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204-156
· . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J,O'=t - J 5 fo Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 D Rescan Needed "111111I1111111 III RESCAN ~J'lor Items: ~Greyscale Items: D Poor Quality Originals: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NolType: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: D Other:: BY: ~ Date ;J./¡;;"/ D 7 I I /5/ .VY\f 1111111111111111111 Project Proofing BY: ~ /5/ M~P BY: Date: + ¡ c!i- = TOTAL PAGES /0..:2.. (Count does not include cover sheet) f) /5/ {r Scanning Preparation Production Scanning 1111111111111111111 Stage 1 Page Count from Scanned File: t 0 3 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES ~ Date: J-J I a-Io 7 NO Stage 1 If NO in stage 1, page(s) discrepancies were found: YES /5/ h1 \P NO BY: BY: Maria Date: /5/ 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 111111111111111111I BY: Maria Date: /5/ Comments about this file: Quality Checked 111111111111111111I 10/6/2005 Well History File Cover Page.doc Marathon Alaska Production LLC ('* /J Alaska Asset Team Marathon Oil P.O. Box 1949 Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 September 19, 2011 Mr. Winton Aubert RECEIVED Alaska Oil & Gas Conservation Commission 333 W 7 Ave SEP 21. 2Olf Anchorage, Alaska 99501 Alaska nil & Gas Cons. Commission Anchorage Reference: 10 -404 Report of Sundry Well Operations �. — I 6 Field: West Fork Field ao Well: West Fork #3 Dear Mr. Aubert: Attached for your records is the10 -404 Report of Sundry Well Operations for WF -3 well. This report covers the work performed to test flow WF -3 to evaluate location reactivation. Results indicate that WF -3 is capable of commercial production. Plans are to reactivate the West Fork location in 2012. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, - kj 9CCL �M i SEP 2 2 2011 Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File (2) KJS • STATE OF ALASKA ALASKA IIPAND GAS CONSERVATION COMMISSICIP REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate Other U Vented Gas Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver El Time Extension ❑ Watt 's Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Alaska Production LLC Development 0 Exploratory ' 204 -156 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 „ 50- 133 - 20543 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: FEE -CIRI • • West Fork #3 9. Field /Pool(s): West Fork Field / Undefined Gas Pool 11. Present Well Condition Summary: Total Depth measured 10,620' feet Plugs (measured) 8,470' feet true vertical 9,737' feet Junk (measured) — 8,442' feet Effective Depth measured 10,490' feet Packer (measured) 7,433' feet true vertical 9,608' feet (true vertical) 6,637' feet Casing Length Size MD TVD Burst Collapse Structural 28' 36" 49' 49' Conductor 80' 20" 101' 101' 3,060 psi 1,500 psi Surface 2,164' 9 -5/8" 2,185' 2,185' 6,870 psi 4,750 psi Intermediate 7,672' 7" 7,693' 6,863' 7,240 psi 5,410 psi Production 10,599' 4 -1/2" 10,620' 9,737' RC 7,500 psi Liner Perforation depth: Measured depth: 7,997' - 9,355' SEP 21 201 True Vertical depth: 7,139' - 8,474' Alaska Oil & Gas Cons. Commission cnorme Tubing (size, grade, MD & TVD): Velocity String 1 -3/4" QT -80 7,940' MD 7,086' TVD SSSV: NA 0 MD 0 TVD Packers and SSSV (type, MD & TVD): Packers: 4 -1/2" Baker Midstring 7,433' MD 6,637' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): WF -3 was flow tested from 11:OOam 8110111 to 6:OOam 8/12/11. WF -3 produced 17 bbls of fluid and vented a total of 2,471.85 mcf of gas Treatment descriptions including volumes used and final pressure: during the test. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 2,575 2,200 Subsequent to operation: 0 0 0 2,705 - 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development 0 r Service ❑ Daily Report of Well Operations 15. Well Status after work: Oil LJ • Gas 12 WDSPL U GSTOR ❑ WAG ❑ GINJ❑ WINJ ❑ SPLUG ❑ 16. 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: 311 -222 Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature Phone (907) 283 -1371 Date September 19, 2011 a Form 10 -404 Revised 7/2009 RBDMS SEP 2 2 2 `' Submit Original Only API #it #: 50-133-20543-00 - ■ est Fork #3 � .. #1 Prop. Des: C- 060898 West Fork Field KB elevation: 317' (21'AGL) 1,981' FNL, 1,919' FEL, Marathon Oil WBS #: DX. 04.10455. CAP.CMP.02 Sec. 6, T6N, R9W, S.M. Alaska Production LLC_ X: 345,130.584 Zone 4 Y: 2,411,693.656 Zone 4 Latitude: 60° 27' 36.75" N Dr v Longitude: 151° 15' 54.42" W e Pi p e Spud: 09/28/2004 20" K -55 133 ppf PE Top Bottom TD: 10/17/2004 MD 0' 101' Riq Released: 10/28/2004 @ 12:00 hrs. TVD 0' 101' Surface Casing: 9 -5 /8" 47 ppf L -80 Mod Butt lop_ Bottom KOP @ 2,200' MD 0' 2,185' Build 3.0 deg /100' TVD 0' 2,185' Hold 36 deg from 2,200' - 5,400' KB Hold 34 deg from 5,400' - 7,181' Cmt'd w/ 533sks (238 bbls.) 12 ppg Class G in a 12 -1/4" Drop 2.25 deg /100' to ,9151' KB hole. (Recovered 5 bbls cement to surface). Bumped plug - Inclination at TD: 3.5 deg floats held. Azimuth: 77 -79 deg. To 8,780' MD & 106 -119 deg. TO TD Intermediate Casing: 7" 26 ppf L -80 Mod Butt Top Bottom 1/4" OD 0.049" wall Chemical injection string tied MD 0' 7,693' into Chemical Injection Nipple top @ 2,418' TVD 0' 6,863' w /double check valve & rupture discs Cmt'd w/184 sks (82.5 bbls) Class G lead cement (12.5 ppg) in an 8 -1/2" hole followed w/162 sks (32 bbls) Class G tail cement 7" x 4 -1/2" annulus filled w/ 10.7 ppg mud (15.8 ppg)in an 8 -1/2" hole.(Recovered 20 bbls of cement to Containing Conquor surface). Did not bump plug - floats held. Production Casing: 7" Casing Annulus TOC calculated @ 4,400' KB 4 -1/2" 12.6 ppf L -80 Hydril 563 Tom Bottom & ''. t MD 0' 10,620' AB- Mod Butt tubing Baker 4-1/2" Midstrinq ZXP Packer. TVD 0' 9,737' Packer top @ 7,433' MD / 6,637' TVD. '; 7" hole Cmt'd w/550 sks 13.5 ppg (178 bbls) Displaced w/ 155 bbls. 6% KCL water. Bumped plug w/ 3,100 psi. Applied pressure to 5,000 psi to set midstring packer. Circulated no °. cement to surface. 4 -1/2" Casing Annulus estimated TOC @ 7,750' KB Velocity Tubing: R 1 -3/4" QT -80 TOj Bottom TOC @ 9740' by USIT /CBT MD 0' 7,940' TVD 0' 7,086' . 1.20" nipple in BHA 1 Fish -3/4" tool string lost in hole. 3/4" knuckle joint looking up. -KJ, 13' x 3/4 "R stem, KJ,13' x 3/4" Rstem KJ,LSSJ,3 /4" dart. (6/30/2011) Cast Iron Bridge Plug @ 8,470' MD 1 • Tyonek Perfs: Correlated to CBL Gamma 12/02/2004 9' off of open hole) Net 4 -1/2" Short Joint Locations: MD TVD Ft 9,206.5' - 9,246.2' MD 7,997' - 8,011' 7,139' - 7,152' 14' 3 -3/8" 6 spf 12/17/2004 9,990.5' - 10,030.3' MD "-` 8,103' - 8,123' 7,239' - 7,258' 20' 3 -3/8" 6 spf 12/16/2004 8,315' - 8,323' 7,442' - 7,450' 18' 3 -3/8" 6 spf 12/17/2004 ti 8,494' - 8,504' 7,616' - 7,626' 10' 3 -3/8" 6 spf 12/16/2004 9,317 - 9,32T 8,436' - 8,446' 10' 3-3/8" 6 spf 12/16/2004 NOTES: 9,345 - 9,355' 8,464' - 8,474' 10' 3 -3/8" 6 spf 12/16/2004 (Sept 2005) Tight casing at 8,003 & 8,029' ELMD. Able to work down 3.74" by 4 "., 3" by 3.75'. Unable to work down 3.375" by 5'. (6/30/2011) Slick line tag @ 8,279' KB TD PBTD 10,620' MD 10,490' MD 9,737' TVD 9,608' TVD Well Name & Number: West Fork #3 Lease: West Fork County or Parish: Kenai Peninsula Borough State: Alaska I Country:I USA Perforations (MD): 7,997 - 9,355' (TVD): 7,139' - 8,474' Angle @ KOP and Depth: 3.0 ° 1 100ft @ 2,200' Angle /Perfs - 1.5° Dated Completed: 1/11/2005 Completion Fluid: 6% KCL Revised by: Kevin Skiba Last Revison Date: 7/14/2011 r • • F FE n ALrrAitiMA SEAN PARNELL, GOVERNOR ALASKA 0114 A1ND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Kevin J. Skiba Regulatory Compliance Representative Marathon Alaska Production, LLC , L i,6 P.O. Box 1949 "f Kenai, AK 99611 -1949 Re: West Fork Field, Undefined Gas Pool, West Fork #3 Sundry Number: 311 -222 Dear Mr. Skiba: 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 reconsideration. A request for reconsideration 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. Sincerely, Daniel T. Seamount, Jr. Chair 3� DATED this 2 l day of July, 2011. Encl. • • Marathon Alaska Production LLC Alaska Asset Team AA Marathon P.O. Box 1949 MARATHON Alaska Production LLC Kenai, AK 99611 Telephone 907/283 -1371 Fax 907/283 -1350 July 15, 2011 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 TM 4 „M:. 5 w `t Reference: 10 -403 Application for Sundry Approvals ”' ' "' ~ , "' ` 'kJEerr�bssion Field: West Fork Field yb Well: West Fork #3 attk:>` Dear Mr. Aubert: Submitted for your approval is the10 -403 Application for Sundry Approvals for WF -3 well. WF -3 has been shut in since December of 2008, due to flow -line issues and hydrate problems inside of the 1.75" V- String. The shut in wellhead pressure has recently risen indicating that an aquifer may be encroaching within the formation. To determine if the well is still viable, Marathon would like to perform a Multi Point Well Test. The test is scheduled to be performed over a 48 hour period with a maximum venting volume of 5000mcf /day. i O tit M - Plans are to reactivate the Wolf Lake location, in 2012, if the WF -3 production test results indicate that it is capable of sustained production. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -403 Application for Sundry Approvals cc: AOGCC Current Well Schematic Houston Well File Kenai Well File (2) KJS sd STATE OF ALASKA • 0- " /I 1 p a— e 7 %9' ' ALASKAAL AND GAS CONSERVATION COMMISSION 1 °' '' F '/ ,, APPLICATION FOR SUNDRY APPROVALS v 01 i ' iii, or/ye/tea 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair well ❑ i ;ii, i ntittgrioffremipri5am ei Suspend III Plug Perforations ❑ Perforate 1] Pull Tubing ❑ Specify: Time xtensi Yf lir Oil Operational shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter casing ❑ Other: 81s4 stin 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Alaska Production LLC Development 0 Exploratory ❑ 204 -156 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 50- 133 - 20543 -00 -00 r 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes 111 No 0 West Fork #3 9. Property Designation (Lease Number): 10. Field / Pool(s): FEE - CIRI West Fork / Undefined Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): Casing Length Size MD / TVD Burst Collapse Structural 28' 36" 49' 49' Conductor 80' 20" 101' 101' 3,060 psi 1,500 psi Surface 2,164' 9 -5/8" 2,185' 2,185' 6,870 psi 4,750 psi Intermediate 7,672' 7" 7,693' 6,863' 7,240 psi 5,410 psi Production 10,599' 4 -1/2" 10,620' 9,737' 8,430 psi 7,500 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7,997' - 9,355' / 7,139' - 8,474' Velocity 1 - 3/4" / QT - 80 7,940' Packers and SSSV Type: SSSV: NA Packers and SSSV MD (ft) and TVD (ft): / . Packers: 4 - 1/2" Baker Midstring 7,433' 6,637' 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development Si Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: July 26, 2011 Oil ❑ Gas Ell WDSPL ❑ Plugged ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba jj� ��,, Title Regulatory Compliance Representative Signature hone (907) 283 -1371 Date July 14, 2011 .45 • COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 311— c 2c Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: (0 - 4 2. 2 . APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: - Z, 1 i 1 0R JUL 2 2 ZO11 ' Form 10 -403 Revised 12/2009 , bmit in Duplicate • Permit #: 207 -156 ___ West Fork #3 / /i'``*� // API #: 50-133-20543-00 West Fork Field Prop. Des: C- 060898 Marathon Oil KB B elevation: 317' (21' AGL) l 1,981' FNL, 1,919' FEL, WBS #: DX.04.10455.CAP.CMP.02 $eC. 6, T' N, R9W, S.M. Alaska Production LLC_ X: 345,130.584 Zone 4 ____ Y: 2,411,693.656 Zone 4 Latitude: 60° 27' 36.75" N - Drive Pipe Longitude: 151° 15' 54.42" W 20" K -55 133 ppf PE Spud: 09/28/2004 T� Bottom TD: 10/17/2004 MD 0' 101' Riq Released: 10/28/2004 @ 12:00 hrs. TVD 0' 101° Surface Casing: 9 -5/8" 47 ppf L -80 Mod Butt Toil - Bottom KOP @ 2,200' MD 0' 2,185' Build 3.0 deg /100' - TVD 0' 2,185' Hold 36 deg from 2,200' - 5,400' KB Hold 34 deg from 5,400'- 7,181' Cmt'd wl 533sks (238 bbls.) 12 ppg Class G in a 12 -1/4" Drop 2.25 deg /100' to ,9151' KB hole. (Recovered 5 bbls cement to surface). Bumped plug - Inclination at TD: 3.5 deg floats held. Azimuth: 77 -79 deg. To 8,780' MD & 106 -119 deg. TO TD Intermediate Casing: 7" 26 ppf L -80 Mod Butt Top Bottom 1/4" OD 0.049" wall Chemical injection string tied MD 0' 7,693' into Chemical Injection Nipple top @ 2,418' TVD 0' 6,863' w /double check valve & rupture discs Cmt'd w /184 sks (82.5 bbls) Class G lead cement (12.5 ppg) - in an 8 -1/2" hole followed w /162 sks (32 bbls) Class G tail cement 7" x 4 -1/2" annulus filled w/ 10.7 ppg mud (15.8 ppg)in an 8 -1/2" hole.(Recovered 20 bbls of cement to containing Conquor surface). Did not bump plug - floats held. Production Casing: 7" Casing Annulus TOC calculated @ 4,400' KB 4-1/2" 12.6 ppf L -80 Hydril 563 Lop Bottom & MD 0' 10,620' AB- Mod Butt tubing Baker 4 -1/2" Midstrinq ZXP Packer.) TVD 0' 9,737' • Packer top @ 7,433' MD / 6,637' TVD. A 7" hole Cmt'd w/550 sks 13.5 ppg (178 bbls) 1 Displaced w/ 155 bbls. 6% KCL water. Bumped plug w/ 3,100 psi. cr Applied pressure to 5,000 psi to set midstring packer. Circulated no • , cement to surface. 1 4 -1/2" Casing Annulus estimated TOC @ 7,750' KB ! y ■ ' ' Velocity Tubing: 1 -3/4" QT -80 Tom Bottom TOC @ 9740' by USIT /CBT MD 0' 7,940' TVD 0' 7,086' 1.20" nipple in BHA 07 " • Fish -3/4" tool string lost in hole. 3/4" knuckle joint looking up. -KJ, 13' x 3 /4 "R stem, KJ,13' x 3/4" Rstem KJ,LSSJ,3 /4" dart. (6/30/2011) - e - Cast Iron Bridge Plug @ 8,470' MD '"" ~' Tyonek Perfs: Correlated to CBL Gamma 12/02/2004 9' off of open hole) Net 4 -1/2" Short Joint Locations: MO TVD Ft 9,206.5' - 9,246.2' MD 7,997 •8,011' 7,139' - 7,152' 14' 3 -3 /8" 6 spf 12/17/2004 9,990.5' - 10,030.3' MD 8,103' - 8, 7,239' - 7,258' 20' 3 -3/8" 6 spf 12/16/2004 - 8,315' - 8,323' 7,442' - 7,450' 18' 3 -3/8" 6 spf 12/17/2004 8,494' - 8,504' 7,616' - 7,626' 10' 3 -318" 6 spf 12/16/2004 _. 9,317 - 9,327 8,436' - 8.446' 10' 3 -3/8" 6 spf 12/16/2004 NOTES: 9,345 - 9,355' 8,464' - 8,474' 10' 3 -318" 6 spf 12/16/2004 * (Sept 2005) Tight casing at 8,003 & 8,029' ELMD. Able to work down 3.74" by 4 "., 3" by 3.75', Unable to work down •- 3.375" by 5'. * (6/30/2011) Slick line tag @ 8,279' KB TD PBTD 10,620' MD 10,490' MD 9,737' TVD 9,608' TVD Well Name 8 Number: West Fork #3 Lease: West Fork County or Parish: Kenai Peninsula Borough State: Alaska I Country:I USA Perforations (MD): 7,997 - 9,355' (TVD): 7,139' - 8,474' Angle © KOP and Depth 3.0 ° / 100ft @ 2,200' Angle / Perfs• ^ 1.5" Dated Completed: 1/11/2005 Completion Fluid: 6% KCL Revised by Kevin Skiba Last Revison Date: 7/14/2011 • • ~~. MICROFILMED 03/01 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc e e Alaska Asset Team Northern Business Unit Marathon Oil Company P.O. Box 3128 Houston, TX 77253 Telephone 713-296-2384 Fax 713-499-8504 February 12,2007 Alaska Oil & Gas Conservation Commission Attn: Howard 0MIanrt bk.\a"'~ 333 W. 7th Avenue, Suite 100 Anchorage,AJe 99501 FEDERAL EXPRESS RE: Marathon West Fork #3 - API 50-133-20543-00 CONFIDENTIAL 11 t-{ <-( ~ ì-- Dear Mr. 0altIa:ntt: ~k\..._~ One CD containing the following confidential well data is enclosed for the above referenced well. West Fork #3 Directional Survey: ¡g¡ WF3_dir _survey.dat Digital Log Data: "!:.: WF#3_DRIll_DVNAMICSjiD.pdf ~WF#3 FORMATION lOG MD.pdf ~ WF#3=FORMATION=lOG=TVD.pdf ~ FINAL_Data_Marathon_West Fork #3_Run 2_Shuttle_complete.dpk ~ FINAL_Data_Marathon_West Fork #3_Run 2_Shuttle-p1otted.dpk ~Reeves_West Fork#3_Final.dpk ~ UZFIELD _ WF3 _PNS. dpk L::.) DSI_013PUP _Main Pass.las L::.)DSC017PUP.las L::.) DSI_022PUP.las L::.) WF3_R2_SPMAIN.las ~ Combined.PDS GJ Cornbined_TVD.PDS ~ VSPPRINT .PDS Mudlog Data: L::) West Fork #3.las ~. WF#3_DRILl_DVNAMICSjiD.pdf "!:.: WF#3JORMATION_lOG_MD.pdf ~ WF#3_FORMATION_lOG_TVD.pdf Please indicate your receipt of this data by signing below and returning one copy to me at the letterhead address or fax to 713-499-8504. S~ FEB .2 0 2007 Thank you, Kaynell Zeman Engineering Technician Received by: ;jJ úlU /4~? })r~ì Date: Enclosures  ù'-f .. / ("(p West Fork #3 . . Hi Kaynell, Help. No open hole data was submitted for West Fork #3 (API 50 133 20543 00 ). Please submit: Open Hole digital log data (LIS, DLlS or LAS format) Open Hole Blue line logs Open Hole reproducables - sepia/mylar or digital graphics files (.pds, .pdf, or .emf). Digital copy (ascii text preferred) of directional survey. TNX Howard p.s. After a couple of weeks of unseasonal warm weather, we are back to "normal". Looking at my home town's report (Winona, MN), it looks like winter is firmly (fridgidly?) entrenched with light snow and 2 deg. I of 1 2/6/2007 10: 18 AM II ¡::;6~ DATA SUBMITTAL COMPLIANCE REPORT 1/30/2007 Permitto Drill 2041560 Well Name/No. W FORK 03 Operator MARATHON OIL CO >"wl. ~r ~Â'~"f API No. 50-133-20543-00-00 MD 10620 /' TVD 9737./ Completion Date 1/11/2005'" Completion Status 1-GAS Current Status 1-GAS UIC N ------ "-_._-~ _._--~-~--~- --~-~._~~--,._~-~~~".~-" --"'--"-~-~-'-"-'~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes --- ----------_.~--_..~ ~-~~._-_. -~----_._~~-_.~-- "."---~,.~,-_._"--~-'"-~,.,.._~- DATA INFORMATION Types Electric or Other Logs Run: See 10-407 Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval OH I Start Stop CH Received Comments . -_.."----~-,_._--_..._~-----_..__._-~"-_._-------~-_.~~,_._- ~_...~_.~,~ --------- I L____.____.___.._________._ --~~~~~- ------ '--~-·'--I ..J Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? .~ Analysis ~ Received? Daily History Received? (Jffl ~/N Formation Tops -~-_.~--~ --"'-~-~- . -"--"-~--------- Comments: ~:~~~~~~:e R~vieW~d By: - =~o-~-__ --c-----==========-D~:e: -t;-r;- <f~~7== £: !IV\(¡..J/JL¿ M"vCÀ 1~(v-- ü140J:- M¡'Jd) o \-+. b~~ '------..-. . . A-òGCL v (.,0 F Alaska Region ¡VI "'11'11 Domestic Production Marathon Oil Company P.O. Box 1949 Kenai, AK 99611 Telephone 907/283·1337 Fax 907/283-1350 Jan 9, 2006 Winton Aubert State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Reference: Report of Sundry Well Operations Field: West Fork Well: West Fork #3 Dear Mr. Aubert, Enclosed please find a Report of Sundry Well Operations, along with the associated attachments for the West Fork 3. We set a plug at 8470' above the bottom 3 intervals to eliminate water production. We then ran a 1.75" CT velocity string to 7940. The well is back on production at 2600 MCF/day with the water rate reduced from 14 BWPD to 8 BWPD. If you require further information, please contact me. Sincerely, ~~~~ Advanced Production Engineer Telephone: 907-398-9954 Email: MAMullin@MarathonOil.com Attachments: Form 404 Daily report of well operations Well bore diagram . STATE OF ALASKA .. ALA t OIL AND GAS CONSERVATION COM~ON REPORT OF SUNDRY WELL OPERATIONS RECEIVED clAN 2 ð IU06 AI~!:k~ Oil & Gas Cons. Commissio 1. Operations Abandon U Repair Well U Plug Perforations l.:j Stimulate U Other l.:j A6\étiò~icity S Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 WaiverD Time Extension 0 Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: Marathon Oil Company Development [] Exploratory 0 204-156 3. Address: P. O. Box 1949, Kenai, AK 99611-1949 Stratigraphic 0 Service 0 6. API Number: 50-133-20543-01 7. KB Elevation (ft): 9. Well Name and Number: 317' West Fork #3 8. Property Designation: 10. Field/Pool(s): C-060898 West Fork/Tyonek 11. Present Well Condition Summary: Total Depth measured 10620' MD feet Plugs (measured) 8470 true vertical 9737' TVD feet Junk (measured) 0 Effective Depth measured 10490' feet true vertical 9608' feet Casing Length Size MD TVD Burst Collapse Structural 28' 36" 28' 28' N/A N/A Conductor 101' 20" 101' 101' 3060 psi 1500 psi Surface 2185' 9-5/8" 2185' 2185' 6870 psi 4750 psi Intermediate 7693' 7" 7693' 6863' 7240 psi 5410 psi Production 10620' 4/1/2" 10620' 9737' 8430 psi 7500 psi Liner Perforation depth: Measured depth: 7997 - 9355 True Vertical depth: 7131-8465 Tubing: (size, grade, and measured depth) 1.75" QT-80 7940 Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft JAN 2 3 2006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1000 14 0 850 Subsequent to operation: 0 2600 8 0 950 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 0 Development [] Service 0 Daily Report of Well Operations X 16. Well Status after proposed work: Oil 0 Gas [] WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: 305-249 Contact Michael A. Mullin Printed Name Michael A. Mullin Title Advanced Production Engineer Signatur~$A'/ud Phone 907-398-9954 Date 9-Jan-06 / /' /' If n Form 10-404 Revised 04/2004 OR\G\NAl Submit Original Only X: 345.130.584 Zone 4 Y: 2,411,693.656 Zone4 est Fork. #3 West Fork. Field 1981' FNL, 1919' FEL, Sec. 6, T6N, R9W, SM GL: 135' KB: 317' 121' AGL) SPUD: 15:30hrs 0912812004 TD: 1011712004 Rio Released: 12:00 hrs 1012812004 20" 133 ppf K-55 driven to 101' MDITVD 114" OD 0.049" wali Chemical injection string tied into Chemical Injection Nipple top at 2418' wldouble check valve and rupture discs 7" X 4-1/2" annulus filled with 10.7 ppg mud containing Conquor API # 50-133-20543·00 Permit # 204-156 WBS # DX.04.1 0455.CAP .CMP .02 Property: C·060898 7" Casing Annulus TOC calculated @ 4400' KB 4-1/2" Casing Annulus estimated TOC @ 7750' KB Baker 4-1/2" Midstrino ZXP Packer. Packer top @ 7433' MD16637' TVD. 4-1/2" Short Joint Locations: 9206.5' - 9246.2' MD 9990.5' - 10030.3' MD 1-3/4" Velocity Strina: 7940' MD 7997'- 8011' MD (14') 3-3/8" 6 spf 7139'-7152' TVD 12/17/2004 -------------------------------------------------------------------------------------- 8103'- 8123' MD (20') 3-3/8" 6 spf 7239'-7258' TVD 12/16/2004 -------------------------------------------------------------------------------------- Cast iron Bridç¡e Plu!:!: 8470' MD 8315'- 8323' MD (18) 3-318" 6 spf 7442'-7450' TVD 12/17/2004 -------------------------------------------------------------------------------------- 8494'- 8504' MD (10') 3-3/8" 6 spf 7616'-7626' TVD 12/16/2004 -------------------------------------------------------------------------.,------------ 9317'- 9327' MD (10') 3-3/8" 6 spf 8436'-8446' TVD 12/16/2004 -------------------------------------------------------------------------------------- 9345'- 9355' MD (10') 3-318" 6 spf 8464'-8474' TVD 12/16/2004 PBTD (Top offloat collar) 10.490' MD/9608' TVD BHl: 1,285' FNl, 1,092' FWL, Sec. 22, T6N, R9W, 8.M Well Name & Number: West Fork 3 I Lease 1 West Fork County or Parish: Kenai I StateJProv. I Alaska Country: USA Date Completed: 12/17/041 RKB: 1317' Prepared By: Ken Waish 1 Last Revision Date: 12117/04 KDW I Last Revision Date: 08/27/05 MAM Legal Well Name: Common Well Name: Event Date Report 'Date 1/17/2005 1/18/2005 1/19/2005 1/24/2005 1/25/2005 8/17/2005 8/20/2005 WEST FORK 3 WEST FORK 3 Sub Code 2.63 LOG OTHR 0.83 RUNPU ELEC 1.00 RURD_ ELEC 10.00 RURD_ EQIP Event From - 18:32 - 21:10 21:10 - 22:00 22:00 - 23:00 07:00 - 17:00 07:00 - 18:00 07:00 - 18:00 07:00 - 18:00 07:00 - 18:00 10:40 - 11:00 11 :00 - 11 :55 11 :55 - 13:00 13:00 - 16:20 16:20 - 18:00 07:30 - 07:55 07:55 - 09:15 09:15 - 11 :10 11:10-12:0 12:00- .15 14:1 - 14:35 14:35- 15:30 15:30 - 16:45 11.00 11.00 11.00 11.00 / 0.33 SAFETY G_ 0.92 R=URD SLlK 1.08 RU SLlK 3.33 R PU SLlK 1.67 ~RURD_ SLlK O. SAFETY MTG_ ,/1.33 RURD ELEC / 1.92 RUNPU ELEC 0.83 RURD_ ELEC 2.25 WAlTON EQIP 0.33 SAFETY MTG_ 0.92 RURD_ SLlK 1.25 RUNPU SLlK Phase CMPFLW CMPFLW CMPFLW CMPFLW SLICK SLICK SLICK SLICK SLICK WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN 16:45 - 17:45 1.00 RUNPU WRLN 17:45 - 18:30 0.75 RURD_ WRLN 9/14/2005 09:00 - 09:45 0.75 09:45 - 10:25 0.67 10:25 - 11 :00 0.58 11 :00 - 11 :30 0.50 11 :30 - 12:45 1.25 12:45 - 13:15 0.50 13:15 - 14:30 1.25 14:30 - 15:30 1.00 15:30 - 16:10 0.67 Marathon Oil Compåny Operations Summary Report - Page 5 of 8 Spud Date: 9/27/2004 Event Type --1-- Objective SideT@c#~..'