 psi test) Size Psi No Item Manufacturer (in) Rating 1 Valve Balon or equivalent 2 3,000 2 Plug Balon or equivalent 2 3,000 3 Wellhead/Spool Wellhead, Inc. 8-5/8 3,000 4 Casing Collar Maverick or equivalent 5-1/2 5,320 5 Frac Valve Demco 5-1/2 5,000 6 Frac Lines FMC or equivalent 4 3,000 Casing Frac BOPE Demco Frac Valve that screws directly into the 5-1/2" casing short thread & coupling collar. From this valve, 15,000 psi frac treating iron is attached. Integrity of the valve is tested before each fracture treatment to 4,000 psi. BLOW OUT PREVENTION EQUIPMENT WIRELlNE OPERATIONS DURING FRAC'S After the zone has been frac'd and flowed back, a wireline set retrieveable bridge plug is set and then perforations are shot. All wireline operations are conducted under a 5-1/2" x Size Psi No Item Manufacturer (in) Rating 1 Valve Balon or equivalent 2 3,000 2 Plug Balon or equivalent 2 3,000 3 Wellhead/Spool Wellhead, Inc. 8-5/8 3,000 4 Casing Collar Maverick or equiv. 5-1/2 5,320 5 Frac Valve Demco 5-1/2 5,000 6 Spool PESCO w/ 2" and 1 nipple & valve 5-1/2 3,000 7 Fullbore Lubricator PESCO or equiv. 4 3,000 10ft fullbore lubricator. Between the lubricator and the Demco Frac Valve is a spool. The spool provides access to the well case the well needs to be killed while logging. Frac pumps will be on location. We do not propose pressure testing the fullbore lubricator. Street: 1075 Check Street, Suite 202 Wasilla, AK 99654 Mailing: P.Q, Box 871845 Wasilla AK 99677 Tel 907-357-8130 Fax 907-357-8340 www.EvergreenGas.com TC·'ISM FRAC LINES 5 1)\ ---- 2 7 -.------.,-.-- I / 5 4 1 ;-:""', j well~eod' ! 2 Wireline BOPE 'It I' ) =\/:; I~(~ I:~= :1"1 11~:~:\ii~J!:t,J ¡It,¡;;¡::~, \gl.!.M~KJq· ~,t>j::I:I.. ¡ii ,i:¡!¡Ö!;iuli;!!]i; :ii¡J 'i::Ilh~¡ji:¡;!T¡i; :;!m!;;ji¡¡!dl!i!i, ¡llh:, BOP DETAIL FOR CLEAN-OUT OPERA TIONS (AFTER FRACTURE TREA TMENT) A schematic of Evergreen's BOPE for well clean- out operations is shown in the adjacent figure and detailed in the table below. We will utilize this set-up after the fracture treatment to retrieve (via tubing) the bridge plugs and to clean-out sand in the wellbore. Here we propose using 3,000 psi, 7-1/16 inch BOPE manually operated system. The BOP is attached to the 8-5/8" casing head which is also our spool in this operation. [~~~1 IDD~~~.~~~I-["~~~~:~~~~~=.~~;~-~nIJ,l" -<~ø g , c I ,.-~-LT~I~~~.._~9~~T,I...J,Ji . ,. "...., "!; ,i º i.[,..... .113 4 To pump.,.~~~~~.~j. "IT(I"Œ'jToTank BOPE for Frac and Well Clean-out work ~.. Evergreen uses a similar set-up in its operations in the Raton Basin where we frac over 1,200 stages per year using two full-time frac fleets. Size Psi No Item Manufacturer (in) Rating 1 Valve FMC or equivalent 2 3,000 2 Valve FMC or equivalent 2 3,000 3 Valve FMC or equivalent 2 3,000 4 Valve FMC or equivalent 2 3,000 5 Tubinghead & Spool Wellhead Inc 5-1/2 x 2-7/8 3,000 6 BOP: Blind Ram Townsend Manual Operated 7-1/16 3,000 7 BOP: Pipe Ram Townsend Manual Operated 7-1/16 3,000 8 Stripping Head High Tech Tools 7 -1/16 3,000 The blowout preventer is a Townsend (Odessa, TX) double gate with blind rams on the bottom and pipe rams on the top. This BOP is manually operated using two wheels. Above the BOP is a High Tech Tools (Aztec, NM) stripping head which functions as an annular preventer. The body is rated to 3,000 psi and the insert rubber, manufactured by Triple M (Odessa, TX), designed for 2-7/8" tubing, is pressure rated to 1,000 psi. Four manually activated FMC block valves are attached to the spool - two for the kill like and the remaining two to the choke line. The kill line is attached to an Evergreen Well Service frac truck or cement truck. Three inch 15M psi treating iron and/or 3 inch 3M psi hose will be used to connect the pump to the spool. A 15M psi valve and check valve also exists at the pump truck. The choke line connects the wellhead to a 500 bbl frac tank. Two 3,000 psi block valves at the spool will be connected to two or three inch 3M pipe running to the 500 bbl frac tank. In line with the choke line are two 3M psi block valves located at least 20 feet from the wellhead. A conventional choke manifold is not specified in this procedure due to the shallow depths, lack of hydrocarbons, and due to our prior experience with this well bore. Street: 1075 Check Street. Suite 202 Wasilla, AK 99654 Mailing: P,O, Box 871845 Wasilla AK 99677 TeI907-357-8130 Fax 907-357-8340 www.EvergreenGas.com ) ) =\'='~eil~==I"1 I:~,~; ~~¡;¡;'I,II:t;;:Ö:;; \1!1.tAjJ;'I1;A' .1t::'Oj~ 1:1. ¡1¡·tfUb!i¡¡jli!!!jj¡.d¡j'i::IIIi!:!jirmj¡¡i'.,!i!f/!li:li¡¡iiJr!IÍi. i¡'ld. PROPOSED PROCEDURE PIONEER UNIT COOK No 1 API: 50-009-20022-00 PERMIT: 202-180 SW/SE OF SECTION 30 Twp 18 NORTH RNG 1 WEST MATANUSKA SUSITNA BOROUGH, ALASKA Obiective: Stimulate Tyonek coals using a three hydraulic fracture treatment using a nitrogen foam and 20/40 proppant. Set production equipment and place well on test. This is the initial completion for the subject well. Elevations: Ground: 409 ft Kelly Busing: 413 ft (4 ft AGL) Tubulars: Surface: 305' KB, 17.0 ppf, J-55, new Production: 3735' KB, 17.0 ppf, J-55, new Tubing: 2-7/8",6.7 ppf, J-55, 8 rd, EUE, new History: The subject well was spud on November 21, 2002 and drilling ended on November 26, 2002 using Evergreen Rig No 1 using air. Surface and conductor holes were drilled and casings were ran and cemented. The well awaits completion and production test. Preparation: 1. AOGCC: Contact AOGCC (907-279-1433), Winton Aubert, 48 hours prior to operations. 2. Tanks: Two Rain for Rent 500 bbl clean tanks with manifolds. 3. Water: Fill both 500 bbl frac tanks with fresh water. Water sourced from City of Wasilla at 17 cents per barrel. Dorwin Smith (907-355-3443 & 907- 376-3443), ,OJ Excavation will haul water. An equivalent 40/0 KCI solution will be added to all water pumped/injected into well bore. Water needs to be heated. 4. Water Truck: Evergreen water trucks in Wasilla using OJ Excavation personnel. 5. Water Heating & Steam Services: Sub Zero Thawing, Wasilla 907-376- 1569. Bernie Shones has a 2.1 MMBTu Fire Tube Boiler with up to 20 steam lines. Will use this equipment to heat water to 80 deg F for frac. 6. Pumping Services: Evergreen Well Service International Frac Fleet 7. Workover Rig: Evergreen Well Service Rig No. 1696 8. Wireline Operations: Patterson Wireline. Scott Allen (907-354-4529). 9. Haul Tubing: Haul at least 3701 feet of 2-7/8" tubing on location. Spills: Alaska Department of Environmental conservation has strict regulations regarding spills. All equipment will have plastic liners underneath them. Liners will also be run around wellhead. A transfer pump from the cellar to the tank will be in place at all times. Duck Ponds to be placed under all vehicles. Tiaht Hole: No information from this well may be shared with anyone outside of Evergreen Resources. Street: 1075 Check Street, Suite 202 Wasilla, AK 99654 Mailing: P,Q. Box 871845 Wasilla AK 99677 Tel 907-357-8130 Fax 907-357-8340 www.EvergreenGas.com ) ,) ::: ·\l'= ø,:".It'IG-:'::"il:?':=:= IDI~ II" UØIA IØIØL' r 'G. .. 1AAU' IØIØØ m 1:~J!:!ii(:!4,lI:t¢¡: $\mE.¡Ìl$KA', !t::.t;J;j~ ¡:I. ¡II , t¡jj:i!¡¡Ii\¡~! I)!: , iiiJ ' ft'lh~!I;ql;~!rr ; !ihjiJ;:¡i¡¡ii!mif. , ¡¡¡rr: , PROPOSED PROCEDURE (CONTINUED) COOK No 1 Personnel: Engineer: 2nd in Engineer: Tool Pusher: EWS Manager: John Tanigawa Shane Gagliardi Michael Polly Eric Vaughan 907 -841-0000 907-357-8130 719-342-5600 303-881-3557 Accommodations: Evergreen will utilize local businesses to garner support for this project. The hotel accommodations are as follows: Evergreen Well Service: Big Lake Motel 907 -892-7976 Completion Rig Crew: Houston Lodge 907 -892-6808 Patterson Wireline: Big Lake Motel 907-892-7976 Mike Polly: Best Western 907-373-1776 Map to Cook No.1: . This well is located in Pilot 2. All other relevant locations are shown in the map below. _...:1 ,. q ,',....,':::::'", "E"" , ," ~'r \": . ,_",... "-:"'-'-::~:;::::~ :''', :' ¡"( ../', \µ/ /1",\ /,' I ,,,: .....), ~ ",,/ '; 1)'- -, ---..- -.- -¡- -, -' ,,' ~ ", ' en dn.. -'....... ',' "., \ , ," ''''j '¡ 'I I /{J-. ,/ , ~tl~;?~~:E~~:;~" =~\:~'í/_:~---~::'0:~,-l-;':~:~'~;~:!~%-';~,~~~'~~~;;,~~~~~,;~~jI~;,:~ ~~£~4~Ç,;::~~~ ':i",,_;I:::,;:;:;1t~~,'~I,~,,~~t:~(~1~~:" i J ! . '+ "".Q"~Jl~JI,~..J,L,tl I '/ ,Ì' ,,_ ~ ,", \~)"'~.., ::;>;.~;:l ..~::;t::= -~"...> ¡ (~l~ 1 '. ¡"'j t:'t~1 'L Il I .," ,.."" lJ{J,,,,,'..' . .:r.. k I 2.' . l "I ._1 - , "~, .,' I .///'''-'11 l~(a' 'flU) ':'''f'j;,¡,a -es ~ .' .", ':"J ..--"."':"'- ¡, I . '~~~~l'l~'!-' I ·~-:;r'\~,?~~~)(Jlcé:,,:/~~~~~~t,j~bac1i'~:' ,;~F~=~wl~ + -...,-'-:. .::, .,/,.: "~ ':~.~ ::\ 1(" ,/1 ," .. /, (11I111"';' I' ..o;..~1-' '; /) ,,:·~l.. . :"'kff' .. ..'::-......../,,';./ ·~,_....I"..'m.:-iG. ~ " 1/ ",'2..:J '7' ,.- i "II! 'I II ...-:--1 ' Ii' I J' 1-.... 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I.;," :...~II\~.I}:' _ _ l~·~'-=--"~-'--=r'· -;- ",.' "-'=, _'::f\l~P,_' :. .:j;"(:' }) ~'".. J,~_:,",~·:~~~~t~ ,~;~/f-Landmg . II',." :..-=-:.-~L::, _--::':=~ ,1 If~IL~ . -::-~·c-::! 1'-.· - ~p :',1. .'tri,n -O''::'~ i , , ?~,~::;... i-lï~ I,:~:..:"- -. ,,;i~,~':,~ .,".;-,:-'- ~I'"··, Tubing Casing Annulus Size (in) 2-7/8 5-1/2 (above) Casing and Tubing Data Strengths taken to 1000/0 for Tubing and 100% of Casing Weight ID Drift Collapse Burst Yield Capacity (ppf) (in) (in) (psi) (psi) (klbs) Bbls/ft 6.4 2.441 2.347 7,680 7,260 72 0.005794 17 4.893 4.767 4,910 5,320 229 0.02217 0.01521 Capacity Ftlbbl 172.6 45.093 70.685 Street: 1075 Check Street, Suite 202 Wasilla, AK 99654 Mailing: P.O. Box 871845 Wasilla AK 99677 Tel 907-357-8130 Fax 907-357-8340 www.EvergreenGas.com ) =\(=llell~==I"1 Re.OURCEI~.L~S¥')~O.~ III ::¡IJi:l!ii,jli;H;,: ml·i::III!!:!jiQlm:j', !i!l!j~;:HJII:Jf!ij¡. ¡llil:. PROPOSED PROCEDURE (CONTINUED) COOK No 1 1. MIRU Evergreen Well Service. Install Frac Valve on 5-1/2" casing. Install Kill Line to Patterson Flow "T" or Spool (see BOPE sketch). 2. MIRU Patterson Wireline. Install fullbore lubricator and spool on top of frac valve (see BOPE sketch). Perforate zones (3,416' - 3,420',3,356' - 3,360' KB, 4 spf, 19 gr premium charges) for stage 1 frac treatment. RD Patterson Wireline. 3. RU Evergreen Well Service for Staqe 1 Frac. Pressure test lines and Demco Frac Valve to 4,000 psi (see BOPE sketch). Perform mini-frac using water. Fracture stimulate interval using FRACPRO analysis to design treatment on-site. Total Proppant is 64,000 Ibs. Collect at least 15 minutes of fall-off. Bleed-off pressure via flow-line. RD Evergreen Well Service. 4. RU Patterson Wirelipe. sing fullbore lubricator and spool on top of Demco Frac Valve, set RBP 3 0 KB at and perforate (3120' - 3,124',3,091' - 3,095' KB, 4 spf, 19 gr char 'zones. RD Patterson Wireline. 5. RU Evergreen Well Service for Stage 2. Pressure test lines and Demco Frac Valve to 4,000 psi (see BOPE sketch). Perform mini-frac using water. Fracture stimulate interval using FRACPRO analysis to design treatment on-site. Total Proppant is 64,000 Ibs. Collect at least 15 minutes of fall-off. Bleed-off pressure via flow-line. RD Evergreen Well Service. "'__""..,.,/..~ 6. RU Patterson Wireline. Set RBP=~"05 KB and perforate (2,954' - 2,958', . ." 2,908' - 2,911',4 spf, 19 gr char . ,goes. RD Patterson. ~ 7. RU Evergreen Well Service for Sta. e 3 Frac. Pressure test lines and Demco Frac Valve to 4,000 psi (see BOPE sketch). Perform mini-frac using water. Fracture stimulate interval using FRACPRO analysis to design treatment on-site. Total Proppant is 56,000 Ibs. Collect at least 15 minutes of fall-off. Bleed-off pressure via flow-line. RD Evergreen Well Service. 8. RDMO Patterson Wireline & Evergreen Well Service. 9. Allow frac to heal for 3 hours. Begin to bleed-off pressure by flowing well through variable choke. 10. M I RU Evergreen Workover Rig and Evergreen Well Service Cement Truck. 11.lnstall and test BOP. 12. Retrieve plugs and clean out hole. Cement truck will be used to clean out hole and for well control. 13. RIH with tubing, rods, stator, pump and no-turn tool. System has bottom hole pressure gauge & cable. Set 1 joint above top perforations. Minimize use of pony rods on bottom and use no pony rods on top. 14. Install drive head and motor. Install 400 bbl tank with 1100/0 containment berm. 15. Install gas, water, pressure metering. 16. Place on production test. r-" ....-- Street: 1075 Check Street, Suite 202 Wasilla, AK 99654 Mailing: P.O. Box 871845 Was ilia AK 99677 Tel 907-357-8130 Fax 907-357-8340 www.EvergreenGas.com =\I=I~GII~= : Il\.l 1:~~:þ'~jl1,I1:1'¡;;i: ~î\l1ilA$I!:.Ji,!. !t;,t;¡;ij 1:1. Iii ,~hi~'!iilÌli!!llj¡ '!i¡i, ë:III¡~I¡Fn;j¡:r !iruj¡::IiJiii:¡jm. ¡¡¡it: ) , ) " WELL BORE DIAGRAM PIONEER UNIT COOK No 1 API: 50-009-20022-00 PERMIT: 202-180 SW/SE OF SECTION 30 Twp 18 NORTH RNG 1 WEST MATANUSKA SUSITNA BOROUGH, ALASKA · · · · · · · · · · · · · · · · · · ; .~.'-: ..~~{.::.. . · ." · 'e' .' ,.- · ".,': · '.,', · "",.:'":' · · · · · · ,.:. .' .,,', '. ,. ." · · e,' · .'. .'. ,e, . e, . ,.L'.:.' . :;~ : ~'. ~,;::'~~'~:~~«:~¡' : , . I 1-', . PBTD3670"ft ~~ 12" Conductor Casing (0 to 249 ft KB) Casing Driven into ground 8-5/8" Surface Casing (Surf to 384 ft KB) 8-5/8",23 ppf, ST&C, Limited Service Cement 146 sx 15.8 ppg Class G sx Circ to Surface ~. 5-1/2" Production Casing (Surf to 3705 Ft KB) 17 ppf, K-55, ST&C, New 2002 Cement with 511 sx 13.7 ppg Class G sx " ' ," .. · · Stage 3 (56,000 20/40 Proppant) : Perforations: (2,954' - 2,958' ,2,908' - 2,911' ft KB · (4 spf, 19 gr charges, 0.48" hole) · RBP 3,050 ft KB · · Stage 2 (64,000 20/40 Proppant) : Perforations: 3120' - 3,124',3,091' - 3,095' ft KB · (4 spf, 19 gr charges, 0.48" hole) · RBP 3,300 ft KB Stage 1 (64,000 20/40 Proppant) Perforations: 3,416' - 3,420',3,356' - 3,360' ft KB (4 spf, 19 gr charges, 0.48" hole) Street: 1075 Check Street, Suite 202 Wasilla, AK 99654 Mailing: P.O. Box 871845 Wasilla AK 99677 Tel 907-357-8130 Fax 907-357-8340 www.EvergreenGas.com '~ =\'=I~GI~==I'~ ) RESOURCES (ALASKA) CORP. A Subsidiary of Evergreen Resources, Inc, ) Friday, December 06,2002 Mr. Winton Aubert Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th, Suite 100 Anchorage, AK 99501 RE: Sundry Notice: Operational Shutdown Evergreen Resources Alaska Corp Cook 1 /' API No: 50-009-20022-00 Permit No: 202-180 SW/SE Section 30 Twp 18 North Rng 1 West, Seward Meridian Pioneer Unit, Matanuska-Susitna Borough Dear Mr. Aubert, As requested, attached is a sundry notice for the subject well and a well bore diagram. This well was spud on November 21, 2002 and was finished drilling on November 26, 2002. Currently the well is awaiting a directional survey and a completion program. Evergreen requests an "Operational Shutdown" for the holidays. We expect to begin fracture stimulation, using our own equipment, during the first quarter 2003. As discussed, all information regarding this well will be submitted after the w~1I is completed. Thank you for your time and consideration. Please call me if you have any questions: office: 907-357-8130 & cell: 907-841-0000. Sincerely, EVERGREEN RESOURCES (ALASKA) CORP ø· JOhnJ.Ta~ RECEIVED DEe 0 9 2002 Alaska Oil & Gas Co AnChori%ë Commission PO, Box 871845 . Wasil/a, AK 99687 · TEL 907.357,8130 . FAX 907.357.8340 ) STATE OF ALASKA ') ALASKA OIL AND GAS CONSERVATION COMMlb\:)ION REPORT FOR SUNDRY APPROVALS µJ6A- I 2-/ ~/oz- I"^ v& I t../, I 0 "'- ~)'S' r~lì CØr / ~,¡,\ , J: 1. Type of Request Abandon C1 Suspend [] After Casing [] Repair Well [] Change Approved Program [] Pull Tubing CI 2. Name of Operator Evergreen Resources Alaska 5. Type of Well Operation Shutdown Plugging Variance Development Exploratory 3. Address: P.O. Box 871845 Stratigraphic Wasilla, AK 99687 Service 4. Location of well at surface: SW/SE of Sec 30 Twp 18 North Rng 1 West, Seward Meridian 9911 FSL & 888' FEL OF SEC At top of productive interval: At effective depth: Total depth: 12. Present well condition summary Total depth: Measured true vertical Effective depth: Measured true vertical Casing: Length Size Structural Conductor 245' 12-3/4" Surface 380' 8-5/8" Intermediate Production 3701' 5-1/2" Liner Perforation depth: Measured none True vertical none Tubing (size, grade, and measured depth) none Packers and SSSV (type and measured depth) 13. Attachments: 3740 feet feet feet feet 3740 Cemented 70 sx on bot & 10 sx on top 146 sx 15.8 ppg Class G, Circ to Surface 511 sx 13.7 ppg Class G, TOC +/. 