¡-- Description of Operations Log 50'/min, 75'/ . ,100'/min up and down passes from 7900' - 9458'. Well rate 3.3MM average, FWHP = 1745 psi. POH PL T tools Verify data re very and RD Expro. OH --/-- loader and thaw unit, break out ice and rack up all flow back equipment. PWS continue with rigging down the test e . ment over the next three days. Move glycol to gas field. OH -/-- Mlloader and thaw unit, break out ice and rack up all flow back equipment. PWS continue with rigging down the t t equipment over the next three days. Vetco Grayout set BPV and pulled the 10k tree and replaced with a permenent tree. OH --/-- Mlloader and thaw unit, break out ice and rack up all flow back equipment. PWS continue with rigging down the test equipment over the next three days. Vetco Grayout set BPV and pulled the 10k tree and replaced with a permenent tree. OH --/-- Mlloader and thaw unit, break out ice to pick up liner and felt on pad OH --/-- Mlloader and thaw unit, break out ice to pick up liner and felt on pad OH --/-- PJSM and sign permit. RUPollard wireline. SITHP = 2500 psi. Run 2:2p" DD bailer. Tag TD at 10,088. Recover formation sand. Run P/Tmemory gauges from 9400' to surface. Good data recovery. RD Pollard à'hQleave location. OH --/-- PJSM'~'M~ign permit. Spot and RU Expro erìhE).. THP = 1900 psi. RIH 3.625" junk basket. Thgged at 8009'. Unable to work down. POH. RD and release Expro. THP = 2050 psi. Wait on Slickline truck. PJSM and sign permit. RU Pollard wireline. THP = 2100 psi. Rigged up slickline and ran 2.25" dd bailer. Tagged at 9588'. Worked down to 9602' and POH. Recovered full bailer of formation sand. Ran 3.70" gauge ring. tagged at 9601'. Rigged down and released Pollard Wireline. OH --/-- Move in rig up wireline unit. Held PJSM prior to setting up on well. Discussed the arming of the bridge plug setting tool. Shut off all phones and radios prior to arming setting tool. MU 3.5" bridge plug with a 3.25" stem, 3" setting tool. WHP= 2150 psig. RIH with plug down to 7500' correct depth to CBL and continue down hole with plug. Tried to work plug down hole with no progress. POOH When tools 200' below surface went to communication black out on pad. Blew down lubricator and broke down tool string. Pulled off the 3.25" weight bar with 2ea 1 11/16" weight bar. Pickup plug and go to well with modified tool strring. Open well. RIH with plug. Correlated depth to CBL for well. Continued down well plug sat down at 8020' below perforations. Tried to work tool string below spot where setting down with no progress. POOH with plug. Discussed other options with crew, decided to pull one of the 1 11/16" weight bars out of tool string and try to get down with shorter tool string. . Printed: 1/9/2006 10:16:49 AM Legal Well Name: Common Well Name: Event Date Report Date 9/17/2005 9/24/2005 11/15/2005 11/16/2005 19:30 - 20:00 0.50 08:00 - 08:25 0.42 SAFETY MTG_ SLICK 08:25 - 10:20 1.92 RURD SLlK SLICK 10:20 - 12:45 2.42 RUNPUl SLlK SLICK 12:45 - 14:20 1.58 RUNPUl SLlK SLICK 14:20 - 16:20 2.00 RUNPUl SLlK SLICK 16:20 - 17:40 1.33 RUNPUl SLlK SLICK 17:40 - 18:45 1.08 RUNPUl SLlK SLICK 18:45 - 20:00 1.25 RUNPUl SLlK SLICK 20:00 - 21 :00 1.00 RURD - SLlK SLICK 08:30 - 09:00 0.50 SAFETY MTG_ WRLN 09:00 - 10:30 1.50 RURD ELEC WRLN 10:30 - 12:17 1.78 RUNPUl ELEC WRLN 12:17 - 13:15 0.97 RUNPUl ELEC WRLN 13:15 - 15:00 1.75 RURD ELEC WRLN 15:00 - 16:45 1.75 RUNPUl ELEC WRLN 16:45 - 18:00 1.25 RURO - ELEC WRLN 13:00 - 13:30 0.50 SAFETY MTG_ CTBG 13:30 - 18:00 4.50 RURD_ COIL CTBG 18:00 - 18:30 0.50 RURD - COIL CTBG 07:00 - 07:30 0.50 SAFETY MTG_ CTBG 07:30 - 12:20 4.83 RURD - COIL CTBG 12:20 - 14:00 1.67 RURO - COIL CTBG 14:00 - 14:40 0.67 TEST_ BOPE CTBG 14:40 - 15:50 1.17 BLOWD COIL CTBG 15:50 - 17:51 2.02 RURD COIL CTBG 17:51 - 18:35 0.73 RUNPUl COIL CTBG 18:35 - 21 :00 2.42 RUNPUl COIL CTBG 21 :00 - 22:20 1.33 RURD - COIL CTBG 22:20 - 22:45 0.42 SAFETY MTG_ CTBG 22:45 - 23:30 0.75 RURD SLlK CTBG 23:30 - 00:30 1.00 RUNPUl SLlK CTBG 00:30 - 01 :35 1.08 RUNPUl SLlK CTBG 01:35 - 03:15 1.67 RUNPUl SLlK CTBG Event FromS'To 16:10 - 16:30 16:30 - 17:20 17:20 - 18:20 18:20 - 19:30 Hours WEST FORK 3 WEST FORK 3 '. Sub Code Code 0.33 0.83 1.00 1.17 Marathon Oil Company Operations Summary Report.. Pervvell Page60f 8 Spud Date: 9/27/2004 Phase EvøÌ'lt fypè ·....I-~()bjective SideTrack- --/-- Description of Operations .... ...... Tool string 200' below surface went to communication black out. Blew down lubricator and layed plug down. Removed 1- 7' 1 11/16" weight bars. PU tool string and went to well with plug. RIH with shorter string, sat down 22' below at 8022' DIL tired to work plug below with no progress. POOH with plug. Tool at 200' went to communication black out, shut in well blew down lubricator and layed down tool string, disarmed setting tool and RD. Cleaned up around well head, Expro left lease. OH --/-- Held PJSM, issue permit. Move in rig up Pollard wireline unit. RIH 3.80" Swab mandrel w/o swab cups. Tag at 8032'. POH RIH 3.74" gauge cutter. Work past tight spots at 8032' and 8302'. Tag TO at 9607'. POH RIH 3.80" Swab mandrel w/o swab cups. Work past tight spots at 8032' and 8302'. RIH to 8525'. POH RIH 5' of 3-3/8" dummy gun and 7' of 2-1/8" stem. Tag at 8015'. Unable to work down. POH. RIH 5' of 3-3/8" dummy gun and 7' of 2-1/8" stem plus knuckle joint. Tag at 8017'. Unable to work down. POH. RIH 3.75' of 3.02" and 7' of 2-1/8" stem. gauge cutter. Work from 8025' to 8043'. Dropped through. Able to work through with 6-7 jar licks each time. POH Rig down and release Pollard. OH --/-- Held PJSM prior to setting up on well. Discussed the arming of the bridge plug setting tool. MIRU Expro eline unit RIH 3" Magna-Range bridge plug and set at 8470' CCL. POH. Left setting tool on bottom. Call for Overshot to fish setting tool. Fish setting tool. Full recovery. RD and release Expro. OH --/-- Held PJSM and discussed rigup. Start Spotting equipment. RU hard lines and all hydraulics. Secure location for night. OH --/-- Held PJSM and discussed rigup. Finish Rig up. Stab velocity string in injector. Pulp roto pig through CT. Full BOP test, 250 psi /4500 psi. Good test. Cool down N2 and purge CT. Unstab injector. MU velocity string BHA (5' straight bar, nipple, WEG). Stab back on and perform shell test. RIH velocity string to 7980'. Pick up to 7968' to cut and install hanger. Cut 1.75" Velocity string. MU slip connector and hanger on V-string. MU dimple on connector and GS pulling tool on CT. Latch V-string and lower into tubing spool. Tighten hold downs and p-test to 5000 psi. Release CT. Purge CT and rig back for wireline. Hold safety meeting. Spot and RU slickline unit. RIH 1.25" JDC pulling tool. Tag at 385'. Unable to pass. POH. Dump 2.5 gal MeOH down tree. RIH 1.25" JDC and tag at 7981'. Work tool. Unable to latch. POH and check tool. Tool not sheared. RIH 1.25" JOC and tag at 7981 '. Work tool. Unable to latch. POH and check tool. Tool not sheared. . . Printed: 1/9/2006 10:16:49 AM Legal Well Name: Common Well Name: 03:15 - 04:30 04:30 - 05:45 05:45 - 06:10 06:10 - 08:00 11/18/2005 09:00 - 09:20 09:20 - 10:00 10:00 - 11:00 11 :00 - 13:10 13:10 - 14:45 14:45 - 16:10 16:10 - 18:15 18:15 - 20:00 20:00 - 21 :00 11/19/2005 07:00 - 07:45 07:45 - 09:10 09:10 - 09:25 09:25 - 18:05 18:05 - 19:10 19:10 - 21:20 21 :20 - 00:00 00:00 - 03:40 03:40 - 04:20 04:20 - 05:45 11/20/2005 10:00 - 10:20 10:20 -11:30 11 :30 - 12:45 12:45 - 19:45 19:45 - 21:30 21 :30 - 22:00 11/22/2005 08:00 - 08:30 08:30 - 12:20 12:20 - 12:40 12:40 - 13:50 13:50 - 15:50 15:50 - 19:20 19:20 - 20:00 11/23/2005 07:00 - 08:00 WEST FORK 3 WEST FORK 3 Hours Phase SLlK CTBG SLlK CTBG 1.83 RURD SLlK CTBG 0.33 SAFETY MTG_ CTBG 0.67 RURD_ SLlK CTBG 1.00 RUNPU SLlK CTBG 2.17 RUNPU SLlK CTBG 1.58 RUNPU SLlK CTBG 1.42 RUNPU SLlK CTBG 2.08 RUNPU SLlK CTBG 1.75 RUNPU SLlK CTBG 1.00 RURD - SLlK CTBG 0.75 SAFETY MTG_ CTBG 1.42 RURD - COIL CTBG 0.25 RURD - COIL CTBG 8.67 RURD - COIL CTBG 1.08 RUNPU COIL CTBG 2.17 RURD - COIL CTBG 2.67 CTBG 3.67 CTBG CTBG CTBG CTBG CTBG CTBG CTBG 1.75 RUNPU SLlK CTBG 0.50 RURD SLlK CTBG 0.50 SAFETY MTG_ CTBG 3.83 RURD - COIL CTBG 0.33 RURD - COIL CTBG 1.17 RURD - COIL CTBG 2.00 RURD - COIL CTBG 3.50 RURD - COIL CTBG 0.67 RURD - COIL CTBG 1.00 SAFETY MTG_ CTBG Marathon Oil Company Operations Summary Reporr":Per Well 70fB 9/27/2004 Event Type SideTrack- --/-- Description of Operations RIH undersize 1.25" SB pulling tool. and tag at 7981'. Work tool. Unable to latch. POH. RIH 1.25" pump bailer. recovered 3" of dirty sand from bailer. RIH undersize 1.25" SB pulling tool. and tag at 7981'. Work tool. Unable to latch. POH Rig back slickline and leave location. OH --/-- Hold safety meeting. Spot and RU slickline unit. RIH 1.25" pump bailer. Bailer almost empty. Run 1.25" LIB. Impression is .5" X .75" with sharp, curved top and bottom. RIH 1.375" SB. No recovery. RIH 1" magnet. No recovery. RIH 1.25" stem wirth open box on bottom. No recovery. RIH 1.25" hydrostatic bailer. No recovery. Rig down slickline. OH --/-- Hold safety meeting. RU Ct and stab onto well. Shell test BOP. Latch velocity string on second attempt. PU and cut our GS tools string and hanger. Attach Ct with roll on connector and walk back down onto tree. POH CT. Break off BHA. Stab back on and circulate 40 Bbls 50/50 to flush CT. Purge CT. Clean rust and solids from above plug. PU BHA and make back up to tree. RIH Velocity string Close pipe rams and blled off. Cut CT and MU hanger assembly and GS spear. Stab spear onto Hanger and walk injector back down and MU lubricator. Equalize and open pipe rams. Land hanger and lock down. Pressure test hanger to 5000 psi. Good test. Release spear and pull into lubricator. Rig back CT and release crew. OH --/-- Hold safety meeting. RU Slickline unit. Run 1.25" JDC pulling tool to 7957'. Unable to latch plug. Run 1.25" SS pulling tool. Latched plug. Jarred on plug up and down for 7 hours. Unable to release plug. Unable to shear out tool. Unable to shear dogs off of tool. Dropped 2 cutter bars with no success. Cut wire at surface. Rig down Pollard wireline and left location. OH --/-- Hold safety meeting. Rig up Ct to pull V-string Shell test to 1000 psi. Latch V-string and PU 12'. Set pipe rams amnd pull test. Release GS by pumping 2 BPM. Bleed V-string. hydrating off in Lubricator. Pump 1 bbl MeOH and tent up Lubricator and heat BOP. Relatch V-string and open Pipe rams. RIH and hang off V-string to secure well for night. Rig back Ct and secure well for night. OH --1-- Start equipment then hold safety meeting. . Printed: 1/9/2006 10:16:49 AM Legal Well Name: Common Well Name: Event Date Report Date 11/29/2005 Event From - To 08:00 - 08:48 08:48 - 09:00 09:00 - 10:12 10:12 - 10:50 10:50 - 13:00 13:00 - 14:22 14:22 - 16:00 16:00 - 16:50 16:50 - 17:50 17:50 - 20:00 20:00 - 21 :30 21 :30 - 22:56 22:56 - 23:35 23:35 - 01 :30 09:30 - 10:00 10:00 - 14:15 14:15 - 15:15 15:15 - 16:15 16:15 - 16:45 16:45 - 17:30 WEST FORK 3 WEST FORK 3 Hours Code 0.80 RURD_ COIL 0.20 RURD_ COIL 1.20 RURD_ COIL 0.63 RURD_ COIL 2.17 RURD_ COIL 1.37 RUNPU COIL 1.63 RURD_ COIL 0.83 RURD_ COIL 1.00 RURD_ COIL 2.17 RUNPU COIL 1.50 RURD_ COIL 1.43 RURD_ COIL 0.65 RURD_ COIL 1.92 RURD_ COIL 0.50 SAFETY MTG_ 4.25 RURD_ SLlK 1.00 RUNPU SLlK 1.00 RUNPU SLlK 0.50 RUNPU 0.75 Sub Code Phase CTBG CTBG CTBG CTBG CTBG CTBG CTBG CTBG CTBG CTBG CTBG CTBG CTBG CTBG CTBG CTBG CTBG CTBG CTBG CTBG . Marathon..Oil Company Op$rãtions Summary Report- Per Well Page B ofB Spud Date: 9/27/2004 Event Type .-1.. Objective SideTrack- --1-- Description of Operations Rig up Ct to pull V-string Shell test to 1000 psi. Latch V-string and PU 12'. Set pipe rams amnd pull test. Release GS by pumping 2 BPM. Bleed V-string and unstab injector head., Cut off hanger and MU roll on connector. Restab injector and P-test to 1000 psi. POH V-string. Close well and bleed off. Break off BHA and recover all tools and cutter bars. Wire broke while pulling tool from CT. Stab back on tree to purge CT. Purge CT MU CT BHA. LD excess lubricator and stab on well. RIH V- string until rollon connector is in chains. Bleed down. Walk up ijnjector and cut pipe. MU hanger on V-string and GS on CT. Stab injector. Equalize across BOP. RIH 12' and hang off V-string at 7940' CTMD. Lock hanger and test to 5000 psi. Release GS spear and bleed V-string to 0 psi. Rig back Ct and leave location. OH --/-- Start equipment then hold safety meeting. Thaw equipment and RU slickline. RIH wire finder / retriever. Tag wire at 38'. Unable to catch wire. Tool is sticking and requires jarring free. POH. RIH wire spear. Work down and catch wire 6 times. Pull wire above BOP. Close BOP rams and open lubricator. Clamp wire and RU to spool wire. POH all wire. Wire has marks from both wire cutters confirming that all wire is retrieved. RD and release Pollard Wireline. . Printed: 1/9/2006 10:16:49 AM . ~. ~ i~,~.. '¡r"" r;::.J . ii ! U.","" 1 i.'.' ..N....,. ". i1.,. '. '1 '. "'."'- 1 ¡ 11 " ¡ "'\ '1 In, ·U" ~ M~"'~ ~) tk.l1 ì ij' ,~ ~UlrllJ,b P¡nì r~ ii. i.. I. ¡ ',' '.:"" , ,'j ¡" 'JdJU e l i J I ¡ FRANK H. MURKOWSKI, GOVERNOR / ¡ I ¡ í 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ALASKA OIL AlVD GAS CONSERVATION COMMISSION Michael Mullin Advanced Production Engineer Marathon Oil Company P.O. Box 1949 Kenai, Alaska 99611-1949 Re: West Fork #3 Sund¡y Number: 305-249 Dear Mr. Mullin: Enclosed is the approved Application for Sund¡y 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 oliday or weekend. A person may not appeal a Commission decisio to perior Court unless rehearing has been requested. DATED thisc3?day of month, 2005 Encl. Rug 27 05 10:22a e . p.2 ,4 Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 Aug 29, 2005 Winton Aubert State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Reference: Application for Sundry Approval Field: West Fork Well: West Fork #3 Dear Mr. Aubert, Enclosed please find a Application for Sundry Approval, along with the associated attachments for the West Fork 3. We will be setting a plug above the bottom 3 intervals to eliminate water pro~~n nd bring the well back on to production. We intend to set the plug on Wednesday ug 3 t if it is possible to have approval by then. After the plug is set we will evaluate t (j, ~ults and continue work as per the attached Summary of Proposal. If you require further information, please contact me. Sincerely, ~~æd Advanced Production Engineer' Telephone: 907-398-9954 Email: MAMullin@MarathonOil.com Attachments: Form 403 Summary of Proposal Proposed well bore diagram · cni-WS !)rs ~( STATE OF ALASKA J</< í» ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 /JJC> /1 i ¡l'¡lOO') p.3 Rug 27 05 10:22a e ~ f~, 'l ~~. .~ 1. Type of Request: Abandon Suspend Repair well 0 Pull Tubing 0 Operational shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: CW<IiVff Stimulate 0 Time Extensieh!8· Re-enter Suspended Well 0 Run V String 5. Permit to Drill Number: Alter casing 0 Change approved program 0 2. Operator Name: MARATHON OIL COMPANY 3. Address: P. O. Box 1949, Kenai, AK 99611-1949 7.KB Elevation (ft): 317" Development D Stratigraphic 0 /' Exploratory 0 204--156 Service 0 6. API Number: 50-133-20543-01 8. Property Designation: C-060898 11. Total Depth MD (ft): 10620' MD Total Depth TVD (ft): 9737' TVD 9. Well Name and Number: West Fork #3 10. Field/Pools(s): West ForkJTyonek PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 10490' 960S' Plugs (measured): Junk (measured): Casing Structural Cond uctor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 7997 - 9355 / 7131 - 8465 Packers and SSSV Type: N/A Length Size 28' 36" 101' 20" 2185' 9-5/8" 7693' 7" 10620' 4/1/2" O' 0 TVD Burst Collapse 28' 28' N/A N/A 101' 101' 3060 psi 1500 psi 2185' 2185' 6870 psi 4750 psi 7693' 6863' 7240 psi 5410 psi 10620' 9737' 8430 psi 7500 psi 0' 0' Tubing Size: Tubing Grade: Tubing MD (ft): 12. Attachments: Description Summary of Proposal ./ Detailed Operations Program 0 BOP Sketch 0 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 Michael A. Mullin Printed Name Mi hae! A. ullin Title Advanced Production Engineer Signaturlr-'""-::? Phone 907-398-9954 Date 8/29/2005 COMMISSION USE ONLY 8/31/2005 / 13. Well Class after proposed work: Exploratory D Development D Service 0 15. WeB Status after proposed work: ./ Oil 0 Gas D Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -3ðS--';;'- t/~ Plug Integrity 0 BOP Test D Mechanical Integrity Test D Location Clearance 0 Other: RBDMS 8FL AUG ~1 (} 2005 COMMISSIONER BY ORDER OF THE COMMISSION Date: I.NSTR,.U. CT 10,. ~NS,..O. ~...R E..VErE a Q î ,<I".~ ¡ " I .~ ,Ii" ,.. \'-'1\,\\' ~ \ \_J I I Rug 27 05 10:23a e . p.4 p Marathon Oil Company Marathon Oil Company Alaska Region WF#3 West Fork Plugback and Coiled Tubing Velocity String History: WF #3 was brought onto production August I S\ 2005 at around 6MM per day. . ~/ On August lSth, during the stabilization period, the production fell from 5.S MMlday to 1.5 MMlday. After static and flowing surveys it is apparent that the loss of production is from the T-S sand. It is also apparent that no gas is being produced from the 3 deepest intervals and they are possibly contributing 12 BPD water production that has remained ~ constant in spite ofthe gas rate change. Obiective: Plug bottom zones to reduce water production. Reperforate and if necessary stimulate T-5 (8315 - 8323) to restore lost production, Run 1.75" coiled tubing velocity /" string to keep the well unloaded. Outline Procedure: 1. MIRV Expro. 2. Run CIBP and set at 8470' MD ./ 3. Test well for 3 days and evaluate results ofCIBP. 4. If deemed necessary, RU BJ and unload well wíth CT and nitrogen. 5. MIRV Expro. 6. Reperforate Tyonek T-5 (8315 - 8323' MD) ~ 7. Test well. 8. If necessary, Acidize T -5 as per separate program. / 9. Install coiled tubing spool and piping. 10. RU BJ coiled tubing 11. Run 1-3/4" coiled tubing velocity string and hang of at 7950' MD. / 12. RD BJ /' 13. Unload and test well. Cel Contacts: Work Phone Mickey Mullin 283-1337 398-9954 Rug 27 05 10:23a e '7 p West Fork #3 West Fork Field 1981' FNL, 1919' FEL, Sec. 6, T6N, R9W, SM X: 345130,584 Zone 4 Y: 2,411.693,656 Zone 4 GL: 135' KB: 317' (21' AGL) SPUD: 1 5:30hrs 09/28f.2004 TD: 10117/2004 Ria Rel.ased: 12:00 hrs 10/2812004 4.1/2" 12.6 ppf L-BO Hydril 563 Casing " ~ 7" X 4·1/2" annulus filled with 10.7 ppg mud containing Conquor " API # 50-133-20543·00 Permit # 204-156 WBS # DX,04.1 04SS.CAP.CMP .02 Property: C~6089B '- KOP @ 2200' Build 3.0 deg/100' Hold 36 dog from 2200'·5400' KB Hold 34 deg from 5400'·7181' Drop 2.25 deg/100' to 9151' KB Inclination at TD~ 3.5 deg Azimuth: 77·79 deg, To 8780' MD & 106·119 deg. TO TO ! 4-1/2" Short Joint locations: 9206,5' - 9246.2' MD 9990.5' - 10030,3' MD 1-3/4" Proposed Velocity Strin~: 7950' MD Proposed Cast iron BridQe Pluq: 8470' MD - ," r. ~ o.".i"h¡ ... '.. ~~.: ~.t ~ ..: : : .. :...'< I "'~..:., . , ~~ ? ~~.~< ~. ,¿ PBTD (Top of float collar) 10,490' MD19608' TVD . p.5 ('. ~ i ., ,- " , . " .' '. <, ',. " ,~., ~. '", ,~ ,. " " ,. t' 20" 133 ppf K-55 driven to 101' MDfTVO 1/4" 000.049" wall Chemi",,1 injection string tied Into Chemica/Injection Nipple top at 2418' w/double check valve and rupture discs Surface CasinQ: 9·5/a" 47 ppf L-80 Mod.Buttress @ 2185' MD/2185' TVD Cmt'd w/533si<s (238 bbls.) 12 ppg CI<iss G in a 12-1/4" hole. (Recovered 5 bbls cement to surface), Bumped plug -floats held, T' Casing Annulus TOC calculated @ 4400' KB 4-1/2" Casing Annulus estimated TOC @ 7750' KB Baker 4-112" Midstrino ZXP Packer. Packer top @ 7433' MD1663T TVO Intermediate Casim:¡: 7" 26 ppl, L-80, Modified Buttress trom 0'-7740' MO/8905' TVD Cmfd w/184 sks (82.S bbls) Class G lead cement (12.5 ppg) in an 8-1/2" hole followed wl162 sks (32 bbls) Class G tail cement (15.8 ppg) in an 8-112" hole. (Recovered 20 bbls of cement to surface). Did not bump plug"floats held, rl!ðr.(>~{ P<1:-Jor8t:ons: 7997'- 8011' MD (14') 3-3/8"" spf 7131'-7144' NO 12/17/2004 -----_._---...-.__._------~---~---------......~--------~---._..-~--.._----- 80103'- 8123' MO (20') 3-3/8" 6 .pf 7230'-7249' TVO 12/16/2004 ._---.._---.._~--------_......_-_.--------------------------_._--.....--- 8315'- 8323' MO (18) 3-318" 6.pl 7435'-7443' NO 12/1712004 --..-----....-----.-----.-----------...----......-------------------- 841>4'· 8504' MO (10') 3·3/8" 6 spf 7609'-7619' TVO 12/1612004 ---------------_..--_....."'"---_._~-------------........_-_..-----------...---..- 9317'- 9327' MO (10') 3-3/8" 6 spf 8427'-8437' ND 12/16/2004 -----------------~-~-----_.._----_..-------~------~--~------------- 9345'- 9355' MO (10') 3-3/8" 6 spf 8455'-8465' TVD 12/16/2004 . , .. -.------.---.. Production Casina: 4-112" 12.6 ppf L.$OHydri 563 0' -10,620' MDJ9,737' TVD / Cmfd wf550 si<s 13.5 ppg (178 bbls) in T hole. Displaced with 155 bbl$. 6%KCL water. Bumped plug with 3100 psi. Applied pressure to 5000 psi to set mldstring paCker. . Circulated no cemert! to surface. BHL: 1,285' FNL, 1,092' FWL, Sec. 22, T6N, R9W, S.M -"~..- ----. .--- ..--.- ... _..,--~-------~----~--~--- ----~------~._----_.---- Well Name & Number: West Fork " T Lease I West For~ County or Parish: Kenai I SIate/Prov, I AlaSka Country: USA Date Camðleted: 12/171051" RKB: 1317' Prepared By: Ken Watsh 1 Lasl Revision Da1e: 12/17105 KOW Last Revision D.a:e: 08/27/05 MAM . dtJ)f- t5Cp . Alaska Asset Team Northern Business Unit Marathon Oil Company P.O. Box 1949 Kenai, AK 99611-1949 Telephone 907/283-1311 Fax 907/283-1350 June 9, 2005 Winton Aubert AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr. Aubert: Attached and submitted for your records is the Form 10-407 for the completion work performed in the West Fork #3. This well is currently shut in waiting on facilities ' installation. Also attached for your records are the operational history, final directional sUNey, and well schematic. If you would like any other information, please contact me at 283-1311 or kdwalsh@marathonoil.com. Sincerely, l~b.w~ Ken D. Walsh Senior Production Engineer Enclosures L · STATE OF ALASKA __ , ALASKA AND GAS CONSERVATION COMMIS~, ," WELL COMPLETION OR RECOMPLETION REPORT AND LGGJ ~ 1a. Well Status: OilU Gas~ Plugged U Abandoned U Suspended 0 WAGU 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 'Ëxðlor~to~¡j GINJD WINJD WDSPL 0 No. of Completions Other Service 0 Stratigraphic: Te~tõ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: MARATHON OIL COMPANY Aband.:January 11, 2005 204-156 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 1949, Kenai, AK 99611-1949 September 28,2004 50-133-20543-00-00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1981' FNL & 1919' FEL Sec. 21 T6N-R9W October 17, 2004 West Fork #3 Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): 1319' FNL & 900' FWL Sec. 22 T6N-R9W 317' (21' AGL) West ForklTyonek Total Depth: 9. Plug Back Depth(MD+TVD): 1305' FNL & 1157' FWL See 22 T6N-R9W 10490' 9608' 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 345131 y- 2411694 Zone- 4 10620' MD 9737' TVD C-060898 TPI: x- 347949 y- 2412356 Zone- 4 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 348207 y- 2412370 Zone- 4 18. Directional Survey: Yes ~ No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost: feet MSL 21. Logs Run: Reeves Quad Combo and pressure tests. Schlumberger DSI and Velocity Survey. 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 36" 0' 28' 0' 28' N/A 20" 133# K-55 0' 101' 0' 101' 26" N/A 9-5/8" 47# L-80 0' 2185' 0' 2185' 12-1/4" in place, 533 sx N/A 7" 26# L-80 0' 7740' 0' 6905' 8-1/2" in place, 346 sx N/A 4/1/2" 12.6# L-80 0' 10620' 0' 9737' 7" in place, 550 sx N/A N/A 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 7988'- 8002' MD (14') 3-3/8" 6 spf 7131'-7144' TVD N/A 8094'- 8114' MD (20') 3-3/8" 6 spf 7230'-7249' TVD 8308'- 8316' MD (18) 3-3/8" 6 spf 7435'-7443' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8486'- 8496' MD (10') 3-3/8" 6 spf 7609'-7619' TVD 9308'- 9318' MD (10') 3-3/8" 6 spf 8427'-8437' TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9336'- 9346' MD (10') 3-3/8" 6 spf 8455'-8465' TVD 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: I Gas-Oil Ratio: 12/22/2004 10 Test Period -+0 2684 12.1 54/64" N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 1255 0 24-Hour Rate ..... 0 6442 29 N/A 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". Lithology: I ed~dstone, shale, and coal ~i RBDMS BFL JUN 2 0 2005 I. /) ,¡ lED ! e- ' ORit~¡t"~J\L . . ../ ~ GY Form 10-407 Revised 12/2003 CONTINUED ON REVERSE G Sterling Gas Beluga Tyonek 4657 6183 7911 29. ORMATION TESTS TVD Include and briefly su e test results. List intervals tested, and attach detailed supporting data necessary. If no tests were conducted, state 4361 "None". 5604 12/17/2004 7059 Perf: 9336-9346 SI N2 Cush 1135#WHP SIWHP increased to 1160# in 90 min Add Perf: 9308-9318 SIWHP 1160# increased to 1190# in 15 min. Add Perf: 8486-8496 SIWHP 1160# increased to 1180# in 15 min. Bled WHP from 1200# to 1050# Add Perf: 8094-8114 Well built to 1110# in 30 min. Perfw/1110# WHP SIFN, SIWHP increased from 1160# to 1575# in 6 hours. 12/18/2004 Bled well down from SIWHP 1575# to 1060# Add Perf: 8308-8316 SIWHP increased to 2000# in 15 min. increased to 3600# after 30 min. Opened well to flow while POOH w/ guns. Add Perf: 7988-8002 SIWHP 2250# built to 2600# in 15 min. Flowed 6.63 MMCFPD @ 2300# WHP 28. NAME GEOLOGIC MARKERS M 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ken D. Walsh Printed Name: Ken D. Walsh t~ 'D. ~0(~ Title: Senior Production Engineer Signature: Phone: (907) 283-1311 Date: 6/9/2005 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 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 prod 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 in 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 . . Marathon Oil Company Page 1 of 4 Operations Summary Report Legal Well Name: WEST FORK 3 Common Well Name: WEST FORK 3 Spud Date: 9/27/2004 Event Name: ORIGINAL COMPLETION Start: 11/24/2004 End: Contractor Name: GLACIER DRILLLlNG Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours COdØ Sub Phase Description of Operati~ns Code 11/24/2004 08:00 - 10:10 2.17 RURD_ ELEC WBPREP MI RU Vetco pulled back pressure valve prior to RU Expro. Move in E-line unit and RU on well. MU 1 11/16" slim hole bond tool to run CBL. Held safety and environmental meeting prior to Rigging up. Had PJSM with crew. 10:10 - 15:30 5.33 LOG_ CSG - WBPREP RIH to bottom of well. Displaced hole fluids to barrel on way in well. Tagged fill at 10483' ELM. Logged up hole to 7400' Had problems with tool. Made several tries to calibrate the tool with no success. Pulled a strip with tool at 4500' to try and see if tool read out looked like in free pipe. Logging tool will need to be shipped to Canada for repairs. 