450 ft none Description Summary of Proposal 0 Detailed Operations Program 0 14. Estimated date for commencing operation 16. If proposal was verbally approved ŒI Re-enter suspended well U ['! Time extension [J Stimulate [] ,.. CI Perforate [] Other [J [] 6. Datum elevation (OF or KB): ŒI 413 ft KB (4 ft AGL) Ü 7. Unit or Property Name: LJ Pioneer Unit 8. Well number: Cook No 1 9. Permit number: 202·180 10. API Number: 50·009·20022·00 11. Field and Pool: Pioneer Plugs (measured) none Junk (measured) none Measured Depth True vertical depth 249' 384' ",....-' 3705' RECEIVED nFC 0 9 200? AJaska Oil & Gas Cons. Commission Anchorage BOP Sketch 0 15. Status of well classification as: Oil 0 Name of approver Date Approved 17. I hereb~th",??-';2_0~ng i~ true and correct to the best of my knowledge. Signed ~ Title Alaska Projects Manager FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Location clearance 0 Mechanical integrity test 0 Subsequent form required 10- '-I ~ ~ ORIGINAL SIGNED BY to r-e--S~l~~ò-v\. S . M L. Bill Commissioner Date ~ /0 /¿? Z- SU M IN TRI~LlëA TE QBDMS 8Fl Plug integrity 0 BOP test D Approved by order of the Commission Form 10-403 Rev 06/15/88 Gas [&] Suspended D Service 0 Date 12/6/02 Approval No!..--~<;J - 37 c I I PBTD 3670 ft KB Cement in Csg 3740 ft KB 3670 ft KB Production Casing 3705 ft KB 5-1/2", 17 ppf, J-55, ST&C Cemented with 511 sx 13.7 ppg Class G TOC +/- 450 ft Surface Casing 384 ft KB 8-5/8",23 ppf, J-55, ST&C Cemented with 146 sx 15.8 ppg Class G Circ to Surface 384 ft KB 249 ft KB Conductor Casing: 249 ft KB 12-3/4", heavy wall, welded connection Cemented with 70 sx on bot & 10 sx on top Well Bore Diagram Cook No 1 Evergreen Resources Alaska I Pioneer Unit SW/SE of Section 30 Twp 18 North Rng 1 West, Seward Meridian ) ') " , ." ,,:, ) :iJ !Æ~!Æ~11!Æ / A.,A~1iA. OIL AND GAS / CONSERVATION COMMISSION / ~~!Æ~E John Tanigawa Alaska Projects Manager Evergreen Resources (Alaska) Corporation PO Box 871845 Wasilla AK 99687 Re: Pioneer Unit Cook # 1 (revised) Evergreen Resources (Alaska) Corporation Pennit No: 202-180 Surface Location: 991' FSL & 888' FEL, Sec. 30, TI8N, RIW, SM Bottomhole Location: 991' FSL & 888' FEL, Sec. 30, TI8N, RIW, SM Dear Mr. Tanigawa: TONY KNOWLES, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276~7542 Enclosed is the approved application for permit to drill the above referenced exploration well, to expand total depth of Cook # 1 by 900 feet. The pennit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this /i'l:'-day of November, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ) ) Waivers for the following regulations are hereby granted for Cook #1 (Permit No. 202-180): 1. 20 AAC 25.030 (d) (2), requiring conductor casing to be cemented to surface; 2. 20 AAC 25.033 (b), requiring drilling fluid of sufficient density for overbalance; 3. 20AAC 25.035, blowout prevention equipment requirements; 4. 20 AAC 25.050 (a) (2), requiring well bore surveys for each 500 feet of well depth; 5. 20 AAC 25.061 (a), requiring seismic surveys of near surface strata; and 6. 20 AAC 25.066, requiring gas detection on drilling rigs. =\'=I~GI~==I'I RESOURCES (ALASKA) CORP. A Subsidiary of Evergreen Resources, Inc, \ } November 4, 2002 Ms. Cammy Oechsli-Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Revised APD - Increase TD from 2,999 to 3,900 ft KB Cook 1 Twp 18 North Rng 1 West Seward Meridian Pioneer Unit Matanuska Susitna Borough Dear Commissioner Taylor, Evergreen Resources Alaska requests permission to drill an additional 900 feet on the subject well evaluate the Tyonek coals and sandstones. Since the additional depth requested is beyond 500 feet, please find the attached APD and a check for $100.00. On November 1, 2002, Evergreen TD'd the Baranof #4 to a depth of 3,700 ft KB. No drilling problems were encountered. There are absolutely no indications that this well will behave differently. Thank you for your assistance. I appreciate the help you and your staff have given our company. Sincerely, EVERGREEN RESOURCES (ALASKA) CORP John J. Tanigawa Alaska Projects Manager -'~ '~'1 ~ --"," RECEIVED NOV 1 2 2002 Alasl<a Off·& Gas Guns. COmmIssIon , ,~, Anchorage PO, Box 871845 . Wasil/a, AK 99687 · TEL 907,357.8130 · FAX 907.357.8340 \ STATE OF ALASKA ALASKA AL AND GAS CONSERVATION CO~~ISSION PERMIT TO DRILL 20 AAC 25.005 [ ] Service [ ] Development Gas [ ] Single Zone [X] Exploratory [] Stratigraphic Test [ ] Development Oil 5. Datum Elevation (OF or KB) 10. Field and Pool OF 3' AGL 6. Property Designati~I.i'9D'-_ :t Pioneer ,pr.Wate-~7Ji~~Ç~ 7. Unit or Property Name 11. Type Bond (See 20 MC 25.025) Pioneer Unit 8. Well Number Cook #1 9. Approximate spud date 11/20/2002 14. Number of acres in property 15. Proposed depth (MD and TVD) 16,780 3,900' MD, TVD 17. Anticipated pressure {see 20 MC 25,035 (e) (2)} Maximum surface 2027 psig , At total depth (TVD) 1 a. Type of work [X] Drill [] Redrill11 b. Type of well [ ] Re-Entry [ ] Deepen 2. Name of Operator Evergreen Resources (Alaska) Corporation 3. Address P.O. Box 871845, Wasilla, AK 99687 4. Location of well at surface 991' FSL & 888' FEL, Sec. 30, T18N, R1W, SM At top of productive interval Same At total depth Same 12. Distance to nearest property line 888 ft (BLM Minerals) 16. To be completed for deviated wells Kick Off Depth N/A 18. Casing Program Size Casing 12.25 8.625 5.5 we-I\- IA ¿Jj t( [15/ () ~ I' /;.r/o z.. KeJ..lIS/~ [ ] Multiple Zone Number RLB0004711 Amount $200M 113. Distance to nearest well 5,450 ft (AK94 CBM) Maximum Hole Angle vertical AlasRa 0'.'& Gas Gons. Commission Anchorage [X] Filing Fee [X] Property Plat [X] BOP Sketch [X] Diverter Sketch [X] Drilling Program [X] Drilling Fluid Program [ ] Time vs Depth Plot [] Refraction Analysis [ ] Seabed Report [ ] 20AAC25.050 Req. Contact Engineer Name!J er: John Tanigawa (907) 841-0000 Prepared By Name/Number: John Tanigawa (907) 841-0000 21. I hereby certify that t oing is true and correct to the best of my knowledge Signed Alaska Projects Manager Commission Use Only API Number ~~roy-a~Date I See cover letter SO -C:r-:Pr- 2c::::t;:,ZZ "C() V\ \ \U D~ for other requirements Samples Required: [ ] Yes Þ<:ú'Jo Mud Log Required [ ] Yes ;Þ<[No Hydrogen Sulfide Measures: [ ] Yes )c:f'No Directional Survey Req'd [] Yes X'No Required '~9<ing Pr~ssure fo~OPE: [] 2M, [) 3M, [] 5M, [] 10M, [] 15M .::h,,~Þt.Ii-~ ~~ Othery(/( th-~'-~ rpu''¡' .::.f¡ jtcl4h~~ . ./ '"to Æ> <J ORIGIN~~ ~~~ED BY Commissioner ~:e o~~~mission Date I h 1¡)t~Z SUbmi~: {'{¡'~~cate Hole 13 11 7.875 Weight 48 24 17 Specifications Grade Coupling K-55 Welded K-55 STC K-55 STC 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Casing Length Structural Conductor Surface I ntermed iate Production Liner Perforation depth: measured true vertical 20. Attachments Title Permit Number 2D 2 .../ PD. Conditions of Approval: Approved By Form 10-401 Rev. 12-01-85 1600 psig Length 125 300 3900 Setting Depth Top Bottom MD TVD MD TVD 3 3 125 125 3 3 300 300 3 3 3900 3900 Quantity of Cement (include stage data) 26 sx. If necessary, pour add'l cement at surface 111 sx. Circulate to Surface 671 sx. Circulated to surface .-'.. Plugs (measured) Junk (measured) Size Cemented TVD MD Re@81VED NOV 1 2' 2002 Date tt(t¿( '2..~(:> \. ORIGI " L~ 100.00 \ Check Amount ~ \ Check Date: 11/05/2002 I ~ Vendor I 009195 Rs«elVED NO'I 1 2' 2002 AlasKa W& Gas Gons. Commissbn A lchorage 100.00 0.00 100.00 .Iq..'"i~11'1_ 11/04/2002 Permit Fees AOGCC Invoice # Inv. Date 110402 JT5 Evergreen Resources (Alaska) Corp 1401 17th Street Suite 1200 Denver CO 80202 :V:I~GI~::N EVERGREEN RESOURCES, INC. "PLEASE DETACH AT PERFORATION ABOVE" "PLEASE DETACH AT PERFORATION ABOVE" Void After 90 Days , Alaska Oil and Gas Conservation, Commission 333 West 7th'~Venue#100'Î'\\ÎIW,,\I\I:¡:i" Anchorage AK 99501 11'00 ??OOOOa ~II' I: ~ ~l~O ~a ? ~I: :51. 20 2 it ?O 1..11' ~":':'i::;:~'':'i'\i:';:~'''''\\\'''~'':,';'':'',\:'::: .. ..... ~.~."...'...'" '"I,,\\, ,,1,,1 . ",.,,": \.." "'..',,," .','..." : One Hundred Dollars and Zero Cents 11/05/2002 "'************$.100.00 Che~~Amount Check Date Check No 1. ,.~\ ,,' II. 0077000081 ",II"" :11' ) Controlled Disburs~r:nent Accour' ,'I '1"'1 ,:ivergreen Resources (Alast\....) Corp x\,<i\:) , ,,, \ ' ,,' \,1' ~\\I'\\\. 1\\\\i~,\'\I\ ...':::(\I\~p1 17th street SUite 1200\\\\\,> \:?Y';\I\' Dinver CO 80202 :;\~('~,(\:;~\'~( ,;;:; ;,:;,; !::;j;; It}i ì}rnia National BanK FW: Well_Location _ Evergreen.xIs ) ) Subject: FW: Well_Location_Evergreen.xls Date: Fri, 11 Oct 2002 11 :40:54 -0800 From: "John Tanigawa" <JohnT@EvergreenGas.com> To: <steve_davies@admin.state.ak.us> Steve, The original file had wellnames that were incorrect. Here is the correct file. Thank you. Have a great weekend. John Tanigawa 907-841-0000 -----Original Message----- From: Enric Fernandez [mailto:efernandez@lynxalaska.com] Sent: Thursday, October 10, 2002 3:31 PM To: John J. Tanigawa (E-mail) Subject: Well_Location_Evergreen.xls John, This is the updated file with the name swap! Enrique Fernandez Information Technology and GIS Director Lynx Enterprises, Inc. 1029 W. 3rd Ave, Stew 400 Anchorage, AK 99501 907-277-4611 efernandez@lynxalaska.com The information contained in this communication is confidential and privileged proprietary information intended only for the individual or entity to whom it is addressed. Any unauthorized use, distribution, copying, or disclosure of this communication is prohibited. If you have received this communication in error, please contact the sender immediately «Well_Location_Evergreen.xls» I., ......,........................~...............',.....'_.w :.·......tI:I:lal::·'JV·tI\\IIII·w·"'mH''''''·lIlImw.:¡,.>''I:LIIWIt.-'M-':(·:.:(Xi-'~tI.....:III!:l!ml"III:IIr.I"l'W"}\::'IIW.:.!'.·xllm.¡W#'I'II\lII\':-'.~·"":.¡·tI.(#'_'-+::III:\"··":III\Im\:II:II\llmllllllllllllllll:11111.lllr·'II"IIV·I'·..·t/·'III'·'CI'!fX·'Y1"" _(w.-'K-""}¡iOW~_V.I\_V.tI··'CXJ(W(~I_I'II'!I.·(~:>w~_I_ _~.. _'-'~"."''<+' Name: Well_Location_Evergreen.xIs , ¡ IWell Location Evergreen.xIs! Type: Microsoft Excel Worksheet (applicationlvnd.ms-exceI), : Encoding: base64 ).:HILIHI'.\ÞO:I'" \I"I!.\·W·'·'··D:\l·I':V.\'Ii··I·I'('''IV~:V''.IHIII'llIIliit:I'.II'I IIII!! '''I': 'I' , 11:11-:'" "'1\1\0:1"1::11," ".11111 11111""" ,,,. . '" "". .....v"'IIi'IIIIII. .WI.·¡·:-I+'t.: :I'~"I·I'II~"·1\'''''''''''''IIIIo\''''''~V'·I''''II·IIo\'II!¡':W¡':'·:IIIU.:'\1I1·"II'u'.....,,·..··I'·..··I'III'..·'··'I·..·'..II·'.-",-.:· IIWI·':II.',IIIIIII··..·· AREA Pilot 1 Pilot 1 Pilot 1 Pilot 1 Pilot 2 Pilot 2 Pilot 2 Pilot 2 Pilot 3 Pilot 3 Pilot 3 Pilot 3 ) } NAME D.L.SMITH #1 GARY & JOANN STROMBERG #2 CORNHUSKER #4 ROBERT SMITH #3 COOK #1 LOWELL #2 BERI NG #3 BARANOF #4 TYONEK #1 KENAI #2 ILlAMNA #3 NANWALEK #4 EL V FT LEGALDESC 274.4 Located 3293' north of the south line and 293' from the west line of section 1 T17N R3W Seward meridian. 296.0 Located 1386' north of the south line and 933' from the west line of section 1 T17N R3W Seward meridian. 249.8 Located 3272' north of the south line and 606' from the east line of section 2 T17N R3W Seward meridian. 265.3 Located 2426' north of the south line and 141' from the east line of section 2 T17N R3W Seward meridian. 408.8 Located 991' north of the south line and 888' from the east line of section 30 T18N R1 W Seward meridian. 399.9 Located 967' north of the south line and 1329' from the east line of section 30 T18N R1 W Seward meridian. 449.0 Located 1523' north of the south line and 471' from the east line of section 30 T18N R1W Seward meridian. 403.6 Located 504' north of the south line and 423' from the east line of section 30 T18N R1 W Seward meridian. 417.4 Located 301' north of the south line and 1841' from the west line of section 20 T18N R1W Seward meridian. 418.9 Located 815' north of the south line and 1832' from the west line of section 20 T18N R1W Seward meridian. 429.3 Located 236' north of the north line and 2403' from the west line of section 29 T18N R1 W Seward meridian. 414.7 Located 353' north of the north line and 1528' from the west line of section 29 T18N R1W Seward meridian. ASP27Z4N ASP27Z4E DD27N DD27E 2774923.09356000000 543786.35874200000 61.59466451260 -149.74861231100 2775528.70150000000 544423.26626200000 61.59631427130 -149.74494210500 2774899.30194000000 542887.46491700000 61.59460882660 -149.75377352900 2774054.90335000000 543355.95720500000 61.59229425450 -149.75110236500 2783408.27296000000 584593.04550000000 61.61724205120 -149.51397565500 2783381.99302000000 584152.01484300000 61.61717914890 -149.51651058400 2783942.33402000000 585004.69554800000 61.61869441150 -149.51158763300 2782923.44787000000 585062.93452400000 61.61590632030 -149.51129695300 2788017.16180000000 587274.33011000000 61.62979282080 -149.49836720300 2788531.16269000000 587261.14713400000 61.63119900780 -149.49842021600 2787480.78035000000 587841.89235100000 61.62831369770 -149.49512903800 2787361.90624000000 586968.42649400000 61.62800698160 -149.50015429700 Evergreen Well Locations NAD 27, AK Zone 4 ) Subject: Evergreen Well Locations NAD 27, AK Zone 4 Date: Thu, 10 Oct 2002 11: 14:27 -0800 From: "John Tanigawa" <JohnT@EvergreenGas.com> To: <steve _ davies@admin.state.ak.us> Steve, I apologize that these have taken so long. Here are the coordinates. >From now on, we will submit all coordinates in NAD 27. please contact me if you have futher questions. Thank you. John Tanigawa 907-841-0000 .-.-.....--.......,....... ¡ Name: Well_Location_E\'ergreen.xls ¡ [IlWell Location Evergreen.xls! Type: Microsoft Excel Worksheet (application/vnd.ms-exceI): _"~"_'~_~._'_"_'"'''''''''''''W'''''''''''''''WN,,"W"~_'',''''''''W_''',..,........'....'..M~",~","W""~"'W,"'~_~,~,~,~~~~'^~_,?,'~~,~?~......,..,~........".>..,"'~..".."".........."....""w...............,,,......,,......................".."......"..,"w......,"w..''''..'''''''''__,,__'''~,,~~_,' I ) ~~~~E :} fÆ~!Æ~~,~fÆ II ALASKA OIL AND GAS John Tanigawa CONSERVATION COMMISSION / Alaska Projects Manager Evergreen Resources (Alaska) Corporation PO Box 871845 Wasilla AK 99687 ') TONY KNOWLES, GOVERNOR 333 W. 7'"H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Pioneer Unit Cook #1 Evergreen Resources (Alaska) Corporation Pennit No: 202-180 Surface Location: 991' FSL & 888' FEL, Sec. 30, T18N, R1W, SM Bottomhole Location: 991' FSL & 888' FEL, Sec. 30, T18N, R1W, SM Dear Mr. Tanigawa: Enclosed is the approved application for permit to drill the above referenced exploration well. The permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. Evergreen Resources (Alaska) Corporation assumes the liability of any protest to the spacing exception that may occur. 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 tenns and conditions of this permit may result in the revocation or suspension of the pennit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). BY ORDER OF THE COMMISSION DATED this~ day of September, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ') ) Waivers for the following regulations are hereby granted for Cook #1 (Permit No. 202-180): 1. 20 AAC 25.030 (d) (2), requiring conductor casing to be cemented to surface; 2. 20 AAC 25.033 (b), requiring drilling fluid of sufficient density for overbalance; 3. 20 AAC 25.035, blowout prevention equipment requirements; 4. 20 AAC 25.050 (a) (2), requiring well bore surveys for each 500 feet of well depth; 5. 20 AAC 25.061 (a), requiring seismic surveys of near surface strata; and 6. 20 AAC 25.066, requiring gas detection on drilling rigs. · STATE OF ALASKA )AND GAS CONSERVATION COM PERMIT TO DRILL 20 AAC 25.005 [ ] Service [ ] Development Gas [ ] Single Zone [ XJ Exploratory [] Stratigraphic Test . [ ] Development Oil 5. Datum Elevation (DI- or KB) 10. !-Ield and Pool DF 3' AGL 6. Property Designation APe.. f>Ç if') ~ 3'Îil¿..i /JY' 7. Unit or Property Name 11. Type Bond (See 20 MC 25.025) Pioneer Unit 8. Well Number Cook #1 9. Approximate spud date 10/8/2002 14. Number of acres in property 15. Proposed depth (MD and TVD) 16,780 2,999' MD, TVD 17. Anticipated pressure {see 20 MC 25:035 (e) (2)} Maximum surface 1559 psig, At total depth (TVD) Setting Depth ' Top Bottom , MD TVD MD TVD 3 3 125' 125 3 3 300' 300 3 3 2999 2999 ALASKA ( 1 a. Type of work ' [X] Drill [] Redrilll1 b. Type of well [ ] Re-Entry [ 1 Deepen, , 2. Name of Operator ' Evergreen Resources (Alaska) Corporation 3. Address ' P.O. Box 871845, Wasilla, AK 99687 4. Location of well at surface 991' FSL & 888' FEL, Sec. 30, T18N, R1W, 8M At top of productive interval Same At total depth Same 12. Distance to nearest property line 888 ft (BLM Minerals) 16. To be completed for deviatedwells Kick Off Depth N/ A 18. Casing Program Size Casing , 12.25 8.625 5.'5 k-i c:. A- .~S I ON -:::JlF" c¡ {-sl OL '11'1/~ [ ] Multiple Zone Pioneer Number RLB0004711 Amount $200M 113. Distance to nearest well .. , 5,450 ft (AK94 CBM) Maximum Hole Angle vertical Hole 13 11 7.875 Weight 48 24 17 Specifications Grade Coupling K-55 Welded K-55 STC K-55 STC 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 1230 psig Length 125 300 2999 Quantity of Cement (include stage data) 26 sx. If necessary, pour add'l cement at surface 111 sx. Circulate to Surface ' 535 sx. Circulated to surface Plugs (measured) Junk (measured) Size MD TVD Cemented 20. Attachments [X] Filing Fee [X] Property Plat [X] BOP Sketch [X] Diverter Sketch '[X] Drilling Program [X] Drillinø Fluid Program [ J Time vs Depth Plot [] Refraction Analysis [ ] Seabed Report ( ] 20AAC25.050 Req. Contact Engineer Name/Number: ohn Tanigawa (907) 841-0000 Prepared By Name/Number: John Tanigawa (907) 841-0000 is true and correct to the best of my knowledge Alaska Projects Manager Commission Use Only IAPI Number Q ") /\ -? 00 ,Ç()-()Cj,- ~O2-¿.-- Samples Required: [ ] Yes I'<) No Hydrogen Sulfide Measures: [ ] Yes þ<J No Required Working Pressure for BOPE: [] 2M, [] 3M, ORIGINAL SIGNED BY Other: D TaYlor Seamount Permit Numb ~ / 202- / {) Conditions of Approval: Approved By Form 10-401 Rev. 12-01-85 Title Date Ø4'o/ZOð 2. Commissioner APrroval Date I See cover letter q D (J ^ for other requirements ~ud Log Required [ ] Yes Þ<J No Directional Survey Req'd [ ] Yes KI No [ ] 5M, [] 10M, [] 15M , ;'1c.../¡ 'y¡c.-f,~ :Sè.{y~e::J O/.1(j' » Date q 1/6 /~:J.. Sub~ In f~iplicate by order of the commission ) ) =\I=I~GI~==I'I RESOURCES (ALASKA) CORP, ,1 0uMI(/iflfY af EV(ilr¡]NWI1 11,~,~()(Jn.''!I, 1(1(' Permit To Drill Additional Information 20 AAC 25.005 (C 1) $100 FEE Check attached to application 20 AAC 25.005(C 2) PLAT IDENTIFYING PROPERTY AND OWNERS The mineral interest ownership map and the survey plat are shown in Figures 1 and 2 respectively. Figure 1 shows the subject well within Pilot Number 2. It also shows the mineral interest owners including a 1,500 foot radius around each well. · ,..Únl~ê.,s:itY:i'.. QfAiå$kti. ' ~:O'clil1.~..'·...·.~"~r~rf).·.~)?·..' State of Alaska (Evergreen) 30 1,500 It radius Figure 1 Mineral Ownership Map and 1,500 foot radius around each well in Pilot 1 Coordinates of the location at surface, top of each formation, at total depth Surface Top Tyonek Total Depth Hole Locations 991' FSL & 888' FEL OF SEC 30 Twp 18 North Rng 1 West 991' FSL & 8881 FEL OF SEC 30 Twp 18 North Rng 1 West 991' FSL & 888' FEL OF SEC 30 Twp 18 North Rng 1 West (a) Coordinates in state plane coordinates Surface Top Tyonek Total Depth Hole Locations North 2783102 ft & East 1724538 ft ASP Zone 4 Nad 83 North 2783102 ft & East 1724538 ft ASP Zone 4 Nad 83 North 2783102 ft & East 1724538 ft ASP Zone 4 Nad 83 APPLICATION FOR PERMIT TO DRILL Cook 1 Pilot 2 ) ) =\f=I~GI~==1\I RESOURCES (ALASKA) CORP. ¡.\ S(/)'~Idimy Of Evm!1rt~m' Rtm({jrr~rs, '(lr: ~ =rtlflll 19 20 N PITTMAN ROAD 30 29 I -JB ~ Ilb,\ NOTES: 1. COORDINATES SHOWN ARE NAD83 ALASKA STATE PLANE ZONE 4, NAD 83. 2. GEOGRAPHIC COORDINATES ARE NAD 83. 3. ALL DISTANCES ARE GROUND IN U.S. SURVEY FEET. 4. VERTICAL DATUM IS M.S.L. NGVD 1929. BASED ON BENCHMARK "V102" ,THIS SURVEY o < o a:: COOK #1 LOCATED 991' FROM THE SOUTH LINE AND 888' FROM THE EAST LINE OF SECTION 30, T 18 N, R 1 W, SEWARD MERIDIAN LA T. 61'36'59.530"N LONG. 149'31'00.037"W ASP ZONE 4 N=2783101.558 E=1724538.137 (NAD 83) GROUND ELEVATION = 408.8' Õ a:: ~~]~ ~~~",'~ VICINTY MAP SCALE 1" 1 MILE N C 1/4 () 29 300 N 89'51'15" W 2639.44' <.0 m ~ ~ è§ N Q::: è ~ ~ ;J:: "0 COOK #1 (j "~ ~887.77'--- ~ o o (/) <.0 N 0'1 1'0 <.0 N SCALE 1" = 600' SE 1/4 SECTION 30 T18N, R1 W, S.M., ALASKA ~ - ~ "co o b o z ;;:; 0'1 0'1 30 @ 30 29 31032 N 89'51'23" W 2639.43' 31 ®LOUNSBURY & ASSOCIATES, INC. ENGINEERS- PLANNERS- SURVEYORS 723 W, 6th AVE. ANCHORAGE, ALASKA 99501 (907) 272-5451 AUGUST 12, 2002 I DWG NAME 028-.3W4,DWG PILOT 2 WELL COOK #1 PERMIT DRAWING DRAWN FWW I CHECKED KWA I SCALE " = 600' APD Cook 1 Pilot 2 =\f=I~GI~==i'I RESOURCES (ALASKA) CORP, A Sub_~lrlfmy 0' f\lnr¡'¡r«IIW R'(I$nuft"~r!/, /('1(: ) ) (b) Proposed Depth, Depth of each objective formation Estimated Formation Tops Quarternary Gravel Surface Tertiary Tyonek 100 (c) Other Information as required by 20 AAC 050(b) For all hole segments, an air hammer will be used to drill the hole. Unlike PDC or conventional bits, air hammers, inherently drill straight holes. This is because the weight on bit is a fraction of the weight required by conventional drilling techniques. Increased weight on bit causes holes to become deviated. For additional information, please refer to Evergreen's response to the waiver request in Appendix A of this application. Since air hammers have not been widely used in Alaska's oil and gas industry, Evergreen will perform a Totco deviation survey for this well. This information will confirm to the commission that air hammers, by their design, must drill straight holes. It is our aim that after showing the commission that air hammers drill straight holes, that surveys will not be required. 25 AAC 25.005 (c 3) DIAGRAM OF BOPE Evergreen will use air to drill conductor, surface and production holes. Using this system, we plan on using a diverter in lieu of a BOP since our proposed diverter system is an equally effective means of well control in shallow gas wells. This discussion is included as Appendix A submitted August 8, 2002. A diagram of Evergreen's well control arrangement is shown in Figure 3. Evergreen Resources Alaska Surface Well Control Setup Two diverters will be used while drilling the subject well. One for the 11 inch surface casing hole and the other for the 7-7/8 inch production casing hole. For the 11" surface hole, the diverter will connect to the cemented in conductor via a 13- 3/8" ST&C collar. The Production hole's diverter will connect to the cemented in 8-5/8" surface casing via the 8-5/8" ST&C collar. These diverters are shown in the Figures 4 and 5. APD Cook 1 Pilot 2 ~ \ 12~ ps), ~~t~ ~~!~e ~9' x 8" !Pß)~~O~t ~i~~ )- ,. ,~~~~_\~~~0i~' VENTING 20 MMSCFD KICK Ground Level FORMATION GAS This schematic shows Evergreen's Air Drilling well control setup. When venting a 20 million standard cubic foot kick of methane, the diverter must contain 40 psi of pressure. The Diverter is rated to 500 psi while drilling and 1,000 psi while static. This is a 12 fold safety factor while drilling and a 24 fold safety factor when pipe is not rotating. Figure 3 - Surface Well Control =\f=I~GI~==I~1 RESOURCES (ALASKA) CORP, A S1jb.~idÙlry of EVi'frmmn Rf,I,'!I(}urC(/S, /111':. ) ) EVERGREEN RESOURCES ALASKA SURFACE CASING DIVERTER EVERGREEN RESOURCES ALASKA PRODUCTION CASING DIVERTER I --I µ '''''''''", 151n I r- r-1 r-1 r-1 WASHINGTON DIVERTER I I -I I I I ~ r¡UBBER ELEMEN..T let t.l::P LJ::J I MODEL 4010-C<; '.' . - ,- - - ¡See Rlght ~¡ // - ',,- ,.,-/- -- . . ','....... ,....""../' I -Ie " '-, "-""~'- 151n I r- r, r-1 r-1 WASHINGTON DIVERTER ij ~ U ~RUBBERELEMENT MODEL 401 O-CG - -- I -,- - ¡See Belowl // 161n 161n /,,/ .-... ,'. _.~._'.. ,/// - To 30 FT BLOOEY LINE 8-5/8', 23 PPE J-55 CA~NG 8,097" ID with Hammer Union connector To 30 FT BLOOEY LINE 8-5/8',23 PPF, J-55 CASING 8,097'ID with Hammer Union connector = CONNECTOR Iso , 3-3/8" PIN ST&C, 8 RD, J-55 .. 1,,"",·'''··.....1 CONNECTOR 8-5/8" PIN ST&C, 8 RD, J-55 ~,.".""..' .'. r Figure 4 Surface Casing Diverter Figure 5 Production Casing Diverter 25 AAC 25.005 (c 4 A) MAXIMUM BOTTOMHOlE PRESSURE The maximum anticipated surface pressure (MASP) for this air-drilled well will equal the formation pore pressure less a full gas column to the surface. Based on offset well data, the highest formation pressure expected in this well is 1,559 psi (10.0 ppg EMW) at the well's TD of 2,999' TVD (or 0.520 psi/ft). Complete evacuation of the well bore, except for a 0.11 psi/ft gas gradient, is assumed. MASP (pore pressure) = (2,999 ft)(0.520 - 0.11) = 1,230 psi 25 AAC 25.005 (c 4 B) DATA ON POTENTIAL GAS ZONES One gas bearing zone will be encountered during the drilling of this well, namely the Tertiary Tyonek formation. Here, coals will be drilled through along with sandstones and siltstones. There are six wells that have penetrated this zone within the Pioneer Unit. The Quarternary Gravel will also be penetrated. This zone has no gas since there are no barriers for accumulation. This is the area's fresh water aquifer. 25 AAC 25.005 (c 4 C) POTENTIAL DRilliNG PROBLEMS Since air drilling will be the drilling fluid for this well, problems associated with differential sticking and loss circulation zones, as identified in the regulations, are not relevant. However, issues associated with hole sloughing are a concern. For this reason, 12-3/4 inch conductor casing will be casing air drilled through the Quarternary APD Cook 1 Pilot 2 ) ) =V=I~GI~==N RESOURCES (ALASKA) CORP, A 0l1b!;l(1imy of EVOrprtf«111 R(I!\t)u/'Clrs, Inr.. Gravel section. This interval will then be cemented in with 26 sacks of cement to prevent water and gravel from sloughing through the conductor annulus. Significant gas volumes produced from formations are easily handled during drilling and this is discussed in Appendix A. To ensure that casing and logs can be run safely, if sufficient gas is being vented, then the well will be killed. On site will be a cement pump, mix tanks and sufficient chemicals to create a 10.5 pound killing fluid. The risk of encountering H2S is negligible. No wells drilled in or near the Pioneer Unit had any indications of hydrogen sulfide. Further, coal bed methane does not contain H2S. Details for H2S are discussed in Appendix A submitted to the commission on August 8, 2002. 25 AAC 2!).005 (c 5) FORMATION INTEGRITY TEST Formation integrity tests are not applicable for this application since air drilling with a diverter is being employed. Formation integrity tests require a pressure containment scheme using BOPs to be relevant. Please refer to Appendix A of this application for further discussion. 25 AAC 25.005 (c 6) CASING AND CEMENT PROGRAM The casing and cementing program for the subject well is shown below. For the first well drilled in Pilot Number 2, a single induction log will be run to confirm that the surface casing is set through the fresh water zone. We will drill and set surface casing below the fresh water zone. All remaining surface casing depths will be modified based on this information. Current setting depths are well below all fresh water wells in the area. Casing Information Depth OD ID Pipe Weight Connection New/Used (ft KB) (in) (in) Grade (Ib/ft) Type Conductor 125 12-3/4 12.00 Line Pipe 48.0 ST&C Limited Svs Surface 300 8-5/8 8.097 K-55 23.0 ST&C New Production 2990 5-1/2 4.892 K-55 17.0 ST&C New For the surface and the production casings, the cement will be circulated to surface. In the case of the conductor pipe, we will attempt to circulate cement with 26 sacks of cement. If cement does not circulate, which is likely since this is a gravel interval drilled with air, then we will fill the annular volume with cement. Cement Information Yield (ft3/sk) Type Comments 1.18 Class G Circulate, if no circulation, then pour from top 1.2 Class G Circulate to Surface 1.35 Class G Circulate to Surface Conductor Surface Production Depth (ft KB) 125 300 2990 Volume (sacks) 26 111 535 20 AAC 25.005 (c 4) DIVERTER SYSTEM The diverter system is described in 25 MC 25.005 (c 3) BOP SETUP. 20 AAC 25.005 (c 8) DRilliNG FLUID SYSTEM APD Cook 1 Pilot 2 =\f=I~GI~==N RESOURCES (ALASKA) CORP. A SIlb.~lrliIllY 01 EW'f'1mm1 11'(t!