15:30 - 17:30 2.00 RURD - ELEC WBPREP POOH with tool. OOH Rig down unit and leave site. 12/2/2004 09:30 - 10:15 0.75 WBPREP MI RU wire line unit. Held PJSM and discussed safety issues around the well head. 10:15-11:15 1.00 WBPREP Made path for walking on ice and sanded. MU the pressure pump with Methanol. Set up the air compressor to pump. Equipment ready to pressure up on well to make pressure logging pass. 11:15-12:00 0.75 WBPREP PU 2.25" MSS sonic tool. Udelhoven on location with boom truck to hold sheave. RIH to 7500'. 12:00 - 13:00 1.00 WBPREP Start up hole logging at 30 FPM to calibrate free pipe signal. Logged up to 7100'. 13:00 - 15:00 2.00 WBPREP RIH and sat down at 10483' DIL. PUH a 30 FPM logging to to 7100'. 15:00 - 15:20 0.33 WBPREP Found top of cement aroumd 7750' DIL. Drop back down to 10480' to make second pass 15:20 - 15:45 0.42 WBPREP Tool at 10480. Pressure up on tubing to make the pressure pass. Tubing pressure at 300 psig. packoff leaking. tried to stop by pumping up pack off to 2500 psig. 15:45 - 17:30 1.75 WBPREP Contacted Walsh to discuss, decided to forgo the pressure log on well. POOH with tool. POOH 17:30 - 18:00 0.50 WBPREP OOH with tool, secured well and RD unit. Bond log shows good cement accross potential perf intervals. Reeves left lease. 12/8/2004 09:00 - 18:00 9.00 RURD - OTHR CMPPRF Trucks moving equipment from SD #2 pad to WF and spot around pad. Had the road plowed and sanded into the location. 12/9/2004 07:00 - 18:00 11.00 RURD - OTHR CMPPRF Held PJSM. Sat liner and spotted equipment on pad. 12/10/2004 07:00 - 18:00 11.00 RURD - OTHR CMPPRF continue with rigging up the flow back equipment. Set flare stack and hard line ot stack. 12/15/2004 14:00 - 14:30 0.50 SAFETY MTG_ CMPPRF Held PJSM with BJ CoilTech, PWS, Veco, and MOC personnel. Discussed potential hazards and operational plan. 14:30 - 18:00 3.50 TEST _ BOPE CMPPRF MIRU BJ Coil Tech to jet well dry. NU flow cross and CT BOP to tree. MU and pull tested wash nozzle to end of coil tubing. Pressure tested CT BOP rams to 250/4500 psi with methanol water. Could not open swab valve due to pressure lock and no relief tool on location. LD injector head and SDFN. 12/16/2004 08:00 - 09:00 1.00 RURD - COIL CMPPRF BJ CoilTech and Veco crane operator warmed up equipment and took injector head to tree. 09:00 - 09:30 0.50 SAFETY MTG_ CMPPRF Held PJSM with BJ CoilTech, PWS, Veco, and MOC personnel. Discussed potential hazards and operational plan. 09:30 - 10:00 0.50 RURD - COIL CMPPRF Installed pressure relief tool on swab valve and bled off pressure trapped in valve body from previous day CT BOP pressure test. 10:00 -11:30 1.50 TEST_ BOPE CMPPRF Performed shell test on CT BOP and flow back line from wing valve through sand buster and to closed PWS choke manifold to 250/4500 psi with methanol water. Displaced methanol water from coil tubing back to supply tank with nitrogen. 11 :30 - 18:00 6.50 JET_ N2 - CMPPRF RIH with 2" OD bull nose jetting nozzle on 1-3/4" coil tubing to 500' at Printed: 5/31/2005 3:58:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/16/2004 12/17/2004 12/18/2004 . . Marathon Oil Company Opera.tions Summary Report WEST FORK 3 WEST FORK 3 ORIGINAL COMPLETION GLACIER DRILLLlNG GLACIER DRILLING Sub From;' To Hours Code Code Phase 11:30 -18:00 18:00 - 19:30 19:30 - 22:00 10:00 - 10:30 10:30 - 13:00 13:00 - 13:30 13:30 - 14:30 14:30 - 15:00 15:00 - 17:00 17:00 - 17:30 17:30 - 18:30 18:30 - 19:30 19:30 - 20:30 20:30 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 01 :00 08:00 - 08:30 08:30 - 09:30 09:30 - 10:30 6.50 JET _ N2_ CMPPRF 1.50 RUNPU COIL 2.50 RURD_ COIL CMPPRF CMPPRF 0.50 SAFETY MTG_ CMPPRF 2.50 RURD_ COIL CMPPRF 0.50 SAFETY MTG_ CMPPRF 1.00 RURD_ ELEC CMPPRF 0.50 PERF _ ELEC CMPPRF 2.00 PERF _ ELEC CMPPRF 0.50 PERF _ CSG_ CMPPRF 1.00 PERF _ ELEC CMPPRF 1.00 PERF _ CSG_ CMPPRF 1.00 PERF _ ELEC CMPPRF 1.50 PERF _ CSG_ CMPPRF 1.00 PERF _ ELEC CMPPRF 1.00 PERF _ CSG_ CMPPRF 1.00 RURD_ ELEC CMPPRF 0.50 SAFETY MTG_ CMPFLW 1.00 RURD ELEC CMPFLW 1.00 PERF _ ELEC CMPPRF Start: 11/24/2004 Rig Release: Rig Number: 1 Spud Date: 9/27/2004 End: Group: 50 fpm. Brought on nitrogen at 500 scfm and reverse circulated 6% KCL water out of hole while RIH. Increased nitrogen rate to 750 scfm while continuing to RIH taking fluid "bites" at 6700', 7550', 8400, 9250', and tagged PBTD of 10477' CT measurement. Recovered 158 bbls of 159 bbl capacity. POOH with coil tubing. Trapped 1230 psi surface nitrogen pressure. Pump methanol water in lines for freeze protection. RD injector head from tree. Will finish RDMO tomorrow AM. Held PJSM with Veco, BJ CoilTech, PWS, and MOC personnel on location to discuss potential hazards and rig down operations. RDMO BJ Coil Tech coil and nitrogen equipment. Veco roustabouts RD MOC chicksan and valves for coil work and moved to another project. Veco vac truck pulled fluid from BJ lines and transferred 170 bbls 6% KCL water to WL #1 rd coil tubing project. Held PJSM with Expro, PWS, and MOC personnel on location to discuss potential hazards and perforating operational plan. RU Expro perforating equipment. PWS bled down nitrogen pressure from 1200 psi to 1135 psi while Expro rigged up. Armed 10' 3-3/8" carrier and take lubricator to tree. Pressure test lubricator with 1135 psi SIWHP. RIH with 3.375" OD perforating gun loaded 10' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF on CCL. Correlated depth with Reeves GR-CCL log run Dec-2-2004 and MOC composite open hole log supplied by Geology. Perforated 9336-9346' KB with 1135 psi WHP. WHP still at 1135 psi after 15 minutes. POOH with gun. WHP at 1140 psi when out of hole with gun #1. All shots fired and round. Armed 10' 3-3/8" carrier and take lubricator to tree. RI H with 3.375" OD perforating gun loaded 10' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF on CCL. Correlated depth. Perforated 9308-9318' KB with 1160 psi SIWHP. WHP at 1190 psi after 15 minutes. POOH with gun #2. All shots fired and round. Armed 10' 3-3/8" carrier and take lubricator to tree. RI H with 3.375" OD perforating gun loaded 10' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF on CCL. Correlated depth. Perforated 8486-8496' KB with 1160 psi SIWHP. WHP at 1180 psi after 15 minutes. POOH with gun #3. All shots fired and round. Armed 20' 3-3/8" carrier and take lubricator to tree. RIH with 3.375" OD perforating gun loaded 20' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF on CCL. Correlated depth. Bled WHP down from 1200 to 1050 psi. Perforated 8094-8114' KB with 1060 psi SIWHP. WHP at 1110 psi after 15 minutes. Perforating gun temporarily stuck when first starting out of hole. Work gun for 5 minutes and pulled free. POOH with gun #4. All shots fired and round. RD Expro lubricator from wellhead. Left well shut in overnight. Held PJSM with Expro, PWS, and MOC personnel on location to discuss potential hazards and perforating operational plan. SIWHP increased from 1160 psi at 00:00 hrs to 1575 psi at 06:00 hrs on 12/17/2004. Bled pressure down to 1050 psi on 18/64" choke and shut-in. Warmed up equipment. RU Expro lubricator. Armed 8' 3-3/8" carrier and take lubricator to tree. RIH with 3.375" OD Printed: 5/31/2005 3:58:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . Page 3 of 4 Marathon Oil Company Operations Summary Report WEST FORK 3 WEST FORK 3 ORIGINAL COMPLETION GLACIER DRILLLlNG GLACIER DRILLING From - To Hours Code ~tJe Phase Date 12/18/2004 09:30 - 10:30 10:30 - 11 :30 11 :30 - 12:30 1.00 PERF _ ELEC CMPPRF 1.00 REPAIR EQIP CMPPRF 1.00 PERF _ CSG_ CMPPRF 12:30 - 13:30 1.00 PERF - ELEC CMPPRF 13:30 - 15:00 1.50 PERF - CSG_ CMPPRF 15:00 - 16:00 1.00 RURD - ELEC CMPPRF 12/20/2004 08:00 - 08:30 08:30 - 10:30 10:30 - 12:00 12:00 - 13:30 0.50 SAFETY MTG_ PR1EVL 2.00 RURD_ SLlK PR1EVL 1.50 TAG_ BOTM PR1EVL 1.50 SETREL TOOL PR1EVL 13:30 - 14:00 0.50 SETREL TOOL PR1EVL 14:00 - 15:00 1.00 RURD - SLlK PR1EVL 1/5/2005 12:30 - 13:30 1.00 CMPFLW 13:30 - 13:50 0.33 CMPFLW 13:50 - 18:45 4.92 CMPFLW 18:45 - 20:45 2.00 CMPFLW 20:45 - 21 :00 0.25 CMPFLW " ' Start: 11/24/2004 Rig Release: Rig Number: 1 Spud Date: 9/27/2004 End: Group: Description of OperationS;, perforating gun loaded 20' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF on CCL. Correlated depth. Spent one hour thawing and cleaning out Expro packoff grease pump. Perforated 8308-8316' KB with 1060 psi SIWHP. GOOD RESPONSE: WHP climbed to 2000 psi in 15 minutes and to 2600 psi in 30 minutes. POOH with gun #5. All shots fired and round. Opened well to flow on a 16/64" choke while POOH. Pressure built to 2610 after 15 minutes. Opened to a 18/64" choke. Armed 14' 3-3/8" carrier and take lubricator to tree. RI H with 3.375" OD perforating gun loaded 20' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF on CCL. Correlated depth. Perforated 7988-8002' KB with 2250 psi SIWHP. WHP built to 2600 psi after 15 minutes. Began flowing well at 2600 psi. POOH with gun #6. All shots fired and round. RDMO Expro perforators. Put well to flow test through PWS. Well flowing at 2300 psi WHP on a 22/64" choke at 6.63 MMscfd, no fluid and starting to stabilize. Rental air compressor failed. Gas rate is dry gas through a variable choke. Will get more accurate rate when air compressor replaced today and able to go through Daniels Senior meter run. Plan to test for 24 hours and then run tandem pressure gauges on 12/19/2004 to get 4-pt test and PBU. Held PJSM with Pollard, PWS, and MOC personnel to discuss potential hazards and operational plan. Shut well in with final rate at 7.026 MMscfd,1 BWPH (19.2 cum water rec), and 1375 psi FWHP. MIRU Pollard slickline to run gauge ring and then tandem pressure gauges for 4-pt test and PBU. MU 3.75" OD gauge ring to spang jars and stem. Took lubricator to wellhead. Pressure tested lubricator to 2500 psi. RIH with 3.75" gauge ring and tagged fill at 10361' MD. Tag depths prior were 10483' MD with Reeves CBL and 10477' MD with BJ coil tubing. Could not detect a fluid level. No hydrates present. Started tandem electronic pressure/temperature gauge program data recovery at 12:10:09 hrs (upper gauge) and 12:11 :16 hrs (lower gauge) on 12/19/2004. PU and RIH with AD-2 stop and tandem gauges. Set AD-2 stop at 7968' MD (WLM) which places the bottom of the lower gauge at 7978' MD (WLM). POOH with AD-2 setting tool. RDMO Pollard Slickline. Put well to test targeting a stabilized flow rate. Testers instructed to maintain FWHP above 1300 psi maintaining a constant rate throughout flow period. MIRU wire line unit. Held PJSM and discussed the environmental and safety issues around well head. Attempted to blow down tree cap. Problem with valves holding accross the tree. Cycled the valves a couple of times. Swab valve held. Used the WHP to pressure test lubricator. WHP= 2800 psig. No leaks. RIH to retrieve tandem pressure gauges. PU gauges at 7978', Pull out of hole making 5 minute stops at the following TVD depths: 6958', 6869', 6781', 6694', 6609', 6524', 6640', 6274',6068',5862',5045',3827', 1999', surface. OOH with pressure gauges, Checked to see if data on gauges. Data looks good. Continue with RD on wire line unit. Secured wellhead, shut down all light plants. Wire line unit left lease. Data should be forward tomorrow. Printed: 5/31/2005 3:58:07 PM · Page 4 of4 Marathon Oil Comp~ny Operations SummarySß,'epprt 2.88 RURD_ ELEC CMPFLW MIRU wire line unit. Held PJSM and discussed the envirionemental and safety issues around well head. Methonal pump failed. Replace methonal pump. RIH with memory PL T tools. Log 50'/min, 75'/min, 100'/min up and down passes from 7900' - 9458'. Well rate 6.5MM average, FWHP = 1150 psi. Log 50'/min, 75'/min, 100'/min up and down passes from 7900' - 9458'. Well rate 4.8MM average, FWHP = 1460 psi. Log 50'/min, 75'/min, 100'/min up and down passes from 7900' - 9458'. Well rate 3.3MM average, FWHP = 1745 psi. POH PL T tools Verify data recovery and RD Expro. Mlloader and thaw unit, break out ice and rack up all flow back equipment. PWS continue with rigging down the test equipment over the next three days. Move glycol to gas field. Mlloader and thaw unit, break out ice and rack up all flow back equipment. PWS continue with rigging down the test equipment over the next three days. Vetco Grayout set BPV and pulled the 10k tree and replaced with a permenent tree. 11.00 MI loader and thaw unit, break out ice and rack up all flow back equipment. PWS continue with rigging down the test equipment over the next three days. Vetco Grayout set BPV and pulled the 10k tree and replaced with a permenent tree. 11.00 Mlloader and thaw unit, break out ice to pick up liner and felt on pad 11.00 Mlloader and thaw unit, break out ice to pick up liner and felt on pad Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Frorn..To WEST FORK 3 WEST FORK 3 ORIGINAL COMPLETION GLACIER DRILLLlNG GLACIER DRILLING C Sub Hours ode Code Phase 1/11/2005 08:30 - 11 :23 11 :23 - 12:40 1.28 RUNPU ELEC CMPFLW 12:40 - 15:55 3.25 LOG_ OTHR CMPFLW 15:55 - 18:32 2.62 LOG - OTHR CMPFLW 18:32 - 21 :10 2.63 LOG_ OTHR CMPFLW 21 :10 - 22:00 0.83 RUNPU ELEC CMPFLW 22:00 - 23:00 1.00 RURD - ELEC CMPFLW 1/17/2005 07:00 - 17:00 10.00 RURD - EQIP CMPFLW 1/18/2005 07:00 - 18:00 11.00 1/19/2005 07:00 - 18:00 1/24/2005 1/25/2005 07:00 - 18:00 07:00 - 18:00 Start: Rig Release: Rig Number: Spud Date: 9/27/2004 End: Group: 11/24/2004 Description of Operations Printed: 5/31/2005 3:58:07 PM · Page 1 of 2 Marathon Oil Company Operations Summary Report P/U 6 1/8" bit and BHA. RIH(bridge@9312'. Wash and ream). Cont. RIH. Circ. clean(CBUX3, 377gpm, 2136psi, 75RPM, B/U gas 265units). Flow check, well static. Pump dry job. POOH to shoe(hole slick). Service rig. RIH to 10620'. Circ. clean. Flow check. Pump dry job. POOH UD DP. POOH UD 4" DP and BHA. Pull wear bushing. RIU Weatherford CSG tools. PJSM prior to running CSG. M/U and Bakerlok shoe tract 4.5" 12.6ppf L-80 Hydril 563 CSG(3 joints between float shoe and float collar). Circ. through shoe tract and check floats. Cont. to run 4 1/2" CSG. While running CSG hit racking board with TDS. Repair damage to rig. Have safety meeting about incident. Cont. to run 4 1/2" CSG. PJSM with crew coming on. Circ. and RIU Pollard to run hyd control line. P/U 100K, S/O 70K, 250GPM, 725psi. Cont. run 41/2" CSG. M/U injection mandrel and connect control line. Cont. run 41/2" CSG (199 of 251run). Cont. to run 4.5" 12.6PPF L-80 Hydril 563 CSG. Circ. down with lastjoint(hole tight, had to work down). Circ. B/U(251gpm, 1600psi, B/U gas 485units). P/U 10' pup circ. down and tag bottom@10,620'. P/U 125K S/O 75K. LID 10' pup and R/U BJ cement head. Attempt to reciprocate CSG. CSG stuck. Attempt to free. Pipe stuck with shoe@10,620'. Circ. CSG (255gpm, 1515psi). 41/2" CSG shoe @ 10620'. PJSM while circ. and spot 132bbls mud with conqor. Lower pit volume to take cement job returns. Pump 2bbls water ahead. Test lines to 5000psi. Mix and pump 30bbls 10ppg spacer. Mix and pump 550sxs Class"G" cement w/10%BA-90, 2.5%BA-56, .1 %ASA 301, .4% CD-32, .1 %R-3, and 1 ghs FP-6L to yield 178bbls 13.5ppg slurry(PTO on RCM failed 115bbls into cement job, after 30min downtime cone mixer was used to finish cement mixing). Wash up cement lines to washup tank. Drop plug and kick out with 5 bbls water. continue to displace CSG with 155bbls 6%KCL. Bump plug with 3100psi 500psi over last displacement pressure. CIP@ 15:30hrs 10/26/2004. Full returns during job. 1.50 PKRPLG SET PR 1 CSG Continue to pressure up to 4500psi to set ZXP packer. No set. Bleed pressure off and check floats. Continue to attemp to set packer by presuring up to 5000psi 3 times. No indicaion of set. Pressure up to 5000psi and pressure dropped back to 1900psi. Pump .5bbls and attempt to pressure up. Can not pressure up. Shut down pumps. 7.00 WAIT CEMT PR1CSG While WOC: Wash and blow down TDS, choke manifold, standpipe manifold, gas buster, #1 and #2 mud pumps,pickle #3pump, start to empty and clean pits, N/D bell nipple and prep to P/U stack. 1.00 NUND DBOP PR1CSG N/D 135/8" 5M BOP stack. 1.00 NUND UTRE PR1CSG Run injection control line through slips. Set Vetco 4 1/2" X 10 3/4" slips Legal Well Name: WEST FORK 3 Common Well Name: WEST FORK 3 Event Name: ORIGINAL COMPLETION Contractor Name: GLACIER DRILLLlNG Rig Name: GLACIER DRILLING Date From - To Hô4~~/ Code Sub Phase Code 10/25/2004 08:00 - 14:00 6.00 TRIP WTRP PR1EVL 14:00 - 16:00 2.00 CIRC CLN PR1CSG 16:00 - 18:00 2.00 TRIP WTRP PR1CSG 18:00 - 19:00 1.00 RIG SERV PR1CSG 19:00 - 20:00 1.00 TRIP WTRP PR1CSG 20:00 - 22:00 2.00 CIRC CLN PR1CSG 22:00 - 06:00 8.00 TRIP LDDP PR1CSG 10/26/2004 06:00 - 10:30 4.50 TRIP LDDP PR1CSG 10:30 - 11 :00 0.50 EQUIP RURD PR1CSG 11 :00 - 14:00 3.00 CSG RUN PR1CSG 14:00 - 16:00 2.00 CSG RUN PR1CSG 16:00 - 19:30 3.50 CSG RUN PR1CSG 19:30 - 21 :30 2.00 RIG RCNT PR1CSG 21 :30 - 03:30 6.00 CSG RUN PR1CSG 03:30 - 04:30 1.00 CIRC CLN PR1CSG 04:30 - 05:00 0.50 CSG RUN PR1CSG 05:00 - 05:30 0.50 CSG RUN PR1CSG 05:30 - 06:00 0.50 CSG RUN PR1CSG 10/27/2004 06:00 - 08:30 2.50 CSG RUN PR1CSG 08:30 - 10:30 2.00 CSG RUN PR1CSG 10:30 - 11 :00 0.50 CEMT PRIM PR1CSG 11 :00 - 12:00 1.00 CEMT PRIM PR1CSG 12:00 - 13:00 1.00 CEMT PRIM PR1CSG 13:00 - 15:30 2.50 CEMT PRIM PR1CSG 15:30 - 17:00 17:00 - 00:00 00:00 - 01 :00 01 :00 - 02:00 Start: 1 0/24/2004 Rig Release: Rig Number: Spud Date: 9/27/2004 End: 10/29/2004 Group: of Operatrons Printed: 5/31/2005 3:58:30 PM · Marathon Oil Compðny . Operations Summary Rap Legal Well Name: WEST FORK 3 Common Well Name: WEST FORK 3 Event Name: ORIGINAL COMPLETION Contractor Name: GLACIER DRILLLlNG Rig Name: GLACIER DRILLING Date From - To Hours Code Sub Phase Code 10/27/2004 01 :00 - 02:00 1.00 NUND UTRE PR1CSG 02:00 - 03:30 1.50 NUND UTRE PR1CSG 03:30 - 06:00 2.50 NUND UTRE PR1CSG 10/28/2004 06:00 - 07:00 1.00 TEST EQUI PR1CSG 07:00 - 09:30 2.50 TEST CSG PR1CSG 09:30 - 11 :00 1.50 TEST PLGS PR1CSG 11 :00 - 12:00 1.00 TEST CSG PR1CSG 12:00 - 00:00 12.00 RIG RDMO RDMO 00:00 - 06:00 6.00 RIG RDMO RDMO 10/29/2004 06:00 - 12:00 6.00 RIG RDMO RDMO Start: 1 0/24/2004 Rig Release: Rig Number: Spud Date: 9/27/2004 End: 10/29/2004 Group: Description of Operations with 105K. Cut CSG and UD cut joint. Load out BOP stack. Final cut 4 1/2" stub. Set 6 3/16" X 10 9/16" packoff. N/U 11" 5M X 4" 10M TBG head adaptor w/4" 1 OM valve and 4" 1 OM X 4" 5M adaptor spool and 5M Otis tree cap. Test tree void to 5000psi. Set TWC. Test tree to 5000psi. Pull TWC. RlU to test CSG. Test 41/2" CSG to 3000psi/30min. RlU to 41/2" X 7" annulus. Test annulus to 1000psi/30min. Set BPV. Secure well . RID Floor, load out #3 pump, Top drive & rail, Pickel #1 and #2 pumps, Drain test pump, all water lines, Draworks, waterpumps boiler feed pumps, change maxi brake on MP trailer, load out cmt silo, epoch, RID pits and prep for move. PJSM. Crane work, wind walls, out riggers, choke house, flow lines, panic line, fuel tank, stairs, flowline. Scope down mast. Unplug electrical. Crane down: Windwalls, choke and dog house, stairs, fuel tank, derrick house. Load out trailers. Load out pits, pump room and boiler house. Release rig to KBU 42-6 @ 12:00hrs 10/28/2004. Printed: 5/31/2005 3:58:30 PM ..... . . MOC Well Name MD TVD Inclin VS N/ (-) 5 E/ (-) W Az Doalea(0/100ft) BUR (0/100ft) WEST FORK 3 0 0 0 0 0 0 0 0 0 WEST FORK 3 133 133 0.4 -0.19 -0.46 -0.09 191.4 0.3 0.3 WEST FORK 3 253 252.99 0.8 -0.34 -1.68 0.04 165.5 0.39 0.33 WEST FORK 3 375 374.98 0.8 -0.31 -3.33 0.45 166.4 0.01 0 WEST FORK 3 497 496.97 0.7 -0.41 -4.9 0.71 175 0.12 -0.08 WEST FORK 3 617 616.96 0.7 -0.52 -6.35 0.93 167.9 0.07 0 WEST FORK 3 741 740.95 0.9 -0.66 -8.06 1.18 174.5 0.18 0.16 WEST FORK 3 866 865.93 1.2 -0.75 -10.3 1.61 165.5 0.27 0.24 WEST FORK 3 991 990.9 1 -0.7 -12.63 2.2 166 0.16 -0.16 WEST FORK 3 1,116.00 1,115.90 0.4 -0.43 -13.97 2.79 131.3 0.57 -0.48 WEST FORK 3 1,240.00 1,239.89 0.6 0.17 -14.72 3.57 135.3 0.16 0.16 WEST FORK 3 1,364.00 1,363.88 1 1.26 -15.77 4.93 123.2 0.35 0.32 WEST FORK 3 1,488.00 1,487.87 0.2 2.1 -16.16 5.89 14.4 0.87 -0.65 WEST FORK 3 1,614.00 1,613.87 0.3 2.53 -15.88 6.27 79 0.22 0.08 WEST FORK 3 1,738.00 1,737.87 0.3 3.18 -15.68 6.88 63.9 0.06 0 WEST FORK 3 1,862.00 1,861.87 0.2 3.64 -15.65 7.35 123.7 0.21 -0.08 WEST FORK 3 1,987.00 1,986.87 0.3 3.93 -15.45 7.6 11.7 0.33 0.08 WEST FORK 3 2,130.00 2,129.87 0.3 4.39 -14.81 7.93 41.8 0.11 0 WEST FORK 3 2,204.00 2,203.87 0.1 4.53 -14.73 8.05 182.6 0.52 -0.27 WEST FORK 3 2,267.00 2,266.85 2.1 5.67 -14.58 9.19 79.7 3.37 3.17 WEST FORK 3 2,329.00 2,328.68 6.1 10.06 -14.14 13.59 86 6.48 6.45 WEST FORK 3 2,391.00 2,390.26 7.2 17.15 -13.65 20.75 86.1 1.77 1.77 WEST FORK 3 2,453.00 2,451.77 7.3 24.85 -13.26 28.57 88.2 0.46 0.16 WEST FORK 3 2,516.00 2,514.26 7.3 32.7 -12.99 36.57 87.9 0.06 0 WEST FORK 3 2,578.00 2,575.65 8.7 41.18 -12.66 45.19 87.8 2.26 2.26 WEST FORK 3 2,640.00 2,636.77 10.6 51.38 -12.3 55.58 88.1 3.07 3.06 WEST FORK 3 2,702.00 2,697.49 12.7 63.74 -11 .42 68.06 84.2 3.62 3.39 WEST FORK 3 2,764.00 2,757.75 14.5 78.26 -9.34 82.48 79.7 3.37 2.9 WEST FORK 3 2,827.00 2,818.50 16.2 94.91 -6.36 98.88 79.7 2.7 2.7 WEST FORK 3 2,889.00 2,877.84 17.5 112.84 -3.56 116.63 82.3 2.42 2.1 WEST FORK 3 2,953.00 2,938.74 18.3 132.44 -0.67 136.09 80.8 1.44 1.25 WEST FORK 3 3,015.00 2,997.33 19.9 152.69 2.61 156.11 80.6 2.58 2.58 WEST FORK 3 3,077.00 3,055.23 22 174.82 6.39 177.95 79.8 3.42 3.39 WEST FORK 3 3,139.00 3,112.27 24.1 199.05 10.47 201.88 80.8 3.45 3.39 WEST FORK 3 3,201.00 3,168.44 26 225.21 14.27 227.85 82.5 3.28 3.06 WEST FORK 3 3,263.00 3,223.65 28.1 253.26 17.85 255.81 82.9 3.4 3.39 WEST FORK 3 3,324.00 3,276.98 30 282.76 21.85 285.16 81.6 3.28 3.11 WEST FORK 3 3,388.00 3,331.98 31.5 315.38 26.78 317.51 81.1 2.38 2.34 WEST FORK 3 3,450.00 3,384.03 34.3 349.01 32.83 350.62 78.3 5.14 4.52 WEST FORK 3 3,511.00 3,433.60 37 384.56 40.69 385.29 76.2 4.86 4.43 WEST FORK 3 3,635.00 3,532.76 36.8 459.01 57.95 457.71 77 0.42 -0.16 WEST FORK 3 3,760.00 3,633.11 36.4 533.52 75.78 530.07 75.3 0.87 -0.32 WEST FORK 3 3,888.00 3,736.54 35.8 608.92 94.29 603.18 76.3 0.66 -0.4 7 WEST FORK 3 4,013.00 3,837.98 35.7 681.95 111 .58 674.13 76.3 0.08 -0.08 WEST FORK 3 4,139.00 3,940.63 35.2 755.02 128.83 745.14 76.4 0.4 -0.4 WEST FORK 3 4,264.00 4,042.26 36 827.78 145 816.08 77.9 0.95 0.64 WEST FORK 3 4,388.00 4,142.84 35.6 900.31 160.27 886.99 77.8 0.33 -0.32 WEST FORK 3 4,513.00 4,244.73 35.2 972.71 175.69 957.74 77.6 0.33 -0.32 WEST FORK 3 4,699.00 4,395.30 36.7 1,081.89 198.86 1,064.45 77.9 0.81 0.81 WEST FORK 3 4,761.00 4,445.07 36.5 1,118.86 206.76 1,100.56 77.4 0.58 -0.32 -. . . MOC Well Name MD TVD Inclin VS N/ (-) 5 E/ (-) W Az Doalea(0/100ft) BUR (0/100ft) WEST FORK 3 4,824.00 4,495.75 36.4 1,156.28 214.64 1,137.15 78.3 0.86 -0.16 WEST FORK 3 4,885.00 4,544.94 36.1 1,192.35 222.26 1,172.41 77.3 1.09 -0.49 WEST FORK 3 4,947.00 4,595.13 35.8 1,228.74 229.99 1,207.97 78.2 0.98 -0.48 WEST FORK 3 5,009.00 4,645.48 35.6 1,264.91 237.32 1,243.40 78.4 0.37 -0.32 WEST FORK 3 5,071.00 4,695.92 35.5 1,300.95 244.85 1,278.65 77.5 0.86 -0.16 WEST FORK 3 5,134.00 4,747.09 35.9 1,337.71 253.28 1,314.44 76 1.53 0.63 WEST FORK 3 5,195.00 4,796.50 35.9 1,373.48 261.78 1,349.18 76.5 0.48 0 WEST FORK 3 5,258.00 4,847.56 35.8 1,410.37 270.45 1,385.04 76.3 0.24 -0.16 WEST FORK 3 5,383.00 4,949.33 35.2 1,482.95 288.13 1,455.44 75.5 0.61 -0.48 WEST FORK 3 5,445.00 5,000.05 35 1,518.59 296.94 1,489.99 75.9 0.49 -0.32 WEST FORK 3 5,508.00 5,051.72 34.8 1,554.63 305.57 1,524.98 76.4 0.55 -0.32 WEST FORK 3 5,570.00 5,102.54 35.1 1,590.14 313.22 1,559.66 78.7 2.18 0.48 WEST FORK 3 5,632.00 5,153.27 35.1 1,625.75 319.69 1,594.72 80.4 1.58 0 WEST FORK 3 5,756.00 5,254.97 34.7 1,696.61 332.18 1,664.55 79.3 0.6 -0.32 WEST FORK 3 5,879.00 5,356.03 34.8 1,766.63 344.66 1,733.54 80.2 0.42 0.08 WEST FORK 3 6,003.00 5,457.92 34.7 1,837.22 357.05 1,803.12 79.6 0.29 -0.08 WEST FORK 3 6,126.00 5,558.50 35.6 1,908.00 371.73 1,872.38 76.5 1.62 0.73 WEST FORK 3 6,201.00 5,619.48 35.6 1,951.65 382.33 1,914.73 75.4 0.85 0 WEST FORK 3 6,318.00 5,714.37 36 2,020.07 399.12 1,981.08 76.2 0.53 0.34 WEST FORK 3 6,437.00 5,810.77 35.8 2,089.85 415.35 2,048.94 76.9 0.38 -0.17 WEST FORK 3 6,563.00 5,913.92 34.3 2,162.19 432.77 2,119.16 75.2 1.42 -1.19 WEST FORK 3 6,685.00 6,014.46 34.7 2,231.26 450.36 2,185.99 75.3 0.33 0.33 WEST FORK 3 6,809.00 6,116.47 34.6 2,301.74 468.14 2,254.21 75.5 0.12 -0.08 WEST FORK 3 6,872.00 6,168.33 34.6 2,337.49 477.42 2,288.76 74.4 0.99 0 WEST FORK 3 6,934.00 6,219.52 34.1 2,372.38 487.65 2,322.21 71.6 2.67 -0.81 WEST FORK 3 7,057.00 6,321.31 34.2 2,441.15 509.1 2,387.84 72.2 0.29 0.08 WEST FORK 3 7,181 .00 6,423.93 34.1 2,510.40 531.52 2,453.73 70.2 0.91 -0.08 WEST FORK 3 7,305.00 6,528.15 31.5 2,577.04 554.65 2,516.78 69.5 2.12 -2.1 WEST FORK 3 7,432.00 6,636.26 31.8 2,643.08 578.2 2,579.12 69.1 0.29 0.24 WEST FORK 3 7,495.00 6,690.12 30.7 2,675.49 589.63 2,609.74 70 1.9 -1.75 WEST FORK 3 7,556.00 6,742.82 29.8 2,705.95 600.46 2,638.50 68.7 1.82 -1 .48 WEST FORK 3 7,620.00 6,798.57 29 2,737.04 611.85 2,667.78 68.8 1.25 -1.25 WEST FORK 3 7,690.00 6,860.21 27.6 2,769.99 622.99 2,699.02 72 2.95 -2 WEST FORK 3 7,723.00 6,889.47 27.5 2,785.19 627.8 2,713.51 71.3 1.03 -0.3 WEST FORK 3 7,785.00 6,944.64 26.8 2,813.36 636.64 2,740.39 72.3 1.35 -1.13 WEST FORK 3 7,847.00 7,000.50 24.6 2,840.15 644.92 2,765.96 71.8 3.57 -3.55 WEST FORK 3 7,909.00 7,057.29 22.7 2,864.91 652.73 2,789.58 71.6 3.07 -3.06 WEST FORK 3 7,971.00 7,114.77 21.3 2,888.06 659.78 2,811.70 73.1 2.43 -2.26 WEST FORK 3 8,034.00 7,173.73 20 2,910.23 666.2 2,832.97 73.3 2.07 -2.06 WEST FORK 3 8,095.00 7,231.30 18.6 2,930.35 671.98 2,852.29 73.4 2.3 -2.3 WEST FORK 3 8,159.00 7,292.16 17.4 2,950.10 677.42 2,871.30 74.7 1.98 -1.88 WEST FORK 3 8,219.00 7,349.51 16.8 2,967.73 681.79 2,888.39 76.6 1.37 -1 WEST FORK 3 8,281.00 7,409.08 15.4 2,984.92 685.65 2,905.14 77.5 2.29 -2.26 WEST FORK 3 8,343.00 7,469.03 14.1 3,000.71 689.03 2,920.56 77.8 2.1 -2.1 WEST FORK 3 8,405.00 7,529.37 12.5 3,014.97 692.07 2,934.50 77.6 2.58 -2.58 WEST FORK 3 8,467.00 7,590.01 11.5 3,027.86 694.97 2,947.06 76.3 1.67 -1.61 WEST FORK 3 8,529.00 7,650.93 9.9 3,039.36 697.4 2,958.30 79.6 2.76 -2.58 WEST FORK 3 8,591.00 7,712.13 8.5 3,049.26 699.01 2,968.08 81.8 2.33 -2.26 WEST FORK 3 8,655.00 7,775.53 7.2 3,057.97 700.32 2,976.72 80.9 2.04 -2.03 WEST FORK 3 8,780.00 7,899.80 5.2 3,071.42 702.27 2,990.08 82.8 1.61 -1.6 WEST FORK 3 8,903.00 8,022.46 3.3 3,080.07 702 2,999.01 106 2.05 -1.54 ""'" MOC Well Name WEST FORK 3 WEST FORK 3 WEST FORK 3 WEST FORK 3 WEST FORK 3 WEST FORK 3 WEST FORK 3 WEST FORK 3 WEST FORK 3 WEST FORK 3 WEST FORK 3 WEST FORK 3 WEST FORK 3 WEST FORK 3 WEST FORK 3 WEST FORK 3 . MD TVD 9,027.00 8,146.30 9,151.00 8,270.16 9,213.00 8,332.10 9,337.00 8,455.99 9,398.00 8,516.94 9,521.00 8,639.84 9,646.00 8,764.71 9,771.00 8,889.57 9,895.00 9,013.40 10,019.00 9,137.19 10,143.00 9,261.02 10,267.00 9,384.89 10,391.00 9,508.73 10,453.00 9,570.64 10,560.00 9,677.46 10,620.00 9,737.35 Inclin VS N/ (-) 5 E/ (-) W 2.6 3,085.77 700.5 3,005.21 2.7 3,091.06 699.54 3,010.86 2.7 3,093.67 698.88 3,013.70 2.1 3,098.22 697.46 3,018.69 2.2 3,100.20 696.81 3,020.88 2.5 3,104.42 695.06 3,025.61 2.7 3,109.31 693.39 3,031.02 2.8 3,114.64 691.91 3,036.83 3.1 3,120.12 689.97 3,042.90 3.6 3,126.09 687.31 3,049.64 2.4 3,131.40 684.89 3,055.66 2.8 3,135.99 682.75 3,060.86 3 3,141.13 680.41 3,066.67 3.2 3,143.92 679.23 3,069.81 3.5 3,148.83 676.57 3,075.46 3.5 3,151.56 674.81 3,078.67 . Az Doalea(0/100ft) BUR (0/100ft) 100.5 0.61 -0.56 98.8 0.1 0.08 107.4 0.65 0 103.9 0.5 -0.48 109.1 0.36 0.16 111.3 0.25 0.24 103.4 0.33 0.16 105.2 0.11 0.08 109.9 0.31 0.24 112.9 0.43 0.4 110.6 0.97 -0.97 113.9 0.34 0.32 110 0.23 0.16 111.2 0.34 0.32 118.8 0.5 0.28 118.8 0 0 est Fork #3 West Fork Field 1981' FNL, 1919' FEL, Sec. 6, T6N, R9W, SM X: 345.130.584 Zone 4 Y: 2.411.693.656 Zone 4 GL: 135' KB: 317' (21' AGL) SPUD: 15:30hrs 09/28/2004 TD: 10/17/2004 Ria Released: 12:00 hrs 10/28/2004 4-1/2" 12Æ ppl L-80 Hydril 563 Casing 20" 133 ppl K-55 driven to 101' MDfTVD 1/4" aD 0.049" wail Chemical injection string tied into Chemical Injection Nipple top at 2418' w/double check valve and rupture discs 7" x 4-1/2" annulus filled with 1 O. 7 ppg mud containing Conquor API # 5M 33-20543-00 Permit # 204-156 WBS # Dx'04.10455.CAP.CMP.02 Property: C-060898 7" Casing Annulus TOC calculated @ 4400' KB 4-1/2" Casing Annulus estimated TOC @ 7750' KB Baker 4-1/2" MidstnnQ ZXP Packer. Packertop @ 7433' MD/6637' TVD. 4-1/2" Short Joint Locations: 9206.5' - 9246.2' MD 9990.5' - 10030.3' MD 7988'- 8002' MD (14') 3-3/8" 6 spl 7131'-7144' TVD 12/17/2004 -~------------------------------------------------------------------------------- 8094'- 8114' MD (20') 3-3/8" 6 spf 7230'-7249' TVD 12/16/2004 --------------------------------------------------------------------------------..,..