\ourcvli, Inc. ) ) The subject well will be air drilled and therefore utilize no fluid system. The proposed process of air drilling and of killing the well when and if necessary are described in detail in Appendix A dated August 8, 2002. 20 AAC 25.005 (c 9) ABNORMAllY GEOPRESSURED ZONES There are no abnormally geo pressured wells in the Pioneer Unit as discussed in Appendix A, submitted on August 8, 2002. 20 AAC 25.005 (c 10) SEISMIC REFACTION/REFlECTION ANALYSIS Evergreen requested a waiver for running seismic as detailed in Appendix A, submitted on August 8, 2002. 20 AAC 25.005 (c 11) OFFSHORE, SEABED CONDITIONS Not applicable. This is an onshore well. 20 AAC 25.005 (c 12) EVIDENCE OF BONDING Evergreen Resources Alaska's state wide bond is on file or will be very shortly with the commission. 20 AAC 25.005 (c 13) COPY OF DRilliNG PROGRAM A copy of the drilling program is shown as Appendix B. 20 AAC 25.005 (c 14) DRilliNG MUD & CUTTINGS DISPOSAL Evergreen has received permission from the Matanuska-Susitna Borough to dispose of drill cuttings at the borough landfill. Because well depths are less than 3,000 feet, we also have permission to dispose of the cuttings at the drill site. 20 AAC 25.005 (d) INTENTIONAllY DEVIATED WEllS This well is not being intentionally deviated 20 AAC 25.005 (e) MULTIPLE BRANCH WEllS This well will not have multiple branches 20 AAC 25.005 (f-h) n/a APD Cook 1 Pilot 2 =\f=I~GI~==I'1 ) ) RESOURCES (ALASKA) CORP. A Sl/b,';lrlÙ:ttY (¡I £vf'f(1f11\m A},g(JII(Ç('~, 1/1î. Appendix A Answer to AOGCC Questions APD Cook 1 Pilot 2 =\f=I~GI~==I'1 RESOURCES (ALASKA) CORP, .J¡ B!lb.~It'/iIl/Y or [\I"'r¡¡mm1 RtIMUf\:'(I.s. Inr ) ) =\I=I~GI~==I'I Evergreen Resources Alaska Corporation Response to AOGCC Questions August8,2002 John Tanigawa Alaska Projects Manager Wasilla, Alaska 907 -841-0000 APD Cook 1 Pilot 2 =\I=I~GI~==I'I '} ) I RESOURCES (ALASKA) CORP, ¡.\ S(Jb..~ld¡Jfy c), EVt!r()rmm RO!J[.lUfl~~S, I/'!è Waiver #1 - 20 AAC 25.030(d)(2)- Don't want to cement 100' to 200' conductor to surface. Will use 10 sacks. Surface csg must be set below the glacial gravel section. The gravel section is 500' to 800' thick, not 100' to 200'. The map (Figure 4) is a structure map using sea level datum. You have to add the topographic elevation to get the true thickness. Coals and permeable sands which may be gas bearing are present immediately underlying the glacial gravel section. (1)What would you do to mitigate risks if you drilled a free gas zone prior to setting surface csg? (2) How will free gas affect your cementing plans? (3) Does the fact that you will be setting the conductor in a permeable gravel zone change your ideas about your cementing plan? First, we must make a correction to figure 4 in the C Plan exemption document. Figure 4 does not represent the top of the Tyonek. The figure is improperly labeled. Instead, this is an isopach map showing the thickness of the gravels based on water well data. You are right, if this were a Tops map for the Tyonek, then the 500 to 800 feet would be co rrect. (1) To mitigate the risks of encountering a gas zone while drilling the surface casing, Evergreen will a) set and partially cement a 12-3/4" conductor casing (to protect fresh water & prevent water from entering well bore during surface hole drilling), b) Use a diverter (to redirect gas from annulus), c) Utilize a series of check valves in the drill string (to eliminate gas up drill pipe) and d) Drill with air. Described below is a description of this process and how it will mitigate dangers during this portion of the well plan. a) Evergreen will hire a water well contractor to casing drill (e.g., casing is drill pipe) the conductor through the Tertiary gravel and into the top +/-25 feet of the Tyonek formation. Depths are estimated to be 100 feet in Pilots 2 and 3 and 200 feet in Pilot 1. This section of the hole will be reverse circulated using air. After the casing is set, a 13-3/8",ST&C, 8 rd, J-55 collar will be installed at surface via a bell nipple. We will attempt to circulate cement to surface using 20-30 sx of 15.6 ppg cement or 150% of the annular volume. If cement does not circulate, which is likely in an air drilled hole through gravel, then we will pour additional cement sacks from surface until full. Before drilling out, the conductor will be pressure tested to 100 psi or ~ psi/ft of the conductor setting depth. The conductor, therefore will be sealed. It is noted here that the primary reason for cementing the conductor is to prevent water from entering into the well bore while drilling the surface hole and not for kick protection. This is because, kick protection in the traditional sense, is not needed in an air drilled hole. b) Next, a 13-3/8" x 4-1/2" drill pipe diverter will then be installed. The diverter will screw into the conductor casing. The 11" surface hole will be drilled using an air hammer bit at 3,000 scfm of air. The diverter will redirect air, methane, cuttings, APD Cook 1 Pilot 2 =\I=I~GI~==N RESOURCES (ALASKA) CORP, A $1b,~I(/iIllY (II E.'vl'I'IJr¡,tll7 Rt':'ì(!ltrÇ(r,~, 111(; ) ) and water from the annulus to the cuttings pit via an 8" diameter by 30 foot blooey line - well away from the drilling table. This diverter head is fabricated by Evergreen, has been used for 7 years, has drilled over 575 wells in a variety of working conditions. Pressure rating is estimated to be 250 psi working and 500 psi static, which is half of a similar Washington or Williams diverter. This pressure rating should be adequate. For example, if 100 MCFD of methane gas were being vented, the diverter would see approximately 20 psi of pressure. c) We must also prevent natural gas from flowing up through the drill pipe during connections. This is handled through a series of check valves inside the 4-1/2" drill pipe. d) Finally, as will be shown later in this report, handling shallow gas kicks is arguably safer using air than in mud drilling. This is because well control is not based on containment of the formation pressures, where high pressure BOP's, and very large (in excess of 16 inches) are required. Instead, the formation is allowed to vent and high pressures are not allowed to build-up. (2) A free gas zone does not affect our cementing plans. Surface cement will have a density of 15 ppg. (3) We plan to sent the conductor casing below the gravel zone and into the top of the Tyonek formation. We plan to drill roughly 25 feet into the Tyonek. We were not planning on setting above the Tyonek. Waiver #2- 20 AAC 25.033 (b) Drill under balanced with air. (1) There are some permeable sands in the section. Some coals may also be permeable and may contain only gas and no water. Your plan is to have fluid and cement on location. Do you understand that the BLT #1 tested individually up to 40BBLS/hour of gassy water from several sands and one coal suggesting artesian or other type of over-pressured systems? We think that the Pittman well also encountered gas sands. You should verify that. (2) Have you evaluated the mud weights in wells drilled in the area? (3) What volume of air will you be using? Would it be sufficient to dilute a zone capable of 2000mcfd to below lower explosive limit (LEL) at hydrostatic pressure? (4) What is the maximum expected equivalent mud weight attainable from the drilling air? (5) What equipment is available to pump kill weight fluid and how will it be pre-staged? What would be the response time if a kick occurred? (1) You are correct for the BL T #1 there was a 40 bbl/hr flow of gas cut water. We were unable to find information at the commission library regarding the Pitman #1 well. However, If we encounter 40 bbls/hr of gas-cut water, this will not be a problem. We have effectively air drilled with water rates in excess of 250 bbls/hr of gas-cut water, further, we will have the pump equipment, and additives to kill the well on site. (2) We have evaluated the mud weights in the area. This data is shown in the table below. Generally, wells were drilled with muds in the 9.5 to 10.0 ppg range for the depths we are drilling. (3) The volume of air we will be 2,000 scfm for the 7-7/8 inch hole and 3,000 scfm for the 11 inch hole. The lower explosive limit (LEL) in ideal conditions is 50/0 and the APD Cook 1 Pilot 2 =\I=I~GI~==I\I RESOURCES (ALASKA) CORP. A $ub.<:r./!'1inry of EVl1rþlrl!l/r1 Rt.I!I(JU/'COti, {('Ie ) ') Upper explosive limit (UEL) is 12% by volume of methane in air [U S Bureau of Mines, R.I. no. 4751, 1950]. At concentrations above the LEL threshold, the air- methane mixture capable of ignition. Formations can therefore flow up to 144 Mcfd of methane in the 7-7/8" production hole and 218 Mcfd in the larger surface hole before fire is possible. Even when one drills wells in this condition, down hole are almost unheard of in CBM reservoirs. This is because even when one is in the explosive window, it is virtually impossible ignite the gas. Ignition sources in these shallow wells are principally thought to be from the bit cutting the rock and drill pipe rotating against a formation or surface/conductor casing. While operating an air hammer however, water is injected into the compressed air at 20 gpm to cool the bit and the hammer mechanism. This water mixture creates a fine mist that prevents sparks from occurring. Further, formation waters are produced during the drilling that further wets the system. Proof however is evident in the fact that thousands of wells have been drilled into CBM reservoirs using air without any down hole fires. (4) The maximum bottom hole pressure just above the bit in the annulus is 30 to 70 psi while air drilling the production hole at 3,000 feet. Mud weights are very low. (5) Equipment that will be on hand to kill the well will be Evergreen's cement unit, batch mixer consisting of two 75 bbl mix tanks water and weighting agents to build two batches of 10.5 ppg mud (or a single 13.5 ppg mud). Evergreen's portable cementer is shown in the figure below. This pump has 4.5" plungers and is capable of pumping at 6,228 psi at 13.3 bpm". The.two 75 bbl batch mlix tanks ar,e designed to be used as a cement mixer or as a mud tank and are equipped with Evergreen Cement Portable Pump paddles to mix the weighting agents into the water. Calcium chloride will be our weighting mechanism, xanthan guar will be used to build viscosity and lost circulation material (bark, celoflake, et cetera) will be used to assist in lowering the fluid loss. Concentrations of each are the following: 123- lbs/bbl CaCI, 1.5 ~bsJbb~ Xanthan guar and 10 Ibs/bbl lost circulation material. A Evergreen Portable Batch Mixer 28 foot trailer will house the chemicals and will be on location at all times. Waiver #3- 20 AAC 25.035- No BOPE. (1) Have you examined the Houston #1 and #2 well histories and operations? These wells were drilled with air up to 500' into the coal sections without even a diverter. Ignore Houston #4 since it spuded in metamorphic basement. (2) Can you demonstrate that you have a means of well control that is equally effective to a BOPE? I will do this. APD Cook 1 Pilot 2 =\I=I~GI~==N ') ) RESOURCES (ALASKA) CORP, 4 $ob,~I(fi(lry 01 Evmpmøn A'(I$CIumrs, I(le (3) Your report states that you will have a lOOOpsi diverter. Is that the pressure rating of the pipe or actual drilling air pressure? Does that imply that you will be using different equipment than what the Commission observed in the Raton Basin? We need a more clear description of your well control equipment. I will do this. I will need some help with CAD work though. (1) The GRI, Inc's Houston 1,2 3 & 4 well records are unavailable to Evergreen. We have talked to people and have read reports on this project. These wells are relevant due to their close proximity to the Pioneer Unit. Four CBM wells were drilled representing the first time that air drilling technology was employed in Alaska. BOP's were installed after the surface casing, drilled 700 feet into the Tyonek formation, was set (Evergreen as a comparison will drill +/- 25 feet into the Tyonek. Wells were then drilled to roughly 2,100 feet and 4-1/2" casing was run. Coal, sandstones and siltstones were encountered from surface to TO. Although shallow gas was venting during the entire drilling process (even w/o a diverter during surface hole drilling), because the well was allowed to vent and not build up pressure, no well control issues arose and the BOP was never engaged for well control purposes. The successful drilling of these four wells proves that air drilling is an effective way to drill the shallow Tyonek formation in this area. (2) Not only will Evergreen demonstrate that we have an equally effective means of well control but, in fact, air drilling at these shallow depths is safer than mud drilling for shallow gas kicks. Mud drilling relies on always being in an overbalanced drilling condition. As history shows, this does not always happen. When kicks occur, the key to safety is detecting before the well becomes uncontrolled. Detecting shallow gas kicks are difficult since they are relatively hard to detect and because they occur very quickly. The well control strategy in mud drilling is pressure containment. For this reason, elaborate BOP's, choke manifolds, gas busters and very large blooey lines, like those stipulated in the AOGCC regulations are required. Air drilling on the other hand, has a completely different approach to well control. In air drilling our strategy is to allow the well to continually kick. The beauty in this strategy is that pressures are not allowed to build-up thereby eliminating the need for a BOP. Gas is redirected away from the drilling table to the cuttings pit via a blooey line and a diverter head. A Diverter head has a rubber element that seals the annular area between the casing and the drill pipe. To prevent gas from migrating up the drill string, a series of check valves (floats) will be incorporated. If a shallow gas zone is encountered, then the formation is allowed to vent while drilling ahead until bad hole conditions or excessive amounts of water are produced. APD Cook 1 Pilot 2 =\f=I~GI~==N RESOURCES (ALASKA) CORP, ¡.\ $ob.ç¡t'liIllY 01 EVflf¡1r1Mn RO!1DtrfÇ(/S. Int. 4~112"dril, , ) L. Vü'~lüÇII.I\Ç"VUI\.Þü" r\lC;¡""Q Surface·WellControlSetup ) The amount Washington gas that can 500 psi f I t d Oiverter sa e y ven e Head drilling is considerable. illustrate, using Evergreen's This schematics proposed set foot kick of met ~ '... drilling and 1,00'0 psi whi consisting of pipe is not rotating. Washington stripping head sealing 4-1/2" drill pipe on 8-5/8" casing, 30 foot by 8" 10 blooey line, venting 20 million cubic feet of gas per day will generate 40 psia (25 psi gauge) of pressure below the diverter. [Reference: Equation 8-3, Air and Gas Drilling Manual, Lyons et ai, McGraw Hill Press, 2001]. This is a lot of gas - roughly 7 times that of our air injection rate. Since the Washington Head is rated to 500 psi dynamic (e.g., while the pipe is rotating) and 1,000 psi static, a 12 fold safety factor still exists when venting while drilling and a 24 fold safety factor while pipe is not rotating. 125 psi gate valve 30' x 8"10 Blooey Line VENTING 20 MMSCFDKICK of be in air Ground Level To up a Finally, if too much gas is being vented, especially during the running of casing and open hole logs, then Evergreen will kill the well by pumping gelled water down the hole. If necessary, a weighted mud system, as described in the previous mitigation measure, will be implemented. Here a cement pump, batch mixer and materials to make a 10.5+ ppg mud will be on location at all times. So far this year, Evergreen has drilled over 42 miles of hole using an under balanced fluid, diverter head and blooey line like the ones proposed here. There have been no well control incidents this year or in any year previous. Simply put, if the well vents too much gas, we get a water truck and pump water to kill the well. In this case, no cement pump is on stand-by on location. (3) Evergreen will utilize two different diverter heads - one for the 11 inch surface hole and one for the 7-7/8 inch production hole. The surface hole diverter is of Evergreen manufacture. The body consists of a 16 inch 75 ppf piece of casing 20 inches high. The bottom has a 13-3/8" pin connector that screws directly into the conductor. There is a 8-5/8" 00 opening (8.097" 10) that mates directly with the 8-5/8" blooey line. On the top is a 9 hole threaded flange where the Washington head is APD Cook 1 Pilot 2 Surface Hole Diverter Rubber Element .. 15"' --' ...Y-~-·--· g" ! ST2CK SiZES ~Ci I:'..~ 2 ·27'6 ":'C1CI-~ 3 ::2 .: :- i \:1 :: ~ ~ 2 . . L' I' ~', r ,_.:, '..' . =\I=I~GI~==I'I RESOURCES (ALASKA) CORP, .4 $11b.~r'rl¡my of E\ltlrpm¡1tT RfJMUrçllft, Int:, ) ') screwed in. This is the diverter seen in by the AOGCC in Colorado. Photos of the head and the rubber element are show to the right. Because of its similar design and materials, compared to the Washington heads, Evergreen has not pressure rated this head. However, from experience, we estimate that it can handle up to 250 psi dynamic and 500 psi static of pressure or 500/0 of the manufacturer's rating for the rubber element. As the calculation in the previous section answered, 250 psi provides several orders of magnitude of safety factors when drilling surface holes. This same head has been used over 1,000 hole sections in Colorado. The production hole will utilize a 1358 Washington Stripping head. This head has an 8-5/8", ST&C, 8 round pin on bottom that directly screws into the 8- 5/8" surface casing. There is an 8-5/8" 00 opening that connects directly with the 30 foot blooey line. For both the production hole and the surface hole, the same rubber stripping element is used. Pressure ratings for this head are 500 psi dynamic (i.e., while drilling) and 1,000 psi static (i.e., while the pipe is not moving). A picture of the Washington head is shown to the right. The only difference between this head and the one we plan to use is that the bottom here is ProductionHoleOiverter flanged whereas Evergreen's has an 8-5/8" pin. Waiver #4- 20 AAC 25.050 No directional surveying. (1) Well is meant to be vertical. The drilling assembly cannot deviate because of its mechanics. However approval of this waiver will probably be dependent on proximity to property lines. Do you have the ability to run a well bore survey log? (2) Can you expand on the reasons deviation of the wellbore will not be significant? (1) Evergreen's drilling rig is not equipped to run (Totco) surveys. well documented fact that air drilling using a hammer must, because of the physics of the system, drill vertical holes. Evergreen will however run Totco surveys via cased hole wireline in the first two wells to prove to the commission that this drilling method produces vertical holes. (2) Evergreen utilizes an Ingersoll Rand Quantum Leap down hole hammer located immediately above the bit. This mechanism is basically a jack hammer located down hole. Air passing through the hammer actuates a piston that that cycles roughly 700 times per minute. Effective stroke on the hammer is roughly 1/5ths of an inch. Pressure required to actuate the hammer action is 200 to 450 psi. In terms of energy transfer to the formation for drilling, the air Hammer is an extremely efficient way to drill. Penetration rates exceeding 200 feet per hour are typical. Shown to the right is a schematic of a down APD Cook 1 Pilot 2 This is because the 'I~·~ , \ "1,',rJ:,~,." ¡fIr ; 4,"'ï·' ",,", . . I,"" ~ ') ) =\I=I~GI~==I'I RESOURCES (ALASKA) CORP. A $1Iu,ot¡ir'lIIllY of EV,o)'I?rl!(111 R(I!'I(}U~~(W. /r1r:. hole hammer and bit. The primary reason that air hammer drilling produces straight holes is because of the low weight on bit required to drill efficiently. Ingersoll Rand recommends that for an 7-7/8" hole, the weight on bit be 3,900 Ibs or 500 psi per inch diameter of hole. More weight would inhibit the hammer's action causing the bit to simply drag across the formation instead of hammering into it. As a comparison, traditional bits require 3,000 to 6,000 pounds of weight per inch diameter of hole drilled. This means that for an 7-7/8" hole, one would need 24,000 Ibs to 48,000 Ibs on the bit to drill. The weight on bit has a profound effect on how vertical a hole is - less weight means straighter holes. Lubinkski and Woods in the 1950's provided the industry with the basic understanding of drilling vertical and inclined holes. Here they defined several forces on the bottom hole assemblies and drill pipes that cause the hole to deviate from vertical. In his paper entitled "Influences of Tension and Compression on Straightness and buckling", API, 1959, Volume 31, Lubinski presents equations, still used today, that conclude that the lower the weight on the bit, the more vertical the hole. Because air drilling requires very little weight on bit, buckling in the BHA and the drill string and torsional affects due to dragging the bit and the drill pipe - all of which create deviations from vertical - are eliminated. Waiver #5- 20 AAC 25.061 No seismic evaluation for shallow gas hazard. Can be justified by answers to questions under Waiver #2. Evergreen hopes that answers found in Waiver 2 and 3 provide sufficient information and surety to grant this waiver. We will further suggest that in shallow gas development, where unconventional reservoirs are the targets, that seismic is not an appropriate exploration technique. This is because unconventional formations - like coal, shales and tight sands - are ubiquitous and cover large areas. The axiom in this exploration realm is: Targets are easy to find but difficult to produce. Thus the preferred method to explore is through the drill bit and the completion rig. Completion and production techniques define the success and failure of these plays, not drilling. Seismic is not valid since we have a high degree of confidence that the formations are there. Oil and gas targets, are the conjugate - difficult to find but easy to produce. Because targets are more difficult to find, seismic is usually run. To have velocity surveys specified in AAC 25.061 make sense in this exploration regime. However, this regulation does not pertain to shallow gas development. Evergreen looks forward to working with the commission on the application of this regulation to shallow gas in particular. Waiver #6- 20AAC 25.066 Not have three methane and H2S detectors present. Meaningless because of rig configuration. No enclosed spaces. (1) Are there any areas where gas could accumulate? APD Cook 1 Pilot 2 ') ') =\f=I~GI~==I'1 RESOURCES (ALASKA) CORP. A SOollI11¡'my 01 E\ljllf~'(ItNl H(M!!fI~!m, Inri (2) Do you know of any circumstances in Tyonek section in Cook Inlet Basin where H2S naturally occurs? (1) There are no areas where gas can accumulate. Gas produced will be methane with a molecular weight of 16 versus (air is 29). This means that methane is lighter and will disperse in an upwardly direction. (2) There are no known instances where H2S naturally occurs in the Cook Inlet and particularly in the wells drilled in the Pioneer Unit. Furthermore, even if H2S was present in the coalification process (there is no evidence of this), it is impossible for the hydrogen sulfide to replace the methane adsorbed on the coal. Waiver #7- 20AAC 25.527- No API standards All relevant waivers already covered. Spacing Exceptions- 20AAC 25.055 Wells may be within 1500' of property lines. Wells are 1100' apart. Cannot waive any regulation that affects other person's rights. Figures 18, 20, & 21 indicate the need for spacing exceptions because the wells appear to be within 1500' of a property line. Are any of the wells within 1500' ofa property/lease line? Are the colored areas on Figures 18, 20, & 21 the only Evergreen leases? I.e.: Are the white areas on Figures 18,20, & 21 leased by Evergreen? Do you have a reallandmap? Who are the lessors? Maps shown in the Plan of Operations are surface landowner maps. Shown below are land maps showing mineral ownership for Pilots 1, 2 and 3. Also shown on these maps are the proposed well sites which have already been surveyed. Also included in these maps are 1,500 foot radius circles around each well showing which mineral interest owners are within this area. It should be mentioned here, that the well names presented in the Plan of Operations and in this document will be changed when drilling permits are submitted. Pilot 1 is situated on the Smith (Fee Lease). Here the Smiths own the surface and the minerals. As the figure illustrates all wells are all within 1,500 feet of the mineral property line. Here, the State of Alaska owns the minerals and Evergreen has those minerals leased. Pilots 2 and 3 are located on State of Alaska Minerals. These minerals are all leased by Evergreen. Like Pilot 1, all wells are within 1,500 feet of the mineral property line. Adjacent to this acreage are federal acreage blocks that are prohibited from leasing. Evergreen has met with the Bureau of Land Management and described our plans to drill. Since this is an exploration project where no gas will be sold (only vented), they are not opposed to our program. If economic quantities of gas are required, then a Compensatory Royalty agreement will be signed between Evergreen and the BLM. Close to but not within the 1,500 foot radius, are the Mental Health Trust Lands to the East of Pilot 3 and the University of Alaska Lands to the west. Evergreen Alaska leases APD Cook 1 Pilot 2 =\I=I~GI~==N RESOURCES (ALASKA) CORP, A $l1b,~ldiIllY 01 EVflf(1m1ll1 R(I!J(Jurcmi, If!~ ') ') the Mental Health Trust Lands and is in the process of finalizing the University lands to the west. All wells are 940 to 1,100 feet apart and are designed in a way to test the Tyonek Coal Seams. In a production mode, wells will be spaced much farther apart. The table on the next page summarizes the well placement information. This data is from the surveys done. Federal 1.500 R radius (µnlea~eabl(¡!.' State of Alaska (Evergreen) State of Alaska (Evergreen) 2 1,600 n. r ðC1lua State of Alaska (Evergreen) ._w_,__~._ ,_~.__".__._,______,_,._~.~,__~____~___,,__~,_.,_____,_",.,~.,.,,_,,__,.____._,___,~,_...___._"".,____.______. ,--,.'.,-_.- ..--.,.,..--.------- Pilot 1 Land Map .ii ....,..,\ /~"....,. '_~J~' ¡·'Mental ;,Healt~1NSt ¡·.··(êv~~~nli ---.........-"..--..-..--...-----..----.,- Permit Name Evergreen Well Placement for Pilots 1, 2 and 3 Pilot 1 Well 1 Pilot 1 Well 2 Pilot 1 Well 3 Pilot 1 Well 4 Pilot 2 Well 1 Pilot 2 Well 2 Pilot 2 Well 3 Pilot 2 Well 4 Pilot 3 Well 1 Pilot 3 Well 2 Pilot 3 Well 3 Pilot 3 Well 4 APD Cook 1 Pilot 2 Well Name DL Smith Gary & Jo Ann Stromberg Robert Smith Corn husker Cook Lowell Bering Baronoff Tyonek Kenai lIiamna Nanwalek S-T-R See 2 T17N R3W See 2 T17N R3W See 2 T17N R3W See 2 T17N R3W See 30 T18N R1W See 30 T18N R1W See 30 T18N R1W See 30 T18N R1W See 20 T18N R1W See 29 T18N R1W See 29 T18N R1W See 20 T18N R1W Footage (from section) 1255 FNL & 933 FWL 2426 FSL & 141 FEL 3272 FSL & 606 FEL 652 FNL & 293 FEL 967 FSL & 1329 FEL 504 FSL & 422 FEL 1523 FSL & 471 FEL 991 FSL & 888 FEL 815 FSL & 1832 FWL 236 FNL & 2403 FWL 212 FNL& 1205 FWL 301 FSL & 1841 FWL .- .... "'" H~:, ,\ f.der,,1 IOn""""",.) --------~----------- ------------ IS Slato of Alaska (Evorgroont Fe..al (Un"'......I.) Slat. 01 AI_ka (Evergreen) -----.-- ------, - Slale 01 AI_ka (Evergreen) 1.Ift1w..*kY, ,of.ÄI" F.dera, ....n"~i~~~i1) (~n..a.......) Slale of Alaska 30 (Evergreen) Sial. 01 Ala.ka (Ev.rgre.n) 51.1. 01 Ala.ka (Ev.rgra.n) F_" (Unllas....I.) 01 Ala.k. rgr..n) Sial. of AI.ska (Ev.rgreen) Flder.' (Unlla.."'I., Pilots 2 (South) and 3 (North ) Land Map APD Cook 1 Pilot 2 ) ') =\I=I~GI~==N RESOURCES (ALASKA) CORP, A SIIl!.~ldin/"y (II Eytlrr¡rmm RO!ì{l(/f\;m" I"r. Appendix B Proposed Drilling Procedure APD Cook 1 Pilot 2 =\I=I~GI~==N RESOURCES (ALASKA) CORP. A Sl/b,~I('/iflry 0' E\lpmrll11l1 A(lMilrc~.s, Inr. ') ') Proposed Drilling Procedure Evergreen Alaska Corporation Well Location Elevation Field Target Proposed TD Cook 1 (Pilot 2) SW /SE of See 30 Twp 18 North Rng 1 West Seward Meridian 991' FSL & 888' FEL OF SEC Matanuska-Susitna Borough, Alaska USA Kelly: 412 Ground: 409 ft (3 ft AGL) Pioneer Unit Tertiary Tyonek 2990 Objective Air drill, log and set casing for the subject coal bed methane exploration well. Casing Program Hole Casing Casing Casing Size Size Weight Casing Casing Depth Cement (in) (in) (Ibs/ft) Grade Connection (ft) Interval Conductor 13.875 12.75 49 H20 Pipe Welded 125 to surface Surface 11.00 8.625 24.0 J-55 ST&C 8 Round 300 to surface Production 7.875 5.50 17.0 J-55 ST&C 8 Round 2990 to surface Open Hole Logging Program Log Interval Spontaneous Potential TO to ± 20 ft in Surface Casing Single Induction TO to ± 20 ft in Surface Casing Gamma Ray TO to ± 20 ft in Surface Casing Caliper TO to ± 20 ft in Surface Casing Compensated Density TO to ± 20 ft in Surface Casing The first well drilled in each pilot will have an induction log run on the surface hole to confirm that we have drilled beyond the fresh water zone. A Totco survey will be run in the cased hole to confirm that hammer air drilled holes must be vertical. Coring Program Roughly 100 feet of core will be cut on this well. Mud logging Program Mud log the subject well from surface to TO. Samples every 10 feet. Formation Tops Formation Quarternary Gravel Tertiary Tyonek Estimated Tops (ft KB) Surface 100 General Information All information not publicly available is considered Tight Hole and confidential. Spill Prevention Plan and Bear Mitigation measures must be adhered to at all times. APD Cook 1 Pilot 2 =\f=I~GI~==I'1 RESOURCES (ALASKA) CORP, A :~f//J~II'ill/v (Jf EV~"7r(lm1 Rl1.<!(lI!'\~mi, J(l1": ) ) Proposed Drilling Procedure Cook 1 (Pilot 2) Section 30 Twp 18 North Rng 1 West Seward Meridian Matanuska..Susitna Borough, Alaska CONDUCTOR PIPE 1. MIRU Water Well Contractor. 