- 8308'- 8316' MD (18) 3-3/8" 6 spf 7435'-7443' TVD 12/17/2004 --------------------------------------------------------------------------,..------- 8486'- 8496' MD (10') 3-3/8" 6 spf 7609'-7619' TVD 12/16/2004 --------------------------------------------------------------------------...------- 9308'- 9318' MD (10') 3-3/8" 6 spf 8427'-8437' TVD 12/16/2004 ----------------------------------------------------------------------------------- 9336'- 9346' MD (10') 3-3/8" 6 spf 8455'-8465' TVD 12/16/2004 PBTD (Top of float collar) 10,490' MD/9608' TVD BHl: 1,285' FNl, 1,092' FWL, Sec. 22, T6N, R9W, S.M ~ . ~1rlånræ ffi)~ ~~~~[{~ . AI1ASIiA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ken D. Walsh Advanced Production Engineer Marathon Oil Company P.O. Box 1949 Kenai, AK 99611-1949 Re: West Fork #3 Sundry Number: 304-484 Dear Mr. Walsh: 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 0 liday or weekend. A person may not appeal a Commission decision to Supe . r Co unless rehearing has been requested. DATED this/~ay of December, 2004 Enc!. ~EC-13-2004 MON 03:05 P~ATHON OIL COMPANY FAX NO, 411Þ2836175 P. 02 Alaska Business Unit ~flarathorTI ~1:~~ f::1:il;rnli8j\:::~~VV P.O. Box 1949 Kcn;li, AK S9611~194!) Tclophono 907/283-1311 Fax 907/283-6175 December 1, 2004 Winton Aubert AOGC(~ 3:33 West ¡th Ave Suite 100 Anch(.wage, AK 99501 DC<1r Mr. Aubert: Atttìc;ll€d <:Ind submitled for your approval is the Form 10·403 to complete the Tyonek Ü~S p:1Y inlhe West Fork #3 weHbore. This well was drilled in October 2004 under AOGCG drilling permit numbèr204-156. Also attached for your records is the well [:chcrn~ltjc. proposed operêltional procedure. and final directio.nalstJrvey. Mnrathön will submit a . Forrn-1 0-403 for yo~r approval prior to initiating any fracture stimul.::..tion trefttment in thÎs well. If you would like any oth0r information, please cåntact me at 283-1311 or l~~~ypJ~ h@ mSlr~1bDILº j/&QITl. ('" I ~)!I\CGm Yl I Ú>A- t> . "'-.J ",.QA Kç.m D. Walsh AcivHIìGcd Production Enginear \b,(/\;~\\ n\~ ,,' '. 1- \'J ~...~t\I'~\ \'\ -.. \1 '\ . (). \,...\ i\,\'- J'\ RECEIVED DEC 13 2004 Alaska OJ/ & Gal Gons, COmmission Anchorage Encl()~ums : ' , ' I ORIGINAL DEC-13-2004 MON 03:05 PMIIIRATHON OIL COMPANY \¡-1 GA I l. ( 141 Loof Dí S J <-L!Ë( :9- FAX NO,.283 8~CEIVro3 ALASKA 011., AND ~:~Tg6~~¡A~ON COMMISSION DEC 132004 APPLICATION FOR SUNDRY APPRO"~a Oil & Gas GOO$. Commission ~~c~~~~;~~~wn LJ I;>~,ioroté' L~ J ~. ~~eþ'~}e ^n~'tJl';r ·ñi;,pói·U Plug POIiorations 0 SÛlOul<1lc n TimG Exk,¡r¡::;lon 1.1 Olllc'r [] I'erforale N~w Pool [] l1e·enlf:( Su:;pond'~d Wc.·1I [l 4. Current Wt¡U Cln¡¡s: 5, 13~rro¡L to Drill Numbèr;· -- - .-.~ Development 0 / Explor:Jtory 0 204-156 / Slr",tioraphlc fJ eervicQ [l 6. ^PIÑllmber: 50-133-20543-01 / i"'f\'I~'\¡ cïR :;llIc~t:'-' "'--fj;;;I;J;';,\T,T'" '''Š{t5IiCOd O' AII,~r C~l~;I\¡) \..1 '~l,!rair well [,j C~I1!!rl(N ;'¡P:)f<)vr.t! prc(ji,111\ Ll Pu/1 Tllbin\J [J ;~, f,.1~;;¡'~ìô¡Ñ~i),ó:·"··-- "~'''--''''''---'- ¡1/I/\I<t\11i()t> 0\1. CON'p,\II Y ...., -.....--...,...........---·-·..···..··___.··____1.............___ :1..Ñi~! 'I.(I!.: (), O. I':Inx 1!)4~, KtH¡::[, AI{ !ì!)611-1Q.;9 . i: í<n 1::í~;.¡:·ti¿(î~ilt..·····__·-----_·'" ,. :ti "I' . , . ¡¡: Fri;l?Õíi¡6~~!;í~I;:,ìiOõ:-·· ---.----- 9. Well Nnme <1nd Number. West Fork #3 /" 10. FielcllPoOls($): West ForklTyonek PRËSENTWELL CONDITION SUMMARY ,.(~;~iif)¡;.plï;MiT('if-~l(1!:--¡ DêP¡~;'1VL) (¡¡¡:-- tffC'ctive-ner'llh MD(tt): Effective D(>p\h TVD (tt); " 10i'.:W NIL) 97~7' TVD 10490' 9611S' .~._'...:':~~~'~:'::~"~::= :"~~I~gth_=:.~:~~~~:C Stl'llCllllr.,l ::18' 3û" -..·-"c;õ¡:;a;¡r.ï(,r·..·· ...·----·10r--".. ''2Õ' - - "Gürt;;~()'" ." '~--'2 185' --. ....----e.-5iW ....-. ¡;:;{(:riñl~:Æ{r;:;· ..... - --~"7·t.93· -,- '-'f'--'o---:¡;-- . -·'..ï:;~~iiIZU7.;;ï······ ·-----1603õ;---... 4/1/2" .' . _··-t~;r:r··"-· .-... ···--iT -.-. ~_. 0 r~~:~:;~:~:~~':~:,~~î~0;~J~~~~~~.ò~ DopL1 1 v~ (fl): -J;~~jng Size: r·'; r;l(crs tlIIl1 ~S~,V l'yrC': Packers and SSSV MD (tt): t~,·(I/;Orm8 11:......................· Pluos (me~::;urcd): Junk (nW\,,!:ur;d): 28' Burst N/A 3060 psi 61:170 p::¡i 7240 p!.i 8430 p!:ì ëollapf.e NfA u"ï 500 psi 4750 p!\i ...-.- 5410 p!'! nl()O pr.i -- lVD 10620' 101' 2185' 6863' 9"/37' 0' 0' TubinQ Grade: Tubing MÖ (fl): -...........--.- NiA ,~: ^\·~;<.h ñ)7;'~: DÐ~~r;,pl~òn sun1"V~rY of Propu~")1 £)ÜI,1iltJd IIp',}:lli('mi 1:\li~qrJI'¡1 0 ¡:;OP Sket(;11 0 ,~f."Ë~iíi;;:,i7,~ i:):;tùf~ ( ...._~--,.-,~._--- Cl;lmn"J1I,ina (')\\~;t,llil\\\5; 12/S/20~ "j 1~~V,'~,t;ït:I'ï;rw?:'í:" ~~--_._-. "[i.1l(~: Ç()I \I'11ìf:~:UO H'.:pr"!t.!nl;.)!ivo: j t :ït~.1ièìiyr,:;rITiÿ·th:;-Giiõfôr:;¡¡Q;ng1¡tru,;·:;;:;dcõñ~éitõìiìõbõ!>t of my knoWlèdgè. Contact --Ken D. Walsh i..'I n:~<1 N·\i\1¡.¡ .~ø,' D'.~:II:"~1._t:~.'-.4--.~.m__~_ ntle Advanced Produclion Enginaer .~.:;~~~~,~o __ \C~.~:~;~'?;.YJ"" ~'£:,I:::-~.,-.:hone 907·30,1-3060 _ Qr¡tc , COMMISSION USE ONLY 13. Well CIJ.S¡> ancr proposed work: E;xplor<1tory 0 D~vclopme(\t 0 ServÎCJ) 0 15. Well Status afl.cr proposed wor\<.; Oil [J Gas 0 / Plugged [J ^I)¡:¡ndonod 0 WAG rJ GINJ 0 WINJ 0 WDSPL 0 . .--......-.. 12/1/2004"- ---""'''- ........ -,..... ",--...-.... .....-_.........-....,-,....--~. , . l~r)n(1Î1il\n:) (,f :1["prrNi¡!; NQtify (:OlniTIi&~,iu¡) !>,J ti'"'t \.ì r~!prC'!)cr.tJt¡VE) msy witness Sundry Nvrnbor: ..3oY-I/N w.__......__.. ["' lIl) Inlc,. ,)ty rl BOP Tc<:,t [] M~~chMicQ\ Inl~or¡ly TC5t 0 LocatiM Clearance D ~ l.e;þ:'-Y'- ~ BFí..t OEti t¡ot b"'¡ lit ~E C 1 3 2004 i¡; ~ O¡I & (~GcrJi1. Co¡Thl¡ii~¡Xi ¡-..w4. ~ r-' l¡~ (~IIIH: q vÌ t' IM'~ l , j'. ORIGINAL Ax~t_¡~ COMMISSIOr-iŒR ¡,y ORDER OF TH~ COMMISSION Date: 'ir4~-.-~ Submit il1l.)'Jplil~;')t¿, . , IN~:Tt'HJCTtONS ON n.EVEHSE ÒEC-13-2004 MON 03:06 PM~ATHON OIL COMPANY FAX NO. ~83 6175 P. 04 MARATHON Oil COMPANY ALASKA REGION West Fork fÎêld West Fork #3 COlT1pletion Procedure WBS # D>L04.10455.CAP.CMP.02 Iy'QflCk COJngretion Þroœdurf.!.t11-17-200:1} ALL DATA RELATIVE TO THE TESTING OF THIS WELL IS CONFIDENTIAL ~~~t0: 'n1i~~rroccdllrG commences witl, operations once work to cement the 4-1/2" production / Cn$ino is complete. ¡he cement was displaced from the produclion casing with 6% KCL wtilcr. 1. ASS V¡;:tco to h3ilg ßnd pressure test 4·1/16", 10K rent~1 frac tree wilh Udélhovenboorn truck. Veco In finis:ll:i;;1~in of production flow line spool to 3-1/8", 5K wing flange connection. 2. MIRU Expro with 0.125" 00 wire. Hold Safety and Mvironmcntal awareness meeting. Install p;jç¡~()rf f.1nd flc.'vV tes. Connect packoff flow tee to flat tank with ctl.icksan or have vac trLlcK on loc;1lion to hnndle ß% KCL water displaced from hole with tools and wireline. Perform wire twi¡.;t test. PU tOt, $tring consh¡;ting of weight bars. toller stem, oil jars, and spang jars into 11.Ibrir.~I!Oí. RIH w/3.80" g3lJgG ring to mg and record PBTD. 3, If PBTD is bolow 9.400' MD, proceed to Step #4. Otherwise, MIRU BJ Cdit Tech 1-3/4" coil / tUl~ing LlnIt and Wc~~tl'erford MHA, j£\rs (DailGY 2-718" OD), 2.7/8" CT-PDM motor, and 3.80" ODrnil1 to c:i(::Inout to 9700' MD with fu!)sh water. Perform Steps #5, #6, and #7 prior to clo<Jnir19 out the '~"'eHborc. 4. MIRU Expro w¡:h P3ckoff to run cement bond log.. Connect packoff flow tee to flat tank with /' CI)fCkSat1 or htovù vac truck on location to handle 6% KCL water displaced from hole with tools and wìrol;!ìE'. Hold SE:lfcty and environmental awar~ness meoting. PU and RIH with C~UGRICCL on wircline, Correlate MD to ReÐves ShutUe Quad Combo openhole logs run 20"Oct~2004. Log rrom PBTD to 200' above cement top behind 4·1/2" casing (estimated at 7100' Kß from C~'I'nent volume pumped). Consider making a pressure pass at 1000 psi in éìdd¡lion to 'orig:n;;,! þ¡:J$s. RD F.:xpro wireline, 5. [)ülivcr cbr:n 500 bbL Rain-for"Rent t<:\nk, ±350 bbl. flow back tank, and MOC gas bLIster to \oc:atìon. D<¡lívcr MOC 2", 5K flowback skid (purchased from Vetco) and flowback chicksM to 10G<'Ilíon. DC'liver APC diesol fuel truck, 1000 gallon diesel tank, liner, and dunnage to locí:tion. Deliver Maif,lhon methanol injection sl<id with double diaphragm and Ha5ke1 pump to locD.tion. Dolive:r Airport RentÐI65 KW rental generator, two light plants, Mode! 185 air cornpr~Gscr wilh MOC air drier, and diesel-fueled rnanlift to location. Deliver two portë.ìble toilel$, dumpster, and ASRC fork lift witl) fork extensíons to localion. Set gas buster on flow b:\c~~ t.1nk ~!1d lind down with cl)ains and boomers. 6. I\I¡\~U Pl1Wc;/\V8~¡ SNviços well testers. NU Pow0rweU Services "csling 3-1/18", 5K comp311ion f\('\IÌ(jo with 3", 1502 connectìon to end of fJowline spool flange downstream of SSV. Lay How line$ to sCpf~rator snd vent stack, Plumb in methanol injection line to flow b~¡ck line fWJ ::IiI' ¡in:·::; 10 SSV. Ensure that SSV has a lock open plug and a needle valve altached. I.o;;.d s'8p:\rator with ± 20 bb!s glycol water. Deliver MOC 30" ID vent stack and base and DEC-13-2004 MON 03:06 PM4IIÞATHON OIL COMPANY T't.~~.~ :'! óf::\ FAX NO, ~83 6175 p, 05 ,0 1~:,.v~ v;~(',o cr,,\¡)t) $µot sarne. Pre$!'ìurc test PowOl'Wel1 Services flowbeck lines to 5cparator to ~bO/100Ù p:~i with 11\\lll1anol wate:r. 7. N~C to I.~y line· ' and bcrtn sroL\nd for Powerwcll Services Well le:;;t separator, flow lines, vent ~ot:::ck, tll1d die$o! fu(~! truck. AÞC to I~y linor ¡,~nd berm around Rain-for-Rent, MOC choke :;. ¡,jrj, cll'Hi V£JCo flùwback {;.'Ink. Liner to be: placed around wellhead and vicinity to bE) occupied by wireline <Ji'\d CQil tubing equipment. 8. Hold P.!:;M. MIRU BJ Serviccs 1-314" coil tubing unit and nitrogen pumper. ND 6-1/2" OtiS C:l.mnection [1'(,:11 top of sw~b valve. Inslall BJ flow cross to top of 4-1/16", 10K swab valve. I IE::ye W:co c.ri.1I1f.: pick up BJ coillubing BOP. Flange up BOP to top of flow cross. Place coil tuhing ÍI'1 Injec.tor houd. MalŒ up lubricator to injector head. Pick up injector head and lubric¡:¡tor with Crûne. In9tall slick wash noz7.le on end of coil tubing and make prop~r pull test. M.¡jkû up CT injector head and lubricator to BOP's. RU MOC 2" flowback line and a 5K choke l'n.aMold to So I. Pre$$ure tost CT BOP pip~ and blind rams with methanol wator to 250 /" low/4!JOO high psi. Pressure tcst flowb8Ck iron to 250 low/4500 high psi. Displace n"Ißthanol \lJ1.ìtcr to tÇlnk w!th nilroøen. 9. O¡)cn w.¡¡11 ~nd R\H witt) coil tubing to PBTP l.m\oading KCL water through Powerwcll Sarvices line to 1Iowl):;.H,;k t:~nk with nitrog.;n. Note.: Irnoortant to œkejniti~1 aile! fiMI f!9wbAck 8.n9 fluid f..L,\PR1~~.i:\I)I).~.1rßJ.~~~.cför~ qt1.d afl~r rL nnina in With coil tubína. POOH with coil tubing trapping 1200 p~ì nHfogÐn píe~surc aL the wotn'1$ad. RDMO BJ Services coil tubing and nitrogen units. !~H.Q.!~.9SE.!l.rYO~ I~ ~( Pi': ~FOR.¡\ TI ONS M!allit£~U)mt.h TVD 9XHJ'-- 9346" Int)8'- 931 H', ~·m6'- 8496~ j gJ08~- R316\ 8\. I).~ ~ Sl14" '}9~8'- 80D2\ 10 ft 10 ft 10 ft 1S n 20 ft 14 ft 8,465' 8,437' 7,619' 7,443' 7,249' 7,144' SBHP (!48 11si/ft) 4063 4050 3657 3573 3480 3429 fiurflH'r. Wellhead Pressure 50% nÐ (îO% U1) 0.967 N2 0.57 ~as 1135 1135 1070 1060 1045 1035 1340 1340 1230 1205 1180 1165 10. RU Expro wirçlìnúservicc with fû1llubricator (pump in sub and flow tubes), and pressure conlrol equiprn¿>l\t. Hold safoly and cnvironmcntal Elwareness m~eting. Blow nitrogen pr0S$lIr~ dO\'vn to 1135 psi WI,P while running in the hole wíth the first perforating gun. PU / 311d HIH wìth eCl aM 3.375" HSP guns loaded 6 SPF 60 degree-Phased wiL\1 SDP-312!5· 311 N'f3 (;tl::irgÐ~ rind PX-1 firing hCDd. API target performance is 0.36" entrance hole and 40.25" pl~ne:r<Jt[on. M¿\x ül;n swell in aír is 3.625" 00. Correlate depth to Expro CSL/GRlCCL log. PorfordO Ð33G'·9346' MD. RDMO Expro wirelinc. i 1. FIDw h;st w,:¡ll. No more than a 50% drawdown with nitrogen in the wellbore or 60% drawdown with methano gal'3 in wcllbore is permitt~d for the lowest open intervaL Obtain st¡:,¡bílizí)o flow within Uw 60% tlrawdown limit. The unloading rate up 4-1/2" casing is 5.0 f\t.MGFGF'I) @ 1,200 psìg FCr. Establish dcliverabiliLy and obl3in gas samples to determine (j;1:; ,¡n,¡:y¡,;is ilowing well CiS per direction of onsite production engineer. Contact Houstol'1 Hl.:$orvo:r í.-7.t1r.i1ìGC'rinlJ with transient tE;st qUéstions - Tara West 713-296-3383. Following ('.ieRn LIP ~I!":d (.I),o::;!;·mt (J3S ratc, prepare for pres~ure transient work. 1 :~. M!¡:'~Ü Poiklrd Wire!inc 10 run t<'lndem pressure gauges on slickline. InstÐII SPIDR or Data 'fwp g,'.Jug\·! an Ir~¡") c¡;:¡p f!é1nge. Houston Roservolr Engìne~ring to provide gûuge data W€3t Fork f¡-'J ì'YM\~k COWpIE.tiç¡r¡ PI{ICndll\~ KOW - 12/3/2004 7:43:18 AM ]EC-13-2004 MaN 03:06 P~ATHON OIL COMPANY FAX NO. .283 6175 P. 06 hl!.'~ j ()f3 (.'o!l(,,~linn Sí.~lnp¡¡ Ì!J ratù. Hold PJSM. RIH and set g~uUos on AO stop with bottom of gaugp.5 r,(;(O$~ p~rr()r.,tiúlÎ:3 (It 9336'-Q34G' MO. Flow and lhen shut-in well per Houston Reservoir l:nnin':'''I"ÎlIU d;r(;(.,lioll. 13. C.or~!ir\ue pç'liomling ï'yol1ck intervals from the boltom up as olJtlinod in Step tf.9 observing pørfor.::ting (Jrawdown limits. Flow test open perl intcrv~l(s). Add perforations as needed to oxcii:cd minimum flow rale nocesstìry to untoad fluids from tlìe wellbore and meet gas sales (~r,ijr~dív,,::. '14. F()l!ow¡na CÛI11pl~t¡of1 of testing. Lubric~te In SPV's and winterize tree. Chain closed the rllastcr vCl1v.?,> tlnd 8ecure the location. RDMO well testers. R~leasÐ rental equipmønt and fr)tlIrn to vendors. f~ºNTAg£.~. KCn Walsll: 907-283~1311 (w) 907~394-3060 (c) David Bri111b~n'Y: 713M296-2265 (w) 713- 408-0703 (c) Bcn Schornrt~nn: 907-565-3035 (w) Tara West: 907-268-0122 (p) 713-296-3383 (w) 713- 408-3001 (c) Hob Lanz: 713-296-3388 (w) 713- 408-3089 (c) KGf Op"n1t~m,: 907-283-1305 , , , W.J$t For~. #3 TY(1I1Gk Compl~liolì Prc.)cedurc KOW - 12/3/2004 7:43:18 AM ÐEC-13-2004 NON 03:06 P~ATHON OIL COMPANY WI'=!:! £.o!:t~H WC&t Fork Field 1!)~1' FNL. 11)19' fEl, Sec, 6, 1"SN, R>,W, $M " t.!; Ii :.,t':I~¡'f: j/ .. ~' Lk~II" t' '1 I'." I",: iI~ ~I . ;, I ¡". ;1,'1' I/t',^",i) 11' " .. ,~ , " f' '1.'1 \: 1'~ ~n.111." t)'I'lr/='~Il! I' . j (r 1'11111I :'.> \~ . II 11.>1 S~I<:,\·· \1 ,1?Q".I!(;¡,I~J?'\~'I~~ . .: ·1 I".~ 1.10 ppr L·~o HYt'll : l:', " '".. '110 . , :J ..)\.1..... ............".: " I, I:. Jo.. I I',' " ~': Ì'!.:-..n.llI\ ',1.,$ TIIII!,.~ ,!'.~..~ ~h\' ~II!~'~ 11\1'\11 ~t 7" x 4-1;:1" /II\rI,¡I,!.~ rlll~·tj wW110 '/ ¡:;,'o rI1\!r) ~.r.~(,!lf1lnÙ C(ln<:;iI(\r '1: !\,I~ ~t.n'f~~.\.?..(I)'~1.~9 t:"wl!i P. ;'l\'.I\~ , ""t)':'J~)I) !'.1 "M!i~ C¡4~!3"Me.n~ t'I.~J1 t""¡õ! t,lId&"J't ;ì;i)"l!i11~(lê;"'''''--''''''''' -- --.. " ....- 1\"lhl:1 ~ ~c.r,I:p.)' \i,IIÙ,J(: /11'11 t¡I,m y,·Or.',~400' Kil ¡ ,Ultl;M il¡'I~ 11\'111 £'¡UU'.~::Jf L;I'(}f1 ~t2': Dtlttlhlh\1 11\ S; i~. tt.":~ lI.ulk¡"lirm ;\1 1L1' :,¡.~ ~,,~ '~"'Oll!i~ t,,(.1 11<:'1' "(,1>7~'1' M:I '" 101',.11:.i ~"r¡ In 10 ,...--.., ..... ........ .~.- ...--. ~ -"__"'-.h. I, ·1_11"" !'; ·,'¡'I.lt1Ì1111 fIt ,lir,n'\' il?()li,r;' . r~;'1\f :,: MU .. ¡¡(I',o.¡',' . 'I "ù,;0.3' hm r I' ;' (" ~ ' . ~,:,; ':'i -- - ---- , '.'. ~ " . -.' . -:"¡'I " 1,/ . FAX NO. 411Þ283 6175 P. 07 20"1$:.1 ~I'¡ 1<·55 ~riYon \0 10 I' M~TVD '.' ~ 114" OD 0.043" w~U Cl\emiClII ÌI~"r.ijun ",Ing Dod ,;' inlo Ch"mic~11n)cç6"n Nil,;,I!! tOp at 2~ 1 B' w/dl,l\lhlO choc~ valyc nnd tu~t"ro ~ scs '.. /" :;~ I, §urface Cn."d~; I. . I I,' :. '... O·hlO' 47 ppl L·8Q Morl,fI"~r"'t t1J 21ð~' Mn~ a!¡' '!Vo \ ., . , . f r.ul 'd Vl/53~Ek!; (;>:111 Þtll.~.) 12 ppn C~1tt:: c¡ Irl n 12-1/.17 holo, (Rocoye<\)¡j 5 ¡,¡, ,. comant 1!101111"t,u). Bumped plug "I'NIQL~ ""Id. .. " '. .' 't, C¡¡~il'O Ñll\1:lus roc ç¡,IÇ(II.¡I,'.:I @. 4400' KEI '. >. ~' " ': 4· 1f.!· C:\sinD Ann:!!\ ... (lo~loned 10C @ 7100'KII Or ." \,.... -~ ',' .. "!\:I I,. . :~t: ~ ("termOdill"~r..9=.~ 7' 2& ppf, L,CO, Moamod Bullru~ fr"m O'-7603>MDI00C3' '1'\11) Cmlt! w/l\14 $!\~ (~2.S Þbls) Clu:.~ G \(:M cc:mont (12.Þ PPO) in an B-112' hOle f<lnQV.'ed wl1G2 $kt (32 bbl.) CbliO G ~"'il CQl\1ont (15.8 ppa) in ~J1 E-112" ho:4:, (ROc:QVC!(od 20 bÞI~ 01 ¡;(¡lnOl1tto Gurf¡;e;c). t1i(l nOlÞump pluG nn~!$ h&l~. t>~~": 4.1/7' M.!i!.~:i~"n 7,XF> Pa~.ki!L F'"rltor IQp @ 7~:¡:1' MDlB637' IVD, I'" .. . ~":. I , ' ~. .~ I ,,:,..~. :' ~mll!"'C:( Tvr¡flnk Þ~rC"rt1/ihn~~ '/.' ........,. I ~ 79t.U'· B002' MD (14') :)·318' 6 spf 113' '.7144'lVD -- ----.....,.---..-.-----....... OO~4·. 8\ 1'1' MD (2Q') 3.310" e !'opf '1230'.7149' '!VI) ,/ -'..' .........---..........----...........- / / / U3QQ', B316' MD (10) 3-318" 6 ¡¡pr 74:¡fi',7443'lVD ---.....;....---..-.........----'" a·16C', s.:9(j' MO (10') 3·010" Sspl 7GW-7G19'1VD - .' -', -.....'.....---...-,.....,.-- 930H'- Da18' MD ('J 0') 3-310' ~ 11:,1 B'12('-e~3" 1VO - ~ ......--......,...... ..........- 03:,0'- e:~( ' MD (10Î 3,:iIíI'S ~pl ð-15~'-a40G' lVD / " , I : I ~ f "::.," ." .' <J,. , , . ':::: .. ., .., ".' .," .J.i,- ..,.. . ...1,' [fïïrÒ'ironóiñë,:;iëõ::.ir) -J..------.,:: </ '{",: ~.Q.~JO' ~1'Jlb';\llJ' TVD . " --- '''' - ..-.-..... .' 1 D 10,6'0' MD ~,73(' ¡VI) I ~.r'aductio~ C"¡'f'¡Q!k , 1 .,' I. '1-1/:!" 12,$ ¡¡pr L,ao Hydnl5G:! 0'" '0,6~O' M0/!1,73r TW ; ,. I,! . , I Cmt'd w/5511 ¡¡1<t.1M ppri (11~ ~hl',) h17" hole. DI~I.I¡lc:"d wiU111>S bbl~,y%I<Cl W,~k.r ¡GIIUlpU.:! pl~O wilh ~JOO p,,1. Applied p[l~~;\lr') Ie SOOO'p:¡1 to $,j midhhil\O PSCkllf, Cifr.td~1Gd ; no ("m.unl 10 ilultJcø. f¡HI.: 1,305' FNL, 1.0$7' FWL, Sec:, 22. T6N, R9W, S.M QEC-13-2004 MON 03:05 PM4IIJATHON OIL COMPANY FAX NO.. 1283 6175 p, 01 r' , r' , Marathon Oil Company, 'II I¡.},.' ~ " ,J' I ,\ .11' \ \ '.. II' ¡ I' , . ,', ¥' 'I '. . 1<' ,I H ...1." , f. .'~''¡ !. ~...'Iii,~)¡'; .¡¡:.;.,...... . ...t 11" j,' \_ , '" .J _, , , , Fax :I!~,: _y.__.._~!r~!on AU£f~,!.t ___w F¡"p¡: 907-27ó-7542 -..-.~.I' __...,_,__......_......,... From: Keli Walsh ......-..... Pa..g<'.s: 7, in¢llldjn~~this cover ~hcût Oate: 12/13/2004 PJ-jOHt.': 907-793-123! .....__... ..... ''''___'>,.J __,,~.___ }~~~:_^,y '_ ~.~:~I_ork!i~~_, ,___. _ _~.," cc: (Ÿ'1lJ I' !,~~at [;2j 'Fo}' Rt~vie'l'v 0 Please Comment ø Please RC'ply 0 f)lcase Recycle --._.."" I..... _.____.... "___"_ .w.... ___" CmmH{'lÎts: Wintc,¡n, F(· xed '.'\Jiltl thie cov(~r sheet, is the signed Form 10-403 Sundry request to complete the West Fork #3 well. rif~.'I~0 i(:view ~nd ~·lpp¡'QV0. I c,"\n ba rc~ched at either 283-1311 (office) or 394-3060 (cell). I apologiz~ for tiV) 11"tC'.onw,nicn(.¡:¡ ñl,d will invest:9ctú on my end why this documentation did not reach you. Please let rn~1 know your dec:siol1 [,S 500n 85 possible so Umt work can progress. I ¡ !(lnkf. C'ig(¡in for you ílÎdu!g;~nGc. ¡<en W;;¡1:;;1\ OUPl'CATE. FI·om.... 34090 KaJifòrnsky Ikad¡ l<o,H1 KcnnÎ, AK 9%11 Phone: (907) 283, [31 t Fux; (907) 2!:G-G175 -..,..-...,,~---~.,,"\~._--- . ~lT lTŒ (ID~ ~~~~~~ . A.I.A.~1iA OILAlQ) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Willard J. Tank Advanced Senior Drilling Engineer Marathon Oil Company P.O. Box 3128 Houston, Texas 77253 Re: West Fork #3 Marathon Oil Company Permit No: 204-156 Surface Location: 1981' FNL, 1919' FEL, SEC. 21, T6N, R9W, S.M. Bottomhole Location: 1285' FNL, 1092' FWL, SEC. 22, T6N, R9W, S.M. Dear Mr. Tank: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional 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. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to ness any required test. Contact the Commission's petroleum field inspector at (907) 659- 07 ager). BY ORDER OR THE COMMISSION DATED thiS~ay of August, 2004 cc: Department ofFish & Game, Habitat Section w/o encI. Department ofEnvÍronmental Conservation w/o encI. t-'...1GA- fJ 1/1 /l.£-o4 . STATE OF ALASKA .. ALA OIL AND GAS CONSERVATION COM~ION PERMIT TO DRILL 20 AAC 25.005 ~~ 1a. Type of Work: Drill ~ Redrill U 1 b. Current Well Class: Exploratory 15 Development Oil U, Multiple Zone 0 Re-entry 0 Stratigraphic Test 0 Service Development Gas ø Single Zone 0 2. Operator Name: 5. Bond: Blanket 0 Single Well U 11. Well Name and Number: Marathon Oil Company Bond No. 5194234 West Fork #3 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 3128, Houston, TX 77253 MD: 10,605 TVD: 9,717 West Fork / Tyonek 4a. Location of Well (Govemmental Section): 7. Property Designation: Surface: 1,981' FNL, 1,919' FEL, Sec. 21, T6N, R9W, S.M. C-060898 Top of Productive Horizon: 8. Land Use Permit 13. Approximate Spud Date: 1,285' FNL, 1,092' FWL, Sec. 22, T6N, R9W, S.M. August25,2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest 1,285' FNL, 1,092' FWL, Sec. 22, T6N, R9W, S.M. 4,801 Property: 1,900 ft 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface: x - 345,130.584 Y - 2,411,693.656 Zone- 4 (Height above GL): (21' AGL) 317 feet Within Pool: NIA 16. Deviated wells: Kickoff depth: 2,300 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 36.12 degrees Downhole: 4,750 Surface: 2,630 18. Casing Program: Specifications Setting Depth Quantity of Cement Size Top Bottom c.f.orsacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 133 K-55 PE 100' 0' 0' 100' 100' 12 1/4" 95/8" 40 L-80 BTC 2,179' 0' 0' 2,200' 2,200' 413 sacks ./ 81/2" 7" 26 L-80 BTC 7,442' 0' 0' 7,463' 6,667' 330 sacks ./ 61/8" 4 1/2" 12.6 L-80 IBT 10,584' 0' 0' 10,605' 9,717' 254 sacks ,/ 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production I Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch ~ Drilling Program ~ Time v. Depth Plot U Shallow Hazard Analysis U Property Plat 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Willard J. Tank Title Advanced Senior Drilling Engineer Signature j,/¡}J/íAjl1~. j~ Phone 713-296-3273 Date August 12, 2004 v Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: .20 7" ~ ~t:' G: 50-133- ~ðS'Y.3 Date: requirements. Conditions of approval : Sampl r uired Yes 0 No ~ Mud log required Yes 0 No ~ _ I ~ HX9 ~n ulfide measures Yes 0 No ~ Directional survey required Yes-S No Othe" '7¡J ~./ 5ÐðO f>L &j ~3IðC/ Approved t)~..-j r (//(/( APPROVED BY THE COMMISSION Date: For~01 ~d 06/200~ I s~mit iiuPlicate ORIGINAL . . MARATHON MARATHON Oil COMPANY DRilliNG PROGRAM West Fork Field West Fork #3 Original 8/12/04 Originator: Drilling Superintendent: North America Drilling Manager: W.J. Tank J1:.--:J- P.K. BerQa B.J. Roy Page 1 of 13 . . Table of Contents General Well Data............................................................................................................................................. ......................3 Geologic Program Summary ............................................................................................................................................ ....... 