2. Casing drill using air and air hammer bit to +/.. 225 feet or at least 25 feet into the Tyonek formation. Casing is 12..3/4 inch 00 and 12 inch 10 casing. Evergreen personnel will be on location to determine when depth is sufficient. Set casing 8 inches below ground level. Water contractor responsible for sourcing casing. Note: Casing must be straight (not bent) Casing must be vertical 3. POOH with casing drill & LD. 4. Install bell nipple consisting of a 13..3/8" (8 Round, Short Thread and Coupling - standard connection in oil industry) collar on 12.75 00 pipe. Weld nipple on both the inside and outside of casing. Water contractor will be responsible for sourcing bell nipple and welder. 5. Install cementing head (13-3/8"x2" swedge with two 2" valves, 2" nipple and 2" plug. Assembly from bottom up are: Swedge, valve, nipple and valve. 6. Cement (grout) program is as follows: a. Pump 110% of casing volume b. Pump annulus volume of cement plus 500/0 excess c. Displace with one casing volume less 2 barrels (100 gal) of water. This will leave 14.2 feet of cement in casing. d. Close both valves at surface, disconnect grouting unit. Ensure surface assembly hold pressure. If leaving well before If cement does not circulate, then place 10 bbls of cement down annulus from the surface or until the surface annular volume is full of cement. Cement Type I Portland Weight 15.6 ppg Yield 1.18 ft3/sk Water Additives 5.2 gal/sk 1 % CaCI 7. Place plug on top valve to secure if valve becomes accidentally opened. 8. Wait on Cement at least 8 hours. 9. Open valves at surface. If cement has not set (water will rush out of 2" valve), then close valve and contact Evergreen immediately. 10. Connect Cement (grouting) head to water pump. Pressure test casing to 200 psi for 10 minutes. If pressure holds 200 psi for 10 minutes, then proceed to the next step. If not then Evergreen Personnel will advise on next step. 11. RIH with 11" bit (tricone or otherwise) on drill rods. Drill out cement in conductor casing and drill ahead an additional 5 feet. Note any gravel that circulates to surface. 12. Circulate hole with air for 15 minutes. Note any evidence that the gravel is sloughing in during drilling or circulating. If sloughing occurs, then notify Evergreen immediately. 13. POOH and LD rods and bit. 14. RDMO Water Well Contractor proceed to next hole. APD Cook 1 Pilot 2 =\f=I~GI~==I'1 RESOURces (ALASKA) CORP. A S(b.~lnf!llY ()/ EVI'!'I7m(m A(lMHrons. Inr: ) ') Proposed Drilling Procedure Cook 1 (Pilot 2) Section 30 Twp 18 North Rng 1 West Seward Meridian Matanuska-Susitna Borough, Alaska SURFACE AND PRODUCTION HOLE 1. MIRU Evergreen Rig Number 1. Rig Layout is shown in Figure 1. Crane will be on location to unload Evergreen Portable cementer and Portable batch mixer. A 28 foot trailer with mud additives to kill well will be adjacent to the cement unit. Have kill likes from cement pump to rig's stand pipe ready for kill operation. 2. NU Oiverter head (13-3/8" pin on bottom x 4-1/2" OP) and 30 feet 8-5/8",24 ppf blooey line with 125 psi gate valve. 3. RIH with 11" bit on hammer, stablizer on 4-1/2", 17 ppf drill pipe. Air hammer drill surface hole to 350 feet. 4. Condition Hole. 5. POOH & LO drill pipe, stablizer, hammer and bit on trailer. Move pipe trailer 30 feet forward. 6. RIH with 8-5/8", 24 ppf, J-55, ST&C, 8 round, Range II casing (no casing greater than 31.5 feet), with centralizers on 1 st, 3rd and 5th joint. Run open-ended. Set casing at ground level. 7. I nstall cement head. 8. RU Cementers. Circulate cement to surface. 9. Shut-valve at surface. Wait on cement 6 hours. 10. Open valve on cementing head. Ensure that the cement has set. RI H with 7- 7/8" drill bit, hammer, stabilizer on 4-1/2" drill pipe. Tag cement. Ensure that there is 10 feet of cement inside casing. If not, then do not drill out, and contact Evergreen for further instructions. 11.lnstall Washington Oiverter Head (8..5/8", 8 rd pin, ST&C) and 30 ft blooey line (used to drill out surface casing). 12. Drill a head to core point and core. Continue drilling to 2,990 ft KB. Well will be TO'd above this level if significant hole problems occur. 13. Condition hole with air. Monitor gas flow from well for 5 minutes. If gas is venting from hole at rates too high to safely run casing, then kill well with water. If water is not sufficient, then, weight up with 10 ppg fluid consisting of xanthan gel (125 CaCI sx/100 bbl, 2 sx xanthan gel/100 bbl). 14. POOH & LO bit, hammer, stabilizer, drill pipe. 15. MIRU Patterson Wireline. Run open hole log suite consisting of gamma, compensated neutron, caliper, induction & spontaneous potential. Confirm setting depth of casing. 16. Install Casing Running Oiverter on 30 foot blooey line. 17. RIH with 5..1/2" guide shoe, shoe joint, insert and remaining 5..1/2" 17 ppf, ST&C, J-55, 8 round, Range II casing (31.5 max length), with 5 bow centralizers on 1st, 3rd, 10th, 15th and 20th joint. Install 500 psi casing head & run 5-1/2" casing with with 6" of stick-up. 18. Cement production casing from bottom to surface. 19. Clean-up well site. 20. ROMO Cement Unit and proceed to next well 21. ROMO Evergreen Rig #1 and proceed to next well. APD Cook 1 Pilot 2 =\f=I~GI~==I'1 RESOURCES (AI.ASKA) CORP. ASI/f¡,~lt1¡IIIY(ì' r,:VI'I'l7rm¡¡tHflß{I(/fI:'(rtl, ¡fir¡ Conductor 12-3/4 inch Welded conn. Surface Casing 8-518 inch 24 ppf, J-55 ST&C, 8 Rd Range II Production Casing 5-1/2 inch 17 ppf, J-55 ST&C, 8 Rd Range II APD Cook 1 Pilot 2 ) ) PROPOSED Drilling Procedure Cook 1 (Pilot 2) Section 30 Twp 18 North Rng 1 West Seward Meridian Matanuska-Susitna Borough, Alaska Set at 125 feet KB Cemented with sx Set at +/-425 feet Cement circulated to surface with xxx sx cement Set at 2,990 ft KB Cement circulated to surface with xxx sx cement =\I=I~GI~==N RESOURCES (ALASKA) CORP, ;.\ Sllb.~I(/iIIIV nr F\I....~1rmm Rf'~mrn;!r,~, I(lf: ) ) PROPOSED Telephone Contact List Cook 1 (Pilot 2) Section 30 Twp 18 North Rng 1 West Seward Meridian Matanuska-Susitna Borough, Alaska Company Name Location Telephone Columbine Mudlogging Spencer Flournoy Henderson, CO Office: 303-289-7764 Fax: 303-289-7764 Trinidad (Trails Inn Motel) Front Desk: 719-846-4425 Patterson Wireline Pat Patterson Weston, Colorado Office: 719-868-2119/3311 Evergreen Resources Alaska John Tanigawa Wasilla, AK Office:907 -357 -8130 P.O. Box 871845 AK Proj Manager Fax: 907-357-8340 Wasilla, AK 99687 Cell :907 -841-0000 Evergreen Resources Inc. Tom Hemler Denver, Colorado Office: 303-298-8100 Suite 1200 Drilling Manager Fax: 303-298-7800 1401 Seventeenth Street Cell:719-680-1378 Denver, Colorado 80202 P.O. Box 660 Jerry Jacobs Denver, Colorado 80201-0660 Enviro Manager Pense Brothers Drilling Larry Pense Glenpool, OK Office:918-322-3095 Mobil 918-625-1668 Fax: 918-322-3829 APD Cook 1 Pilot 2 ;:t:: Ll) ,....., ~ Q (/) ø z t= ::J U I- U UJ Q::: o "-' ¿ Q::: UJ co ~ EVERGREEN RESOURCES ALASKA CORP DRilliNG SITE LAY OUT 500 Bbl Frae Tank Q. (]) (]) "'0 ;t:: ;t:1.() a.. (f) "'0 1J a>c(]) .ç 0 c ~;t:::.::J ::J ~ ug x ;t:: o o ill x ~ ..c. () Õ co 0J I ill ~ ..c. () Õ ~ Blooey Line 30 ft (8 in) Mudlogger Trailer "D Q) "Eo> ::J .- oc:::: 2'ê .:::¿Q () ::J ~ o WfU Light Plant D ill ë Q) E (]) u II LJ Light Plant Cement Additives Q) C J 52 Mud Supply Trailer Two Compressors Air Booster & Fuel Trailer Doghouse & Parts Trailer Pipe Trailer 20' Trailer I Flatbed I I Truck Core Desorb Trailer DC] Toilet Trash 200 ft ~~ 0~ ~~ ~~ (J) (J) () en C o 0 (J)~ .....JC tLU 0"0 cryg C::: =\I=I~GI~==I'I RFSOURCES (AlASKA' CORP Wellhead Location ;t:: a a 80 ft 0 1 20 ft ;t: 10 ........ ..~ Light Plant n L-J Items Description Mud Supply Trailer - 28 ft enclosed Batch Mixer - Two 75 bbl tanks 500 BBl Frac Tank - Fresh Water Cementer - on 20'x8'x8.5i skid Cement Additives - 20'x8'x8.5' conex light Plants - Two to Three on site I Compressor - Two Ingersoll Rand XHP 900 scfmI350 psi Booster - Hurricane 3,000 sdm at 1,000 psig Fuel Tank - 1,500 gallon di~ tank w/auto shut-off Doghouse Toolshed - 40 ft oontainer wIgen-set Pipe Trailer - has 3,300 ft of 30 ft rods 20' Trailer - holds spider, casing running equipment, BHAs Core Desorbtion Trailer - 18-24 ft trailer on site when coring Mudlogging Trailer -18 ft trailer wI gas chromat & computer Drill Rig -1999lngersoll Rand RD-20 Truck Mounted Drill Rig Blooey Une - 30 ft length & 8-518", 24 ppf casing Cuttings Pit - 100ft by 30 ft by 6 ft deep lined Berm - use material from cuttings pit to stop b100eY line pits Parking Area - At rear of Location Kill lines - from cementer tQ drtll rig, always rigged up Toilet - Portable Toilet on Trailer Trash - Commercial or Fabticated Bin -~' Sample Photo =V=I~GI~==i'I RESOURCES (ALASKA) CORP :.. :::.~s,--,r, :1 E,-;'-;j~""-; P~~:·fc·"" '-.~ Well Control Diagrams Cook 1 EVERGREEN RESOURCES AlASKA SURFACE CASING DIVERTER EVERGREEN RESOURCES AlASKA PRODUCTION CASING DIVERTER 15 in ---~---------- ---------~---------- 16 in CONNECTOR ¡sa 1 3-3/8" PIN ST&C. 8 RD. J-55 , 0' ~-~~CIÞ..i··- ¡ Y: .::.........:> :::;7.'::::. ., . - - ~... ',2 .. APD Cook 1 Pilot 2 ------------ -- 15 in WASHINGTON OIVERTER RUBBER ELEMENT MODEL 401 O-C (See Below) --~---- WASHINGTON DlVERTER RUBBER ELEMENT MODEL 401O-C (See Below) ---------- Pressure Rating: 1 ,000 psi Static, 500 psi Dynamic "___I 16 in '----- To 30 FT BLOOEY LINE 8-5/8",23 PPE J-55 CASING 8.09r 10 with Hammer Union connectc To 30 FT BLOOEY LINE 8-5/8", 23 PPE J-55 CASING 8.097" 10 with Hammer Union connector CONNECTOR 8-5/8" PIN ST&C. 8 RD. J-55 ,5~--~ ....71;2--.. =\I=I~GI~==I'I RESOURCES (AlASKA) CORP. .. 5..:'$'- ,-, ~! E;£-·~·,:, " ·J,.,,;·__,o:.. "-.;: Tubular and Cement Information Cook 1 (Pilot 2) Section 30 Twp 18 North Rng 1 West Seward Meridian Matanuska-Susitna Borough, Alaska Drill Pipe 11" Hole 11" Hole 8" Hole 8" Holle Size Pipe Weight ID Drift Collapse Burst Tinsile Capacity Capacity Capacity Capacity Annulus Annulus Annulus Annulus (in) Grade (ppf) (in) (in) (psi) (psi) (Kpsi) (bbl/ft) (ftlbbl) (gal/ft) (ftlgal) (bbl/ft) (ftlbbl) (bbl/ft) (ftlbbl) 4-1/2 0 16.6 3.826 2.812 7,620 7,210 242 0.01422 70.32 0.5972 1.6744 0.0979 10.2175 0.0425 23.5295 I'~ Surface Casing 11" Hole 11" Hole 11" Hole 11" Holle Size Pipe Weight ID Drift Collapse Burst Tinsile Capacity Capacity Capacity Capacity Annulus Annulus Annulus Annulus (in) Grade (ppf) (in) (in) (psi) (psi) (Kpsi) (bbllft) (ftlbbl) (gal/ft) (ftlgal) (bbl/ft) (ftlbbl) (gal/ft) (ftlgal) 8-5/8 K-55 24.0 8.097 7.9272 1370 2950 263 0.0636 15.70 2.6749 0.3738 0.0453 22.0860 1.9017 0.5259 Production Casing 8" Hole 8" Hole 8-5/8 Surf 8-5/8 Surf Size Pipe Weight ID Drift Collapse Burst Tinsile Capacity Capacity Capacity Capacity Annulus Annulus Annulus Annulus (in) Grade (ppf) (in) (in) (psi) (psi) (Kpsi) (bbllft) (ftlbbl) (gal/ft) (ftlgal) (bbl/ft) (ftlbbl) (bbl/ft) (bbllft) 5-112 J-55 15.5 4.950 4.825 4040 4810 202 0.0238 42.01 0.9997 1.0003 0.0328 30.5012 0.0343 27.94 51/2 J-55 17.0 4.892 4.767 4910 5320 229 0.0232 43.01 0.9764 1.0242 0.0328 30.5012 0.0343 27.94 '--- Cement Information Density Yield Yield Water 11" Hole 8" Hole Name (Ib/gal) (ft3/sk) (bbl/sk) (gal/sk) Additives Capacity Capacity Surface Set 15.6 1.21 0.2155 5.3 Versaset ~%, 5% Salt, % Ib/sk Flocele 0.1175 bbllft 0.622 bbllft Pioneer LS 12.2 1.94 0.3455 9.4 2% gel, 2% CaCl, 1 % Thixset A %% Thixset B, ~ #/sk Flocele 8.5076 fUbbl 16.0846 fUbbl APD Cook 1 Pilot 2 NOI1~()~JX3 "["a 6909-9¿£:GI 10"d tOO"ON oG:St Go,ot d3S ..~ . , SEP 1 0 ZOOl A\a&kaOi\ ¡ Ga& Con$. CommiSSion And\OJIge RECE'VED ,- t ",.",'" ÂMJA- 'SIlV~ CA-tA.rA:'') ~Af ';?;,vð t1L~¿y ::l' 4vT>fIJn.I'e# pU(Æ::r ¡;G~dW'~~ æ&Jwlc:.",. f!ðJ4'- CdA/Sd L 17 AAf ~ ¿,.",. .f"/et!..A ?» ;Þ'"Jpd /dS'Mrr/,.;v" tfF ~ r;",Il(}Vt'1j ,¡.f'þ (.t. ;tA/.òG It þ.Jþ.. o,4'rt/4?Þ( ð~*,LØ41'5 r 1J.M¡Vþf. 0/ IJV /Î1L % &.It. $;- ~ Awa ~ ~tlZJ~Tl4rA" t J: Al'PlJ.t~/A-~ I(~~ ~¡ø. ") Z AM ð-vr- /N ?Wp 1!:;ff?G}J. 1hè:-,uosr (k"'fF()t'~Î' ¿..JAy ?Þ 6,u;:.. ftft ~(!~ ~n.(i!J;.rtn~ ~J v~~ ,II- ~. ÂtNz;1l.I!è--A-?"Ioý?b ~ ¡U~,+ ,u/~ 8ê"(.ow'e~ ~ '1ñ'e- ~~_,._#) !,.t., <f ~ðl2.cl()~ ~1'Et-é : RÆ: PA7G : , -.' ~.~ ~II^/ ~¿~ A'tVA .. r- - f14-x ~ c-.:: _ ~ð?~ 2. ,),,~ ">pt 1- ~¿.6- è..v¿~ .~ ) (' .')' ) f: " II' :. . . 1 :.. I , ,. ". r" .~" I""·" '.' 'I ~ 0',.. . , . II. . ' r 7)~ "'--' . ) ) CHECKLIST - SPACING EXCEPTION APPLICATION OPERATOR Evergreen Resources PROPERTYID/LEASE ADL 384685 FIELD/POOL Pioneer, Tyonek Undefined WELL NAME Cook #1 VERTICAL X EXPLORATORY X GAS X DEVIATED DELINEATION OIL DEVELOPMENT SURFACE LOCATION PRODUCTIVE INTERVALS (Top and Bottom) BOTTOM HOLE 991' FSL and 888' FEL, S. 30, T18N, R1W, S.M. Same Same Same Check applicable reason(s) for spacing exception: (1) to drill a well for oil within 500 feet of a property line X (2) to drill a well for gas within 1500 feet of a property line (3) to drill and complete more than one oil well in a governmental quarter section; or to drill and complete an oil well closer than 1000' to any well drilling to or capable of producing from the same pool X (4) to drill and complete more than one gas well in a governmental section; or X or to drill and complete a gas well closer than 3000' to any well drilling to or capable of producing from the same pool Does the application contain: YES A brief explanation for why the operator has chosen to drill the specified location. A plat drawn to a scale of one inch equaling 2,640 feet or larger, showing the location of the well or portion of the well for which the exception is sought, all other YES completed and drilling wells on the property, and all adjoining properties and wells within 1,000 feet of a well or portion of the well requiring the spacing exception that is drilling for oil or within 3,000 feet of a well or portion of the well requiring the spacing exception that is drilling for gas. The names of all owners, landowners, and operators of all properties within 1,000 YES feet of a well or portion of the well requiring the spacing exception that is drilling for oil or within 3,000 feet of a well or portion of the well requiring the spacing exception that is drilling for gas. A copy of the notice sent by certified mail to the owners, landowners and operators YES described above, the date of mailing, and the addresses to which the notice was sent. YES An affidavit by a person acquainted with the facts verifying that all facts are true and that the plat correctly portrays pertinent and required data. NA If the operator requests a variance from the notice requirements of 20AAC25.055(d), sufficient information to demonstrate that it is not feasible to comply with the notice requirements because of the complexity of ownership within the notice area. =\'=I~GI~==I'I RESOURCES (ALASKA) CORP. A Subsidiary of Evergreen Resources, Inc, ') ) August 262002 Ms. Cammy Oechsli- Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill: Cook Number 1 SW/SE of Sec 30 Twp 18 North Rng 1 West Pioneer Unit, Matanuska-Susitna Borough Target: Tertiary Tyonek, Proposed TD: 2990 Feet Proposed Spud Date: 8-0ct-2002 Dear Ms. Oechsli -Taylor, Evergreen Resources Alaska Corporation hereby applies for a Permit to Drill for the subject well located approximately 30 miles north of Anchorage. The well is planned as a shallow, straight hole drilled to evaluate the producibility of the Tyonek Coals. A local water well drilling contractor will casing drill a 12-3/4" conductor past the base of the unconsolidated gravels and cement the conductor in place. Evergreen's Ingersoll Rand RD-20 air-drilling rig, which recently arrived in Alaska, will then drill the 11" surface hole to a depth that protects the fresh water aquifer. A string of 8-5/8" surface casing will be run and cemented to the surface. A 7-7/8" hole will then be drilled to TD and a string of 5-1/2" casing will be run and cemented to surface. The subject well will have roughly 100 feet of core cut. Attached is information required by 20 AAC 25.005 (a) and (c) for your review. Due to the differences in equipment and methods used for air-drilling coal bed methane (CBM), we require several variances from current AOGCC regulations. These variances are recapitulated in this APD. Three items are of note. First, Evergreen has already contacted adjacent mineral interest owners. All parties, whether they be the State of Alaska or the Bureau of Land Management, know that some well locations are within 1,500 feet of our adjoining property lines. All affected parties are support of our exploration efforts. Secondly, to better determine the depth that surface casing should be run, an induction log will be run to determine the appropriate depth of the surface casing for the pilot. Finally, we will run a directional survey in the first one or two wells in the cased hole to prove that down hole hammer drilling must drill straight holes. The designated contact for reporting responsibilities to the Commission is John Tanigawa, Alaska Projects Manager, 907-841-0000 as outlined in 20 AAC 25.070 and 20 AAC 25.071. Evergreen appreciates you and your staff's assistance during this, our first drilling campaign in Alaska. We look fOlWard to working with you in the future. Sincerely, R S (ALASKA) CORPORATION enclosures PO. Box 871845 · Wasil/a, AK 99687 · TEL 907.357,8130 · FAX 907.357.8340 AO.FRM Publisher/Original Copies: Department Fiscal, Department, Receiving 02-902 (Rev. 3/94) DIVISION APPROVAL: R:QUISITIONED ax: \ (:¡ (A\ ,f . ~ I \U U {vv.----- /'¡ \_- : ; J 2 3 2 ARD 02910 3 4 FIN AMOUNT sy CC PGM LC ACCT FY. NMR DIST llO 03 02140100 73540 PAGE 1 OF TOTAL OF 2 PAGES ALL PAGES$ COMMENTS :i.~~:~~g:t~B~9~"·~~J~~J~~~~~1~:r AOGCC, 333 W. 7th Ave., Suite 100 ";Q!..""L,~>""~"..""~,.,,,,,,,,,,,,,,,.,,,,,,,,:t(¡l,,,.,,,.i{¡,.1.,~1j.1<"',',.",~..""..,.,,,,,,",; Anchorage, AK 99501 REF TYPE NUMBER AMOUNT DATE VEN SEE ATTACHED PUBLIC HEARING Account #STOF0330 Advertisement to be published was e-mailed D Classified DOther (Specify) \ o Display Type of Advertisement X Legal THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: (907) 793 -1 ??1 . DATES ADVERTISEMENT REQUIRED: August 17,2002 ~ Anchorage Daily News POBox 149001 Anchorage, AK 99514 DATE OF A.O. AGENCY CONTACT lody Colombie PHONE STATE OF ALASKA ADVERTISING ORDER :~::L:i:":~';~:~.J~~~~r:·F.ø~,\~~¥~~~~:.~p.;~~F:~"¡'~;.;~:~:.. F' ,~AOGCC'" " R 333 W 7th Ave, Ste 100 o Anchorage, AK 99501 M August 16, 2002 PCN AO-02314010 INVOIC~ST BE I~~~~,'; !2,~'!n~~~I~~ER NO~R'nD . AFFIDAVIT OF PUBLICATION (PART2 OF THIS FORM) WITH ATTACHED COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE ADVERTISING ORDER NO. 202v/~Ó J J Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Evergreen Resources (Alaska) Corp. Pioneer Unit, Matanuska, Susitna Borough Evergreen Resources (Alaska) Corp. by letter dated August 15, 2002, has requested an exemption from the gas detection equipment' requirements of 20 AAC 25.066. The Commission has tentatively set a public hearing on this application for September 19, 2002 at 1 :30 pm at the Alaska Oil and Gas Conservation Commission at 333West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm on September 3,2002. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221. In addition, a person may submit written comments regarding this application to the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. Written comments must be received no later than 4:30 pm on September 17, 2002 except that if the Commission decides to hold a public hearing, written comments must be received no later than 9:00 am on September 19,2002. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact lody Colombie at 793-1221 before September 5,2002. ~~. ~t/ Cammy Oechsli Taylor Chair Published Date: August 17,2002 ADN AO# 02314010 J Anchorage Daily· News Affidavit of Publication J 1001 Northway Drive, Anchorage, AK 99508 PRICE OTHER OTHER OTHER OTHER OTHER GRAND AD# DATE PO ACCOUNT PER DAY CHARGES CHARGES #2 CHARGES #3 CHARGES #4 CHARGES#S TOTAL 532873 08/17/2002 02314010 STOF0330 $128.78 $128.78 $0.00 $0.00 $0.00 $0.00 $0.00 $128.78 STATE OF ALASKA THIRD JUDICIAL DISTRICT I;; ,~,.- ,'(' ". . , 'I Lorene Solivan, being first duly sworn on oath deposes and says that . she is an advertising representative of the Anchorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all said time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on the above dates and that such newspaper was regularly distributed to its subscribers during all of said period. That the full amount of the fee charged for the foregoing ublication is not in excess of the rate charged private individ ~if '., . ." ;iN:~~:l:~~b,~rJ:!:~~~,:V. .', .', " ,'. .AI~~kaO.il and .~~s~Ori~e~,;ati~n~oniml,sslon .. ,Re:',Evergreen, R~sources (AlaskQJ:'Corp.~, ,Pionee,rUn It "MatariU~~(I,iS~slrlÌa :Bo'rou91),"··, Evêr:~re~n Resou'¡'c~S(ÄlaSk~):.è()r,p. .bVJetter ,dated' Aug·ust:1S, 2002,has·requested,ön ex~mptio:n 'from the. ~as'detectiòtJ eciUlpro,ent réquireÏ'n~nts of 20ÄAC~5,.~66.! '::~,;.';':',,_~:' :'-':"":, The Com'mlssIQn:'has.tentotlvely'set a' pÜbllc he.ar- ing on this applkàtionfó'rSeptembe,r 19,,20020t 1 :30 pm at the': Alaska 011 and GasConser,vatlon CommlssiòlÌ,t:it 333West'7th~~y~nue, Sult~'100; An- chdrage,. Alask09950,l;A:pÊlt~on may request that thetentativelyschedoled hearing be held by filing a written request ,with 'the ''Commission' no 'Iater ,:th(n':1:30')ITI:~n,s~~t~q1~~r¡,3, ~~~~;> " Úa'.requ~st'.forah~ci'ring, is 'not,t'l melvti led, the Comfr¡fssionWIÜ'conslderthe issùance of.anprder ' 'without a hearing. Tolea,rn If the CommissionwlU , hO.ldthe~ubl:i~ ,~~~r,in~ì PI~ase'c~ll. 793-1~21.':" ",::':' In, add ition;-å,pér~on:l1'IaYSUbmit:wrltt~i1:(;()rrl:~: merits regarding this, appliCation to theAlé:I'sko'Oir and Gas Conservation Commission at 333 West 7th 'Avenue, Suite 100, Anchorage, Alaska 99501. Writ- 'ten comments must be 'received no later than 4:30 pm on September 17, 2002 'except that If the Com- .mission decides to hold a public hearing,written -:comments must be rece~ved no later than 9:00'am 'on September 19, 2002. Subscribed and ~; J;e this date: :, ,", """ ",' IfyoÙ are a person with 0 disability who mQYheed a speciallTlodificatioo in order tocomment.o(,to 'atte'nd the ,pu'bllc :bearing, ple(lse contactJ,odY 90, lo~~ie at. 793~ 1221 before September 5;2002; èammy Oechsll Taylor Chair Publish: August 17, 2002 .", AO# 02314010 Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska :/, L MY CO~EXPIRES: ~ {5<.5f/é J r¡:~_Z<?Af£ " ~ \\\trft1 'f,r. , ,,\~~~\:\[!:~..¡~ ~q;;:~OTAR'::~S ~ . ~ --- . ';:. '- . . .... - . Þum.;\C . - -~. .~~ - ". CI!:.. __~: ~ _.~ . ~ ~~~~, ··~Of ...~,~ ~;.s .. ... ~ :\' ///.IJ})~))\'" AO.FRM PUBLISHER 02-901 {Rev. 3/94) Page 2 Notary public for state of My commission expires 2002, This _ day of Subscribed and sworn to before me individuals. the rate charged thereon is not in excess of the rate charged private . 2002, and that publication appearing on the _ day of 2002, and thereafter for _ consecutive days, the last day of is a true copy, was published in said publication on the and that the advertisement, of which the annexed state of and in said division Published at of he/she is the who, being first duly sworn, according to law, says that INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COpy OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE. Before me, the undersigned, a notary public this day personally appeared division. ss State of AFFIDAVIT OF PUBLICATION REMINDER United states of America Account #STOF0330 SPECIAL INSTRUCTIONS: THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. Jody Colombie AQPJlSt 16, ?,OO?, PHONE pcNr (907) 793 -1 ?,?, 1 DATES ADVERTISEMENT REQUIRED: August 17, 2002 ~ ' Anchorage Daily News POBox 149001 Anchorage,AJ( 99514 AGENCY CONTACT DATE OF A.O. AOGCC R 333 West 7th Avenue, Suite 100 o Anchorage,AJ( 99501 M F l NOTICE TO PUBLISHER 1. ADVERTISING ORDER NO. INVOI~ST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NøRTIFIED' AO 02 31401 0 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COpy OF - ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE STATE OF ALASKA ADVERTISING ORDER :,,:..:,:~E~::~Brr~~~I~'~~~~~F·:~~~f~~'~,~t~ John Katz State of Alaska Alaska Governor's Office 444 North Capitol St., NW, Ste 336 Washington, DC 20001 Alfred James 107 North Market Street, Ste 1000 Wichita, KS 67202-1822 Conoco Inc. PO Box 1267 Ponca City, OK 74602-1267 Gregg Nady Shell E&P Company Onshore Exploration & Development PO Box 576 Houston, TX 77001-0576 G. Scott Pfoff Aurora Gas, LLC 10333 Richmond Ave, Ste 710 Houston, TX 77042 William Holton, Jr. Marathon Oil Company Law Department 5555 San Fecipe St. Houston, TX 77056-2799 Chevron USA Alaska Division PO Box 1635 Houston, TX 77251 Chevron Chemical Company Library PO Box 2100 Houston, TX 77252-9987 James White Intrepid Prod. Co.lAlaskan Crude 4614 Bohill SanAntonio, TX 78217 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 ~ Daniel Donkel 2121 North Bayshore Drive Ste 1219 Miami, FL 33137 Christine Hansen Interstate Oil & Gas Compact Comm Excutive Director PO Box 53127 Oklahoma City, OK 73152 Mir Yousufuddin US Department of Energy Energy Information Administration 1999 Bryan St., Ste 1110 Dallas, TX 75201-6801 Michael Nelson Purvin Gertz, Inc. Library 600 Travis, Ste 2150 Houston, TX 77002 G. Havran Gaffney, Cline & Associations Library 1360 Post Oak Blvd., Ste 2500 Houston, TX 77056 T.E. Alford ExxonMobilExploration Company PO Box 4778 Houston, TX 77210-4778 W. Allen Huckabay Phillips Petroleum Company Exploration Department PO Box 1967 Houston, TX 77251 Shawn Sutherland Unocal Revenue Accounting 14141 Southwest Freeway Sugar Land, TX 77478 Doug Schultze XTO Energy Inc. 3000 North Garfield, Ste 175 Midland, TX 79705 Scott Webb Ocean Energy Resources, Inc. 1670 Broadway, Ste 2800 Denver, CO 80202-4826 ~ SD Dept of Env& Natural Resources Oil and Gas Program 2050 West Main, Ste #1 Rapid City, SO 57702 Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Mary Jones XTO Energy, Inc. Cartography 810 Houston St., Ste 2000 Ft. Worth, TX 76102-6298 Paul Walker Chevron 1301 McKinney Rm 1750 Houston, TX 77010 David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 Texico Exploration & Production PO Box 36366 Houston, TX 77236 Donna Williams World Oil Statistics Editor PO Box 2608 Houston, TX 77252 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 Jerry Hodgden Hodgden Oil Company 408 18th St. Golden, CO 80401-2433 John Levorsen 200 North 3rd St., #1202 Boise,ID 83702 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Duane Vaagen Fairweather 715 L St., Ste 7 Anchorage, AK 99501 Steve E. Mulder Dorsey & Whitney 1031 West 4th Ave., Ste 600 Anchorage, AK 99501 Robert Mintz State of Alaska Department of Law 1031 West 4th Ave., Ste 200 Anchorage, AK 99501 Tim Ryherd State of Alaska Department of Natural Resources 550 West 7th Ave., Ste 800 Anchorage, AK 99501 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 John Harris NI Energy Development Tubular 3301 CSt., Ste 208 Anchorage, AK 99503 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Greg Noble Bureau of Land Management Energy and Minerals 6881 Abbott Loop Rd Anchorage, AK 99507 ) . Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Thor Cutler OW-137 US EPA egion 10 1200 Sixth Ave. Seattle, WA 98101 Julie Houle State of Alaskan DNR Div of Oil & Gas, Resource Eva!. 550 West 7th Ave., Ste 800 Anchorage, AK 99501 Richard Mount State of Alaska Department of Revenue 500 West 7th Ave., Ste 500 Anchorage. AK 99501 Susan Hill State of Alaska, ADEC EH 555 Cordova St. Anchorage, AK 99501 Jim Arlington Forest Oil 310 K St., Ste 700 Anchorage, AK 99501 Mark Dalton HDR Alaska 2525 C St., Ste 305 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Judy Brady Alaska Oil & Gas Associates 121 West Fireweed Lane, Ste 207 Anchorage, AK 99503-2035 Jeff Walker US Minerals Management Service Regional Supervisor 949 East 36th Ave., Ste 308 Anchorage, AK 99508 ~ John F. Bergquist Babson and Sheppard PO Box 8279 Long Beach, CA 90808-0279 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Williams VanDyke State of Alaska Department of Natural Resources 550 West 7th Ave., Ste 800 Anchorage, AK 99501 Cammy Taylor 1333 West 11th Ave. Anchorage, AK 99501 Ed Jones Aurora Gas, LLC Vice President 1029 West 3rd Ave., Ste 220 Anchorage, AK 99501 Trustees for Alaska 1026 West 4th Ave., Ste 201 Anchorage. AK 99501-1980 Schlumberger Drilling and Measurements 3940 Arctic Blvd., Ste 300 Anchorage, AK 99503 Mark Hanley Anadarko 3201 CSt, Ste 603 Anchorage, AK 99503 Arlen Ehm 2420 Foxhall Dr. Anchorage. AK 99504-3342 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Rose Ragsdale Rose Ragsdale & Associates 3320 E. 41st Ave Anchorage, AK 99508 Chuck O'Donnell Veco Alaska,lnc. 949 East 36th Ave., Ste 500 Anchorage, AK 99508 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 Perry Markley Alyeska Pipeline Service Company Oil Movements Department 1835 So. Bragaw - MS 575 Anchorage, AK 99515 Jeanne Dickey BP Exploration (Alaska), Inc. Legal Department PO Box 196612 Anchorage, AK 99518 J. Brock Riddle Marathon Oil Company Land Department PO Box 196168 Anchorage, AK 99519-6168 BP Exploration (Alaska), Inc. Land Manager PO Box 196612 Anchorage, AK 99519-6612 Shannon Donnelly Phillips Alaska, Inc. HEST -Enviromental PO Box 66 Kenai, AK 99611 Penny Vadla Box 467 Ninilchik, AK 99669 John Tanigawa Evergreen Well Service Company PO Box 871845 Wasilla, AK 99687 .- Jim Scherr US Minerals Management Service Resource Evaluation 949 East 36th Ave., Ste 308 Anchorage, AK 99508 Richard Prentki US Minerals Management Service 949 East 36th Ave., 3rd Floor Anchorage, AK 99508 Jim Ruud Phillips Alaska, Inc. Land Department PO Box 100360 Anchorage, AK 99510 Jordan Jacobsen Alyeska Pipeline Service Company Law Department 1835 So. Bragaw Anchorage, AK 99515 David Cusato 600 West 76th Ave., #508 Anchorage, AK 99518 Kevin Tabler Unocal PO Box 196247 Anchorage, AK 99519-6247 Dudley Platt D.A. Platt & Associates 9852 Little Diomede Cr. Eagle River, AK 99577 Kenai Peninsula Borough Economic Development Distr PO Box 3029 Kenai, AK 99611 Claire Caldes US Fish & Wildlife Service Kenai Refuge PO Box 2139 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 ..