3 Summary of Potential Drilling Hazards..................................................................................................................... ...............4 Formation Evaluation Summary................................................................................................................................ ..............4 Drilling Program Summary..................................................................................................................................... .................5 Casing Program.................................................................................................................................. .....................................6 Casing Design........................................................................................................................ .............................. ..... ..............6 Maxim um Anticipated Surface Pressure................................................................................................................................. 6 BOPE Program ........................................................................................................................................................................8 Wellhead Equipment Summary............................................................................................................................ ..................9 Directional Program Summary............................................................................................................................ ....................9 Directional Surveying Summary ............................................................................................................................................ 1 0 Drilling Fluid Program Summary........................................................................................................................................... 1 0 Drilling Fluid Specifications........................................................................................................................ ............................11 Solids Control Equipment........................................................................................................................................ ..............11 Cement Program Summary................................................................................................................................................... 12 Hydraulics Summary......................................................................................................................................... .................... 12 Formation Integrity Test Procedure....................................................................................................................................... 13 Page 2 of 13 . . General Well Data Well Name West Fork #3 LeaselLicense Surface Location 1,981' FNL, 1,919' FEL, Sec. 21, T6N, R9W, S.M. WBS Code DX.04.10455.CAP.DRL Slot/Pad West Fork Pad Field West Fork Spud Date 8/23/04 (est.) KB Elev. 317 County/Province Kenai Peninsula API No. Ground Level Elev. 296 State I Country Alaska Well Class Exploitation Perm. Datum KB Total MD 10,605' Rig Contractor Glacier Drilling Water Depth NIA Total TVD 9,717' Rig Name #1 Water Protection Depth Comments: Geoloaic Proaram Summary MD - RKB TVD - RKB Pore Pressure Pore Pressure PosSible Fluid Formation (ft) (ft) (psi) (ppg) Lithology Content Sterling B-4 (Not a Prod Target) 5,412 4,967 5.00 Sandstone Gas M. Beluga Congl. (Not a Prod Target) 6,378 5,767 9.00 Conglomerate Gas I Water Tyonek (Target) 8,856 7,967 9.40 / Mix Sand/Silt/Coal Gas Tyonek T-2 (Target) 9,006 8,117 9.40 Sandstone Gas Comments: Surface Location Coordinates From Lease/Block Lines 1,981' FNL, 1,919' FEL, Sec. 21, T6N, R9W, S.M. Latitude 600 35' 54.555" N Longitude 1500 51' 41 .879" W UTM North (Y) 2,411,693.656' UTM East (x) 345,130.584' Tolerance Depth Horizontal Displacement (ft) MD TVD +N/-S +EI-W Tolerance Directional Target (ft) (ft) Location (Y) (X) (ft) Sterling 8-4 5,412 4,967 1,705' FNL, 453' FEL, Sec. 21, T6N, R9W, S.M. 276 1 ,466 Circle 100' radius Tyonek 8,856 7,967 1,285' FNL, 1,092' FWL, Sec. 22, T6N, R9W, S.M. 696 3,011 Circle 100' radius Tyonek T-2 9,006 8,117 1,285' FNL, 1,092' FWL, Sec. 22, T6N, R9W, S.M. 696 3,011 Circle 100' radius TO 10,605 9,717 1,285' FNL, 1,092' FWL, Sec. 22, T6N, R9W, S.M. 696 3,011 Circle 100' radius Comments: Page 3 of 13 . . Summary of Potential DrillinCl Hazards Hazard Event Lost Circulation in Low Pressure Sterling sands Discussion Control losses by using sufficiently sized LCM. Comments: Potential Hazards Statement To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the drillers dog house. The man on the brake (driller or relief driller) is responsible for shutting the well in (BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. Gas sands will be encountered from +/- 5,012' MD (4,644' TV D) to total depth of the well. These sands will run from highly depleted to slightly above normal pressure. Lost circulation and differential sticking are potential hazards in the underpressured Sterling. The Flo-Pro mud system that will be properly weighted to hydraulically control all sands and lost circulation materials will be available on location, if required. Formation Evaluation Summary Interval LWD Electric Logs Mud Logs Surface None None None 0' - 2,200' MD Intermediate None Reeves Quad Combo. Pull GR-Neutron to Basic with GCA, shale density, temperature in and out, 2,200' -7,463' MD surface inside casing. Schlumberger OS!. sample collection (10' samples). Production None Reeves Quad Combo. Schlumberger DSI Basic with GCA, shale density, temperature in and out, 7,463' -10,605' MD and Check Shot Survey. sample collection (10' samples). Completion NIA GR, CCL NIA Coring Requirements: None Comments: Page 4 of 13 . . Drilling Program Summary CONDUCTOR: 1. 2. 3. 4. 5. Drive 20" conductor to +1-100 ft. RKB. Move in and rig up rotary drilling rig. Install starting head 20" SLC x 21 1/4", 2M flanged. Nipple up 21 1/4", 2M diverter, 16" diverter valve, and 16" diverter line. Function test diverter and diverter valve. / SURFACE: 1. Drill a 12 1/4" hole to 2,200' MD (2,200' TVD) per the directional plan. 2. Run and cement 9 5/8" casing. 3. Cut off 9 5/8" casing. ND diverter. 4. Install 9 5/8" slip lock connection X 11" 5M flanged multibowl wellhead. /' 5. NU 11" 5M X 135/8" adapter spool. NU 135/8" 5M BOP'S. Test BOP'S and choke manifold to 250/3,000 psi. 6. Set wear bushing. 7. Test surface casing to 3,000 psi. INTERMEDIATE: 1. 2. 3. 4. 5. Drill out float equipment and 20' of new for ti n wI 81/2" bit. CBU. Test shoe to leak off. Estimated EMW i 14.. ppg. <> Drill 8 1/2" directional hole to 7,463' MD ,667' TVD) as per directional program, short tripping as required. / At TD circulate hole clean. Make wiper trip. TOOH. RU logging company. Run open hole logs as per plan. RD logging company. TIH w/8 1/2" bit to TD for wiper trip. TOOH. Pull wear bushing. Run and cement 7" casing. Land mandrel hanger in multibowl wellhead. Back out landing joint. Set wear bushing. Test casing to 3,000 psi. 6. 7. PRODUCTION: 1. PU 6 1/8" PDC bit and directional BH~. Drill float equipment and 20' of new formation. CBU. 2. Test shoe to leak off. Estimated EM'{I ~ppg. 3. Drill a 6 118" hole to 10,605' MD (9, 71'7'TVD) per the directional program, short tripping as required. 4. At TD circulate hole clean. Make wiper trip. TOOH. 5. RU logging company. Run open hole logs as per plan. RD logging company. // 6. TIH w/6 1/8" tri-cone bit to TD for wiper trip. TOOH and laydown BHA and drill pipe. Pull wear bushing. 7. RU and run 41/2" casing with Baker Oil Tools 4 1/2" X 7" Mid-String ZXP Packer spaced out to 7,200' MD (at least 200' above 7" intermediate shoe). 8. Cement 4 1/2" casing while reciprocating. Bump cement wiper plug to energize ZXP with pressure. WOC. 9. PU 41/2" casing. PU BOP stack. Set slips. Cut 41/2" casing. 10. LD BOP. Set 41/2" packoff. NU 11" 5M X 31/8" 5M tubing head adapter and 31/8" 5M tree. Test tree to 5,000 psi. 11. Rig down and move out drilling rig. COMPLETION: Completion will be done without a rig. Page 5 of 13 . . Casina Proaram MD (ft) Connection API Ratings NIA * Hole Size (in) 12 1/4 81/2 61/8 ~:::- ;:) r/) m8 ( ) !.~ ~ fl 0-- o c: 0- .- r/) r/) 0. ¡¡¡ :¡¡¡: .....-- Casing Size (in) 95/8 7 41/2 Top Surface Surface Surface Bottom 2,200 7,463 10,605 Weight (Ibslft) 40 26 12.6 Grade L-80 L-80 L-80 Type BTC BTC IBT O.D. (in) 10.625 7.656 5.200 Makeup Torque (ft-Ibs) NIA * NIA * 5,750 7,240 8,430 3,090 5,410 7,500 979 604 288 Comments: A 41/2" X 7" Mid-String ZXP Packer will be placed in the 41/2" monobore at approximately 7,200' MD (at least 200' above the 7" casing shoe). This packer will be set by pressuring up after landing the wiper plug on the cement job. * The make up of the buttress connection will be to the proper mark. Casina Desian Casing Shoe Safety Factors ( ) c Casing Setting Mud Wt Frac. Form Maximum Surface fl 0 Size Weight Depth When Set Grad Pressure ~ as ïii Press ;3 c ;:) {!? (in) (lbItt) Grade (TV D) (Ib/gal) (Ib/gal) (Ib/gal) (psi) m 95/8 40 L-80 2,200 9.4 14.3 8.45 1,473 3.54 2.26 5.24 7 26 L-80 6,667 9.5 15.0 9.00 2,630 1.92 1.42 2.43 41/2 12.6 L-80 9,717 9.5 17.7 9.40 2,630 2.27 1.57 1.60 Comments: Maximum Anticipated Surface Pressure Setting Depth Casing Size TVD MAWP * MASP ** Mud/Gas (in) (ft) (psi) (psi) Ratio 95/8 2,200 3,899 1,473 30170 7 6,667 5,033 2,630 30170 41/2 9,717 5,850 2,630 30170 * MAWP = Maximum allowable working pressure ** MASP = Maximum anticipated surface pressure Comments: MASP I MAWP CALCULATIONS: Surface casina: 9 5/8" (2.200' MD. 2.200' TVD) MASPfrac = «Fracture gradient at shoe + S.F.) x .052 x TVDshoe) - Hydrostatic pressure of gas column at the shoe. MASPfrac = (14.3 ppg + 0.5 ppg) x .052 x 2,200' - (.1 psilft x 2,200') MASPfrac = 1 ,693 psi - 220 psi MASPfrac = 1,473 psi. Page 6 of 13 . . MASPbhP = BHP open hole td - Hydrostatic pressure of mud portion - Hydrostatic pressure of gas portion MASPbhp = (9.00 ppg x .052 x 6.667') - (0.3 x 9.5 ppg x .052 x 6.667') - (0.7 x 0.1 psi/ft x 6.667') MASPbhp = 3,120 psi - 988 psi - 467 psi MASPbhp = 1,665 psi MASP = MASPbhp = 1,473 psi MAWP = (0.7 x Casing Burst) - (Mud Wt. - Backup Fluid Wt.) x .052 x TVD MAWP = (0.7 x 5,750) - (9.4 - 8.3) x .052 x 2,200' MAWP = 4,025 psi - 126 psi = 3,899 psi Intermediate casino: 7" (7,463' MD. 6.667' TVD) MASPfrac = ((Fracture gradient at shoe + S.F.) x .052 X TVDshoe) - Hydrostatic pressure of gas column at the shoe. MASPfrac = (15.0 ppg + 0.5 ppg) x .052 x 6,667' - (.1 psi/ft x 6,667') MASPfrac = 5,373 psi - 667 psi MASPfrac = 4,706 psi. MASPbhp = BHP open hole td - Hydrostatic pressure of mud portion - Hydrostatic pressure of gas portion MASPbhp = (9.40 ppg x .052 x 9,717') - (0.3 x 9.5 ppg x .052 x 9,717') - (0.7 x 0.1 psi/ft x 9,717') MASPbhp = 4,750 psi - 1,440 psi - 680 psi MASPbhp = 2,630 psi MASP = MASPbhp = 2,630 psi / MAWP = (0.7 x Casing Burst) - (Mud Wt. - Backup Fluid Wt.) x .052 x TVD MAWP = (0.7 x 7,240) - (9.5 - 9.4) x .052 x 6,667' MAWP = 5,068 psi - 35 psi = 5,033 psi Production casino: 41/2" (10.605' MD. 9.717' TVD) MASPfrac = (Fracture gradient at shoe + S.F.) x .052 x TVDshoo) - Hydrostatic pressure of gas column at the shoe. MASPfrac = (17.7 PP9 + 0.5 ppg) x .052 x 9,717' - (.1 psi/ft x 9,717') MASPfrac = 9,196 psi - 972 psi MASPfrac = 8,224 psi. MASPbhp = BHP open hole td - Hydrostatic pressure of mud portion - Hydrostatic pressure of gas portion MASPbhp = (9.40 PP9 x .052 x 9,717') - (0.3 x 9.5 PP9 x .052 x 9,717') - (0.7 x 0.1 psi/ft x 9,717') MASPbhp = 4,750 psi - 1,440 psi - 680 psi MASPbhp = 2,630 psi MASP = MASPbhp = 2,630 psi / MAWP = (0.7 x Casin9 Burst) - (Mud Wt. - Backup Fluid Wt.) x .052 x TVD MAWP = (0.7 x 8,430) - (9.5 - 9.4) x .052 x 9,717' MAWP = 5,901 psi - 51 psi = 5,850 psi Page 7 of 13 . . BOPE ProQram Casing Test Test Casing Test Fluid Pressure Size MAWP MASP Press Density BOPS Low/High Casing (in) (psi) (psi) (psi) (Iblgal) Size & Rating (psi) (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram Surface 95/8 3,899 1,473 3,000 9.4 (1) 13518" 5M blind ram 250/3,000 ('" (1) 13-518" 5M drilling spool with 3-1/8" 5M outlets (1) 13-5/8" 5M pipe ram (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram Intermediate 7 5,033 2,630 3,000 9.5 (1) 135/8" 5M blind ram 250/3,000 (1) 13-5/8" 5M drilling spool with 3-118" 5M outlets (1) 13-5/8" 5M pipe ram (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram Production 41/2 5,850 2,630 3,000 9.5 (1) 135/8" 5M blind ram 250/3,000 ... v (1) 13-5/8" 5M drilling spool with 3-118" 5M outlets (1) 13-5/8" 5M pipe ram ...-- Comments: Blowout Preventers The blowout preventer stack will consist of a 13·5/8" x 5000 psi annular preventer, a 13-5/8" x 5000 psi double gate ram type preventer ",,-/ with blind rams in the bottom and pipe rams in the top, a 13-5/8" x 5000 psi drilling spool (mud cross) with 3-1/8" x 5000 psi outlets, and a 13-5/8" x 5000 psi single pipe ram. The choke manifold will be rated 3-1/8" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor-boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mud pits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. Casing Test Pressures Casing test pressures are based on the lesser of (1) MASP, or (2) 70% of rated burst pressure of the casing adjusted for the mud weight used during the test less a 8.3 ppg back-up unless otherwise noted. Page 8 of 13 . . Wellhead Eauipment Summary Component Description Casing Hanger Type Casing Head 11" 3M X 9-5/8" Slip loc WI 2, 2" lPO, Landing Base for 20" Conductor, U, AA, PSl1, PR1 103/4" x 7" Fluted Mandrel Tubing Head 11" 3M Studded Bottom X 11" 5M Fig Top, WI 2, 2-1/16" 5M Studded Outlets, 11" x 4 1/2" Manual Slip U,AA,PSl1,PR1 Adapter Flange 11 " 5M X 4-1/16" 5M WI Seal Pocket and 3" H BPV Threads Comments: Directional Proaram Summary Build Turn Coordinates Sec. MD TVD Rate Rate Dogleg Inclination Azimuth +N/-S +E/-W VS No. Description (ft) (ft) (°/100') (°/100') (°/100') (deg) (deg) (ft) (ft) (ft) 1 Tie On 0 0 0 0 0 0 0 0 0 0 2 KOP 2,300.0 2,300.0 0 0 0 0 0 0 0 0 3 Build up Section 3.00 6.59 3.00 79.35 4 End of Build 3,504.0 3,425.8 3.00 6.59 3.00 36.12 79.35 67.8 360.8 366.8 5 1" Hold Section 0 0 0 36.12 79.35 6 End of 1st Hold 5,411.9 4,967.0 0 0 0 36.12 79.35 275.6 1,466.0 1,490.4 7 1s1 Drop Section -2.72 -1.25 2.00 74.63 8 End of 1 sl Drop 5,585.7 5,109.3 -2.72 -1.25 2.00 33.94 74.63 297.9 1 ,563.2 1,590.1 9 :;!,d Hold Section 0 0 0 33.94 74.63 10 End of 2nd Hold 7,497.2 6,695.1 0 0 0 33.94 74.63 580.9 2,592.4 2,656.6 11 :;!,d Drop Section -2.25 -5.68 2.25 74.62 12 End of 2nd Drop 9,005.8 8,117.0 -2.25 -5.68 2.25 0.00 74.62 695.9 3,010.8 3,090.2 13 TD 10,605.8 9,717.0 0 0 0 0.00 74.62 695.9 3,010.8 3,090.2 Comments: Vertical section calculated from a reference azimuth of 76.99° taken from surface location to bottom hole location. Potential Well Interference: Well CIRI West Fork #1-21 CIRI West Fork #2-21 Distance (ft) 94.80 96.47 Depth (MD) 3,209 o No serious interference exists. See attached directional plan and anticollision analysis for more details. Page 9 of 13 200 C c ::i2 0 400 ::i2 0 0 0 0 £2. to .£:; :s ã. 500 +' <D ?: 0 1:: ~ 0 'ë 600 ~ g; ?: <D 700 '5 ::¡ 0 ¡:: (f) -2000 -1000 0 1000 2000 3000 4000 5000 6000 7000 Vertical Section at 76.99° (3000ft/in] 900 1000 West(-)/East(+) (1500ft/in] Directional Survevina Summary o - 2,200' 2,200' - 7,463' 7,463' -10,605' x x x Comments: Drillina Fluid Proaram Summary 0 2,200 8.6 - 9.4 Gel I Gelex Spud Mud Gel, Gelex, Soda Ash, Caustic, Barite, Polypac Supreme UL Flo-Vis, PoluPac UL, KCI, SafeCarb 2,200 6,667 9.0 - 9.5 6% Flo-Pro wi Safecarb F&M, Barite, Lubetex, Caustic, Conqor 404, Sodium Meta Bisulfate Flo-Vis, DualFlo, KCI, Greencide 25G, 6,667 9,717 9.0 6% Flo-Pro wi Safecarb SafeCarb F&M, Barite, Caustic, Conqor 404, Sodium Meta Bisulfate Comments: See mud prognosis for details. Sized CaC03 (SafeCarb) will be used to controlleakoff. Page 10 of 13 . . Drillina Fluid Specifications Interval - TVD LSRV From To Density Vis 1 min PV YP Fluid Loss Drill Solids (ft) (ft) (Ib/gal) ( seclqt) (lb./100W) (cP) (lb/100 W) (cc) pH (0/0) 0 2,200 8.6 - 9.4 60 - 100 NIA 25 - 35 NC - 12 +1- 9.5 <7 2,200 6,667 9.0 - 9.5 30,000 8 - 12 7-9 +1- 9.5 +1- 5 6,667 9,717 9.0 - 9.5 30,000 10 - 14 <7 +1- 9.5 +1- 5 Comments: As a standard practice for long string completions, the drilling mud that will remain above the top of cement on the 4 W' production casing will be treated with corrosion inhibitor (Conqor 303A) at a concentration of 1 drum per 100 barrels of drilling fluid. See mud prognosis for details. Solids Control Equipment c:: 0 CD Qj Qj g 21 ~ III Qj c:: CD 0 Ë .s:: m CIJ ~ '0 ~ ~ I/) I/) Qj ~ õ CIJ CIJ Õ c:: c:: c:: ~ III ë III ~ .~ -g ~ =: e .s:: ð :::¡ CD Interval en 0 ::¡¡ (,,) (,,) N Comments 0-10,605' MD X X X X Closed Loop System, Full Containment Equipment Specifications Item (quantity, design type, brand, model, flow capacity, ete) Shaker 2 - Derrick Model 2 E48-90 F-3TA Desander NIA Desilter 1 - Derrick Model 0522 Mud Cleaner NIA Centrifuge 2 - MllSwaco units Cuttings Dryer NIA Cuttings Injection Marathon G&I Facility Zero Discharge NIA Comments: The solids control equipment will consist of two flowline cleaners, a desilter, and the MI centrifuge van. Included will be equipment to de-water the underflow from the mud processing equipment to allow for disposal of the cuttings and solids by slurrification and injection into the disposal well at the KGF. Page 11 of 13 . . Cement Proaram Summary Depth Gauge Top of Cement Open Casing Hole Ann Vol Slurry woe Hole Size MD TVD Size MD TVD ToTOC Vol Time Excess (in) (ft) (ft) (in) (ft) (ft) (ft~ (tf) (hrs ) (%) 95/8 2,200 2,200 12 1/4 0 ,/ 0 689 1,037 8 50 7 7,463 6,667 81/2 4,400 ,/ 4,150 388 542 8 35 41/2 10,605 9,717 61/8 6,900 t' 6,200 355 465 N/A 35 , Mix Water Compressive Casing / / Slurry TOC Streng1h Size Density Qty Yield Vol MD Qty WL FW (psi) (in) Slurry Cement Description (Iblgal) (sx) (tf/sx) (tf) (ft) ¡(gal/sx) Type (00) (%) 8hr 24hr 95/8 Tail Type I Cement 12 413 2.51 1,037 0 11.28 Fresh 812 0 500 Lead Class "G" 12.5 168 2.1 353 4,400 13.79 Fresh 7 Tail Class "G" 15.8 162 1.17 189 6,463 4.99 Fresh 4 1/2 Tail Class "G" 13.5 254 1.83 465 6,900 9.22 Fresh Comments: See cement prognosis for details and spacer specifications. Hydraulics Summary Rig mud pumps available are shown below. Max Press @ Displacet!nent @ Liner ID Stroke 90% WP 95%¡eff Max Rate Hole Sections Used Qty Make Model (in) (in) (psi) (gal/st~oke) (spm/gpm ) On 5 8 2,597 2.04 125/255 Surface 3 National Oil A600PT 125/255 Intermediate Well 5 8 2,597 2.04 5 8 2,597 2.04 125/255 Production Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. Hole Standpipe Min Nozzle Depth-MD Size Pump Rate Pressure AV ECD Size (ft) (in) (gpm) (psi) (fpm) (Ib/gal) (32"s) Remarks o - 1,900 12 1/4 633 1,850 124 6 - 13's Actual Data from BC 12 (@ 1,405' MD) 1,900 - 5,930 81/2 460 1,500 239 5 -15's Actual Data from BC 12 (@ 7,183' MD) 5,930 - 11,094 7 310 1,700 230 4 - 13's Actual Data from CLU 7 (@ 10,864' MD) Comments: See separate hydraulics calculations. 5" drillpipe used to calculate the surface and intermediate hole sections, 4" HT38 drillpipe used on the production hole section. Page 12 of 13 . . Formation Intearitv Test Procedure / Surface and Intermediate casing shoes will be tested to Leak-off. Prior to drilling out of casing strings, test BOPs and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests (LOT) are to be conducted as described below: 1. Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out. 2. Pull drill string into the casing shoe and close ram preventer, and line up to the choke manifold with a closed choke. 3. Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drillpipe pressures at 1/2 bbl intervals. A running plot of pressure versus volume should be kept by the drilling foreman while the test is in progress. 4. Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the lADe and morning reports. 5. Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. Page 13 of 13 . 121 1/4" 2M Diverter I ~ I Diverter Spool . Marathon Oil Well West Fork #3 Diverter I Flow line ~ / 116" Automatic QI = þ \ - I I \ 116" Diverter Line I Knife Valve / . . Marathon Oil Well West Fork #3 BOP Stack I Flow Nipple 1 -------. I Flow Line I 13 5/8" 5M Annular Preventer þ 13 5/8" 5M Double Ram Preventer Pipe Ram I I -----. I Blind Ram 1 / 21/16" 5M Manually Operated Valves 31/8" 5M Manually Operated Valve ŒillJ 1 Choke I 113 5/8" 5M Cross Î Pipe Ram 1 / 3 1/8" 5M Hydraulically Operated Valve 13 5/8" 5M Single Ram Preventer ~ Bottom of Single gate must be 24-45" from ground level for Glacier 1 rig placement. 135/8" 5M x 13 5/8" 5M Drilling Spool ~113 5/8" 5M Tubing Head Flange . . Marathon Oil Well West Fork #3 Choke Manifold ITO Gas Buster t Bleed off Line to Shakers ~ I!þ C ~ ~ q3 13" 5M Valves r 2 9/16" 10M Swaco Hydraulically Operated Choke 3 1/8" 5M Manually Adjustable Choke . . Surface Use Plan for West Fork #3 Surface location: 1,981' FNL, 1,092' FEL, Sec. 21, T6N, R9W, S.M. 1) Existing Roads The Swanson River Road off of Sterling Highway will be used for access to the West Fork #3 well and is shown on the attached map. Sterling, Alaska is the nearest town to the site. 2) Access Roads to be Constructed or Reconstructed No new roads will be required to access West Fork #3. 3) Location of existing wells Well West Fork #3 will be drilled on West Fork pad. A pad drawing is enclosed that shows existing wells and the proposed location of West Fork #3. 4) Location of existing and/or proposed facilities The locations of existing production buildings on the West Fork pad are shown on the enclosed pad drawing. No equipment resides in these buildings at this time. If commercial gas is found, equipment will be installed to tie West Fork #3 into the existing pipeline system. 5) Location of Water Supply A water supply well exists on the pad that West Fork #3 will be drilled from. 6) Construction Materials No construction is planned on the pad, only proper leveling of the pad will occur. 7) Methods of handling waste disposal; a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be hauled to Pad 41-18 of the Kenai Gas Field for disposal into Well KU 24-7, a Class" disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). b) Garbage All household and approved industrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be hauled to Pad 34-31 of the Kenai Gas field and injected in Well WD #1, an approved disposal well (AOGCC Permit #7-194). d) Chemicals . . Unused chemicals will be returned to the vendors that provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. 8) Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the existing water well on the pad. Town & Country will collect and transport sanitary wastes to their ADC approved disposal facility. No additional structures will be necessary. 9) Plans for reclamation of the surface West Fork #3 will be drilled from an existing pad. Reclamation of the pad, if required by the landowner, will occur after the abandonment of West Fork #3 and the other existing wells on the pad. 10) Surface ownership CIRI is the surface owner of the land at the West Fork pad. 11) Operator's Representative and Certification I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions that currently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and that the work associated with operations proposed herein will be performed by Marathon Oil Company and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U.S.C. 1001 for the filing of a false statement. Date: <6/1.'L/6C¡ d1J~ 9~ Willard J. Tank, 1dvanced Senior Drilling Engineer Marathon Oil Company P. O. Box 3128 Houston, TX 77253 (713) 296-3277 Name and Title: . . 1 SECTION 21 T6N R9W SM AK .....J Z u. ..- to ~ WEST FORK NO.3 '\ AS STAKED ./'1 ~ GRID N:2411693.656 /x X\ x--"x_x GRID E:345130.584 x J -X_ -, LATITUDE: 60035'54.555''N x/ X\ o ì LONGITUDE: 150051'41'879"WQ/ /x )( ELEV. 296' ,¿x X\ x ./ ~ x J A x X_X-ciI_x__// XI / 0 COMPRESSOR X BUILDING / _ (ON SKIDS) ¡ .r c:=5 61 ì CO~TROL POINT #1 'I IN=2411699.04 IiJ / E = 345015.96 WEST FORK NO. 2-21 /IX X ELEV = 296.64 11.5' x 15.3' WELL HOUSE f8' L 10' DIA. WELL CELLAR I.!!J I N = 2411672.56 -x_x E = 345224.71 WEST FORK NO. 1-21 : __ -x-x_x~ 296.2 15.3' x 15.3' WELL HOUSE I __ __ x-x_x_ 10' DIA. WELL CELLAR __ x-x---I>H.24..1.Jp,;36.80 X -- __ EX'ST,"~ __ E =345:150'7== ~GE W'''H ..ELEV. = 295.6 -- - -- I . 1919' FEL v CONTROL POINT #2 N = 2411680.08 E = 345484.82 ELEV = 304.77 I """'" ...... F , .... ~~ 0 Al.AI t I :.(~ * ~.LI, -~..... -,~ , : * 49 I.I:i .,,* ~ "" , ~ ~ ~ ~ , 7J. rr "'" , ~ M. SCOTT MCLANE¡O __ I ..- - " ~ 4928-S ,: I,'~() .;P - " . ~fSS I ()tIÞ.\. \.. ...~.. ",\"", SURVEY NOTES 1. BASIS OF HORIZONTAL COORDINATES IS KEN1 CORS STATION, BASED ON NGS OPUS SOLUTION, NAD27 ALASKA STATE PLANE ZONE 4. 2. BASIS OF VERTICAL CONTROL IS NGS MONUMENT Q791991 RESET AT MILEPOST 83.7 OF THE STERLING HIGHWAY. ELEVATION = 252.34 FEET (NAVD 88). 3. OFFSETS TO SECTION LINE DETERMINED FROM TIES TO THE C1/4 AND W1/4 SECTION 21 FOUND. o I SCALE 1" = 100' 100 I FEET 200 I P.C. 8cx 468 SCLCCTNA, AK 99669 ~ Consulting C;roup ~ Testing DATE Œ SURVEY:5!10/04 No. DATE BY APP. __ BOOK NO.: 01-33 r-EL 9C7.283.421 8 FAX 9C7.283.3265 PRo.