Þ Thomas R. Marshall, Jr. 1569 Birchwood Street Anchorage, AK 99508 Paul L. Craig Trading Bay Energy Corp 5432 East Northern Lights, Ste 610 Anchorage, AK 99508 Kristen Nelson IHS Energy PO Box 102278 Anchorage, AK 99510-2278 Robert Britch, PE Northern Consulting Group 2454 Telequana Dr. Anchorage, AK 99517 Tesoro Alaska Company PO Box 196272 Anchorage, AK 99519 Sue Miller BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Bob Shavelson Cook Inlet Keeper PO Box 3269 Homer, AK 99603 James Gibbs PO Box 1597 Soldotna, AK 99669 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 131 Fairbanks, AK 99707 Harry Bader ... State of Alaska Department of Natural Resources 3700 Airport Way Fairbanks, AK 99709 .. North Slope Borough PO Box 69 Barrow, AK 99723 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 Senator Loren Leman State Capitol Rm 113 Juneau, AK 99801-1182 .. Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 J =\f=I~GI~==I~1 RESOURCES (ALASKA) CORP. A Subsidiary of Evergreen Resources, Inc. .,j RECEIVED Mr. Dan T. Seamount Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99500 AUG 1 5 2002 Alaska Oil & Gis Cons. Commission Anctrorage August 15, 2002 RE: Waiver for exception from 20AAC 25.066 Gas Detection Dear Commissioner Seamoun~, Evergreen Resources is the current operator for the Pioneer Unit, Matanuska Susitna Borough and plans to drill eight wells to test the Tyonek Coals in September 2002. In this letter, Evergreen Resources Alaska requests an exemption from 20 AAC 25.066, Gas Detection for the upcoming drilling program. 20 AAC25.066 sets forth the minimum gas detection equipment for drilling and work over rigs. This portion of the regulations are included at the end of this letter. Evergreen requests a waiver from this regulation since (1) there is no H2S gas from the shallow gas formations in the Pioneer Unit and (2) due the air drilling system that we employ. To date, 12 wells have been drilled on or directly adjacent to the Pioneer Unit. None of these wells reported H2S. We therefore believe there is sufficient evidence that no H2S exists. Secondly, due to the truck mounted drilling system that Evergreen employs, sensors cannot be placed in the cellar or substructure and next to the shale shaker. Methane gas, the primary constituent of natural gas from coal bed methane, will evolve from the air drilling process. However, these gasses are blown well away from the drill rig, out the 30 foot blooey line and are prevented from flowing up the drill pipe due to check valves (floats). We are confident we can safely drill, complete and produce coal bed methane wells in Alaska using our well-proven systems and methods discussed in earlier correspondences. This year alone, we have drilled over 40 miles of coal bed methane wells in the US, UK and Ireland with no accidents. We hope we can employ the same types of drilling measures, necessary for successful coal bed methane development, in Alaska. Thank you for considering Evergreen's request. Please contact me if you have questions. My telephone number is 907-841-0000 and my e-mail is JohnT@EvergreenGas.com Sincerely, John J Tanigawa P.O. Box 871834 Wasilla. Alaska 99687 Tel: 907-357-8130 Fax: 907-357-8340 J =\(=I~GI~==I'I J \ , RESOURCES (ALASKA) CORP. A Subsidiary of Evergreen Resources. Inc. 20 AAC 25.066 GAS DETECTION. (a) Drilling and workover rigs must meet the following minimum requirements for methane and hydrogen sulfide gas detection: (1) the methane detection system must have a minimum of three sensing points; one sensing point must be under the· substructure near the cellar, one must be over the shale shaker, and one must be above the drill rig floor near the driller's station or above the drilling platform; if the mud pits are remote from the shale shaker and enclosed, a fourth sensor must be located over the mud pits; (2) methane sensors must be placed to detect a "lighter-than-air" gas; (3) the hydrogen sulfide detection system must have a minimum of three sensing points; one sensing point must be under the substructure near the cellar, one must be near the shale shaker, and one must be above the drill rig floor near the driller's station or above the drilling platform; the commission will require additional sensors as the commission considers necessary for safety, such as at the entrance to living quarters if they are adjacent to the drill rig, or over the mud pits if they are remote from the shaker and enclosed; (4) hydrogen sulfide sensors must be placed to detect a "heavier..than-air" gas; (5) sensors must be automatic, acting independently and in parallel, and with one- minute minimum sampling intervals; (6) each detection system must include separate and distinct visual and audible alarms; the visual alarm must signal the low level gas alarm and the audible alarm the high level gas alarm; an audible alarm may have an "acknowledge" button; (7) the methane low level gas alarm must be set at not over 20 percent LEL; the high level alarm must be set at not over 40 percent LEL; (8) the hydrogen sulfide low level gas alarm must be set at 10 ppm; the high level alarm must be set at not over 20 ppm; (9) each alarm must be automatic and must be visible and audible from the driller's or operator's station; the hydrogen sulfide alarm must be audible throughout the drilling location, including the camp buildings. (b) A gas detection system that continuously performs self-checking or diagnostics must be function-tested when a BOP stack is initially installed after a drill rig is set up, when a commission-witnessed BOP test occurs, and no less frequently than once every six months. Other gas detection systems must be calibrated and tested when' a BOP stack is initially installed after a drill rig is set up, when a commission-witnessed BOP test occurs, and no less frequently than once every 30 days. The operator shall maintain at the drill rig an accessible record of gas detection system tests and calibrations. (c) A failure in a gas detection system must be reported to the commission within 24 hours after the failure. The commission will, in its discretion, require well operations to be discontinued if a gas detection system fails. History - Eft. 11fl/99, Register 152 Authority - AS 31.05.030 P.O. Box 871834 Wasilla. Alaska 99687 Tel: 901-357-6130 Fax: 907-357-8340 ':;:\I~::,\'\\:'\\ .;f~:r:¡I":I~}~.: I~": l::tll ~~·,~W~.. ~ .!~~,,~~~~,~\~~,':'~~~,,~~~~~~~'I~~~~1'l'jl'J ~.!.'I~ ·.A!¿~{~U~,~1J''.!.' :t.. 1..,,11'''''' \~*¡\~i' . .ii;i!". .... .',w£';:!¡;À¡!Ji¡~¡m¡¡~\¡¡(':\~¡\¡':1\1~~~\\~ìl\;ili;¡i:P;i» \~i¡lî~ii\i 'Î::::::~(::S'\\, ' <';~:::':::I:~'\\ '."\:q,(,i,i',\:"i::,';!",, ,:::i',:G().ri1~rplled" D is,bQrsef11~,,)t, AçQ(¡»L:;Int , ",":"""""\'1"\1':, , """",,\',\\1,\'1'.' ,1')0",'\'1"'\ """"'~\~ I\\\~,'~\~;\\'\',~~\\ ':>';\~\~' \:\\i~,~:i¡:~:"\;i\'ì: lr{f¡~ì' I' ~:\\~ "ì~\Î' ,'\\I¡\':¡\\ ...\~,:~\:\'~~~,: \~'\I,\\I:': '~.; Ii' ,:; ~\:~ ':~\~ '::,\\1\\ \'~\\\\\I, '\\\~ PAY , One Hundred Dollars and ,\\008300490Z 05/30/2002 "************$100.00 .\~: :'.'::. TO THE ORDER OF , Alaska Oil andGae , Conservation Commission 333 West 7th Avenué ,#1 00 Anchorage AK 99501 \\\:: ~:~~~: Void After 90 Days II- 008 laD l. ~ 02"- I: ~,,~' ~ ¡ Ol. 8?q,l: 5... 20 2l. 701.11- ... . -... ,,_...I. .._.,_...... __ _. .... .._~ "_ ~ _. ,_.... _, d . .'...._.... _.._.... __ ~.. .... _. ,. _. _.~" ......_.... _ ... _. _ _~ __ ........,_...... ..._ ,_ '~"" _"..._.. ......',ø".... .__... ~_.. __ "_., .~_ _... ~_ __ ,. _..'._.' ~.'..J..... __.. ..._. ._. .. ^PLEASE DETACH AT PERFORATION ABOVE^ ^PLEASE DETACH AT PERFORATION ABOVE^ : :V:llGll::N i EVERGREEN RESOURCES,INC. _1IIlIEmI 1- 042802 JT-10 04/18/2002 i 12 Month Drilling Permit Fee I I Evergreen Opera tin a Corp 1401 17th Street, Suite 120"'6 Denver CO 80202 Check Number '__1 I 1 ' I 00.00 0.00 I i f 100.00 nnQ1Q" b \/pnrlnr Check Date: 05/30/2002 Check Amount ~ 100.00 ) ~) , TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME (!~K... / PTD# 2.02-,- I~() CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). paOT (PH) SPACING EXCEPTION /' / DRY DITCH SAMPLE Rev: 07/1 0/02 C\jody\templates The permit is approved subject to full' compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issu~nce of a conse~ation ord..!J:- appro. ving a spacing exceptIOn. ~veA~ (Company Name) assumes the liabiliQlof any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. f"-' '-"'-\1'-'" . WE~L'PERIII!Ir.,'Ç~EÇK~Sj FIELD & POOL ADMINISTRATION APPR SFD DATE 9/6/2002 (For Service Well Only) (For Service Well Only) ENGINEERING APPR WGA DATE 9/3/2002 GEOLOGY (For Service Well Only) APPR SFD COMPANY 610500 WELL NAME Cook 1 Initial ClassfType EXP /1-GAS PROGRAM Explontory (EXP) -.!... Development (DEV) GEOL AREA 820 UNIT No. Redril ~ervice (SER) _Well bore seg 51550 ON/OFF SHORE On Annular disposal para req EVERGREEN 1. Permit fee attached ..............................................................................................' 2. Lease number appropriate...... ... ... ... ... ... ... ... ...... ... ...... ... ...... ...... ......... ...... ... ... ... .... 3. Unique well name and number ... ... ... ...... ... ..................... ... ... ...... ............................ 4. Well located in a defined pool................................................................................. 5. Well located proper distance from drilling unit boundary ............................................... 6. Well located proper distance from other wells ... ... ............... ... ...... ......... ... ...... ...... ... ...' 7. Sufficient acreage available in drilling unit................................................................. 8. If deviated, is wellbore plat included ......................................................................... 9. Operator only affected party ................................................................................... 10. Operator has appropriate bond in force ................................................................... 11. Permit can be issued without conservation order ....................................................... 12. Permit can be issued without administrative approval................................. ................ 13 Can permit be approved before 15-day wait......... ...... ...... ...... ... ............ ............... .... 14 Well located within area and strata authorized by Injection Order # 15 All wells witthin 1/4 mile area of review identified ....................................................... 16 ACMP Finding of Consistency has been issued for this projec ..................................... 17 Conductor string provided ....................................................................................' 18 Surface casing protects all known USDWs ............................................................... 19 CMT vol adequate to circulate on conductor & surf csg .............................................. 20 CMT vol adequate to tie-in long string to surf csg ...................................................... 21 CMT will cover all known productive horizons ........................................................... 22 Casing designs adequate for C, T, B & permafrost.................................................... 23 Adequate tankage or reserve pit.............................. ...... ...... ............ ......... ... ...... .... 24 If a re-drill, has a 10-403 for abandonment been approved .......................................... 25 Adequate wellbore separation proposed ... ...... ... ... ... ... ... ......... ... ... ...... ... ...... ... ... ... ... 26 If diverter required, does it meet regulations............................................................. 27 Drilling fluid program schematic & equip list adequate...... ......... ... ...... ...... ...... ... ... ...... 28 BOPEs, do they meet regulation ............................................................................ 29 BOPE press rating appropriate; test to ..................... psig ........................... 30 Choke manifold complies w/API RP-53 (May 84) ....................................................... 31 Work will occur without operation shutdown...... ......... ... ...... ... ...... ... ... ... ...... ...... ... ... .. 32 Is presence of H2S gas probable ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... 33 Mechanical condition of wells within AOR verified ...................................................... Yes # 0083004902 No ADL 384685 based on DNR Mineral Estate map. Yes No No No No Yes Yes No Yes No Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes 34 Permit can be issued w/o hydrogen sulfide measures................................................ Yes 35 Data presented on potential overpressure zones...... ... ...... ... ...... ... ......... .., ... ... ... ...... . DATE 36 Seismic analysis of shallow gas zones ... ......... ............................................. ... ........ 37 Seabed condition survey (if off-shore) ..................................................................... 9/6/2002 38 Contact name/phone for weekly progress reports [exploratory only} ............................ Yes GEOLOGY: ENGINERING: RES. ENGINERING: RPC:. TEM: JD; ;:.).11/ SF~~WGA: \JGA-'MJW: COMMISSION: COT: Cg:r 4 !tp 10 'Z- DTS:()þ~¿ Cook 1 will be located in the Pioneer unit in an undefined pool within the Tyonek Fm. SPACING EXCEPTION REQUIRED «1500' from property line, <3000' from Bering 3, Baranoff 4, Lowell 2) Well will lie <700' from Bering 3, Lowell 2 and Baranoff 4. Fourth gas well in Sec. 30, T18N, R1W, SM Not Applicable: vertical well SPACING EXCEPTION REQUIRED; text for public notice drafted. Waiting on application. SFD Not Applicable Not Applicable 8-29-02: DNR rules that the project is consistent with the Alaska Coastal Management Program and the Local District Plan. SFD f 12-1/4" @ 125'. 8-28-02: No information. Surface Casing 9-6-02: Offset well data and Evergreen's C-Plan Exemption request suggests that casing set at the proposed 300' depth should be adequate to protect glacial till layer, which is the drinking water aquifer for this area. Nearest drinking water wells are about 1 mile away, and they range in depth from 41 to 285 feet deep, Prior well Bering #3 will be logged to demonstrate depth of drinking water aquifer. Not Applicable Air drilled. Not Applicable Not Applicable Not Applicable No (- Not Applicable Not Applicable Not Applicable Not Applicable John Tanigawa: 907-841-0000 Commentsll nstructions 8-28-02: Spacing exception required to produce the well. Inclination only survey required. SFD