£CT NO.: 043009 DRAWING NO.: 043009S1.O SCAlE 1".100' DRAWN BY: 115M REVISIONS GRID (M) Marathon IIARAlIiON Oil Com pan y . Alaska Region ~ ENGINEER APPROVAl BY DAlE WEST FORK PAD STERLING, ALASKA WEST FORK NO.3 WELL AS STAKED SURFACE LOCATION DIAGRAM I \ PRo.£CT SIRUCT. PROCESS ....""AN. ELECT. INSlRUII. ARCH. SCALE OWN..... DAlE 5/15/1>< aiKD. DAlE 1".100' Al'P.o. _ DAlE Al'P. w. T_ "...,.. FIlE NO. ITIPE DRG MOD DISC SYST BC3 SOOO 000 DWG NO. 0001 SliT NO REV 1 0 \ NORTH J \' ~ 1/ Y';::;;'-"Y' ~"::Ý ~ - MOC estfork #3 10,605' md 9717' tvd -9400' sstvd . R T I I L_______ I I I I I I I I I t ...--..., I,~' 11ErïASSER} I, I ! '...--' I r-----1__J-----1 r 1 I t I ..--, 11 I I I II I : I I ,! ! I III: I I i .. 1 t 1101 t I .. I I I II 1 , I I II 1 J '" I I ~ u: R I 1 2Ii II I L____..I 1..._____..11 I r---~--~~ì I 1 ~ -\oj "\...! ! L.. r-----' I I b:NT~ 1 IMT I 14')(10' I I I I I 1 I I I 1 DlI4P I -\ I ! I, I I ,-, I 1....____.1 1 KCIJoIY 3' X 12' j 1111 II . 75HP 6X5 U' .. 'RIll! IIE&\UEIr .~ _ 1IIUH \.. 7'.:itP 6X5 11" ~ 1,.:,:.1 GLACIER DRILLING RIG #1 MUD PITS AND PUMP ROOM LAYOUT 75 HP , X :5 U' !l ..... 1519 6X:5 11' r'\ 5\1 9l. IHiIIO PT "" I I i- '- I~I ~ m.~ ill m._~ ---¡ 5'" 9L A-6OO PT - I T T '\ ~, - . ... I'I.L PIT 104'''' ! '.... I ~ '\ I~nal ~..I ¢:: 0 -500 10 N II E 0 -0 CIJ ~ C/) 500 1000 1500 2000 2500 3000 3500 - - G> .!! 4000 - .c - Q, G> 4500 C c; (J 5000 :e ;!: 5500 G> :::s ~ l- I 6000 V 6500 7000 7500 8000 8500 9000 9500 10000 10500 RATHON Oil Com Location: Kenai Peninsula, Alaska Field: West Fork Installation: West Fork 1-21 -400 Seale 1 em = 200 ft 400 j l 9 5/8" Casing KOP 6.00 12.00 DLS: 3.00 deg/100ft 24.00 30.00 End of Build Sterling B-4 Tgt o s ~ '%>. Q'OI"~ ~ ~'" \I}~ Q' í9 y Slot: Slot #3 Well: West Fork#3 Wellbore: West Fork#3 Ver 4 East (feet) -> 800 1200 1600 2000 2400 2800 3200 3600 1200 /~ 800 ^ I 1> ~I' Z 400 0 I o m !: IS'~ ~..;. í9~ 'Y~ .91' .---<:\ >. ~o 0- ~~~..;. ~rJ! Q ~.t o~ &1': ~t(¡¡ II -400 ~ o ;::II End of Hold / Casing PI ');, ~ 7" Casing Bottom Conglomerate 29.38 24.88 DLS: 2.25 deg/100ft WF#3 Tyonek Tyonek T-2 Tgt 4 1/2" Casing -500 -0 500 1000 1500 2000 2500 3000 3500 Scale 1 em = 250 II Vertical Section (feet) -> Azimuth 76.99 with reference 0.00 N, 0.00 E from Slot #3 15.88 11.38 6.88 2.38 TDTgt / WELL PROFILE DATA Point MD Inc AzI TVD North e..t deg/10011 V. Sect Tie on 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 KOP 2300.00 0.00 0.00 2300.00 0.00 0.00 OJ)() 0.00 End of BuildITurn 3503.95 36.12 79.35 3425.78 67.82 360.76 3.00 366.76 Target WF#3 Sterling B 5411.88 36.12 79.35 4967.00 275.59 1466.04 0.00 1490.45 End of DropITum 5585.66 33.94 74.63 5109.32 297.92 1563.19 2.00 1590.13 End of Hold 7497.21 33.94 74.63 6695.13 580.86 2592.37 0.00 2656.59 Target WF#3 Tyonek T-2 9005.80 0.00 74.62 8117.00 695.90 3010.78 2.25 3090.16 T.D. & Target WF#3 TD 10605.80 0.00 OJ)() 9717.00 695.90 3010.78 0.00 3090.16 reate y; Planner Date plotted: 3-Aug-2004 Plot reference is West F0rk#3 Ver 4. Ref wellpath is West F0rk#3 Vers#4. Coordinates are in feet reference Slot #3. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to Mean Sea Level: 317.00 ft. Plot North Is aligned to TRUE North. . . MARATHON Oil Company,Slot #3 West Fork 1-21, West Fork,Kenai Peninsula, Alaska PROPOSAL LISTING Page 1 Wellbore: West Fork#3 Ver 4 Wellpath: West Fork#3 Vers#4 Date Printed: 3-Aug-2004 ... ..,. INTEQ Created 8-Jun-2004 Government ID Latitude N60 35 54.5552 51 41.8788 North~_~~_ Goord SYStem Name 347077.815 2413649.025 AK-4 on NORTH AMERICAN DATUM 1927 datu -~_._,----_._-- -_.._~--_._----_.._--------_.._--"--- All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 317.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 76.99 degrees Bottom hole distance is 3090.16 Feet on azimuth 76.99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . MARATHON Oil Company,Slot #3 West Fork 1-21, West Fork,Kenai Peninsula, Alaska PROPOSAL LISTING Page 2 Well bore: West Fork#3 Ver 4 Well path: West Fork#3 Vers#4 Date Printed: 3-Aug-2004 _i. BIll. INTEQ -.' ...... >i >\\....... ."/ i.·..',..' i... ........ 'i MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft East[ft] Dogleg Vertical Easlil1g deol10Oftl Seclionlftl 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 345130.5 2411693.6 100.0( 0.00 0.00 100.0c O.OON O.OOE 0.00 0.00 345130.5 2411693.6 200.0( 0.00 0.00 200.0C O.OON O.OOE O.OO~_ 0.00 345130.5 2411693.6 300.0( 0.00 0.00 300.0C O.OON O.OOE 0.00 0.00 345130.5 2411693.6 400.0( 0.00 0.00 400.0C O.OON O.OOE 0.00 0.00 345130.5 2411693.6 500.0( 0.00 0.00 500.0C O.OON O.OOE 0.00 0.00 345130.5 2411693.6 600.0( 0.00 0.00 600.0C O.OON O.OOE 0.00 0.00 345130.5 2411693.6 700.0C 0.00 0.00 700.0C O.OON O.OOE 0.00 0.00 345130.5 2411693.6 800.0C 0.00 0.00 800.0C O.OON O.OOE 0.00 0.00 345130.5 2411693.6 900.0C 0.00 0.00 900.0C O.OON O.OOE 0.00 0.00 345130.51 2411693.6 1000.0( 0.00 0.00 1000.0( O.OON O.OOE 0.00 0.00 345130.5 2411693.6 1100.0( 0.00 0.00 1100.0( O.OON O.OOE 0.00 0.00 345130.51 2411693.6 1200.0C 0.00 0.00 1200.0( O.OON -.MQ1; - 0.00 0.00 345130.51 2411693.6 1300.01 0.00 0.00 1300.0( O.OON O.OOE 0.00 0.00 345130.51 2411693.6 1400.01 0.00 0.00 1400.0( O.OON O.OOE 0.00 0.00 345130.5 2411693.6 1500.01 0.00 0.00 _ 150_tLQ! . O.OON O.OOE --º--ºº 0.00 345130.5 2411693.6 1600.0c 0.00 0.00 1600.0( O.OON O.OOE 0.00 0.00 345130.5 2411693.6 1700.0c 0.00 0.00 1700.0( O.OON O.OOE . 0.00 0.00 345130.5 2411693.6 1800.01 0.00 _--ºJ2D _ 1800.0( O.OON O.OOE QÆ) 0.00 345130.5 2411693.6 1900.0c 0.00 0.00 1900.0( O.OON O.OOE 0.00 0.00 345130.5 2411693.6 2000.0c 0.00 0.00 2000.0( O.OON O.OOE __-ºÆ) 0.00 345130.5 2411693.6 2100.01 0.00 0.00 2100.0( O.OON O.OOE 0.00 0.00 345130.5 2411693.6 2200.0c 0.00 0.00 2200.0( O.OON O.OOE 0.00 0.00 345130.51 2411693.6 2300.0c 0.00 0.00 2300.0( O.OON O.OOE 0.00 0.00 345130.5 2411693.6 2400.0C 3.00 79.35 2399.91 0.48N 2.57E 3.00 2.62 345133.11 2411694.1 2500.0( 6.00 79.3< 2499.6< 1.93N 10.28E 3.00 10.41 345140.8! 2411695.4 2600.0( 9.00 79.3< 2598.7 4.34N 23.11 E 3.00 23.4~ 345153.7! 2411697.7 2700.0( 12.00 79.35 2697.01 7.71N 41.02E ~'ººt- 41.7( 345171.6! 2411700.8 2800.0( 15.0C 79.35 2794.31 12~~__ 63.~1--_~t-. 65.02 345194.6! 2411704.8 2900.0( 18.00 79.35 2890.11 -------.J7.2zr,/ 91.87E 3.00 93.4( 345222.6 2411709.7 3000.0( 21.00 79.31 2984.4' 23.44N 124.67E 3.00 126.7< 345255.5- 2411715.4 3100.0( 24.0C 79.31 3076.81 30.50N 162.27E 3.00 164.91 345293.2 2411722.0 3200.0( 27.00 79.31 3167.0£ 38.46N 204.58E 3.00 207.91 345335.6 2411729.4 3300.0( 30.00 79.31 3254.9~ 47.27N 251.47E 3.00 255.61 345382.6 2411737.6 3400.0( 33.00 79.35 3340.11 56.92N 302.81 E 3.00 307.85 345434.0 2411746.6 3500.0C 36.00 79.35 3422.5~ 67.39N 358.47E 3.00 364.44 345489.8 2411756.3 3503.9 36.1~ 79.35 3425.7~ 67.82N 360.76E 3.00 366.7E 345492.1 2411756.7 3600.0c 36.12 79.35 3503.3 78.28N 416.40E 0.00 423.3 345547.9 2411766.4 3700.0c 36.1~ 79.35 3584.11 89.17N 474.33E 0.00 482.21 345606.0 2411776.5 3800.0r 36.12 79.3'i 3664.9 100.06N 532.26E 0.00 541.1' 345664.0 2411786.7 3900.0( 36.12 79.3'i 3745.71 110,95N 590.19E 0.00 6º~, 345722.1 2411796.8 4000.0r 36.P 79.3'i 3826 .4~ 121.84N 648.12E 0.00 658.91 345780.2( 2411806.9 4100.0C 36.12 79.35 .-. 3907.2 132.73N 706.06E 0.00 717.81 345838.2 2411817.1 4200.0C 36.12 79.35 3988.05 143.62N 763.99E 0.00 776.70 345896.3 2411827.2 4300.0( 36.12 79.35 4068.8 154.51N 821.92E -Jì.QQ 835.60 345954.3 2411837.3 4400.0( 36.12 79.35 4149.61 165.40N 879.J.!.~ __ 0.00 894.5( 346012.41 2411847.5 4500.0C 36.12 79.35 4230.3~ 176.29N 937.78E_-ºÆ)_ 953.3~ 346070.5 2411857.6 4600.0C 36.12 79.35 4311.1 187.18N 995.71E 0.00 1012.21 346128.51 2411867.7 4700.0C 36.12 79.35 4391.95 198.07N 1053.64E 0.00 1071.11 346186.6: 2411877.8 4800.0C 36.12 79.3'i 4472.7 208.96N 1111.57E 0.00 1130.0.! 346244.7 2411888.0 4900.0C 36.12 79.35 4553~~ _ 219.85N 1169.51E _--ºJ2D 1188.9 346302.71 2411898.1 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 317.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 76.99 degrees Bottom hole distance is 3090.16 Feet on azimuth 76.99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . MARATHON Oil Company,Slot #3 West Fork 1-21, West Fork,Kenai Peninsula, Alaska PROPOSAL LISTING Page 3 Wellbore: West Fork#3 Ver 4 Wellpath: West Fork#3 Vers#4 Date Printed: 3-Aug-2004 Bi. ....,. INTEQ < \'«< ... 'Ji/i<))..,·· ....<.,. MD[ft) Inc[deg] Ali[deg) TVD[ft) North[ft) East{ft] Dogleg Vertical Easting rdea/10Oft! I SectionIft! 5000.0C 36.12 79.3~ 4634.2! 230.74N 1221A1f -- 0.00 1247.8 346360.81 2411908.2 5100.0C 36.1 79.3~ 4715.0 241.63N 1285.37E 0.00 1306.7E 346418.9 2411918.4 5200.0C 36.1 79.3~ 4795.81 252.52N 1343.:iQl; -' 0.00 1365.6€ 346476.9f 2411928.5 5300.0C 36.12 79.3~ 4876.6 263.41 N 1401.23E 0.00 1424.5€ 346535.0 2411938.6 5400.0C 36.12 79.3~ 4957.41 274.30N 1459.16E 0.00 1483.41 346593.1 2411948.8 5411.8~ 36.12 79.3~ 4967.0( 275.59N 1466.04E 0.00 1490.41 346600.0 2411950.0 5500.0C 34.9E 77.02 5038.6! 286.07N 1516.19E 2.00 1541.6 346650.2 2411959.8 5585.66 33.94 74.63 5109.3 297.93N 1563.19E 2.00 1590.1 346697.4 2411971.0 5600.0( 33.94 74.61 5121.2 300.05N 1570.91E 0.00 1598.1 346705.1 2411973.0 5700.0( 33.94 74.61 5204.11 314.85N 1624.75E 0.00 1653.9 346759.2 2411987.1 5800.0( 33.94 74.63 5287.1 329.65N 1678.59E 0.00 1709.7 346813.2 2412001.2 5900.0( 33.94 74.61 5370.0! 344.45N 1732.43E 0.00 1765.5( 346867.2 2412015.3 6000.0( 33.94 74.63 5453.01 359.25N 1786.27E 0.00 1821.2~ 346921.2 2412029.4 6100.0( 33.94 74.63 5536.01 374.05N 1840.11E 0.00 1877.0f 346975.3 2412043.5< 6200.0( 33.94 74.61 5618.9 388.86N 1893.95E 0.00 ~8 347029.3 2412057.6 6300.0( 33.94 74.63 5701.9 403.66N 1947.79E 0.00 1988.66 347083.3 2412071.7 6400.0e 33.94 74.61 5784.8! 418.46N 2001.63E 0.00 2044.4~ 347137.3 2412085.8 6500.0e 33.94 74.61 5867.81 433.26N 2055.47E 0.00 2100.2 347191.4 2412099.9 6600.0( 33.94 74.63 5950.81 448.06N 2109.31E 0.00 215M~ f---' 347245.4 2412114.0 6700.0( 33.94 74.63 6033.7 462.86N 2163.15E 0.00 2211.8~ 347299.4 2412128.1 6800.0e 33.94 74.63 6116.7 477.66N 2216.99E 0.00 2267.61 347353.4 2412142.2 6900.0e 33.94 74.63 6199.6! 492.46N 2270.83E 0.00 2323.4e 347407.5 2412156.2 7000.0e 33.94 74.61 6282.6 507.27N 2324.67E 0.00 2379. H 347461.5 2412170.3 7100.0e 33.94 74.63 6365.6e 522.07N 2378.51E 0.00 2434.9f 347515.5 2412184.4 7200.0( 33.94 74.63 6448.5€ 536.87N 2432.35E 0.00 2490.7 347569.5 2412198.5 7300.0e 33.94 74.63 6531.5 551.67N 2486.19E 0.00 2546.56 347623.6 2412212.6 7400.0e 33.94 74.63 6614.4E 566.47N 2540.03E 0.00 2602.3" 347677.6 2412226.7 7497.21 33.94 74.61 6695.1 580.86N 2592.37E 0.00 2656.5! 347730.1 2412240.4 7500.0C 33.88 -~ 6697.44 581.27N 2593.87E 2.25 2658.14 347731.6 2412240.8 7600.0C 31.63 74.63 6781.5 595.62N 2646.03E 2.25 2712.2C 347783.9 2412254.5 7700.0C 29.38 74.63 6867.6! 609.07N 2694.98E -~ -' 2762.91 347833.1 2412267.3 7800.0C 27.13 74.63 6955.7 621.62N 2740.§2!; ~- 2.25 2810.21 347878.9 2412279.2 7900.0C 24.88 74.63 7045.6< 633.24N 2782.ªID; ~- 2.25 2854.0 347921.3 2412290.3 8000.0C 22.63 74.63 7137.16 643.92N 2821.73E 2.25 2894.26 347960.3c 2412300.5 8100.0C 20.38 74.63 7230. H 653.63N 2857.08E 2.25 2930.8~ 347995.7 2412309.7 8200.0C 18.13 74.63 7324.5! 662.38N 2888.88E -~ 2963.81 348027.6 2412318.0 8300.0C 15.88 74.63 7420.21 670.13N 2917.07E 2.2'i 2993.0~ 348055.9 2412325.4 8400.0C 13.61 74.63 7516.9C 676.88N 2941.63E 2.25 3018.5C 348080.6 2412331.8 8500.0e 11.38 74.63 7614.5 682.62N 2962.51E 2.25 3040.11 348101.51 2412337.3 8600.0e 9.13 74.63 7712.9 687.34N 2979.67E 2.25 3057.9 348118.71 2412341.8 8700.0C 6.88 74.63 7811.94 691.03N 2993,10E -~ 3071.8 348132.21 2412345.3 8800.0C 4.63 74.61 7911.4 693.69N 3002.77E 2.25 3081.81 348141.91 2412347.8 8900.0C 2.38 74.63 8011.2 695.31N 3008.67E 2.25 3087.91 348147.8 2412349.4 9000.0C 0.13 74.63 8111.21 695.89N 3010.78E 2.25 3090.1 348150.0( 2412349.9 9005.8e 0.00 74.62 8117.0C 695.90N 3010.78E 2.25 3090.11 348150.0( 2412350.0 9100.0C 0.00 74.62 8211.2C 695.90N 3010.78E 0.00 3090.11 348150.0e 2412350.0 1---. 9200.0e 0.00 74.62 8311.2C 695.90N 3010.78E 0.00 3090.11 348150.0( 2412350.0 9300.0C 0.00 74.6 8411.2C 695.90N 3010.78E 0.00 3090.11 348150.0e 2412350.0 9400.0C 0.00 74.6 8511.2C 695.90N 3010.78E 0.00 3090.16 348150.0( 2412350.0 9500.0C 0.00 74.6 8611.2C 695.90N 3010.78E 0.00 3090.16 348150.0( 2412350.0 9600.0C 0.00 74.62 8711.2C 695.90N 3010.78E 0.00 3090.16 348150.0e 2412350.0 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 317.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 76.99 degrees Bottom hole distance is 3090.16 Feet on azimuth 76.99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . MARATHON Oil Company,Slot #3 West Fork 1-21, West Fork,Kenai Peninsula, Alaska PROPOSAL LISTING Page 4 Wellbore: West Fork#3 Ver 4 Wellpath: West Fork#3 Vers#4 Date Printed: 3-Aug-2004 .1. ~ INTEQ TVD[ft] North[ft) East[ft] Vertical Easting 100ft Sect' 9700.0 0.00 74.6 695.90N 3010.78 0.00 3090.1 348150.0 2412350.0 9800.0 0.00 74.6 695.90N 3010.78 0.00 3090.1 348150.0 2412350.0 9900.0 0.00 74.62 695.90N 3010.78 0.00 3090.1 348150.0 2412350.0 10000.0 0.00 74.62 695.90N 3010.78 0.00 3090.1 348150.0 2412350.0 10100.0 0.00 74.6 695.90N 3010.78 0.00 3090.1 348150.0 2412350.0 10200.0 0.00 74.6 695.90N 3010.78 0.00 3090.1 348150.0 2412350.0 10300.0 0.00 74.6 695.90N 3010.78 0.00 3090.1 348150.0 2412350.0 10400.0 0.00 74.62 695.90N 3010.78 0.00 3090.1 348150.0 2412350.0 10500.0 0.00 74.6 695.90N 3010.78 0.00 3090.1 348150.0 2412350.0 10600.0 0.00 74.62 695.90N 3010.78 0.00 3090.1 348150.0 2412350.0 10605.8 0.00 0.00 695.90N 3010.78 0.00 3090.1 348150.0 2412350.0 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Datum #1 317.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 76.99 degrees Bottom hole distance is 3090.16 Feet on azimuth 76.99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . MARATHON Oil Company,Slot #3 West Fork 1-21, West Fork,Kenai Peninsula, Alaska PROPOSAL LISTING Page 5 Wellbore: West Fork#3 Ver 4 Wellpath: West Fork#3 Vers#4 Date Printed: 3-Aug-2004 _i. -wa- INTEQ MDft 2300.0 3503.9 5411.8 7463.31 7497.21 9005.8 10605.8 Name 36 1.4 36 1.4 3557.2 36 1.4 Lon ¡tude Eastin W150 5041.57 W150 5041.57 W150 5112.51 W150 5041.57 Norhti Last Revised 2412350.0 8-Jun-200 2412350.0 8-Jun-200 2411950.0 8-Jun-200 2412350.0 8-Jun-200 Latitude N60 N60 N60 N60 348150.0 348150.0 346600.0 348150.0 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 317.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 76.99 degrees Bottom hole distance is 3090.16 Feet on azimuth 76.99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated 2400 2200 2000 1800 1600 1400 1 ~ 1200 ( ) .! ~ 1000 1:: 0 Z 800 600 400 200 ¢:: 0 0 0 .... II E :: -200 Q) ro 0 (J) -400 r&a. BAKER IIUGIIIS INTEQ Seale 1 cm = 100 ft -200 0 200 400 600 ~ 5300 ~ 5200j 5100 ¡ 5000f 4900 j 4800 f 4700 ; 4600i 4500 j 44001 4300 + 4200 ; 4100 j 4000 .¡: 3900+ 3800 ' . 3700 f 3800, 3500 ./- 3400 i 3300 ~ 3200 ¡ 3100f / 30001 29001 2800f 2700 ~ 26001 2500¡' 2400 t 2300 i 2200 I 2100 f 2000/. -200 0 200 400 600 Scale 1 em = 100 ft MARATHON Oil Company Location: Kenai Peninsula, Alaska Field: West Fork Installation: West Fork 1-21 Slot: Slot #3 Well: West Fork#3 Wellbore: West Fork#3 Ver 4 800 East (feet) -> 1000 1200 1400 1600 1800 2060 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 WF#3 TO ~ "... . "- '!¡¡, " ''b .'" ~ "'- " " >'b "b ",,, ~''b '\, ,,'If¡, ",v''bv~''1¡, 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 East (feet) -> 2400 2200 2000 . 1800 1600 1400 ^ 1200 Z o ;+ 1000 ..a: är CD - 800 - 600 400 200 en o -0 ~ o 3 -200 II ...... o o -400 ~ RA THON Oil Com y location: Kenai Peninsula, Alaska Field: West Fork Installation: West Fork 1-21 Slot: Slot #3 Well: West Fork#3 Wellbore: West Fork#3 Ver <I Created by: Planner Date plotted: 4-Aug-2004 Plot refeiencelS-weSfFork#3n-ver~ Ref wellpath Is West Fork#3 Vers#4. Coordinates are in feet reference Slot #3. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to Mean Sea Level: 317.00 ft. Plot North to TRUE North. TRUE NORTH o 10 350 340 20 290 280 270 260 250 200 160 190 180 170 Normal Plane Travelling Cylinder - Feet 70 80 90 100 110 All depths shown are Measured depths on Reference W I . . West Fork#3 Vers#4, West Fork#3 Ver 4 Slot #3, West Fork 1-21 CLEARANCE LISTING Page 1 Date Printed: 4-Aug-2004 West Fork, Kenai Peninsula, Alaska Mi. .Au INTEQ Ellipse separations are reported ONLY if BOTH wells have uncertainty data On Iv Depth and MaQnetic Reference Field error terms are correlated across tie points Cutoff is calculated on CENTRE to CENTRE distance Summary data uses Closest Approach clearance calculation for all minima Hole size/CasinQs are NOT included Hole size/CasinQs are NOT subtracted from Centre-Centre distance Ellipses scaled to 2.00standard deviations. ClosinQ Factor Confidence limit of 99.80% Errors on Ref start at Slot Permanent Datum (0.00) Report uses Revised: (D-C)/E Factor Calculation Created 8-Jun-2004 Last Revised 3-Au -2004 Government ID Last Revised 8-Jun-2004 ,..eêi$ùmma Offset Offset Offset WellName Wellbore Slot Latitude ----"'ºº--_;35 54.5552 Lon itude W150 51 41.8788 Coord Stem Name 2413649.025 AK-4 on NORTH AMERICAN DATUM 1927 datu nment True 1-21 1-21 (AWB) Slot #1 1-21 1-21RD Slot #1 2-21 2-21 Slot #2 Offset Minimum MD[ft] Structure Distance ft West Fork 94.80 3209.2 1-21 West Fork 94.80 1-21 West Fork 96.47 0.00 0.00 1-21 Ellipse MD[ft] Clearance Clearance Factor MD[ft] All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 317.0ft above Mean Sea Level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated . . West Fork#3 Vers#4, West Fork#3 Ver 4 Slot #3, West Fork 1-21 CLEARANCE LISTING Page 2 Date Printed: 4-Aug-2004 West Fork, Kenai Peninsula, Alaska Ba. ØWLs INTEQ i&,'C¡,¿"',',,,,",,¡;;,,¡ ii"'· .'<i " , , '" Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Closest Ellipse MD[ft] WD[ft] North[ft] East[ft] MD[ft] WD[ft] North[ft] East[ft] From Approach Separation Highside Distance [ft] Irdãa1 I rft1 0.00 0.00 O.ºW O.OOE 1-21 0.00 1.40 53.97!; 220.67F 103. 227.1E -- 100.0C 1 OO~QÇ O.OON O.OOE 1-21 98.59 99.99 53.81!; 220.72F 103.7 227.1E 200.0C 200.0C O.OON O.OOE 1-21 198.51 199.9! 53.31!; 220.86F 103.f 227.2C 300.0C 300.0C O.OON O.OOE 1-21 298.5 299.9 52.48ii 221.091: 103} 227 .2~ 400.0C 400.0C O.OON O.OOE 1-21 397.91 399.3( 51.55~ 221.53F 103.1 227.4E 500.0C 500.0C O.OON O.OOE 1-21 497.6 499.01 50.87~ 222.11F 102.9 227.8 600.0C 600.0c O.OON O.OOE 1-21 597.3 598.71 50.53~ 222.71F 102.8 228.3E 700.0C 700.0C O.OON O.OOE 1-21 697.4' 698.8' 50 .40~ 223.29F 102.7 228.91 800.0C 800.0C O.OON O.OOE 1-21 796.9~ 798.3 50.52~ 223.91 I' 102.7 229.5E 900.0C 900.0C O.OON O.OOE 1-21 896.91 898.2~ 50.84~ 224.601' 102.8 230.29 1000.0C 1000.0C O.OON O.OOE 1-21 997.T 999.m 50.96~ 225.091' 102.8 230.79 1100.0C 1100.0C O.OON O.OOE 1-21 1098.21 1099.6 50.98~ 225.311' 102.8 231.0C 1200.0C 1200.0C O.OON O.OOE 1-21 1198.5! 1199.91 51.12~ 225.331' 102.8 231.0E 1300.0C 1300.0C O.OON O.OOE 1-21 1¡!~ --, 1299.71 51.37~ ..- 225.341' 102.8 231.P 1400.0C 1400.0C O.OON O.OOE 1-21 1397.9\ 1399.31 51.65~ 225.51 I' 102.9 231.3E 1500.0C 1500.0C _--º-,QW ----.---- O.OOE 1-21 1497.8 1499.21 51.82~ 225.801' 102.9 231.6 1600.0C 1600.0C O.OON O.pOE 1-21 1598.0 1599.4( 51.87~ 226.061' 102.9 231.91 1700.0C 1700.0C O.OON O.OOE 1-21 1698.4( 1699.7 52.00~ 226.161' 103.0 232.0 1800.0C 1800.0C O.OON O.OOE 1-21 _ ___ 1798.2 . 1799.6< 52.37~ 226.21 E 103.0 232.19 1900.0( 1900.0C O.OON O.OOE 1-21 1898.11 1899.5 52.785 226.32E 103.1 232.39 2000.0C 2000.0C O.OON O.OOE 1-21 1998.01 1999.4 53.035 226.50E 103.2 232.6 2100.0C 2100.0C O.OON O.OOE 1-21 -- 2098.2 2099.5~ 53.125 226.66E 103.2 232.80 2200.0C 2200.0C O.OON O.OOE 1-21 2198.5 2199.9( 53.275 226.69E 103.2 232.8 2300.0C 2300.0C O.OON O.OOE 1-21 2298.3~ 2299.71 53.39~ 226.74E 103.3 232.9 2400.0C 2399.9E 0.48N 2.57E 1-21 2397.9 2399.2 53.37~ 226.99E 24.2 230.7~ 2500.0C 2499.6 1.93N 10.28F 1-21 2498.1! 2499.5 53.34~ 227.16E 25.1 223.81 2600.0C 2598.7 4.34N . 23JjJ; j-21___ 2597.11 2598.4 53.41 ~ 227.22E 26.7 212.1 ~ 2700.0C 2697.0~ 7.71N 41.02F 1-21 2695.4 2696. 7~ 53.61~ 227.31E 29.4 196.1 2800.0C 2794.31 12.02N 63.96F 1-21 -- 2793.1 2794.4~ 53.65~ 227.27E 33.5 176.0~ 2900.0C 2890.1E 17.27N 91.87E 1-21 2889.21 - 2890.6 53.58~ 227.04E 39.8 152.6~ 3000.0C 2984.4 23.44N 124.67E 1-21 2983.0 2984.4( 53.68~ 226.83F 49.6 128.0C 3100.0C 3076.81 30.50N 162.27E 1-21 3075.51 3076.8f 53.77~ 226.78F 65.3 106.1 3200.0C 3167.0E 38.46N 204.58E 1-21 3165.4! 3166.8' 53.83~ 226.66F 87.4 94.89 3209.2 3175.21 39.24N 208.73 1-21 ._- 1---. 3173.6 3175.0 53.85( 226.65F 89.7 94.8( 3300.0( 3254.9' 47.27N 251.471 1-21 3253.2! 3254.61 54.11 ~ 226.581' 111.A 104.3! 3400.0( 3340.11 56.92N 302.811 1-21 3338.5( 3339.91 54.38~ 226.691' 130.r 134.81 3500.0( 3422.5~ ._-ºI..3.ID'-1 __~58An l:£L 3420.8( 3422.11 54.605 226.70F 142.1 179.5 3503.9' 3425.7! 67.82N 360.761 1-21 3423.9! 3425.31 54.61~ 226.691' 142'< 181.5' 3600.0( 3503.3 78.28N 416.401 1-21 3501.21 3502.6 54.94~ 226.691' 150f 231.81 3700.0( 3584.1' 89.17N 474.331 1-21 3581.81 3583.11 55.34~ 226.63F 156.1 286.7 3800.0( 3664.9' 100.06N 532.261 1-21 3662.0C 3663.41 55.74~ 226.51 F 160.r 343.1 3900.0( 3745.71 110.95N 590.191 1-21 3742.6 3744.0 56.295 226.39F 16V 400.4( 4000.0( 3826.4~ 121.841\ 648.121 1-21 3823.61 3825.0 56.66~ 226.22F 164.Ç 458.11 4100.0( 3907.2 132.73N 706.061 1-21 3904.7 3906.01 56.925 226.12F 166.6 516.0E 4200.0( 3988.01 ___ 14~~ 763.99E 1-21 3984.3C 3985.71 57.225 225.97F 167.9 574.2E 4300.0( 4068.8 154.51N 821.92E 1-21 4066.5( 4067.81 57.555 225.801' 169.0 632.71 4400.0( 4149.61 165.40N 879.85E 1-21 _._- 4147.61 4149.0< 57.76~ 225.78F 169.9 - 691.0~ 4500.0( 4230.3~ 176.29N 937.781 1-21 4226.8C 4228.21 57.92~ 225.661' 170.7 749.6E 4600.0( 4311.1 187.18N 995.711 1-21 -- "" 4306.81 4308.2 58.09~ 225.471' 171.3 808.3E 4700.0( 4391.9E 198.07N 1053.641 1-21 4367.4 4388.8( 58.29~ 225.221' 171.9 867.1E 4800.0( 4472.7 208.96N 1111.571 1-21 4467.61 4468.9 58.46~ 224.951' 172.4 926.0E 4900.0( 4553.51 219.85N 1169.511 1-21 4548.3( 4549.61 58.57~ 224.651' 172.8 985.0~ 5000.0( 4634.2~ 230.74N 1227.441 1-21 4629.4 4630.7\ 58.66~ 224.371' 173.3 1 043.9~ All data is in Feet unless otherwise stated Coordinates are from Slot and WD's are from Rig ( Datum #1 317.0ft above Mean Sea Level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated . . West Fork#3 Vers#4, West Fork#3 Ver 4 Slot #3, West Fork 1-21 CLEARANCE LISTING Page 3 Date Printed: 4-Aug-2004 West Fork, Kenai Peninsula, Alaska _.. 'III.s INTEQ ... /ÌÍóioi.,¡¡ . / .......// . Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Closest Ellipse MD[ft] TVD[ft] North[ft] East{ft] MD[ft] TVD[ft] North[ft] East[ft] From ApprOách Separation Highside Distance [ft] [deal ftl 5100.0( 4715.0 241.631\ 1285.37E 1-21 4710.3 4711.7" 58.72S 224.10E 173.E 11 02.9~ 5200.0( 4795.8~ 252.521\ 1343.30E 1-21 4788.0C 4789.3~ 58.83S 223.89E 173.~ 1161.91 5300.0( 4876.6 263.411\ 1401.23E 1-21 4820.3" 4821.6€ 59.79S 223.38E 174.C 1222.6 5400.0( 4957.41 274.301\ 1459.16E 1-21 4857.7~ 4858.8~ 63.56S 222.03E 173.~ 1286.21 5411.8E 4967.0( 275.59N 1466.04E 1-21 4861.0C 4862.0 64.01S 221.91 E 173.~ 1293.9 5500.0( 5038.7( 286.07N 1516.19E 1-21 4898.2~ 4898.5E 71.35S 220.31E 176.8 1351.5~ 5585.6f 5109.3 297.93N 1563.19E 1-21 4926.0C 4925.2~ 78.61S 219.01 E 179.E 1408.0C 5600.0( 5121.2 300.05N 1570.91E 1-21 4926.0C 4925.2~ 78.61S 219.01E 179.6 1417.5 5700.0( 5204.1f 314.85N 1624.75E 1-21 4950.8C 4948.8C 86.32S 217.44E 179.3 1485.4~ 5800.0( 5287.1 329.65N 1678.59E 1-21 4965.7C 4962. 7~ 91.48S 216.12E 179.0 1556.0~ 5900.0( 5370.m 344.45N 1732.43E 1-21 4988.0C 4983.2~ 99.82S 213.68E 178.7 1628.9~ 6000.0( 5453.0~ 359.25N 1786.27E 1-21 500§Æ ~- 5002.0C 108.15S 211.07E ---- 178. 1703.8€ 6100.0( 5536.01 374.05N 1840.11E 1-21 5046.4~ 5035.7~ 124.36S 205.99F 177.E 1780.1f 6200.0( 5618.9 388.86N 1893.95E 1-21 -~ ~-~~ ~_5105.91 158.05S -- 195.65E 176. 1856.4E -- 6300.0( 5701.9" 403.66N 1947.79E 1-21 -- ~_ 5125.0C 5105.91 158.05S 195.65E 176.3 1934.0~ 6400.0C 5784.8~ 418.46N 2001.63E 1-21 -~ 5125.0C 5105.91 158.05S 195.65E 176.3 2013.6F 6500.0C 5867.8~ 433.26N 2055.47E 1-21 --- 5125.0C 5105~~ 158.05S 195.65E 176.3 2095.0 -- 6600.0C 5950.81 448.06N 2109.31E 1-21 5125.0C 5105.9 158.05S 195.65E 176.3 2177.91 6700.0C 6033.7 462.86N 2163.15E 1-21 5125.0C 5105.9 158.05S 195.65E 176.3 2262.1E 6800.0C 6116.7 477.66N 2216.99E 1-21 5125.0C 5105.9 158.05S 195.65E 176.3 2347.6~ 6900.0C 6199.6E 492.46N 2270.83E 1-21 5125.0C 5105.9 158.05S 195.65E 176.3 2434.3C 7000.0C 6282.6 507.27N 2324.67E 1-21 5125.0( 5105.9 158.05S 195.65E 176.3 2521.91 7100.0C 6365.6C 522.07N 2378.51E 1-21 5125.0( 5105.9 158.05S 195.65E 176.3 2610.4C 7200.0C 6448.5f 536.87N 2432.35E 1-21 5125.0( 5105.9 158.05S 195.65E 176.3 2699.7C 7300.0C 6531.5 551.67N 2486.19E 1-21 5125.0( 5105.9 158.05S 195.65E 176.3 2789.71 7400.0C 6614.4E 566.47N 2540.03E 1-21 5125.0( 5105.9 158.05S 195.65E 176.3 2880.41 7497.21 6695.1 580.86N 2592.37E 1-21 5125.0( 5105.9 158.05S 195.65E 176.3 2969.1~ 7500.0C 6697.4 581.27N 2593.87E 1-21 5125.0( 5105.9 158.05~ 195.65E 176.3 2971.6~ 7600.0C 6781.5 595.62N 2646.03E 1-21 5125.0( 5105.9 158.05~ 195.65E 176.6 3062.6E 7700.0C 6867 .6~ 609.07N 2694.98E 1-21 5125.0( 5105.9 158.05~ 195.65E 176.9 3152.6C 7800.0C 6955.7f 621.62N 2740.62E 1-21 5125.0( 5105.9 158.05~ 195.65E 177.1 3241.4C 7900.0C 7045.6 633.24N 2782.89E 1-21 5125.0( 5105.9 158.05~ 195.65E 177.3 3329.01 8000.0C 7137.1E 643.92N 2821.73E 1-21 5125.0( 5105.9 158.05~ 195.65E 177.5 3415.4E 8100.0C 7230. H 653.63N 2857.08E 1-21 5125.0( 5105.9 158.05~ 195.65E 177.6 3500.64 8200.0C 7324.5~ 662.38N 2888.88E 1-21 5125.0( 5105.9 158.05~ 195.65E 177.8 3584.5E 8300.0C 7420.21 670.13N 2917.07E 1-21 5125.0( 5105.9 158.05~ 195.65E 177.9 3667.1~ 8400.0C 7516.91 676.88N 2941.63E 1-21 5125.0( 5105.9 158.05~ 195.65E 178.0 3748.3a 8500.0C 7614.5" 682.62N 2962.51E 1-21 5125.0( 5105.9 158.05~ 195.65E 178.1 3828.2 8600.0C 7712.9~ 687.34N 2979.67E 1-21 5125.0( 5105.9 158.05~ 195.65E 178.2 3906.6~ 8700.0C 7811.9~ 691.03N 2993.10E 1-21 5125.0( 5105.9 158.05~ 195.65E 178.3 3983.61 8800.0C 7911.4 693.69N 3002.77E 1-21 5125.0( 5105.9 158.05~ 195.65E 178.4 4059.0~ 8900.0C 8011.2~ 695.31N 3008.67E 1-21 5125.0( 5105,9 158.05~ 195.65E 178.4 4133.0! 9000.0C 8111.21 695.89N 3010.78E 1-21 5125.0( 5105.9 158.05~ 195.65F 178.5 4205.4f 9005.8C 8117.0C 695.90N 3010.78E .1-21 -- __5125.0( 5105.9 158.05~ 195.65E -106.9 4209.6( 9100.0C 8211.2C 695.90N 3010.78E 1-21 5125.0( 5105.9 158.05~ 195.65E -106.9 4277.4~ 9200.0C 8311.2C 695.90N 3010.78E 1-21 5125.0( 5105.9 158.05~ 195.65E -106.9 4350.6 9300.0C 8411.2C 695.90N 3010.78E 1-21 5125.0( 5105.9 158.05~ 195.65E -106.9 4424.8 9400.0C 8511.2C 695.90N 3010.78E 1-21 5125.0( 5105.9 158.05~ 195.65F -106.9 4500.01 9500.0C 8611.2C 695.90N 3010.78E 1-21 5125.0( 5105.9 158.05~ 195.65E -106.9 4576.1! 9600.0C 8711.2C 695.901\ 3010.78E 1-21 5125.0( 5105.9 158.05~ 195.65E -106.9 4653. H 9700.0C 8811.2C 695.901\ 3010.78E 1-21 5125.0( 5105.9 158.05~ 195.65E -106.9 4731.m 9800.0C 8911.2C 695.901\ 3010.78E 1-21 5125.0( 5105.9 158.05~ 195.65E -106.9 4809.81 9900.0C 9011.2C 695.901\ 3010.78E 1-21 5125.0( 5105.9 158.05~ 195.65F -106.9 4889.31 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 317.00 above Mean Sea Level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated . . West Fork#3 Vers#4, West Fork#3 Ver 4 Slot #3, West Fork 1-21 CLEARANCE LISTING Page 4 Date Printed: 4-Aug-2004 West Fork, Kenai Peninsula, Alaska 81. -.:I.u INTEQ Offset MD[ft] Offset TVD[ft] Offset North[ft] Offset East[ft] All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 317.0ft above Mean Sea Level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (10) Prepared by Baker Hughes Incorporated . . West Fork#3 Vers#4, West Fork#3 Ver 4 Slot #3, West Fork 1-21 CLEARANCE LISTING Page 5 Date Printed: 4-Aug-2004 West Fork, Kenai Peninsula, Alaska .i. ...,. INTEQ ."''''' ...., 'L < ,,/·<Jhi~ ...,'.' Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle CiosestElljpse MD[ft) TVD[ft) North[ft) East[ft) MD[ft) TVD[ft) North[ft) East[ft) From Approach Separation Highside Distance [ft) deal ftl 0.00 0.00 O.OON O.OOE 1-21 - 0.00 1.40 53.978 - 220.67E 103.7 227.18 100.0C 100.0G O.OON O.OOE 1-21 98.59 99.99 53.818 220.72E 103. 227.18 200.0C 200.0G O.OON O.OOE 1-21 198.5f 199.9~ 53.315 220.86E 103.6 227.2G 300.0G 300.0G O.OON O.OOE 1-21 298.5 299.9 52.485 221.09E 103.3 227.21 400.0C 400.0G O.OON O.OOE 1-21 397.91 399.3C 51.555 221.53E 103.1 227.4'i 500.0C 500.0G O.OON O.OOE 1-21 497.6 499.01 50.875 222.11E 102.9 227.8 600.0G 600.0G O.OON O.OOE 1-21 597.3 598.7f 50.535 222.71 E 102.8 228.38 700.0C 700.0G O.OON O.OOE 1-21 697.4 698.8 50.405 223.29E 102.7 228.91 800.0C 800.0G O.OON O.OOE 1-21 796.9~ 798.3 50.525 223.91 E 102.7 229.5~ 900.0G 900.0G O.OON O.OOE 1-21 896.91 898.2~ 50.845 224.60E 102.8 230.2~ 1000.0C 1000.0C O.OON O.OOE 1-21 997.7 999.0~ 50.965 225.09E 102.8 230.7~ 1100.0C 1100.0( O.OON O.OOE 1-21 1 098.2~ 1099.6 50.985 225.31E 102.8 231.0C 1200.0C 1200.0( O.OON O.OOE 1-21 1198.5~ 1199.9f 51.125 225.33E 102.8 231.0f 1300.0C 1300.0( O.OON O.OOE 1-21 ,,- r-- 1298.3f 1299.7E 51.37S 225.34E 102.8 231.1 1400.0C 1400.0( O.OON O.OOE 1-21 1397Æ 1399.3E 51.65S 225.51E 102.9 231.3~ 1500.0C 1500.0( O.OON O.OOE ~. 1497.8 1499.2~ 51.82S 225.80E 102.9 231.6 1600.0( 1600.0( O.OON O.OOE 1-21 1598.0 1599.4C 51.87S 226~QQ!: -- 102.9 231.9 1700.0( 1700.0( O.OON O.OOE 1-21 1698.4C 1699.7 52.00S 226.16E 103.C 232.0 1800.0( 1800.0( O.OON O.OOE 1-21 1798.2 1799.6~ 52.37S 226.21 E 103.C 232.1~ 1900.0( 1900.0( O.OON O.OOE 1-21 1898.1E 1899.5" 52.78S 226.32E 103.1 232.3~ 2000.0( 2000.0C O.OON O.OOE 1-21 1998.0E 1999.4" 53.03S 226.50E 103.2 232.6~ 2100.0( 2100.0C O.OON O.OOE 1-21 .. 2098.2~ 2099.5~ 53.12S 226.66E 103. 232.8C -- 2200.0C 2200.0C O.OON O.OOE 1-21 2198.5" 2199.9C 53.27S 226.69E 103.2 232.8 2300.0C 2300.0C O.OON O.OOE 1-21 2298.3~ 2299.7E 53.39S 226.74E 103.3 232.9~ 2400.0( 2399.9~ 0.48N 2.57E 1-21 2397.91 2399.2 53.37S 226.99E 24.2 230.7~ 2500.0C 2499.6" 1.93N 10.28E 1-21 2498.1~ 2499.5< 53.34S 227.16E 25.1 223.81 2600.0C 2598.7 4.34N 23.11 E 1-21 .. 2597.1C 2598.4 53.41S 227.22E 26.7 212.1~ 2700.0C 2697.0f 7.71N 41.02E 1-21 2695.4 2696. 7~ 53.61S 227.31E 29.4 196.1~ 2800.0C 2794.31 12.02N 63.96E 1-21 2793.1 2794.4~ 53.65S 227.27E 33.5 176.0~ 2900.0C 2890. H 17.27N 91.87E 1-21 2889.2E 2890.6 53.58S 227.04E 39.8 152.6~ 3000.0C 2984.4 23.44N 124.67E 1-21 2983.0 2984.4C 53.68S 226.83E 49.6 128.0C 3100.0C 3076.81 30.50N 162.27E 1-21 3075.51 3076.86 53.77S 226.78E 65.3 106.1" 3200.0( 3167.0f 38.46N 204.58E 1-21 3165.4E 3166.8~ 53.83S 226.66E 87.4 94.89 3209.2 3175.2f 39.24N 208.73E 1-21 3173.66 3175.0~ 53.85S 226.65E 89.7 94.8G 3300.0( 3254.9 47.27N 251.47E 1-21 3253.2~ 3254.61 54.11S 226.58E 111.4 104.39 3400.0( 3340.H 56.92N 302.81E 1-21 3338.5~ 3339.9~ 54.38S 226.69E 130.C 134.8'i 3500.0C 3422.5~ 67.39N 358.47E 1-21 3.4~ 3422.16 54.60S 226.70E 142.1 179.5 3503.9~ 3425.7~ 67.82N 360.76E 1-21 3423.9~ 3425.36 54.61S 226.69E 142.'i 181.5'i 3600.0( 3503.3 78.28N 416.40E 1-21 3501.21 3502.6~ 54.948 226.69E 150.6 231.81 3700.0C 3564. H 89.17N 474.33E 1-21 3581.81 3583.18 55.348 226.63E 156.1 286.7 3800.0C 3664.9 100.06N 532.26E 1-21 3662.01 3663.4~ 55.74S 226.51 E 160.0 343.1 3900.0C 3745.71 110.95N 590.19E 1-21 3742.6 3744.0 56.298 226.39E 162.8 400.4G 4000.0C 3826.4~ 121.84N 648.12E 1-21 3823.61 3825.0 56.66S 226.22E 164.9 458.11 4100.0C 3907.2 132.73N 706.06E 1-21 3904.7 3906.01 56.92S 226.12E 166.6 516.05 4200.0C 3988.0~ 143.62N .. 763.99E 1-21 3984.31 3985.7f 57.228 225.97E 167.9 574.28 4300.0C -~ 154.51N 821.92E 1-21 4066.5( 4067.8f 57.55S 225.80E 169.G 632.71 4400.0C 4149.61 165.40N .. 879.85E 1-21 4147.6! 4149.0 57.76S 225.78E 169.9 691.09 4500.0C 4230.3~ 176.29N 937.78E 1-21 4226.81 4228.2f 57.92S 225.66E 170.7 749.65 4600.0C 4311.1 187.18N 995.71E 1-21 .. 4306.81 4308.2 58.09S 225.47E 171.1 808.36 4700.0C 4391.9~ 198.07N 1053.64E 1-21 4387.4 4388.8C 58.29S 225.22E 171.9 867.18 4800.0C 4472.7" 208.96N 1111.57E 1-21 4467.6 4468.9 58.46S 224.95E 172.4 926.08 4900.0C 4553.51 219.85N 1169.51E 1:21 4548.3( 4549.6f 58.57S 224.65E 172.8 985.01 5000.0C 4634.2~ 230.74N 1227.44E 1-21 4629.4 4630.7~ 58.66S 224.37E 173.3 1043.99 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 317.0ft above Mean Sea Level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (10) Prepared by Baker Hughes Incorporated . . West Fork#3 Vers#4, West Fork#3 Ver 4 Slot #3, West Fork 1-21 CLEARANCE LISTING Page 6 Date Printed: 4-Aug-2004 West Fork, Kenai Peninsula, Alaska B¡¡. .... INTEQ II ). ......, J" >,;.' ,..... < " Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Closest Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Approach Separation Highside Distance [ft] Idea] Iftl 5100.0( 4715.0 241.631\ 1285.37E 1-21 4710.3 4711.7 58.72~ 224.10E 173.E 1102.9! 1-. 5200.0( 4795.81 252.521\ 1343.30E 1-21 4791.7( 4793.0! 58.84~ 223.89E 173.~ 1161.91 5300.0( 4876.6 263.41 N 1401.23E 1-21 4872.3 4873.71 58.99~ 223.73F 174.~ 1220.S. 5400.0( 4957.41 274.301\ 1459.16E 1-21 4952.9! 4954.3 59.15~ 223.57F 174.f 1279.8! 5411.81 4967.0( 275.59N 1466.04E 1-21 4962.51 4963.9 59.17~ 223.55F 174.f 1286.8( 5500.0( 5038.7í 286.071\ 1516.19E 1-21 5035.4 5036.7 59.29~ 223.43F 177.6 1338.1( 5585.61 5109.3 297.931\ 1563.19E 1-21 5105.9 5107.3 59.38~ 223.35F -179.5 1386.6 5600.0( 5121.2 300.051\ 1570.91E 1-21 5117.81 5119.21 59.391' 223.33F -179.5 1394.6~ 5700.0( 5204.11 314.85N 1624.75E 1-21 5200.7 5202.0! 59.491' 223.24F -179.5 1450.6f 5800.0( 5287.1 329.65N 1678.59E 1-21 5285.01 5286.41 59.551' 223.18F -179.5 1506.5f 5900.0( 5370.0~ 344.45N 1732.43E 1-21 5367.9~ 5369.3< 59.581' 223.14F -179.5 1562.4< 6000.0( 5453.0! 359.25N 1786.27E 1-21 5450.9 5452.2F 59.61S 223.11F -179.6 1618.31 6100.0r 5536.01 374.05N 1840.11E 1-21 5459.0r 5460.3< 59.61~ 223.11F -179.6 1675.8! 6200.0( 5618.9 388.86N 1893.95E 1-21 5459.0r 5460~~ -. 59.61S 223.11F -179.6 1737 .2~ 6300.0( 5701.9 403.66N 1947.79E 1-21 5459.0r 5460.3< 59.61S 223.11F -179.6 1802.0e 6400.0( 5784.8~ 418.46N 2001.63E 1-21 5459.0( 5460.3< 59.61S 223.11F -179.6 1870.0< 6500.0 5867.8 433.26~ 2055.471 1-21 5459.0 5460.3 59.61 ~ 223.11F -179.6 1940.7 6600.0( 5950.81 448.06~ 2109.31E 1-21 5459.0( 5460.3' 59.61~ 223.11F -179.6 2013.91 6700.0( 6033.7 462.86~ 2163.151 1-21 5459.0( 5460.31 59.61 ~ 223.11F -179.6 2089.3! 6800.0( 6116.7 477.66~ 2216.991 1-21 5459.01 5460.3' 59.61~ 223.11F -179.6 2166.81 6900.0( 6199.61 492.46~ 2270.831 1-21 5459.01 5460.3' 59.61~ 223.11F -179.6 2246.01 7000.0( 6282.6 507.27~ 2324.671 1-21 5459.0( 5460.3' 59.61~ 223.11F -179.6 2326.8~ 7100.0( 6365.6( 522.07~ 2378.51E 1-21 5459.01 5460.3' 59.61~ 223.11F -179.6 2409.01 7200.0( 6448.51 536.87~ 2432.351 1-21 5459.0( 5460.3' 59.61~ 223.11F -179.6 2492.61 7300.0( 6531.5 551.67~ 2486.191 1-21 5459.0( 5460.31 59.61~ 223.11F -179.6 2577.3 7400.0C 6614.4E 566.471\ 2540.031 1-21 5459.0( 5460.31 59.61~ 223.11F -179.6 2663.H 7497.21 6695.1 < 580.86N 2592.371 1-21 ..-- 5459.0( 5460.31 59.61~ 223.11E -179.6 2747.41 -- 7500.0C 6697 .4~ 581.27N 2593.871 1-21 5459.0( 5460.31 59.61 ~ 223.11 F -179.6 2749.8 7600.0C 6781.5< 595.62N 2646.03E 1-21 ~~ -. 5460.3! 59.61 ~ 223.11E -179.6 2836.4 _7700.0( 6867 .6~ 609.07N 2694.98E 1-21 5459.0( 5460.3! 59.61~ 223.11E -179.6 2921.9E 7800.0r 6955.7f 621.62N 2740.62E 1-21 5459.0r 5460.3! 59.61~ 223.11E -179.6 3006.3E 7900.0( 7045.6 633.24N 2782.89E 1-21 5459.0( 5460.3 59.61~ 223.11 E -179.7 3089.61 8000.0( 7137.1f 643.92N 2821.73E 1-21 5459.0r 5460.3 59.61~ 223.11 F -179.7 3171.6 8100.0( 7230.1 653.63~ 2857.081 1-21 5459.01 5460.3 59.61~ 223.111 -179.7 3252.51 8200.0( 7324.5! 662.381\ 2888.88E 1-21 5459.0r 5460.3! 59.61~ 223.111 -179.7 3332.11 8300.0( 7420.2 670.13" 2917.071 1-21 5459.0r 5460.3' 59.61~ 223.1H -179.7 341 Q.4 8400.0( 7516.91 676.88~ 2941.631 1-21 5459.0r 5460.3' 59.61~ 223.11E -179.7 3487.4 8500.0( 7614.5 682.62N 2962.511 1-21 5459.0r 5460.3' 59.61~ 223.1H -179.8 3563.H 8600.0( 7712.9' 687.34" 2979.67E 1-21 5459.0r 5460.3' 59.61~ 223.11E -179.8 3637.4( 8700.0( 7811.9 691.03" 2993.10E 1-21 5459.0r 5460.3' 59.61~ 223.11E -179.8 3710.3( 8800.0( 7911.4 693.69" 3002.771 1-21 5459.0r 5460.3! 59.61~ 223.11F -179.8 3781.7 8900.0( 8011.2 695.31" 3008.671 1-21 5459.0( 5460.3' 59.61~ 223.111 -179.8 3851.7! 9000.0C 8111.21 695.89" 3010.78E 1-21 5459.0r 5460.3' 59.61~ 223.11 F -179.8 3920.3 9005.8C 8117.0( 695.90N 3010.78E 1-21 -- -. 5459.0( 5460.31 59.61~ 223.11F -105.2 3924.21 9100.0C 8211.2( 695.901\ 3010.78E 1-21 .. 5459.0( 5460.31 59.61~ 223.11F -105.2 3988.6 9200.0( 8311.2( 695.901\ 3010.781 1-21 5459.0( 5460.31 59.61~ 223.11F -105.2 4058.2 9300.0C 8411.2C 695.90N 3010.78E 1-21 5459.0( 5460.31 59.61~ 223.11F -105.2 4129.H 9400.0C 8511.2C 695.90N 3010.78E 1-21 ---¡--- 5459.0( 5460.31 59.61~ 223.11F -105.2 4201.1 9500.0( 8611.2C 695.90N 3010.78E 1-21 .-' 5459.0( 5460.31 59.61~ 223.11F -105.2 4274.3~ 9600.0C 8711.2C 695.90N 3010.78E 1-21 5459.0( 5460.31 59.61~ 223.11F -105.2 4348.5E .- 9700.0C 8811.2C 695.901\1 3010.78E 1-21 5459.0( 5460.3 59.61~ 223.11F -105.2 4423.81 9800.0C 8911.2C 695.901\1 3010.78E 1-21 -- f--.~~ -- 5460.3< 59.61~ 223.11 F -105.2 4500.03 9900.0C 9011.2C 695.901\1 3010.78E 1-21 5459.0r 5460.3' 59.61~ 223.11F -105.2 4577.17 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 317.0ft above Mean Sea Level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated . . West Fork#3 Vers#4, West Fork#3 Ver 4 Slot #3, West Fork 1-21 CLEARANCE LISTING Page 7 Date Printed: 4-Aug-2004 West Fork, Kenai Peninsula, Alaska .i. ~ INTEQ ..... .'."", .... '.' . ..i..···.. ···············'··.Et ........ .'.i Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle ClOsest Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Approach Separation Highside Distance [ft] Irden] I rft] 10000.0( 9111.2( 695.90N 3010.78E 1-21 5459.0( 5460.3' 59.615 223.11~ -105.2 4655.1 10100.0( 9211.2( 695.90N 3010.78E 1-21 5459.0( 5460.3! 59.615 223.11~ -105.2 4734.0( 10200.0( 9311.2( 695.90N 3010.78E 1-21 5459.0( 5460.3' 59.615 223.11E -105.2 4813.6 10300.0( 9411.2( 695.90N 3010.78! 1-21 5459.0( 5460.3 59.615 223.11 E -105.2 4893.9! 10400.0( 9511.2( 695.90N 3010.781 1-21 5459.0( 5460.31 59.615 223.11E -105.2 4975.0 10500.0( 9611.2( 695.90N 3010.781 1-21 5459.0( 5460.31 59.615 223.11F -105.2 5056.8 10600.0( 9711.2( 695.90N 3010.781 1-21 5459.0( 5460.31 59.615 223.11F -105.2 5139.2 10605.8( 9717.0( 695.90N 3010.781 1-21 5459.0( 5460.3! 59.615 223.11F -105.2 5144.0 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 317.0ft above Mean Sea Level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated . . West Fork#3 Vers#4, West Fork#3 Ver 4 Slot #3, West Fork 1-21 CLEARANCE LISTING Page 8 Date Printed: 4-Aug-2004 West Fork, Kenai Peninsula, Alaska B¡¡. BWcI.u INTEQ _r .......... . .....i·csitY/t;i .... .. Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Closest EllipSe MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Approach Søparation Highside Distance [ft] deal ftl 0.00 0.00 O.OON O.OOE 2-21 ~_~AJM --.- -0.06 19.875 94.40E 101.9 96.47 100.0C 100.00 O.OON O.OOE 2-21 104.9~ 99.94 19.955 94.45E 101.9 96.54 200.00 200.00 O.OON O.OOE 2-21 204.81 199.81 20.115 94.55E 102.0 96.67 300.00 300.00 O.OON O.OOE 2-21 304.81 299.81 20.365 94.70E 102.1 96.87 400.00 400.00 O.OON O.OOE 2-21 404.71 399.71 20.755 94.92E 102.3 97.1 500.00 500.00 O.OON O.OOE 2-21 504.6" 499.61 21.22S 95.17E 102.6 97.51 600.0C 600.0c O.OON O.OOE 2-21 604.6 599.6 21.74S 95.44F 102.8 97.8S 700.0C 700.0C O.OON O.OOE 2-21 704.81 699.8~ 22.24S 95.67E 103.1 98.22 800.0C 800.0C O.OON O.OOE 2-21 804.81 799.81 22.55S 95.78E 103.3 98.40 900.0C 900.0C O.OON O.OOE 2-21 903.91 898.9C 20.73S 96.68E 102.1 98.88 1000.0( 1000.0( O.OON O.OOE 2-21 1003.4< 998.24 15.40S 99.11 E 98.8 100.31 1100.0C 1100.0( O.OON O.OOE 2-21 1102.0 1096.5 7.995 102.48E 94.5 1 02.8~ 1200.0( 1200.0( O.OON O.OOE 2-21 1200.6~ 1194.41 2.54N 107.11E 88.6 107.2S 1300.0( 1300.0( O.OON O.OOE 2-21 1298.6.Ç 1291.21 16.73N 111.93E 81.5 113.5 1400.0( 1400.0( O.OON O.OOE 2-21 .-. -. 1395.3~ . .. 1386.3 33,30N 117 .38E 74.2 122.7 1500.0( 1500.0C O.OON O.OOE 2-21 1490.0~ 1478.9< 52.38N 123.68E 67.0 135.9~ 1600.0( 1600.0( O.OON O.OOE 2-21 1582.6~ ~568.7 73.83N 130,m r- 60.6 153.5~ 1700.0( 1700.0C O.OON O.OOE 2-21 1674.5C 1656.7 98.44N 139.35E 54.8 176.0C 1800.0( 1800.0C O.OON O.OOE 2-21 1764.2~ 1742.1E 124.44N 148.38E 50.0 202.1C 1900.0( 1900.0C O.OON O.OOE 2-21 1852.3~ 1824.9C 153.25N 157.77E 45.8 232.4~ 2000.0( 2000.0C O.OON O.OOE 2-21 1942.9£ 1909.0 185.65N 166.97E 42.0 265. 7~ 2100.0C 2100.0C O.OON O.OOE 2-21 2031.21 1990.7C 217.74N 176.34E 39.0 300.7€ 2200.0C 2200.0C O.OON O.OOE 2-21 2114.7 2067.44 249.34N 186.06E 36.7 338.1 2300.0( 2300.0C O.OON O.OOE 2-21 2204.0E 2148.81 284.32N 197.22E 34.8 377.6~ 2400.0( 2399.9~ 0.48N 2.57E 2-21 2294.31 2230.8 320.31N 208.48E -45.7 416.28 2500.0( 2499.6 1.93N 10.28E 2-21 2383.0 2311.2C 356.24N 219.37E -47.0 452.51 2600.0( 2598.7 4.34N 23.11 E 2-21 2474.0 2393.54 393.41 N 230.71E -48.5 486.4C 2700.0( 2697.m 7.71N 41.02E 2-21 2563.5~ 2474.3C 430.36N 241.89E -50.1 518.28 2800.0C 2794.31 12.02N 63.96E 2-21 2653.9~ 2555.6E 468.11N 252.92E -52.0 548.34 2900.0C 2890.1E 17.27N 91.87E 2-21 ..ZL41B _. 2634.4~ 505.25N 263.66E -54.0 577.08 3000.0C 2984.4 23.44N 124.67E 2-21 2830.3~ 2713.8 543.14N 274.61E -56.1 604.80 3100.0< 3076.81 30.50N 162.27E 2-21 2917.7C 2791.9C 580.81N 285.35E -58.4 631.79 3200.0C 3167.0f 38.46N 204.58E 2-21 3005.1~ 2869.8€ 618.93N 295.90E -60.7 658.50 3300.0C 3254.9 47.27N 251.47E 2-21 .- . 3091.7! 2947.0 656.97N 306.29E -63.1 685.2~ 3400.0C 3340.H 56.92N 302.81E 2-21 3172.8! 3019.1 692.79N 316.14E -65.5 712.4!i 3500.0C 3422.5~ 67.39N 358.47E 2-21 I 3254.1! 3091.1 729.11N 326.10E -67.8 740.80 3503.9~ 3425.7£ 67.82N 360.76E 2-21 3256.5! 3093.3( 730.21N 326.40E -67.8 741.95 3600.0C 3503.3 78.28N 416.40E 2-21 3334.9 3162.51 765.55N 335.91 E -70.9 771.35 3700.0C 3584.1< 89.17N 474.33E 2-21 3413.2 3231.61 801.11N 345.50E -73.7 804.80 3800.0C 3664.9 100.06N 532.26E 2-21 3491.4! 3300.4 837.15N 355.00E -76.3 841.1 3900.0C 3745.71 110.95N 590.19E 2-21 3568.5 3367.9~ 873.09N 364.49E -78.8 880.06 4000.0C 3826.4~ 121.84N 648.12E 2-21 3647.0 3436.4 910.18N 374.39E -81.0 921.1 a 4100.0C 3907.2 132.73N 706.06E 2-21 3724.3( 3503.5! 947.12N 384.11E -83.1 964.29 4200.0C 3988.0~ 143.62N 763.99E 2-21 3799.6~ 3568.8( 983.65N 393.65E -85.0 1009.24 4300.0C 4068.8 154.51N 821.92E 2-21 .- 3882.3 3640.2 1023.90N 404.11E -86.9 1055.51 4400.0C 4149.61 165.40N 879.85E 2-21 3968.7 3714.9! 1065.83N 415.05E -88.7 1102.5S 4500.0C 4230.3~ 176.29N 937.78E 2-21 ] 4050.9 3786.2 1105.5011 425.32E -90.4 1150.3~ 4600.0C 4311.1 187.18N 995.71E 2-21 4135.6~ 3859.8~ 1146.2911 435.58E -91.9 1198.89 4700.0C 4391.9E 198.07N 1053.64E 2-21 4219.71 3932.9 1186.5011 445.66E -93.4 1247.9 4800.0C 4472.7 208.96N 1111.57E 2-21 4304.41 4006.7 1226.9011 455.85E -94.8 1297.44 4900.0C 4553.51 219.85N 1169.51E 2-21 4388.1 4079.7~ 1266.6211 465.71E -96.1 1347.41 5000.0C 4634.2~ 230.74N 1227.44E 2-21 4472.5~ 4153.41 1306.5211 475.52E -97.3 1397.81 5100.0C 4715.0 241.63N 1285.37E 2-21 4555.8! 4226.3( 1345.8211 485.18E -98.4 1448.6C All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 317.0ft above Mean Sea Level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (10) Prepared by Baker Hughes Incorporated . . West Fork#3 Vers#4, West Fork#3 Ver 4 Slot #3, West Fork 1-21 CLEARANCE LISTING Page 9 Date Printed: 4-Aug-2004 West Fork, Kenai Peninsula, Alaska ria. IIfcl.u INTEQ _.'F F F ··'<i< ·XX)·'X. 7';;~))2· ,. . .... ,/ ...........'..... ................... Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Closest Ellipse MD[ft) TVD[ft) North[ft) East[ft) MD[ft) TVD[ft) North[ft) East[ft) From ApproaCh Separation Highside Distance [ft) rd8al· rftl 5200.0C 4795.85 252.52N 1343.30E 2-21 4637 .5~ 4297.81 1384.131\ 494.33E -99.5 1499.7f 5300.0C 4876.6~ 263.41 N 1401.23E 2-21 4722.8~ 4372.71 1423.931\ 503.61E -100.5 1551.2S 5400.00 4957.41 274.30N 1459.16E 2-21 4812.01 4451.0f 1465.281\ 513.49E -101.5 1602.A4 5411.8S 4967.00 275.59N 1466.04E 2-21 4823.1 4460.8f 1470.431\ 514.74E -101.7 1608.9 5500.00 5038.70 286.07N 1516.19E 2-21 4895.3~ 4524.4f 1503.741\ 522.70E -101.0 1653.5'" 5585.66 5109.3" 297.93N 1563.19E 2-21 4969. H 4589.5f 1537.621\ 530.54E -100.2 1695.09 5600.00 5121.2" 300.05N 1570.91E 2-21 4981.4 4600.4 1543.241\ 531.83E -100.3 1701.89 5700.0C 5204.1 314.85N 1624.75 2-21 5068.2 4677.11 1582.911\ 540.92E -101.0 1749.4? 5800.0C 5287.1< 329.65N 1678.59F 2-21 5156.41 4755.01 1623.0711 550.11F -101.7 1797.1C 5900.0C 5370.0~ 344.45N 1732.43F 2-21 5245.5( 4833.9( 1663.4411 559.26F -102.4 1844.8 6000.0C 5453.0' 359.25N 1786.27F 2-21 5332.5E 4911.1! 1702.6211 568.05F -103.1 1892.71 6100.0C 5536.01 374.05N 1840.11F 2-21 - 5420.5 4989.41 1741.9511 576.68F -103.8 1940.6E -- 6200.0C 5618.9 388.86N 1893.95F 2-21 5505.6! 5065.2! 1779.6911 584.72F -104.4 1988.7 6300.0C 5701.9 403.66N 1947.79F 2-21 5594.2! 5144.4C 1818.6511 592.72F -105.0 2036.9 6400.0C 5784.8~ 418.46N 2001.63F 2-21 5676.9C 5218.3 1854.841\ 600.07F -105.6 2085.3 6500.0C 5867.8f 433.26N 2055.47F 2-21 5765.4E 5297.6C 1893.601\ 607.79F -106.1 2133.91 6600.0C 5950.81 448.06N 2109.31F 2-21 5850.0C 5373.2 1930.531\ 615.29F -106.7 2182.51 6700.0C 6033.7 462.86N 2163.15F 2-21 5850.0C 5373.2 1930.531\ 615.29F -106.7 2232.9 6800.0C 6116.7 477.66N 2216.99F 2-21 5850.0C 5373.2 - 1930.531\ 615.29F -106.7 2286.6£ 6900.0C 6199.6f 492.46N 2270.83F 2-21 5850.0C 5373.2 1930.5311 615.29F -106.7 2343.46 7000.0C 6282.6 507.27N 2324.67F 2-21 5850.0C 5373.2 1930.5311 615.29F -106.7 2403.04 7100.0C 6365.6C 522.07N 2378.51F 2-21 5850.0C 5373.2 1930.531\ 615.29F -106.7 2465.24 7200.0C 6448.5f 536.87N 2432.35F 2-21 5850.0C 5373.2 1930.531\ 615.29F -106.7 2529.8 7300.0C 6531.5~ 551.67N 2486.19F 2-21 5850.0C 5373.2 1930.531\ 615.29F -106.7 2596.74 7400.0C 6614.4f 566.47N 2540.03F 2-21 5850.0C 5373.2 1930.531\ 615.29F -106.7 2665.6S 7497.21 6695.1~ 580.86N 2592.37F 2-21 5850.0C 5373.2 1930.531\ 615.29F -106.7 2734.54 7500.0C 6697.44 581.27N 2593.87E 2-21 5850.0C 5373.2 1930.531\ 615.29E -106.7 2736.54 7600.00 6781.5~ 595.62N 2646.03F 2-21 5850.0C 5373.2 1930.531\ 615.29F -109.0 2808.75 7700.00 6867.69 609.07N 2694.98E 2-21 5850.0C 5373.2 1930.531\ 615.29E -111.2 2881.7 7800.0C 6955.76 621.62N 2740.62E 2-21 5850.0C 5373.2 1930.53N 615.29E -113.5 2955.4 7900.0C 7045.6~ 633.24N 2782.89E 2-21 5850.0C 5373.2 1930.53N 615.29E -115.8 3029.56 8000.0C 7137.16 643.92N 2821.73E 2-21 5850.0C 5373.2 1930.53N 615.29E -118.0 3104.04 8100.0C 7230.1£ 653.63N 2857.08E 2-21 5850.0C 5373.2 1930.53N 615.29E -120.2 3178.71 8200.0 7324.5 662.38N 2888.88E 2-21 5850.QC 5373.2 1930.531\ 615.29E -122.4 3253.4E 8300.0C 7420.21 670.13N 2917.07E 2-21 5850.0C 5373.2 1930.53110 615.29E -124.5 3328.1f 8400.0C 7516.91 676.88110 2941.63E 2-21 5850.0C 5373.2 1930.531\ 615.29E -126.5 3402.74 8500.0C 7614.5 682.62110 2962.51E 2-21 5850.0C 5373.2 1930.531\ --- 615.29E -128.5 3477.0E 8600.0C 7712.9 687.34110 2979.67F 2-21 5850.0C 5373.2 1930.531\ 615.29E -130.4 3551.0 8700.0C 7811.9 691.03110 2993.10F 2-21 5850.0C 5373.2 1930.531\ 615.29E -132.3 3624.5E 8800.0C 7911.4 693.69110 3002.77F 2-21 5850.0C 5373.2 1930.531\ 615.29E -134.0 3697.5f 8900.0C 8011.2 695.31N 3008.67F 2-21 5850.0C 5373.2 1930.53110 615.29E -135.7 3770.0C 9000.0C 8111.21 695.89N 3010.78F 2-21 5850.0C 5373.2 1930.53110 615.29E -137.3 3841.7 9005.8C 8117.0C 695.90N 3010.78F 2-21 5850~OC 5373.2 1930.53110 615.29E -62.7 3845.8 9100.0C -- 8211.2C 695.90N 3010.78F 2-21 5850.0C 5373.2 1930.53110 615.29E -62.7 3913.6 9200.0C 8311.2C 695.90110 3010.78F 2-21 5850.0C 5373.2 1930.53110 615.29E -62.7 3986.74 9300.0C 8411.2C 695.90110 3010.78F 2-21 5850.0C 5373.2 1930.53110 615.29F -62.7 4061.0C 9400.0C 8511.2C 695.90N 3010.78F 2-21 5850.0C 5373.2 1930.531\ 615.29E -62.7 4136.34 9500.0C 8611.2r 695.90N 3010.78F 2-21 5850.0C 5373.2 1930.53N 615.29E -62.7 4212.7C 9600.0C 8711.2r 695.90N 3010.78F 2-21 5850.0C 5373.2 1930.53N 615.29E -62.7 4290.0<1 9700.0C 8811.2r 695.90N 3010.78F 2-21 5850.0C 5373.2 1930.53110 615.29E -62.7 4368.3C 9800.0C 8911.2C 695.90N 3010.78F 2-21 5850.0C 5373.2 1930.53110 615.29E -62.7 4447.4 9900.0C 9011.2C 695.90N 3010.78F 2-21 5850.0C 5373.2 1930.53110 615.29E -62.7 4527.3f 10000.0 9111.2r 695.90N 3010.78F 2-21 5850.0C 5373.2 1930.53110 615.29E -62.7 4608.1 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 317.0ft above Mean Sea Level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (10) Prepared by Baker Hughes Incorporated . West Fork#3 Vers#4, West Fork#3 Ver 4 Slot #3, West Fork 1-21 Reference Offset Well East[ft] Offset MD[ft] 5850.0 5850.0 5850.0 5850.0 5850.0 5850.0 5850.0 s S rve Name MWD<0-5850'> . CLEARANCE LISTING Page 10 Date Printed: 4-Aug-2004 West Fork, Kenai Peninsula, Alaska .1. aw&u INTEQ Offset TVD[ft] Offset North[ft] Offset East[ft] 5373.2 5373.2 5373.2 5373.2 5373.2 5373.2 5373.2 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 317.0ft above Mean Sea Level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated Marathon Oil Company Well Name: West Fork #3 Location: Kenai, Alaska. 1 I,,' ¡ 1,/ ¡ Prepared For: MARAT ON OIL COMPANY Well West Fork #3 Kenai Peninsula, Alaska Prepared by: Tony Tykalsky Reviewed by: Hal Martens Presented to: Will Tank \ August 4th, 2004 . . faR Marathon Oil Company Well Name: West Fork #3 Location: Kenai, Alaska. Marathon Oil Company PO Box 190168 Anchorage, Alaska 99519 ATTN: Will Tank Will: Enclosed is the recommended drilling fluid program for the West Fork # 3 Well to be drilled this year. The following is a brief synopsis of the program. Overview: West Fork #3 is an exploration well targeting the Tyonek formation at the exploration site. F10-Pro fluid will be used for the intermediate and production intervals. After logging the production interval, the well will be completed with a 4-112" casing string cemented in place. Surface Interval: The surface interval will be drilled with the standard GeVGe1ex spud mud. No problems are expected in the straight hole interval. Intermediate Interval: This interval will be drilled with a F10-Pro NT fluid. After drilling out the surface cement, the well will be displaced to a standard Flo-Pro KC1 fluid. SafeCarb bridging material will be maintained according to the mud program to minimize losses to the formation. Fluid loss should be maintained @ 7 - 9 cc' s API. Over 900 feet of conglomerate is expected at the bottom portion of this interval. Pore pressure may be as low at 5.0 PPG from 5000 - 5600' TVD. Production Interval: This interval will be drilled with a new FloPro fluid using Dua1F10 for fluid loss. All fluid dilutions should be made in order to keep the mud properties at the recommended specifications. Fluid loss should be maintained @ <7 cc's API for this interval. Completion: The cement will be displaced with 6% KC1 brine for the completion phase of the program. Conqor 303A and Sodium Meta Bisulfate will be added to the drilling fluid that will be left between the 4-112" completion string and the 7" casing on the final circulation prior to cementing. Tony Tyka1sky Project Engineer 1M-I SWACO Offset Reference Well: Westfork 2-21 NOTE: This prOl!ram is provided as a I!uide onlv. Well conditions will alwavs dictate fluid properties required. r:zj ..FE ~~ elÆ rm.~ ~ _R . . Marathon Oil Company Well Name: West Fork #3 Location: Kenai, Alaska. EXECUTIVE SUMMARY Our overall goal is no spills and no incidents while providing fluids and solids control services to our customer. Our goal for West Fork # 3 is to remove drill solids from the mud system at a cost of less than $0.23 per pound. This has been the average for the last four years of centrifuge van operations We plan to drill this well at an average fluid cost of $16.06 per foot. Expected volume usage is estimated to be 4860 barrels. These estimates do not include any unforeseen lost circulation or formation pressures exceeding 9.5 PPG. Use of the MI Swaco centrifuge van for the last four years has provided an estimated savings in dilution and disposal costs to Marathon Oil of over $800,000. With continued usage of our equipment, we expect to provide more savings to you during future operations. ~ ..FE ~~ . . eFE Marathon Oil Company Well Name: West Fork #3 Location: Kenai, Alaska. Interval Benchmarks and Targets Drilling Intervals ;c... Benchmal'k 1 Benchmark 2 Benchmark 3 PO. i ..' ..,tÍ , .. j.... . .. ,.L, Fluid cost per foot Volume Usage Solids Removal o - 2200' < $4.49 ft < 1683 bbls 2200 - < $18.68 ft < 2039 bbls 7463' 7463 - < $19.59 ft < 1139 bbls 10605' Total Avg. Max. Project < $16.06 ft <4860 bbls < $0.23 Ib No Spills from Targets for Centrifuge Van Drilling Operation Interval r:zj 81Æ ~~ . . eFE Marathon Oil Company Well Name: West Fork #3 Location: Kenai, Alaska. Project Summary Casing Hole Casing Depth TVD Mud Mud Sum Interval Size Size Program System Weight Days Mud Cost (in) (in) (ft) (ft) Solids Control (ppg) 9-5/8" 12-1/4" 2200' 2200' GellGelex Spud Mud 8.6 - 9.4 5 $13,248 Screens 150/180 mesh Desilter Centrifuge Van 7" 8-112" 7463' 6667' Flo-Pro w/SafeCarb 9.0- 10 $105,055 Screens 180 - 210 <9.5 mesh Desilter Centrifuge Van 4-1/2" 6-118" 10605' 9717' Flo-Pro w/SafeCarb 9.0- 7 $66,872 Screens 230 - 210 < 9.5 mesh Desilter Centrifuge Van 4-112 " 6-1/8" Completion 10605' 9717' 6% KCI 8.55 2 $2,968 ~ Utilize all solids control equipment to minimize the build up of drill solids in the system (if possible, centrifuge the surface mud during trips to reduce drill solids). ~ Condition the mud prior to running casing for all intervals. ~ Cost includes the use of 1.5% Lubetex in the intermediate and production intervals. r:zì ..FE am'~ . . eFE Marathon Oil Company Well Name: West Fork #3 Location: Kenai, Alaska. Offset Well History Well Hole Size Depth PPG PV YP FL Comments WF 2-21 17.5 390 8.9 16 41 16.2 Spud in 1635 9 11 21 19.8 Drill ahead 2215 9.4 15 33 18.8 Drlg to surface T.D., high torque 12.25 3380 9 13 22 13.4 Swap to new mud, drill out 4697 9.1 17 24 6 Drill ahead, no problems 5420 9.2 18 17 6 Short trip OK, drlg to core point, POH 5850 9.1 18 16 5.8 Finish coring, log well 5850 9.2 14 10 12 Run & cmt casing with no problems. r:!j 81Æ rmr~ Marathon Oil Company Well Name: West Fork #3 Location: Kenai, Alaska. M-I Bar (50#) 0 204 228 0 432 1.7 M-I Gel (50#) 673 0 0 0 673 3.0 Gelex 21 0 0 0 21 0.15 Soda Ash 12 10 11 0 33 0.3 Caustic Soda 17 20 11 0 48 0.72 Conqor 404 0 5 4 0 9 6.02 Sodium Meta 17 20 11 0 50 1.9 Bisulfate Bicarb 17 10 11 0 38 0.39 Conqor 303 0 0 0 2 2 0.56 FloVis 0 163 91 0 254 29.16 Desco CF 17 0 0 0 17 0.46 Polypac UL 10 81 0 0 91 8.28 Bioban BP Plus 0 20 91 0 111 1.42 KCl 0 856 478 42 1376 10.02 SafeCarb 0 815 455 0 1270 12.86 Lubetex 0 23 13 0 36 15.34 Defoam X 0 23 6 0 29 1.48 Engineer Service 5 10 7 2 24 . . _FE Marathon Oil Company Well Name: West Fork #3 Location: Kenai, Alaska. Plans & Procedures => COMMUNICATION - The Field Mud Engineer will communicate daily with the In-Town Project Engineer. The Project Engineer will then communicate daily with the rig Drilling Engineer. Communications should be about, but not limited to, fluid properties, hole difficulties, possible changes to the mud program, and proposals to use products not included in the mud program. => Whole Mud Losses to the Sterln9 Sands - Refer to fluid formulas and the Optibridge charts for maintaining proper bridging material concentration in the mud system while drilling the intermediate and production intervals. => FLUID LOSS CONTROL - In the intermediate interval the API fluid loss will be maintained in the 7 - 9 cc's range. In the production interval the API fluid will be maintained below 7 cc's at all times. In addition to sufficient fluid loss agent additions, this may require adequate dilution of the mud system in order to keep reactive drill solids to a minimum. => LSRV - When drilling with a FloPro fluid, the low shear rate rheology should be maintained at approximately 30,000 cps. In addition to adequate additions of FloVis Plus, this will also require keeping reactive drill solids to a minimum in order to reduce or eliminate false and unwanted high LSRV. => DRILL SOLIDS - MBT - The MBT should be kept at less than 7.5 ppb in the intermediate and production intervals through aggressive use of solids equipment and dilution as needed. => MIXING CONDITIONS - Whenever possible all treatments to the mud system should be made as pre-mix additions. Polymers and KCI should first be mixed in fresh water in that order and then blended into the active system over one or two circulations as needed. => CORROSION - Conqor 404 additions should be made daily when drilling with FloPro fluid in order to maintain a Conqor 404 concentration of +/- 2000 PPM. => CORRISION - Sodium Meta Bisulfate additions should be made daily as needed withanv fluid in the hole. Maintain a DO reading of less than 3 ppm => SOLIDS VAN USAGE - The Solids Van should be used whenever drill solids become un- acceptably high and reduction of drill solids in the mud can be more economically done with centrifuging and dilution then just with dumping and diluting. The weight of the drilling fluid alone should not be the determining condition for when to use the Solids Van. => WEIGHTING UP - All increases in mud weight should be accomplished with barite additions. In the production interval, insure chloride concentration is maintained at 30,000 to minimize the need for barite additions. ~ 81FE ~~ . . elÆ Marathon Oil Company Well Name: West Fork #3 Location: Kenai, Alaska. Interval Summary -12-1/4" hole ·i "Oi....ZZOO' Drilling Fluid System GellGelex Spud Mud Key Products MI Gel / Gelex / Soda Ash / Caustic Soda / MI Bar / PolyPac Supreme UL Solids Control Shale Shakers 1 Desilter / Centrifuge Van Recommended shaker screens - 150 - 180 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions r....terVa.I.Î)..iJIÎng..Fluid Properties ..... ... Depth Mud Funnel Yield API Drill Interval Weight Viscosity Point Fluid Loss pH Solids (ft) (ppg) (sec.lqt) (lb.llOOft2) (mI/30min) (%) 0 - 2200' 8.6 - 9.4 60 - 100 25 - 35 NC - 12 +1- 9.5 < 7% ~ Treat drill water with Soda Ash to reduce hardness. ~ Build spud mud with 20 - 25 PPB M-I Gel to +/- 100 seconds/quart funnel viscosity. ~ Lower funnel viscosity to +/- 75 after any gravel zones have been drilled. ~ Add Gelex as needed to maintain sufficient viscosity for hole cleaning. ~ Increase funnel viscosity if fill on connections begins to occur. ~ Reduce fluid loss with additions of Polypac Supreme UL prior to running surface casing. ~ Add Sodium Meta Bisulfate to maintain a DO of < 3 PPM. ~ Condition mud prior to cementing casing to reduce yield point and gel strengths. ~ Estimated volume usage for interval - 1683 barrels. ~ Estimated haul off volume - 2565 barrels. ~ ..FE ~~ . . elÆ Marathon Oil Company Well Name: West Fork #3 Location: Kenai, Alaska. Interval Summary - 8-1/2" hole !!UU ~ ·7463' ............ Drilling Fluid System Flo-ProFluid Key Products Flo- Vis / PolyPac Supreme UL / KCl/ SafeCarb F & M 1 MI Bar 1 Caustic Soda 1 Conqor 404 / Sodium Meta Bisulfate / lLubetex Solids Control Shale Shakers / Desilter / Centrifuge Van Recommended shaker screens - 210 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions lfûtêrvalDl'illiøgFluid Properties Depth Mud Plastic LSRV API Drill Interval Weight Viscosity 1 min Fluid Loss MBT Solids (ft) (ppg) ( cp.) ( cps ) (ml/30min) (%) 2200 - 7463' 9.0- < 9.5 8 - 12 30,000+ 7 - 9 < 7.5 +/- 5% ~ Use one rig pit to drill out surface casing. In other rig pits, build new Flo-Pro fluid using the enclosed fluid formula. ~ After drilling out surface casing, displace hole to Flo-Pro fluid prior to running leak off test ~ Ifrunning coals become a problem, treat with a 2 PPB addition of Asphasol D. ~ If torque or sliding problems occur, add 1 - 3% Lubetex. ~ Estimated volume usage for interval - 2039 barrels. ~ Estimated haul off volume - 2955 barrels. ~ Condition mud prior to running 7" casing. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. ~ _.FE œr~ . . eFE Marathon Oil Company Well Name: West Fork #3 Location: Kenai, Alaska. Fluid Formula - 8-1/2" Interval 8-1/2" Interval from 2200 - 7463' Inout Des(¡nþt!øl'l West Fork #3 MudWeíaht 9.0 +/- PrehvdratødGel No We¡ahtMatøri¡¡IC()(Je MI Bar PrehvdratedGel·Cónç. ~e¡i1htMåtønärSG 4.2 KCI Wt% 6 Outout . 1 bbl Otder.øfl Products CQI'Icentration Volume ... .A.ddition r Fielci.lb Lab am Fielci.·Þbl ."".........1 ..... uSåÐé··./ . 1 Water 298.70 298.70 0.853 298.70 2 Soda .A.sh 0.25 0.25 0.000 0.10 Reduce Hardness 3 Flovis 2.00 2.00 0.004 1.33 Viscositv 4 Polvpac Supreme UL 2.00 2.00 0.004 1.25 Fluid Loss Control 5 Caustic Soda 0.50 0.50 0.001 0.23 pH Control 6 Potassium Chloride 19.07 19.07 0.023 7.98 Inhibition 7 CONQOR 404 2.00 2.00 0.004 1.43 Corrosion Control 8a SafeCarb F 10.00 10.00 0.010 3.60 Bridaina Aaent 8b SafeCarb M 10.00 10.00 0.010 3.60 Bridaina Aaent 9 Sodium Meta Bisulfate 0.04 0.04 0.001 0.04 Oxvaen Scavenaer If bit ballina becomes a problem, add the following: 10 D-D CWT 1.00 1.00 0.003 1.00 Reduce BHA Balling If toraue becomes a Droblem, or slidina is difficult, add UDto 5% of the followina: 11 Lubetex 14.00 14.00 0.041 14.43 Lubricitv Total 399 399 1.000 350 pälcl.flatødM...c:lWelght 9.05 Estimated \folum.a..aø. 2039 Barrels Total ChlOride 29600 ~ ..FE ~~ MI © 1999 - 2004 M-Il.l.C. - AU RiSht. Reserved 1.0 0.9 0.8 c: 0 :¡::; 0.1 :;, .Q .¡: - IJI a 0.6 aJo N ü} aJo 0.5 U :e (II 11- (! 11.4 :0- ¡ :; 11.3 E :;, 0 0.2 0.1 ~)(1 0.2 Particle Size (microns) Marathon Oil Company Well Name: West Fork #3 Location: Kenai, Alaska. Max Permeability : Sand Control Device: 400 mDarcy 010 Targets Blend: 0.8 050 Target / Blend: 20.0 000 Target / Blend: 64.8 1.5 microns 16.5 microns 135.4 microns Brand Name B"Safe-Carb 1 0 IF) C"Safe-Carb 40 1M) E=Safe-Carb 250 IC) Bridging Agent(lblbblj 9.9 10.1 0.0 ~ 49.26 50.74 0.00 B 49.3% Calcium Carbonate added: Avg Error 0 ·100 % CPS Range: Max Error 0 -100 % CPS Range: 20 Ib/ÞÞi 3.43 % 17.08 )ô> Zone of interest - Sterling sands ~ Pore Pressure - 5.0 - Maximum Porosity - 400 mD ~ True Vertical Depth - +1- 5000' ~ Build additional volume as needed usine: the blend Ustedabove. . . faR Marathon Oil Company Well Name: West Fork #3 Location: Kenai, Alaska. Interval Summary - 6-1/8" hole >v 7463··...:1.0605' .. .>. Drilling Fluid System Flo-ProFluid Key Products Flo- Vis / DualFlo / KCl / SafeCarb F & M/ MI Bar 1 Caustic Soda / Conqor 404 / Sodium Meta Bisulfate / Greencide 25 G Solids Control Shale Shakers / Desilter / Centrifuge Van Recommended shaker screens - 210 - 230 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions ... ~ntervatÐrining Fluid Properties ..>. Depth Mud Plastic LSRV API Drill Interval Weight Viscosity 1 min Fluid Loss MBT Solids (ft) (ppg) (cp.) (cps) (mIl30min) (%) 7463 - 10605' 9.0 - < 9.5 10- 14 30,000+ <7 < 7.5 +/- 5% ~ Use one rig pit to drill out intermediate casing. In other rig pits, build new Flo-Pro fluid using the enclosed fluid formula. ~ After drilling out 7" casing, displace hole to Flo-Pro fluid prior to running leak off test ~ Ifrunning coals become a problem, treat with a 2 PPB addition of Asphasol D. ~ Estimated volume usage for interval- 1139 barrels. ~ Estimated haul off volume - 1856 barrels. ~ Condition mud prior to running 4-112" casing. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. r:zj ..FE ~~ . . eFE Marathon Oil Company Well Name: West Fork #3 Location: Kenai, Alaska. Fluid Formula - 6-1/8" Interval 6-1/8" Interval from 7463 - 10605' InDut Des ¢ripijpn West Fork #3 Mu dWéiaht 9.0 +1- Prehvdrated èel No We r htMåteriaFCc>dè SafeCarb Prehvdrated Gel Cone. I$G. 2.8 KCI Chloride Price . 0.35 KCI Wt% 6 No KCI Price 0.2516 No NaCIChloride l!J8I ..... NaCI Wt% GelPriœ NaCI Price OutDut . 1 bbl Ore! erof ProduCts Concentration Valum.e Add itiao Field,lb Lab. am Field, bbl Låb'rll Usaåé 1 Water 325.19 325.19 0.929 325.19 2 Soda Ash 0.25 0.25 0.000 0.10 Reduce Hardness 3 FloVis Plus 1.50 1.50 0.040 1.00 Viscositv 4 DualFlo 4.00 4.00 0.080 2.68 Fluid Loss Control 5a SafeCarb Fine 10.00 10.00 0.010 3.60 Bridaina Aaent 5b SafeCarb Medium 10.00 10.00 0.010 3.60 Bridaina Aaent 6 Potassium Chloride 20.76 20.76 0.025 8.68 Inhibition 7 Greencide 25G 0.25 0.25 0.001 0.30 Biocide 8 CONQOR 404 2.00 2.00 0.004 1.43 Corrosion Control 9 Caustic Soda 0.50 0.50 0.001 0.23 oH Control 10 Sodium Meta Bisulfate 0.04 0.04 0.001 0.04 Oxvaen Scavenaer If Bit balling becomes a problem, add the followina 11 D-D I 4.00 I 4.00 I 0.011 4.00 Reduce BHA Ballina If sliding or hiah toraue becomes a Droblem add 1 . 3% of the followina 12 Lubetex I 7.00 I 7.00 I 0.021 7.00 Lubricitv If sloughing coals become a Droblem add 2 . 4 DDb of the followina 13 Asphasol Supreme I 2.00 I 2.00 I 0.004 1.33 Well bore Stabilitv Mix fluid in the order listed above. Wait for 1 - 2 circulations before adding Sodium Meta Bisulfate to the system. Alternate additions of Greencide 25G and Sodium Meta Bisulfate as needed. Maintain 4+ ppb concentration of DualFlo to maintain as Iowa API fluid loss as possible. Plan on daily additions of DualFlo to achieve 6.0 - 7.0 cc's API Fluid Loss Reduce concentration of FloVis as needed to maintain rheoloav. Total I 380.1 380.1 EstlînåtedVoIÜÎÞe.U$ââêl 1139 Barrels Calculated MudiWèiaht 9.050 TotalChloridè 29600 ~ .FE ~~ Marathon Oil Company Wen Name: West Fork #3 Location: Kenai, Alaska. - Corrosion Control Additive in Casing x Tubing Annulus Well West Fork #3 Volumes: Tubing Volume 4-1/2" Tubing barrels Annular Volume Casing x Tubing barrels Open Hole x Tbg barrels Total Annular Volume Tubing Volume Total Hole Volume 191.52 164.24 355.76 x 6.276 @ 7463 ft MD 10605 ft MD Treatment Procedures. 1. After the 4-1/2" tubing is run and the drilling fluid is circulated and conditioned for the cement job, circulate an additional 140 barrels of drilling fluid. 2. Add 2 drums of Conqor 303A and 2 sacks Sodium Meta Bisulfate to this 140 barrels. 3. After the 140 barrels of drilling fluid with Conqor 303A and Sodium Meta Bisulfatehave been pumped downhole, begin the cement job. 4. This rocedure will lace corrosion control in the 4-1/2" x 1" annulus. . . eFE Marathon Oil Company Well Name: West Fork #3 Location: Kenai, Alaska. HSE Issues HANDLING OF DRilLING FLUID PRODUCTS HEALTH AND SAFETY 1. Drilling crews should be instructed in the proper procedures for handling fluid products. 2. Personal Protective Equipment (PPE) charts should be posted in the pit room, the mud lab, and the office of the Drilling Forman. 3. PPE must be in good working order and be utilized as recommended by the PPE charts. 4. Product additions should be made with the intent to use complete unit amounts of products (sacks, drums, cans) as much as possible in order to minimize inventory of partial units. 5. Insure all MSDS sheets are up to date and readily available for workers to access for information. ENVIRONMENTAL 1. Insure that all product stored outside is protected from the weather. 2. Do not store partial units (sacks, etc) outside if possible. 3. Properly secure all products for shipment between job sites. 4. When transferring fluid and or cuttings from the rig to trucks, insure all hoses are properly secured. 5. When utilizing the centrifuge solids van, insure all hoses and connections between the van and the rig are secure. ~ ..FE rmr:~ Marathon Oil Company Wen Name: West Fork #3 Location: Kenai, Alaska. Product Function M-I BAR Weighting Agent M-I GEL Viscosity control GELEX Bentonite Extender FlOVIS Viscosifier DUAL-FLO Modified Starch POlYPAC Fluid Loss Reducer XCD Viscosifyer HEC Loss Circulation Materia Safe-Carb F,M,C Bridging and weighting agent LO WA TE Weighting agent Nut Plug Loss Circulation Materia M-I Seal F, M, C Loss circulation Material Mix II F,M,C Loss circulation Material DESCO CF Dispersant SPERSENE CF Dispersant TANNATHIN Dispersant E VENTROl 401 Surfactant ? SAl T {Solar} Densifier BROMIDE (NaBr) & Densifier Brine Solution POTASSIUM Shale Inhibitor CHLORIDE - Marathon Oil Company Well Name: West Fork #3 Location: Kenai, Alaska. Product Function CAUSTIC SODA CAUSTIC POTASH BORAX SAPP SODA ASH IUM RBONATE CITRIC ACID BAN BP-PlUS EEN CIDE 25G - DEFOAM X - G-SEAl KlA-GARD e Control agent ETEX Detergent Corrosion Inhibitor AFEKlEEN Drilling fluid additive Shale Inhibitor Shale Inhibitor odium Meta Oxygen Scavenger Bisulfate . . eFE Marathon Oil Company Well Name: West Fork #3 Location: Kenai, Alaska. Product Health and Safety Reference HMIS HAZARD RATINGS HAZARDOUS MATERIALS IDENTIFICATION SYSTEM (HMIS) HAZARD RATINGS 4 - Severe hazard 3 - Serious hazard 2 - Moderate hazard 1 - Slight hazard o - Minimal hazard * An asterisk next to the health rating indicates that a chronic hazard is associated with the material. HMIS PERSONAL PROTECTIVE EQUIPMENT INDEX A - Safety Glasses B - Safety Glasses, Gloves C - Safety Glasses, Gloves, Synthetic Apron D - Face Shield, Gloves, Synthetic Apron E - Safety Glasses, Gloves, Dust Respirator F - Safety Glasses, Gloves, Synthetic Apron, Dust Respirator G - Safety Glasses, Gloves, Vapor Respirator H - Splash Goggles, Gloves, Synthetic Apron, Vapor Respirator I - Safety Glasses, Gloves, Dust and Vapor Respirator J - Splash Goggles, Gloves, Synthetic Apron, Dust and Vapor Respirator K - Air Line Hood or Mask, Gloves, Full Suit, Boots X - Consult your supervisor for special handling directions r:zj .FE ~~ . . elÆ Marathon Oil Company Well Name: West Fork #3 Location: Kenai, Alaska. Contacts Contact Title e-mail Work Cellular Pete Berga Drilling pkberga@marathonoil.com 907 564-6319 907 231-0663 Marathon Superintendent Will Tank Drilling Engineer wjtank@marathonoil.com 713 296-3277 713 203-8398 Marathon Don Eynon Completion Engineer deeynon@marathonoil.com 907283-1337 907 398-9954 Marathon Tony Tykalsky Project Engineer ttykalsky@miswaco.com 907 274-5011 907 227-2412 MISWACO Gus Wik Warehouse Manager gwik@miswaco.com 907 776-8722 907776-8680 MISWACO Michael Barry Senior Field gratefulmeb.@hotmail.com 907 260-4666 907 590-3636 MISWACO Engineer (home) Locke Rooney Field Engineer rooneyl@alaska.net 907 235-0598 907 590-3636 MISWACO (home) Gene Anderson Drilling Foreman 907283-1312 Marathon Roland Lawson Drilling Foreman 907283-1312 Marathon Larry Meyers Drilling Foreman 907 283-1312 Marathon Dave Morris Drilling Foreman 907283-1312 Marathon . MI Project Engineer and Tech Service Engineer will coordinate between the Marathon office, rig, warehouse, and the M-I field engineers. . Well progress will be monitored to look for any changes, which will improve the efficiency of the operation or avert trouble. ~ .FE m!'~ . . Worldwide Drilling North America Marathon Oil Company P.O. Box 3128 Houston, TX 77253-3128 Telephone 713-629-6600 Fax 713-499-6737 August12,2004 John Norman Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Ave, Suite 100 Anchorage, AK 99501 Reference: Drilling Permit Application Field: West Fork Well: West Fork #3 Dear Mr. Norman Enclosed please find the PERMIT TO DRILL application, along with the associated attachments and filing fee of $100. The intent is to drill a Tyonek exploitation well. If you require further information, I can be reached at 713-296-3273 or bye-mail at wjtank@ marathonoil.com. Sincerely, )11~>~ Willard J. Tank Advanced Senior Drilling Engineer Enclosures OR\G\NAL Marathon Oil Company P. o. Box3128 Houston, TX 77253 ~~'¿'¿~~~~~Ä~ÄBLE DEPARTMENT Accts Payable Contact Center Phone: 918-925-6097 Hndlg HS Illi1nnn l1 ::¡. ? c:; ::¡.nllg .=n L J. fin ~B iii 51: 0 JoB :U.B L.IIB . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRlA TE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ø~~i ¡¡, 3 PTD# ?ðY'-/;b ~ ,/ Exploration Stratigraphic Development Service CHECK WßA T ADD-ONS ~'CLVEn APPLIES (OPTIONS) MULTI Tbe permit is for a new weJlboresegment of LATERAL existing weD . Permit No, API No. . (If API number Production. sbould continue to be reported as last two (2) digits a function 'of tbe original API number stated are between 60-69) above. PILOT HOLE In accordance witb 20 AAC 25.005(1), all (PH) records, data and logs acquired for the pilot bole must be clearly differentiated In both name (name on permit plus PH) .. and API Dumber (SO - 70/80) from records, data and logs acquired for wen (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance with 20 AAC 25.055~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:x ception. (Company Name) assumes tbe liability of any protest to tbe spacing .exception tbat may occur. DRY DITCH AU dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from wbere samples are first caught and ) 0' sample hiter:vals tbrough target zones. .' . .. D D Well bore seg Annular Disposal Field & Pool W FORK, UNDEFINED GAS - 924500 Well Name: West Fork 03 Program DEV THON OIL CO Initial ClasslType DEV 11-GAS GeoArea Unit On/Off Shore -ºn - Administration P~rmit fee attacheø. - - - - - - - - - ........ Y~s. - - - - -- 2 Leas~.number .appropriate. . . . . Yes - - - - - - - - - - - - - 3 .U.nlque well.n.arn~.aod Ol!mb.er . . . . . . . . . . . . . . . . . . . ........ Y~s - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 4 WeJIJQcat~d in.a. d.efioed J ool . . . . . . .... No - - - - - - - - - - - - - - - - - - - - - - - - - 5 WeJIJQcat~d pr.oper .dlstaoce. from driJling ul1itb.oul1d.ary. . . . . Y~s The West ForK #3 well. wiIJ be. the Ürstg.as cQmpJe.tioo i.n .S~ctjoo 22, TfìN R9W. . 6 WellJQcat~d pr.oper .dlstaoce. from othe.r welJs Y~s West Fork.well$. within3~QOO .of the prOPQsed WF#3are. Sterlin.Q.Fm. produœrs, 7 .S.uffjcieotacreaQ.e.ayail¡;¡ble in.drillioQ. unjt . . . . . . . . . ... Y~s 8 Jf.deviated, js weJlbQre platiocJu.ded . - - - - - - ..... Y~s 9 OJ er.ator only affected party. . .... Y~s 10 .0J erator has.approprlate.l.lond lnJorce. . . . . . . . . . . . . . . ........ Y~s - - - - - - - - - - - - - - - - - - -- 11 P~rmit ~o be i.sSl!ed wjthQut ço.nservatioo order. . .. Y~s - - - - - - - - - Appr Date 12 Permit cao be lssl!ed wHhQut ad.mioistratilie.approvaJ . ........ Y~s RPC 8/16/2004 13 Can permit be approved before 15-day wait Yes 14 We.ll JQcated wlthin area and strata authorized by lojectiolJ Ord~r # (put 10# in.cor:nrneots). (for. .NA - - - - - - - - - - - - - - - - - 15 AJI w~lJs. witJ1i.n Jl4.mil.e.are.a.of reyieW ideotified (For servjc.e .well ooly). . . . . . . . . . . . . .NA - - - - - - - - - - - - - - - - - - - - 16 Pre.-produ~ed iojeçtor; øur.ation.of pre-J roductioo tes$. than. 3 months. (for.servi.ce well QnJy) .NA - - - - - - - - - - - - - - - - - 17 ACMPfindjng .of Con.si.steoçy.has bee.nj$.sued. for. this proiect NA Engineering 18 Coodu~tor stringprQvided . - - - - - - - - Y~s 2Q" @ 1QO~.. . . . . . . 19 .Surfaœ .casing. p.rotect$. alLknown USDWs . - - - - - - Y~s 20 CMT vol adeQl!ate. to circ.utateoncooductor. & su.rf csg . Y~s Ade~uate excess, . 21 .CMT v.ol adeQu.ate. to tie-lnJQng .striog to.surf çsg. . - - - - - - - - No. - - - - - - - -- - - - - - - 22 CMTwilJ coyer.aJl klJown-Pfo.ductiye hQrizon.s. Yes 23 .C.asiog de.sigos ad.equate. for C,.T~ B.&permafrDst . Y~s - - - - - - - - 24 Adequ.ate.tanJ<age.o.r re.serve pit. . - - - - - - - - - - - .Y~s 25 Jf.a.re-drilL has.a 10:403 fQr abandonment be~1J app.rQved . . . NA New well, . . . . . . . . . . . . . . 26 .Adequ.ate.weJlbore.separatjo.n.proJ osed. . . . . . . . . . . . . . . . . . . Y~s . - - - - - - - - - - - - - - - - - -- 27 Jfdjver:ter .req.uired, dQes it meet reguJatioos. Y~s Appr Date 28 D.rillilJg fluid. program schematic.& eq.uipJistadequate. Y~s Max MW9,5 ppgc WGA 8/17/2004 .29 BOPEs,d.o.they meetreguJatioo . .Y~s - - - - - - - - - - - - - - - - - - - 130 BOPEpres$ ratiog appropriate;.test to.(pu.t psig in.commeots). . . . .Y~s Test to .3000 RstMSf> 2630 psi. 31 Cholçemanifold cQmpJie$. w/APtRf>-53 (May 64). Y~s 132 WQrlç will occ.ur withoutoperation .shutdow.n. . . . Y~s 133 Js pre$.eoçe. Qf H2S gas. prob.able - - - - - - - - - - - - - - - - - - No. I 134 Meçha.nicç¡l.coodJtjooof wells withio ,t\OR yerified (For.s.ervice welJ only) NA ---l ----,---.----.-.' .-- Geology 35 Permit cao be lssu.ed wfo hydrogen sulfide measures. .Yes 36 .D.atap.reselJted on. Rote.ntial ove.rpre~sure .zooes. - - - - - - - - - - .NA Appr Date 37 .S~i.srn¡c.analysjs Qf shaJlow 9as.zooes. . . . . . . . NA RPC 8/16/2004138 .S~abedcoodjtjolJ Sl!rvey(if off-shore) . . . . . . . . . . . . . . . . . . .NA 39 . CQnta.ct oam.elpJ1oneJor.weelçly progre~sreRorts [explorç¡tory .0olYl NA - Geologic Date: Engineering Date Commissioner: Commissioner: J)7S~ f'//¡j//1 {
